dự án lọc dầu Nghi Sơn

Ho Chi Minh CityJune 2010

NGHI SON REFINERY AND PETROCHEMICAL LIMITED NGHI SON REFINERY AND PETROCHEMICAL LIMITED LIABILITY COMPANYLIABILITY COMPANY

REPORTREPORT

ENVIRONMENTAL IMPACT ASSESSMENT ENVIRONMENTAL IMPACT ASSESSMENT FOR NGHI SON REFINERY AND PETROCHEMICAL FOR NGHI SON REFINERY AND PETROCHEMICAL

COMPLEX PROJECTCOMPLEX PROJECT(This report is revised and supplemented as (This report is revised and supplemented as MONREMONRE’’ss appraisal appraisal

committee on May 27committee on May 27thth 2010)2010)

Ho Chi Minh CityJune 2010

NGHI SON REFINERY AND PETROCHEMICAL LIMITED NGHI SON REFINERY AND PETROCHEMICAL LIMITED LIABILITY COMPANYLIABILITY COMPANY

Project owner:

NGHI SON REFINERY AND PETROCHEMICAL LIMITED LIABILITY COMPANY (NSRP-LLC)

Consultant organization:

BRANCH OF VIETNAM PETROLEUM INSTITUTE (HANOI CITY) RESEACH AND DEVELOPMENT CENTER FOR

PETROLEUM SAFETY AND ENVIRONMENT

REPORTREPORT

ENVIRONMENTAL IMPACT ASSESSMENT ENVIRONMENTAL IMPACT ASSESSMENT FOR NGHI SON REFINERY AND PETROCHEMICAL FOR NGHI SON REFINERY AND PETROCHEMICAL

COMPLEX PROJECTCOMPLEX PROJECT(This report is revised and supplemented as (This report is revised and supplemented as MONREMONRE’’ss appraisal appraisal

committee on May 27committee on May 27thth 2010)2010)

CONTENTS Page

0. INTRODUCTION 0-1

0.1 PROJECT BACKGROUND 0-1

0.2 LEGAL AND TECHNICAL BASIS OF EIA PREPARATION 0-4

0.2.1 Scope of the EIA report 0-4 0.2.2 International Regulations 0-5 0.2.3 Vietnamese Laws and Standards 0-6

0.2.3.1 Vietnamese Law and Legislation 0-6 0.2.3.2 Environmental Standards 0-10 0.2.3.3 Project Standards 0-12

0.2.3 Technical basis and related documents 0-22

0.3 METHODOLOGY FOR EIA IMPLEMENTATION 0-23

0.4 EIA IMPLEMENTATION ORGANIZATION 0-24

1. PROJECT DESCRIPTION 1-1

1.1 PROJECT NAME 1-1

1.2 PROJECT OWNER 1-1

1.3 GEOGRAPHICAL LOCATION 1-1

1.3.1 Plant location 1-4 1.3.2 Onshore Pipeline System 1-4 1.3.3 Harbour Location 1-5 1.3.4 SPM Location 1-6 1.3.5 Crude Oil Pipeline Location 1-6 1.4 MAIN CONTENTS OF NSRP PROJECT 1-6

1.4.1 Refinery and petrochemical capacity 1-9

1.4.1.1 Material Balance 1-9 1.4.1.2 Designed Capacities for Process Units 1-10

1.4.2 Feedstock and products 1-13

1.4.2.1 Feedstock 1-13 1.4.2.2 Project Products 1-14

1.4.3 Technology process 1-15

1.4.3.1 Refinery Process Units 1-15 1.4.3.1.1 Crude Distillation Unit (CDU) 1-15 1.4.3.1.2 LPG Recovery Unit (LRU) 1-17 1.4.3.1.3 Saturated LPG Treater Unit (LTU) 1-17 1.4.3.1.4 Kerosene Hydrodesulphuriser Unit (KHDS) 1-17 1.4.3.1.5 Gas Oil Hydrodesulphuriser (GOHDS) 1-18 1.4.3.1.6 Residue Hydrodesulphuriser Unit (RHDS) 1-18 1.4.3.1.7 Residue Fluid Catalytic Cracker Unit (RFCC) 1-18 1.4.3.1.8 RFCC LPG Treater 1-19 1.4.3.1.9 RFCC light Naphtha Treater 1-19 1.4.3.1.10 Propylene Recovery Unit (PRU) 1-19 1.4.3.1.11 Indirect Alkylation Units (InAlk) 1-20 1.4.3.1.12 Hydrogen Manufacturing Unit (HMU) 1-20 1.4.3.1.13 Hydrogen Compression and Distribution system (HCDS) 1-20 1.4.3.1.14 Sour Water Stripper unit (SWS) 1-21 1.4.3.1.15 Amine Regeneration Unit (ARU) 1-22 1.4.3.1.16 Sulphur Recovery Unit (SRU) and Tail Gas Treating Unit (TGTU) 1-23

i

1.4.3.2 Petrochemical Process Units 1-25 1.4.3.2.1 Naphtha and Aromatics Complex (NAC) 1-25 1.4.3.2.2 Polypropylene Unit 1-26

1.4.4 Plant utilities 1-26

1.4.4.1 Crude Oil Storage Tanks 1-26 1.4.4.2 Product Tankage Farm 1-27

1.4.4.2.1 Product storage tank 1-27 1.4.4.2.2 Product blending component storage tanks 1-27 1.4.4.2.3 Intermediate Storage tanks 1-28

1.4.4.3 Other Receiving and Storage 1-28 1.4.4.3.1 Catalyst and chemical storage 1-28 1.4.4.3.2 Slop storage tanks 1-28 1.4.4.3.3 Sulphur forming and storage unit (SFSU) 1-29

1.4.4.4 Gas Recovery System 1-29 1.4.4.5 Fuel System 1-29 1.4.4.6 Flushing Oil System 1-31 1.4.4.7 Waste oil recovery, storage and pump systems 1-31 1.4.4.8 Power and Steam Generation System 1-31 1.4.4.9 Nitrogen Supply System 1-32 1.4.4.10 Water Supply System 1-33 1.4.4.11 Intake system 1-33

1.4.4.11.1 Structure 1-33 1.4.4.11.2 Cooling Water 1-34

1.4.4.12 Chemicals, Catalysts, and Packing 1-35 1.4.4.13 Flare System 1-36 1.4.4.14 Fire and Gas Detection and Protection System 1-39 1.4.4.15 Waste treatment system 1-39

1.4.4.15.1 Off gas treatment system 1-39 1.4.4.15.2 Effluent Treatment Plant 1-39 1.4.4.15.3 Incinerator 1-41 1.4.4.15.4 Waste storage area 1-41

1.4.4.16 List of main equipments of the Refinery 1-41 1.4.5 Offsite facilities 1-41

1.4.5.1 Marine Facilities 1-41 1.4.5.1.1 Access channel 1-43 1.4.5.1.2 Turning basin 1-43 1.4.5.1.3 North breakwater 1-44 1.4.5.1.4 Harbour revetments 1-44 1.4.5.1.5 Berth pockets 1-44

1.4.5.2 Single Point Mooring (SPM) 1-45 1.4.5.3 Crude oil pipeline 1-46 1.4.5.4 Product Pipeline 1-46 1.4.5.5 Ship Loading System 1-47 1.4.5.6 Product Truck Loading System 1-47

1.4.6 Refinery layout 1-48

1.4.7 Project construction 1-50

1.4.7.1 Onshore Constructions 1-50 1.4.7.2 Offshore Construction 1-52 1.4.7.3 Supply source of constructional materials 1-54 1.4.7.4 Accommodation Facilities for Construction and Operation Workers 1-54

1.4.8 Construction schedule 1-55

1.4.9 Total capital and estimated cost for environmental treatment and monitoring facilities 1-55

ii

2. NATURAL ENVIRONMENT AND SOCIO-ECONOMIC CONDITION 2-1

2.1 NATURAL ENVIRONMENT CONDITION 2-1

2.1.1 Offshore 2-1

2.1.1.1 Marine Topography and Geology 2-1 2.1.1.2 Bathymetric condition 2-3 2.1.1.3 Extreme climatic conditions 2-8 2.1.1.4 Existing Natural Environment 2-11 2.1.1.5 Marine Resources 2-29

2.1.2 Onshore environmental baseline 2-36

2.1.2.1 Topographic, geological and seismic conditions 2-36 2.1.2.2 Meteorological conditions 2-42 2.1.2.3 Water Resources 2-48 2.1.2.4 River system and flooding situation in project area 2-50 2.1.2.5 Existing Environmental Conditions of Onshore and Coastal Area 2-50

2.1.2.5.1 Air quality 2-50 2.1.2.5.2 Water quality 2-55 2.1.2.5.3 Groundwater quality 2-60 2.1.2.5.4 Sediment Quality 2-63 2.1.2.4.5 Soil quality 2-68 2.1.2.5.6 Biological Ecosystem 2-69

2.1.3 Preliminary assessment on environmental loading capacity 2-94

2.1.3.1 Assessment on Environmental Sensitivity of the Project Area 2-94 2.1.3.2 Preliminary Assessment on Environmental Loading Capacity 2-96

2.2 EXISTING SOCIAL CONDITIONS 2-97

2.2.1 Economic Condition 2-97

2.2.1.1 Agriculture 2-97 2.2.1.2 Industry 2-97 2.2.1.3 Forestry 2-99 2.2.1.4 Aquaculture and Fisheries 2-101 2.2.1.5 Salt industry 2-102 2.2.1.6 Tourist 2-102

2.2.2 Social Condition 2-102

2.2.2.1 Population 2-102 2.2.2.2 Transportation and Infrastructure 2-103 2.2.2.3 Power system 2-106 2.2.2.4 Telecommunications 2-106 2.2.2.5 Land use status in NSEZ 2-107 2.2.2.6 Affected area 2-109 2.2.2.7 Affected graves 2-109 2.2.2.8 Existing Potable Water Drainage and System 2-109 2.2.2.9 Drainage system and waste water treatment plant in NSEZ 2-112 2.2.2.10 Solid waste collection and treatment system in NSEZ 2-114 2.2.2.11 Culture, Health and Education 2-114 2.2.2.12 Cultural Resources and Archaeology 2-115

3. ENVIRONMENTAL IMPACT ASSESSMENT 3-1

3.1 SOURCE OF IMPACT TO THE ENVIRONMENT 3-2

3.1.1 Impact Source Relating to Wastes 3-2

3.1.1.1 In construction phase 3-2 3.1.1.2 Source of impact in operation phase 3-6

iii

3.1.1.2.1 Emission gas 3-6 3.1.1.2.2 Wastewater 3-9 3.1.1.2.3 Solid waste 3-10 3.1.1.2.4 Accidental impact sources 3-11

3.1.2 Impact source not related to wastes 3-11

3.2 IMPACTED OBJECTS 3-13

3.2.1 Construction, installation and commissioning phase 3-13

3.2.1.1 Environmental impacts for construction of onshore facilities (refinery and supported facilities) 3-13 3.2.1.1.1 Air quality 3-14 3.2.1.1.2 Surface water 3-17 3.2.1.1.3 Groundwater 3-18 3.2.1.1.4 Soil environment 3-19 3.2.1.1.5 Biological environment 3-20

3.2.1.2 Offshore Construction (Harbor, Breakwater, Pipeline and SPM) 3-21 3.2.1.2.1 Air environment 3-21 3.2.1.2.2 Surface water 3-25 3.2.1.2.3 Land and Terrestrial Ecology 3-35 3.2.1.2.4 Marine ecosystem 3-36

3.2.2 Operation phase 3-37

3.2.2.1 Operation of Onshore Facilities (the Plant and support facilities) 3-37 3.2.2.1.1 Air environment 3-37 3.2.2.1.2 Water Quality 3-49 3.2.2.1.3 Groundwater environment 3-60 3.2.2.1.4 Soil environment 3-61 3.2.2.1.5 Marine ecosystem 3-62

3.2.2.2 Operation of the offsite facilities (harbor, breakwater, crude pipeline and SPM) 3-64 3.2.2.2.1 Air environment 3-64 3.2.2.2.2 Water environment 3-65 3.2.2.2.3 Soil and groundwater environment 3-75 3.2.2.2.4 Marine Environment 3-75

3.2.3 Cumulative impact during operation phase of onshore and offshore constructions on other projects in the local area 3-76

3.2.4 Socio-economic impact assessment 3-78

3.2.4.1 Impacts caused by land acquisition 3-78 3.2.4.2 Impact caused by graves relocation 3-79 3.2.4.3 Impact caused by compensation and resettlement 3-80 3.2.4.4 Impact on training and recruitment plan of NSEZ 3-87 3.2.4.5 Land and natural resources 3-90 3.2.4.6 Loss of agricultural lands to other uses 3-91 3.2.4.7 Loss of forestry land 3-92 3.2.4.8 Loss of residential land 3-92 3.2.4.9 Livelihood activities 3-93 3.2.4.10 Education 3-93 3.2.4.11 Disruption/Damage to Infrastructure and Services 3-94 3.2.4.12 Gender 3-94 3.2.4.13 Indirect employment and local procurement opportunities 3-95 3.2.4.14 Fisheries 3-96 3.2.4.15 Access restrictions and diversions 3-97 3.2.4.16 Impact on health 3-98 3.2.4.17 Impact on poverty 3-99 3.2.4.18 Economic activities 3-99 3.2.4.19 Infrastructure and Service 3-100

3.2.5 Potential environmental accidents caused by project implementation 3-101

iv

3.2.5.1 Fire and Explosion 3-101 3.2.5.2 Toxic gas leakage 3-103 3.2.5.3 Hydrocarbon Spills 3-104 3.2.5.4 Ship Collision 3-107 3.2.5.5 Pipeline Rupture or Leakage 3-107 3.2.5.6 Radioactivity 3-108

3.3 EVALUATION OF DETAILED AND CONFIDENCE LEVEL OF THE ASSESSMENT 3-108

3.3.1 Determination of impact significance 3-108

3.3.2 Assessment method 3-109

4. MITIGATION MEASURES FOR NEGATIVE IMPACTS, PREVENTION & RESPONSE ENVIRONMENTAL INCIDENTS 4-1

4.1 MITIGATION MEASURES IN FEED DESIGN PHASE 4-1

4.2 MITIGATION MEASURES FOR ONSHORE FACILITIES (REFINERY AND PETROCHEMICAL COMPLEX AND SUPPORTED FACILITIES) 4-2

4.2.1 Construction Phase 4-2

4.2.1.1 Air Quality 4-2 4.2.1.2 Noise and vibration 4-3 4.2.1.3 Soil quality 4-4 4.2.1.4 Surface water 4-10 4.2.1.5 Groundwater 4-11 4.2.1.6 Ecosystem 4-11 4.2.1.7 Safety for the workers 4-13 4.2.1.8 Water way and road traffic 4-14 4.2.1.9 Mitigation measures for natural calamity 4-14

4.2.2 Operation Phase 4-15

4.2.2.1 Air Quality 4-15 4.2.2.2 Noise control 4-20 4.2.2.3 Water quality 4-20 4.2.2.4 Groundwater 4-26 4.2.2.5 Soil quality 4-26 4.2.2.6 Marine ecosystem 4-33 4.2.2.7 Road traffic 4-33

4.3 MITIGATION MEASURES FOR OFFSITE FACILITIES (HARBOUR, BREAKWATER,

CRUDE PIPELINE AND SPM) 4-34


4.3.1.1 Air Quality 4-34 4.3.1.2 Noise and Vibration 4-34 4.3.1.3 Soil Environment 4-35 4.3.1.4 Water environment 4-35 4.3.1.5 Biological environment 4-36


4.3.2.1 Air quality 4-37 4.3.2.2 Noise and Vibration 4-38 4.3.2.3 Soil environment 4-38 4.3.2.4 Water Resources 4-38 4.3.2.5 Onshore biological environment 4-42 4.3.2.6 Ecosystem 4-42

4.4 MITIGATION MEASURES FOR ACCIDENTS AND ABNORMAL EVENTS 4-43

4.4.1 Fire and Explosions 4-43

v

4.4.2 Toxic Gas Release 4-43 4.4.3 Shipping collision 4-44 4.4.4 Emergency Response Planning for oil spills 4-44 4.5 MITIGATION MEASURES FOR SOCIAL COMMUNITY IMPACTS 4-46

4.5.1 Pre-construction phase 4-46 4.5.2 Construction Phase 4-48 4.5.3 Operation Phase 4-48

5. ENVIRONMENTAL MANAGEMENT AND MONITORING PROGRAM 5-1

5.1 OBJECTIVES 5-1

5.2 ENVIRONMENTAL MANAGEMENT PROGRAM 5-2


5.2.1.1 Air Quality Management Plan (Onshore and Offshore Facilities) 5-3 5.2.1.2 Noise Management Plan (Onshore and Offshore Facilities) 5-4 5.2.1.3 Soil Contamination Management Plan 5-4 5.2.1.4 Surface Water Management Plan (Onshore Facilities) 5-5 5.2.1.5 Surface Water Management Plan (Offshore Facilities) 5-7 5.2.1.6 Groundwater Management Plan 5-8 5.2.1.7 Terrestrial Flora Management Plan 5-8 5.2.1.8 Waste Management Plan 5-9 5.2.1.9 Employment and Training Management Plan 5-10 5.2.1.10 Health and Safety Management Plan 5-11 5.2.1.11 Social Impact Management Plan 5-12 5.2.1.12 Capital expenditure for constructing main treatment and monitoring works 5-14


5.2.2.1 Air Quality Management Plan 5-15 5.2.2.2 Noise Management Plan 5-16 5.2.2.3 Soil Contamination Management Plan 5-16 5.2.2.4 Surface Water Management Plan (Onshore Facilities) 5-18 5.2.2.5 Surface Water Management Plan (Offshore Facilities) 5-19 5.2.2.6 Groundwater Management Plan 5-21 5.2.2.7 Marine Habitat Management Plan 5-21 5.2.2.8 Waste Management Plan 5-22 5.2.2.9 Social and Community Management Plan 5-24 5.2.2.10 Employment and Training Management Plan 5-24 5.2.2.11 Health and Safety Management Plan 5-25 5.2.2.12 Emergency response plan 5-25

5.3 PROJECT ENVIRONMENTAL MONITORING PLAN 5-26

5.3.1 Monitoring Program for the Discharge Sources 5-27

5.3.2 Monitoring Program for the Surrounding Environment 5-30

5.3.2.1 Pre-construction phase 5-30 5.3.2.2 Construction phase 5-34 5.3.2.3 Operation phase 5-35

5.3.3 Additional Environmental Monitoring Surveys 5-39

5.3.4 Proposed budget for environmental monitoring program 5-39

6. PUBLIC CONSULTATION 6-1

6.1 PUBLIC CONSULTATION AND DISCLOSURE 6-1

vi

vii

6.1.1 Regulations and Requirements 6-1 6.1.2 Public Consultation and Disclosure Program 6-1 6.2 PUBLIC CONSULTATION RESULTS 6-3

6.2.1 The First Consultation (4 & 5 November 2008) 6-3 6.2.2 The Second Consultation (27th & 28th January 2010) 6-4 6.3 OPINIONS OF LOCAL COMMUNAL PEOPLE COMMITTEE

AND FRONT FARTHERLAND COMMITTEE 6-6

6.3.1 Consultation with Mai Lam Commune 6-6 6.3.2 Consultation with Tinh Hai Commune 6-7 6.3.3 Consultation with Hai Yen Commune 6-8 6.4 FEEDBACK AND COMMITMENT OF PROJECT OWNER 6-9

6.4.1 Feedback from Project Owner 6-9 6.4.2 Commitment of the Project Owner 6-10

6.4.2.1 Social Issues 6-10 6.4.2.2 Environmental Issues 6-11

7. CONCLUSION, RECOMMENDATION AND COMMITMENT 7-1

7.1 CONCLUSION 7-1

7.2 RECOMMENDATION 7-4

7.3 COMMITMENT 7-4

ENVIRONMENTAL IMPACT ASSESSMENT Page 0-1 NGHI SON REFINERY AND PETROCHEMICAL COMPLEX Final Report

NSRP LLC - CPSE/SNC Lavalin June, 2010

Section 0 INTRODUCTION 0.1 PROJECT BACKGROUND As proposal in Pre-Feasibility Study Report (PFS), the second Refinery and Petrochemical Complex Project is selected in Nghi Sơn, Tinh Gia District, Thanh Hoa Province based on natural condition, infrastructure, products market, socio-economic activities and national security by comparison in four (04) best locations in the North to establish the second refinery, including:

1. Dinh Vu, Hai Phong Province 2. Nghi Son, Thanh Hoa Province 3. Vung Ang, Ha Tinh Province 4. Hon La, Quang Binh Province

The site selection was carried out from August 1998 to March 1999 by Inter-ministrial Working Group including the members from the Government Office, Ministry of Planning & Investment, Ministry of Construction, Ministry of Transportation, Ministry of Industry, Ministry of Science, Technology & Environment and Vietnam Oil and Gas Petroleum Cooperation – presently Vietnam Oil and Gas Group (PetroVietnam). The criteria for site selection were based on natural conditions, infrastructure, product market, socio-economic activities and national security. The most important reasons for the selection of the site can be summarized as follows:

Close to the key economic triangle of Hanoi-Hai Phong-Quang Ninh, northern Delta and former Zone IV.

Suitable natural condition: large area, high topography and Bien Son Island can be used as natural breakwater.

Available infrastructure system including transportation system, power supply, water supply and port

Suitable with strategic development orientation of PetroVietnam

Suitable with master social and economic plan development of the North Central Zone, Northern Zone and the nation.

Suitable with master plan development of the Nghi Son area. The Pre-FS Report was approved by the Vietnamese Prime Minister under Decision No.647/QD-TTg dated August 5, 2002 and according to this Decision, Nghi Son had formally been selected as the site for the Refinery and Petrochemical Complex No. 2. In 2003, Petrovietnam had carried out Detail Feasibility Study (DFS). However, since that time to 2007, there were many changes in marketing situation. The different of light and heavy oil price is insignificant, so the heavy oil processing have not brought much benefit than the light oil processing because of heavy oil processing uses complicated technology and needs much investment capital. Since 2004, crude price was sharply increased and broke out refinery investment that made investment capital was increased. And the consequence of project investment capital was increased accordingly.



Therefore, it is necessary to reconsider project feasibility to propose Vietnam Government to issue regime, priority policy for the project and re-optimize technological diagram based on DFS 2003 in order to increase economic efficiency as well as upgrade information and suitable economic data with existing marketing which is objective indispensable requirement. In 2007, PetroVietnam together with foreigner partners including Idemitsu Kosan Co., Ltd. (IKC), Mitsui Chemicals Inc (MCI) and the Kuwait Petroleum International (KPI) had signed project Joint Venture on 31st May 2007 (considered as initial landmark of cooperation) and studied to revise DFS and propose priority policy for project. The DFS has confirmed the project feasibility and economic efficiency if Vietnam Government approves these project proposed priorities. On 22 January 2008, Vietnam Prime Minister had signed official letter of 05/TTg-DK about priorities for Nghi Son Refinery and Petrochemical Complex Project. Based on this letter, PetroVietnam, IKC, MCI and KPI had decided to organize Joint Venture named “Nghi Son Refinery and Petrochemical Limited Liability Company” (NSPR - LLC) dated 7th April 2008 in which Petrovietnam holds 25.1 percent of the total paid-up capital, Idemitsu Kosan Co., Ltd. (IKC) 35.1%, Mitsui Chemicals Inc (MCI) 4.7% and the Kuwait Petroleum International (KPI) 35.1%. The project is located within the Nghi Son Economic Zone (NSEZ) at Tinh Gia district, Thanh Hoa Province, approximately 200 km south of Ha Noi capital and 80km north of Vinh City, Nghe An province (Figure 0-1). Total area in land is about 394 ha. The capital investment for the refinery is estimated to be US$ 6 billion. The construction is expected to start in 2010 and the refinery and petrochemical complex to become operational by 2013.

Figure 0-1 Project location



The Refinery and Petrochemical Complex Project is classified as new project - Class A and received Investment License No.262022000036 dated 14th April 2008 and Adjusted Investment Certification No.262022000036 dated 29th May 2008 from Nghi Son Economic Zone Management Board (Annex 1). The Refinery and petrochemical complex is designed to process 200,000 BPSD of imported Kuwait Export Crude (KEC) oil. The fuels section of the refinery includes Residue Hydrodesulphurisation and Residue Catalytic Cracking as the main upgrading units. The refinery is integrated with petrochemical production. The Aromatics plant produces Paraxylene and Benzene. A key product from the Residue Cracker is Propylene which is used to produce Polypropylene product. The following products of the refinery and petrochemical complex include:

LPG Gasoline – 92/ 95 RON Kerosene / Jet A-1 Diesel – Premium and Regular Fuel oil Paraxylene / Benzene Polypropylene Sulphur

The NSRP Project includes all process units and associated utility, offsite and infrastructure facilities to support the Complex operation.

Complete utility facilities designed to meet demands of the Complex for cooling water, fuels, power, steam, water, instrument and plant air, inert gas, etc.

Offsite facilities including tankage for feedstocks plus intermediate and final products as well as systems for import and export of feed and products.

Other offsite facilities including flare, effluent treatment, firewater, interconnecting piping and pipelines, etc.

General facilities, including Control System, Electrical and Telecommunication, Buildings.

Marine facilities including a Single Point Mooring (SPM)/ Crude import pipelines, product loading jetties, and cooling water intake and outfall.

The NSRP will be the second major oil refinery in Vietnam after Dung Quat. This is one of the nation’s key projects that will ensure an adequate supply of energy to the country said by Prime Minister Nguyen Tan Dung at groundbreaking ceremony (VN Oil and Gas News on 3rd March 2009). It will not only promote the socio-economic development of the provinces and cities in the central part of Viet Nam and as a result the whole country in general but satisfy necessary of national energy safety in the future as well. The NSRP project implementation will bring many advantages as follows:

Contributing to the national energy security, by securing long-term imported crude supply of at about 10 million tons per year, which will be processed by this Complex to produce voluminous fuels and petrochemicals.

http://en.wikipedia.org/wiki/Vietnam



Products of the Complex include Mogas (2.1 millions tons per year MTPY), Diesel (2.7 MTPY), as well as jet LPG (1.4 MTPY), jet fuel/kerosene, fuel oils and petrochemicals. As the Project comes into operation from 2013, the production of both the Project and Vietnamese first refinery (Dung-Quat) can cover 50% local demand for fuel products.

Paving the way for the development of the petrochemical industries, associated industries and other related services.

Robustly motivating the socio-economic development of the south Thanh Hoa and north Nghe An province and vicinities.

Creating jobs for dozens of thousand people during construction phase, and thousands of people during operation phase.

0.2 LEGAL AND TECHNICAL BASIS OF EIA PREPARATION 0.2.1 Scope of the EIA report Based on Official letter of 1370/TTg-KTN dated 21st August 2008 of Prime Minister on approval of building Nghi Son Refinery and Petrochemical Complex Project, the responsibilities of each related parties in project implementation are classified as follows:

Telecom VNPT Post is responsible in telecom

EVN is responsible to supply electricity to boundary limit of Refinery for construction phase and for operation phase of emergency case

PVN is responsible in mine-disarming, site leveling and initial dredging for Jetty, SPM and access channel

Thanh Hoa Province People’s Committee is responsible in compensation, resettlement, site clearance, road, water and infrastructure for resettlement sites.

Then PVN assigned Nghi Son Project Management Board (NSPM) to take responsibility of mine-disarming, basic site leveling and initial dredging for Jetty, SPM and access channel. Thanh Hoa People’s Committee assigned Tinh Gia District People’s Committee to take responsibility of compensation and site clearance and assigned Nghi Son Economic Zone Management Board (NSEZMB) to take responsibility of road and water to Refinery boundary limit, resettlement and infrastructure for resettlement site. Hence, resettlement of plant site is the responsible of the Thanh Hoa People Committee/Tinh Gia District People Committee and the site leveling is responsible of PVN/NSPM. The basic site leveling and site leveling phase II have already been considered in a previous EIA report and environmental commitment certification approved by NSEZ Management Board. Two following approved EIA decision and certification will be attached of this report as Annex II.

1. EIA approved Decision No.195/QĐ-BQLKKTNS dated 4th September 2008 of NSEZMB for soil exploitation for site leveling period at Chuot Chu mountain, Hai Yen and Hai Thuong commune, NSEZ;



2. Environmental commitment certification No.416/GXN-BQLKKTNS dated 16th April 2010 of NSEZMB for project site leveling Phase 2 before infrastructure construction of Nghi Son Refinery and Petrochemical Complex.

Moreover, resettlement of plant site and related area is the responsible of the Thanh Hoa Province, Tinh Gia District and Nghi Son Economic Zone Management Board. Therefore the scope of this EIA report includes 394ha for the onshore facilities and 259ha of offshore area during 25 years project implementation in two following phases:

Construction and Installation phase: Define impact sources, detail impact assessment and propose mitigation measures for: i) construction and installation of onshore facilities (Refinery and Petrochemical Complex, tankage farm, product pipeline system, intake cooling water system, effluent outfall system; ii) construction and installation of offshore facilities (harbour, breakwater, crude pipeline and SPM).

Operation phase: detail impact assessment and propose mitigation measures for: i) operation

of onshore facilities (Refinery and Petrochemical Complex (Process units) and support facilities (including tank farm system, steam recovery system, power and steam system, intake water system, flare, etc.) in normal and abnormal operation, treatment and effluent discharge, collect, treat and dispose solid wastes, environmental management and monitoring); ii) operation of offshore facilities (crude import at SPM, crude pipeline transportation, product loading at harbour, shipping activities, maintenance dredging, oil spill at offshore facilities..) and iii) cumulative impact between project facilities and other facilities in the area.

In order to ensure that the project will be developed in a manner that is socially responsible and reflect sound environmental management practices, the NSRP-LLC has committed to follow strictly Vietnamese Laws, Regulations and Standards as well as International Financial Corporation (IFC) Performance Standards on Social & Environmental Sustainability in April 30, 2007 and World Bank Safeguard Policy. 0.2.2 International Regulations The new facilities should fully comply with the following international regulations which are signed by Vietnamese authorities:

Montreal Protocol 1987/90/92/95/97/99 on the Control of Substances that Deplete the Ozone Layer (CFCs, HFCs)

Basel Convention 1989, Convention on the Control of Transboundary Movements of Hazardous Wastes and their Disposal

The Protocol of 1978, Relating to the International Convention for the Prevention of Pollution From Ships 1973 (MARPOL), Annexes I & II

Kyoto Protocol 97/05, on Reducing CO2 Emissions and other Greenhouse Gases (GHG) that affect Climate Change

Stockholm Convention on Persistent Organic Pollutants (2001)

The United Nations Convention on the Law of the Sea (LOS) 1982/1994

The United Nations Framework Convention on Climate Change 1992/1994

International Declaration on Cleaner Production 1989



0.2.3 Vietnamese Laws and Standards 0.2.3.1 Vietnamese Law and Legislation The Project will comply fully with the following Vietnamese Laws:

1. Investment Law No.59/2005/QH11 dated 29th November 2005 issued by National Assembly of the Socialist Republic of Vietnam;

2. Construction Law No.16/2003/QH11 dated 26th November 2003 issued by National Assembly of the Socialist Republic of Vietnam;

3. Law No.38/2009/QH12 dated 19th June 2009 issued by National Assembly of the Socialist Republic of Vietnam on revising and supplementing some Articles of Construction Law No.16/2003/QH11, Bidding Law No.61/2005/QH11, Business Law No.60/2005/QH11, Land Law No.13/2003/QH11 and Housing Law No.56/2005/QH11;

4. Exported and Imported Tax Law No.04/1998/QH10 dated 20th May 1998 issued by National Assembly of the Socialist Republic of Vietnam;

5. Environmental Protection Law No.52/2005/QH11 dated 29th November 2005 issued by National Assembly of the Socialist Republic of Vietnam;

6. Governmental Decree No.80/2006/NĐ-CP dated 9th August 2006 on Regulations and Guidelines for Detailed Implementation of the Law on Environmental Protection;

7. Governmental Decree No.117/2009/NĐ-CP dated 31st December 2009 on dealing with infringing Environmental Protection Law;

8. Governmental Decree No.21/2008/NĐ-CP dated 28th February 2008 of the Government on revising and supplementing some Articles of Governmental Decree No.80/2006/NĐ-CP;

9. Circular No. 05/2008/TT-BTNMT dated 8th December 2008 of the MONRE - Guidelines on Strategic Environmental Impact Assessment, Environmental Impact Assessment and Commitment to Environmental Protection;

10. Law on Water Resources No.08/1998/QH10 dated 20th May 1998 issued by National Assembly of the Socialist Republic of Vietnam;

11. Governmental Decree No.179/1999/NĐ-CP dated 30th December 1999 on implementing Water Resource Law;

12. Governmental Decree No.149/2004/NĐ-CP dated 27th July 2004 issued by the Government – on the regulation of permission of exploration, production, use of water resources and waste water discharge to the water source

13. Circular No.02/2009/TT-BTNMT dated 19th March 2009 issued by MONRE on assessing receiving capacity of water source;

14. Circular No.21/2009/TT-BTNMT dated 5th November 2009 issued by MONRE on norms of economic – technical investigation, wastewater status and receiving capacity of water source assessment;

15. Land Law No.13/2003/QH11 dated 26th November 2003 issued by National Assembly of the Socialist Republic of Vietnam;



16. Governmental Decree No.181/2004/NĐ-CP dated 29th October 2004 on implementing Land Law;

17. Forest Protection and Development Law No.29/2004/QH11 dated December 2004 issued by National Assembly of the Socialist Republic of Vietnam;

18. Dyke Law No.79/2006/QH11 dated 29th November 2006 issued by National Assembly of the Socialist Republic of Vietnam;

19. Ordinance No.26/2000/PL-UBTVQH10 dated 24th August 2000 issued by Standing Committee of the National Assembly;

20. Governmental Decree No.171/2003/ NĐ-CP dated 26th December 2003 on implementing some Articles of Dyke Law;

21. Mineral Law No.47-L/CTN dated 20th March 1996 issued by National Assembly of the Socialist Republic of Vietnam;

22. Revising and Supplementing Law on some Articles of Mineral Law No.46/2005/QH11 dated June 2010;

23. Governmental Decree No.07/2009/NĐ-CP dated 2nd January 2009 on modifying Mineral Law 2009;

24. Petroleum Law No.19/2000/QH10 dated 9th June 2000 issued by National Assembly of the Socialist Republic of Vietnam;

25. Governmental Decree No.48/2000/NĐ-CP dated 12th September 2000 - Detail Regulations for the Implementation of the Revised Petroleum Law

26. Decision No. 395/1998/QĐ-KHCNMT dated 10th April 1998 - Regulations on Environmental Protection in Petroleum Exploration, Field Development, Production, Storage, Transportation, Processing and Related Services, issued by MOSTE

27. Law No.10/2008/QH12 to modify and supplement of Petroleum Law, ratified by the national assembly of 3 June 2008

28. Decision No. 41/1999/QĐ-TTg dated 8th March 1999 - Safety Management Regulation in Oil and Gas Activities, issued by Prime Minister

29. Decision No.103/2005/QĐ-TTg dated 12th May 2005 on Regulations for Oil Spill Response Plan, issued by the Prime Minister;

30. Decision No.129/2001/QĐ-TTg dated 29th August 2001 issued by Prime Minister - National Oil Spill Response Plan for the Period 2001 – 2010;

31. Decision No.2469/QĐ-DKVN of Petrovietnam dated 5th May 2006 on Oil Spill Response Plan;

32. Marine Codes No.40/2005/QH11 dated 14th June 2005 issued by National Assembly of the Socialist Republic of Vietnam;

33. Decree No. 71/2006/ND-CP dated 25th July 2006 about Seaports and Channel Management Safety;

34. Governmental Decree No.25/2009/NĐ-CP dated 6th March 2009 on integrated resources management and marine and island environment protection;

35. Governmental Decree No.137/2004/NĐ-CP dated 16th June 2004 on administrative fining on sea regions and continental shelves of Vietnam;



36. Governmental Decree No.26/2010/NĐ-CP dated 22nd March 2010 on modifying and supplementing Clause 2 Article 8 Governmental Decree No.67/2003/ NĐ-CP dated 13th June 2003 on environmental protection fee to wastewater;

37. Ordinance No.15/2007/L-CTN dated 5th December 2007 of Government on issuing Chemicals Law;

38. Governmental Decree No.108/2008/NĐ-CP dated 7th October 2008 for detailing and guiding the implementation of a number of articles of the Chemical Law 2007;

39. Governmental Decree No.68/2005/NĐ-CP dated 20th May 2005 on Chemical Safety;

40. Governmental Decree No.02/CP dated 5th January 1995 on Toxic Chemicals and Radioactive Substances;

41. Circular No.12/2006/TT-BCN dated 22nd December 2006 by Ministry of Industry on Guideline in implementation of Decree No. 68/2005/ND-CP on Chemical Safety;

42. Circular No.01/2006/TT-BCN dated 11th April 2006 issued by Ministry of Industry - Guideline in Management of Importation/Exportation of Toxicants and Products containing toxicant, Predrugs and Chemicals with Technical Standards managed by Ministry of Industry and Trading;

43. Biodiversity Law No.20/2008/QH12 dated 13th November 2008 by National Assembly of the Socialist Republic of Vietnam;

44. Governmental Decree No.16/2005/NĐ-CP dated 7th February 2005 on managing investment capital and project constructions;

45. Governmental Decree No.29/2008/NĐ-CP dated 14th March 2008 on Regulation of forming, operating, policy and state management for industrial parks, export processing zone, economic zone and border gate EZs;

46. Circular No.08/2009/TT-BTNMT dated 15th July 2009 by MONRE on environmental management and protection in Economic Zone, Hi-tech Park, Industrial Park and Industrial Group;

47. Governmental Decree No.50/1998/NĐ-CP dated 25th June 1998 in Detailed regulations on implementing Radiation Safe and Control Ordinance;

48. Governmental Decree No.59/2007/NĐ-CP dated 9th April 2007 in Solid waste management;

49. Decision No.23/2006/QĐ-BTNMT dated 26th December 2006 by MONRE on List of hazardous wastes;

50. Decision No.155/1999/QĐ-TTg dated 16th July 1999 issued by the Prime Minister on Hazardous wastes management regulations;

51. Circular No.12/2006/TT-BTNMT dated 26th December 2006 issued by MONRE on Guidelines for practice conditions of transporting and registering, licensing hazardous wastes management practice and code;

52. Circular No.13/2007/TT-BXD dated 31st December 2007 issued by Ministry of Construction – Guidelines for implementing some Articles of Decree No.59/2007/NĐ-CP dated 9th April 2007 on Solid waste management;



53. Circular No.05/2006/TT-BKNCN dated 11th January 2006 issued by Ministry of Science, Technology and Environment on Guidelines for declaring, licensing procedures and activities concerned with radioactive substances;

54. Decision No.3733/2002/QĐ-BYT dated 10th October 2002 issued by the Ministry of Health – 21 Standards for hygiene, 5 rules and 7 parameters for labour hygiene;

55. Decision 4613/QĐ-KHCNMT dated 15th November 2000 by Petrovietnam on Guidelines for monitoring of the marine environment in the vicinity of offshore petroleum installations in Vietnam;

56. Guidelines for Monitoring of onshore environment surrounding the Petroleum Installations were issued in 2006 by Petrovietnam

57. Decision No.3044 /QĐ-ATSKMT dated 13th June 2005 by Petrovietnam on Guidelines for the implementation of requirements on use and discharge of chemicals and drilling fluids in petroleum operations offshore Vietnam;

58. Circular No.16/2009/TT-BTNMT dated 7th October 2009 issued by MONRE on Promulgating National Technical Regulations of QCVN 05:2009/BTNMT – Regulations on ambient air quality and QCVN 06:2009/BTNMT – Regulations on some toxic substances in ambient air environment;

59. Circular No.25/2009/TT-BTNMT dated 16th November 2009 by MONRE – Application of National Technical Regulation of QCVN 19:2009/BTNMT – National Technical Regulations on industrial emission gases to dust and inorganic substances, QCVN 20:2009/BTNMT – National Technical Regulations on industrial emission gases to some organic substances, QCVN 22: 2009/BTNMT – National Technical Regulations on industrial emission gases in thermoelectric plant, QCVN 24:2009/BTNMT – National Technical Regulations on industrial wastewater;

60. Decision No.16/2008/QĐ-BTNMT dated 31st December 2008 by MONRE – Promulgating National Technical Regulations on Environment, including QCVN 08:2008/BTNMT – National Technical Regulations on surface water quality; QCVN 09:2008/BTNMT – National Technical Regulations on ground water quality; QCVN 10:2008/BTNMT – National Technical Regulations on coastal water quality;

61. Decision No.3900/2007/QĐ-UBND dated 13th December 2007 of Thanh Hoa PPC on approval of overall plan on compensation, clearance the site for Nghi Son Refinery and Petrochemical Project in Tinh Gia District, Thanh Hoa Province.

62. Governmental Decree 69/2009/NĐ-CP dated 13th August 2009 on Promulgating supplemental regulations on land using, price, acquiring, compensating, assisting and resettlement plan.

63. Joint Circular No.14/2008/TTLT/BTC-BTNMT dated 31st January 2008 issued by MONRE on Guidelines for implementing some Articles of Decree 84/2007/NĐ-CP of 25th May 2007 on Supplemental regulations on licensing Land Using Right Certification, Land Acquirement and carrying out land using right, order, compensation procedure, assistance, resettlement in case of land acquiring and complaint solving.

64. Decision No.1511/2007/QĐ-UBND dated 24th May 2007 issued by Thanh Hoa PPC on compensation rates for properties on land in areas of Thanh Hoa Province;

65. Decision No.3931/2006/QĐ-UBND dated 31st December 2006 issued by Thanh Hoa PPC on approval of price of land types in Thanh Hoa Province in 2007;



66. Decision No.4238/2007/QĐ-UBND dated 31st December 2007 issued by Thanh Hoa PPC on approval of price of land types in Thanh Hoa Province in 2008;

67. Decision No.1151/2008/QĐ-UBND dated 28 April 2008 issued by Thanh Hoa PPC on adjusting price of agricultural land types in Nghi Son Economic Zone;

68. Letter No.1606/UBND-KTTC dated 18th April 2008 issued by Thanh Hoa PPC on compensation rates for different roads in implementation of projects in Nghi Son Economic Zone (NSEZ) and Tinh Gia District;

69. Decision No.1048/2008/QĐ-UBND dated 22nd April 2008 issued by Thanh Hoa PPC on compensation rates for architectural objects;

70. Decision No.2531/2008/QĐ-UBND dated 18th August 2008 issued by Thanh Hoa PPC on assistance policy for relocating, resettlement applied for NSEZ;

71. Resolution No.128/2009/NQ-HĐND dated 15th July 2009 issued by Thanh Hoa PPC on policy of relocation assistance and resettlement applied for NSEZ.

72. Guideline No.2108/HD/STC dated 25th September 2009 issued by Financial Department of Thanh Hoa Province on implementation policy of relocation assistance and resettlement applied for NSEZ.

73. Decision 2622/2009/QĐ-UBND dated 7th August 2009 issued by Thanh Hoa PPC on policy of relocation assistance and resettlement applied for NSEZ.

74. Decision 4366/QĐ-UBND dated 9th December 2009 issued by Thanh Hoa PPC on replacing Decision 2622/2009/QĐ-UBND.

75. Investment License No.262022000036 dated 14th April 2008 and Adjustment License of Investment No.262022000036 dated 29th May 2008 issued by NSEZ Management Board for NSRP.

0.2.3.2 Environmental Standards The following environmental standards have been developed by the Ministry of Natural Resource and Environment (MONRE) in Vietnam and form the environmental framework for all industrial developments: Air Quality

QCVN 05:2009/BTNMT: National Technical Regulation on Hazardous substances in ambient air;

QCVN 06:2009/BTNMT National Technical Regulation on ambient air quality;

QCVN 19:2009/BTNMT National Technical Regulation on Industrial Emission of Inorganic Substances and Dusts;

QCVN 20:2009/BTNMT National Technical Regulation on Industrial Emission of Organic Substances;

QCVN 22: 2009/BTNMT National Technical Regulation on Emission of Thermal Power industry

TCVN 6438:2005 Road Vehicles. Maximum permitted emission limits of exhaust gas.



Water Quality

QCVN 08:2008/BTNMT National Technical Regulation on Surface Water Quality; QCVN 09:2008/BTNMT National Technical Regulation on Groundwater Quality; QCVN 10:2008/BTNMT National Technical Regulation on Coastal Water Quality.

Wastewater Quality

QCVN 24: 2009/BTNMT National Technical Regulation on Industrial Wastewater; QCVN 14: 2008/BTNMT National technical regulation on domestic wastewater; TCVN 5298:1995 General requirements for the use of wastewaters and their sludge’s for

watering and fertilizing purposes.

Hazardous Wastes

TCVN 7221:2002 General environmental requirements for central industrial wastewater treatment plants;

QCVN 07:2009/BTNMT National Technical Regulation on Hazardous Waste Thresholds; TCVN 6705:2000 National Standards on Classification Non-hazardous solid wastes; TCVN 6706:2000 National Standards on Classification Hazardous waste; TCVN 6707:2000 National Standards on Warning signal and prevention Hazardous waste; TCVN 6868:2001 National Standards on Radiation Protection. Radioactive waste

management. Classification of radioactive waste.

Noise and Vibration

TCVN 3985:1999 National Standards on Acoustics. Allowable noise level at working place;

TCVN 5290:1990 System of standards for environmental protection. General requirements;

TCVN 5654:1992 National Standards on Regulations on environmental protection at offshore mooring terminals for loading exploited raw petroleum;

TCVN 5948:1999 National Standards on Acoustics. Noise emitted by accelerating road vehicles. Maximum Permitted Noise Level;

TCVN 5949:1998 National Standards on Acoustics. Noise in public and residential areas. Maximum Permitted Noise Level;

TCVN 6436:1998 National Standards on Acoustics. Noise emitted by stationary road vehicles. Maximum Permitted Noise Level;

TCVN 6962:2001 National Standards on Vibration and shock. Vibration emitted by construction works and factories. Maximum permitted levels in the environment of public and residential areas;

TCXDVN175:2005 Maximum permitted noise levels for public buildings – Design Standard;

QCVN 01/2008/BXD National Technical Regulation on constructional planning



0.2.3.3 Project Standards The NSRP Project and associated facilities are designed according to the more stringent environmental standards in order to minimize emissions to air, water and land. These requirements will be compliant with Vietnamese legislation and international standards including World Bank /IFC (International Finance Corporation) Guidelines and they will respect the international conventions ratified by the Government of Vietnam. The standards used for this Project will be current World Bank/IFC Standards, except for where the Vietnamese Standards are the more stringent, or where there is no World Bank Standard for a substance regulated by Vietnamese Standards. The following International Financial Cooperation/ World Bank Guidelines are referenced for NSRP:

International Financial Cooperation/ World Bank (IFC/WB) General Environmental Health and Safety (EHS) Guidelines (April 30, 2007)

IFC/WB Industry Sector Guidelines for Petroleum Refining (April 30, 2007)

IFC/WB Industry Sector Guidelines for Petroleum Based Polymer Manufacturing (April 30, 2007)

IFC/WB Industry Sector Guidelines for Large Volume Petroleum based Organic Chemicals Manufacture (April 30, 2007)

IFC/WB Industry Sector Guidelines for Crude Oil and Petroleum Product Terminals (April 30, 2007)

IFC/WB Industry Sector Guidelines for Port, Harbours and Terminals (April 30, 2007).

IFC/WB Industry Sector Guidelines for Thermal power plants (December 19, 2008).

Air Quality

Ambient Air Quality Standards Ambient Air Quality Standards (AAQS) for Vietnam are set out in QCVN 05:2009/BTNMT National Technical Regulation on Hazardous substances in ambient air and QCVN 06:2009/BTNMT National Technical Regulation on ambient air quality. The IFC-World Bank Guidelines are based on the World Health Organisation (WHO) Air Quality Guidelines (Global Update, 2005). All emissions from the project will be limited in order to meet the requirements of the IFC and Vietnamese Standards. IFC states in their General guideline that "Emissions do not result in pollutant concentrations that reach or exceed relevant ambient quality guidelines and standards by applying national legislated standards, or in their absence, apply WHO guidelines." So, Project applies the Vietnamese Standards as Project Standards which are shown in Table 0.1



Table 0.1 Ambient Air Quality Standards (μg/m3)

Parameter Averaging Period Vietnamese Ambient Air

Quality Standards 1

Sulphur Dioxide (SO2) 1 hour

24 hour 1year

350 125 50

Carbon Monoxide (CO) 1 hour 8 hour

24 hours

30,000 10,000 5,000

Nitrogen Dioxide (NO2) 1 hour

24 hours 1year

200 100 40

Ozone (O3) 1 hour 8 hour

24 hour

180 120 80

Suspended Dust (TSP) 1 hour

24 hour 1 year

300 200 140

Dust ≤ 10µm (PM10)

24 hour 1 year

150 50

Lead (Pb) 24 hour 1 year

1.5 0.5

Notes: 1: QCVN 05:2009/BTNMT National Technical Regulation on ambient air quality

Source Emissions Standards The Vietnamese standards for the control of hazardous substances in the air are set out in QCVN 19:2009/BTNMT for inorganic gases, QCVN 20:2009/BTNMT for organic substances and QCVN 22:2009/BTNMT Emission standards for Thermal Power Industry. Applicable World Bank Standards can be found in the Guidelines for Petroleum Refining, Petroleum based Polymer manufacturing, Thermal Power Plants, and Large Volume Petroleum based Organic Chemicals Manufacture. World Bank Standards will take precedence, except for where the Vietnamese Standards are the more stringent, or where there is no World Bank Standard for a substance which is regulated by Vietnamese Standards. These limits are summarized in Table 0.2 along side the corresponding Vietnamese standards. In case of variations between IFC and Vietnamese standards the more stringent level will be applied.



Table 0.2 Project Point Source Emission Standards 1

Vietnamese Standard for industrial Emissions 2

World Bank EHS-Guideline Value 3 Pollutants

NSRP process Units Max allowable concentration in mg/Nm3

Applicable World Bank Guideline

values in mg/Nm3

Project standards 2

mg/Nm3 Remarks

1. For Refinery Boilers – Considering Non Degraded Airshed (a) Fuel-Natural gas/other gases 42.5 Not Applicable 42.5 Dry gas@3% excess O2

(b) Fuel-Liquid> 50MWth to <600MWth

127.5 50 50 Dry gas@3% excess O2

(c) Fuel- Liquid & solid > 600MWth 127.5 50 50 Dry gas@3% excess O2

2. For Gas Turbine – Considering Non Degraded Airshed (a) Fuel-Natural gas (NG) >50MWth

42.5 Not Applicable 42.5 Dry gas@15% excess O2

(b) Fuel-Other than NG>50MWth 127.5 50 50 Dry gas@15% excess O2

3. For other process Heaters under Refinery Complex (a) General Process Heaters/sources

160 (dust in smoke) 40 (for dust containing silic)

50 50 Dry gas@3% excess O2

(b) Sulphur recovery Units 160 50 50 Dry gas@3% excess O2

4. For other Process Heaters under Large Volume Petroleum Based Organic Chemical Manufacturing

PM

All Fuel 160 (dust in smoke) 40 (for dust containing silic)


1. For Refinery Boilers – Considering Non Degraded Airshed (a) Fuel-Natural gas 255 Not Applicable 255 Dry gas@3% excess O2

(b) For other gaseous fuel 400 400 400 Dry gas@3% excess O2

(c) Fuel-Liquid> 50MWth to<600MWth

400 900 (Lower value) 400 Dry gas@3% excess O2

(d) Fuel- Liquid > 600MWth 400 200 (Lower value) 200


255 Not Applicable 255 Dry gas@15% excess O2

(b) Fuel-Other than NG>50MWth 425 Use of 1% or less sulphur fuel

400 (Use of 1% or

less fuel)

Dry gas@15% excess O2

3. For other process Heaters under Refinery Complex (a) General Process Heaters/sources

400 500 400 Dry gas@3% excess O2

(b) Sulphur recovery Units 400 150 150 Dry gas@3% excess O2


SO2

All Fuel 400 100 100 Dry gas@3% excess O2

1. For Refinery Boilers – Considering Non Degraded Airshed (a) Fuel-Natural gas/other gases 212.5 240 212.5 Dry gas@3% excess O2

(b) Fuel-Liquid> 50MWth to <600MWth

510 400 400 Dry gas@3% excess O2

(c) Fuel- Liquid & solid > 600MWth 510 400 400 Dry gas@3% excess O2


212.5 (Ref.QCVN22:2009/BTNMT)


(b) Fuel-Other than NG>50MWth 510 (Ref.QCVN22:2009/BTNMT)


3. For other process Heaters under Refinery Complex (a) Solid fuels 680 450 450 Dry gas@6% excess O2

(b) Liquid and gaseous fuels 680 450 450 Dry gas@3% excess O2


NOx

All Fuel 680 300 300 Dry gas@3% excess O2

CO For all Emission sources 800 - 800 Maximum allowable concentration

Vanadium For all Emission sources - 5 5 Dry gas@3% excess O2

Nickel For all Emission sources - 1 1 Dry gas@3% excess O2

For Refinery Emission sources 6 10 6 Maximum allowable concentration

H2S

For Unit associated with Organic Chemical manufacturing

6 5 5 Dry gas@273K, 101Kpa (1 atm), 6% O2 for Solid fuel & 3% for gas fuel

For Refinery Emission sources 50 - 50 Maximum allowable concentration

HCl



Benzene For all Emission sources 5 5 5 Maximum allowable concentration



Vietnamese Standard for industrial Emissions 2

World Bank EHS-Guideline Value 3 Pollutants

NSRP process Units Max allowable concentration in mg/Nm3

Applicable World Bank Guideline

values in mg/Nm3

Project standards 2

mg/Nm3 Remarks

1,2 Dichloroethane


- 5 5 Dry gas@273K, 101Kpa (1 atm), 6% O2 for Solid fuel & 3% for gas fuel


Vinyl Chloride (VCM)




Ammonia



VOCs For Unit associated with Organic Chemical manufacturing


Heavy Metals For Unit associated with Organic Chemical manufacturing

- 1.5 1.5 Dry gas@273K, 101Kpa (1 atm), 6% O2 for Solid fuel & 3% for gas fuel

Mercury & Compounds




Formaldehyde


20 0.15 0.15 Dry gas@273K, 101Kpa (1 atm), 6% O2 for Solid fuel & 3% for gas fuel

Ethylene For Unit associated with Organic Chemical manufacturing



Ethylene Oxide



Hydrogen Cyanide




Organic sulphide and Mercaptans For Unit associated with Organic

Chemical manufacturing 15 2 2 Dry gas@273K, 101Kpa

(1 atm), 6% O2 for Solid fuel & 3% for gas fuel


Phenols, cresols and xylos (as phenol) For Unit associated with Organic

Chemical manufacturing 19 10 10 Dry gas@273K, 101Kpa

(1 atm), 6% O2 for Solid fuel & 3% for gas fuel

Dioxins/Furans ng TEQ/Nm3



Notes: 1. Emission standard at source is developed from following standards:

1. QCVN 19:2009/BTNMT with coefficient Kp of 0.8 as total emission is over 100.000 m3/h and value of Kv is 1 due to project is sited in industrial park

2. QCVN 20:2009/BTNMT 3. QCVN 22:2009/BTNMT with coefficient Kp of 0.85 as designed capacity of thermoelectric plant is less than

1.200MW and more than 300 MW and value of Kv is 1 due to project is located in industrial park. 4. From IFC Guidelines values for Petroleum Refining Facilities. 5. From IFC Guidelines values for Large Volume Petroleum-based Organic Chemical Manufacture 6. From IFC Guidelines values for Thermal Power Plants 7. From IFC Guidelines values for Petroleum-based polymers Manufacturing

2. Nm3 at condition of 1 atm and 0oC 3. Nm3 at condition of 1 atm and 25oC



Effluent discharge to water source

Industrial wastewater discharged from the production process will be treated in an industrial wastewater treatment plant and shall comply with the standards as outlined before discharge into the receiving environment. Clean effluents with low levels of contamination such as storm water run-off from non-process units will be discharged directly to sea. Industrial wastewater discharge standards Vietnamese Standard QCVN 24:2009/BTNMT has been established to control industrial wastewater discharge. However considering that the Project will follow the international standards, the IFC – EHS Guidelines will be applied, except for where the Vietnamese Standards are the more stringent, or where there is no IFC – EHS Guidelines available for a substance which is regulated by Vietnamese Standards. The following table compares Vietnamese Standard to the IFC – EHS Guidelines Values. Process discharge water and sanitary water will be treated in ETP to meet Project standard in Table 0.3.

Table 0.3 Industrial wastewater discharge standard

IFC EHS Guideline Values Pollutants Units Vietnamese Standards

QCVN – Max Limit Value 3

Petroleum

Refining Facilities1

Petroleum –based

polymer Manufacturing

Large Volume Petroleum-based

Organic chemicals

Manufacturing

Project Standards

pH S.U 5.5-9 6-9 6-9 6-9 6-9 BOD5 mg/l 45 30 25 25 25 COD5 mg/l 90 150 150 150 90 TSS mg/l 90 30 30 30 30 Cadmium (Cd) mg/l 0.009 - 0.1 0.1 0.009 Hydrocarbons mg/l 4.5 (mineral oil

and fat) or 18 (animal –

vegetable oil)

10 (oil and grease)

10 (oil and grease)

10 (oil and grease) 4.5 (mineral oil and fat)

or 10 (animal – vegetable

oil) Chromium (total) mg/l 0.9 0.5 0.5 0.5 0.5 Chromium (Hexavalent)

mg/l 0.09 0.05 0.1 0.1 0.05

Copper (Cu) mg/l 1.8 0.5 0.5 0.5 0.5 Zinc (Zn) mg/l - - 2 2 2 Iron (Fe) mg/l 4.5 3 3 3 3 Cyanide Total (Free)

mg/l

-

0.1

0.1

0.1

0.1

Cyanide (CN-) mg/l 0.09 1 1 1 0.09 Lead (Pb) mg/l 0.45 0.1 0.5 0.5 0.1 Nickel (Ni) mg/l 0.45 0.5 0.5 0.5 0.45 Mercury (Hg) mg/l 0.009 0.02 0.01 0.01 0.009 Vanadium mg/l - 1 1 1 1 Phenol mg/l 0.45 0.2 0.5 0.5 0.2 Benzene mg/l - 0.05 0.05 0.05 0.05 Benzo(a)pyrene mg/l - 0.05 0.05 0.05 0.05 Vinyl Chloride mg/l - - 0.05 - 0.05



(VCM) Dicloroethane mg/l - - 1 1 1 Adsorbable organic halogens (AOX)

mg/l - - 1 0.3 0.3

Sulphide mg/l 0.45 1 1 1 0.45 Total Nitrogen mg/l 27 102 10 10 10 Total Phosphorus

mg/l 5.4 2 2 2 2

Temperature oC <404 Max increase

<=3

Max increase <=3

Max increase <=3 - <40oC at final outfall discharge

- Max increase <=3 at the edge of mixing zone

Notes:

1. Assumes an Integrated Petroleum Refinery;

2. The effluent concentration of nitrogen (total) is up to 40 mg/l in processes that include hydrogenation;

3. From Vietnamese Standard QCVN 24:2009/BTNMT, Limit Values from Column B, factor applied where applicable. These limits are valid for discharges of industrial wastewater into water bodies used for navigation, irrigation purposes or for bathing, aquatic breeding and cultivation, etc. Value of Output/capacity coefficient (kq) is 1 as receiving source is coastal water used for aquacultural protection and sport. Value of Kf is 0.9 as discharge flow of effluent is more than 5,000 m3/day except for some parameters as pH, colour, Coliform, total radioactivity α and β;

4. NSRP Project will comply with Vietnamese Standard 24:2009/BTNMT for discharge from sea water cooling system;

5. COD as analyzed by Chrome method as specified on ISO 6060-1989.

Sanitary water discharge

IFC states in their General EHS Guidelines that if sewage from the industrial facility is to be discharged to surface water, treatment has to meet national or local standards for sanitary wastewater discharges. Considering this statement, project’s wastewater will be treated to meet the National technical regulation on sanitary wastewater QCVN 14:2008/BTNMTas described at Table 0.4.

Table 0.4 Sanitary water discharge standards

Pollutants Units Vietnamese requirement QCVN

14:2008/BTNMT- Max limit value

pH S.U 5-9

BOD (20 Deg C.) mg/l 50

Total Suspended Solids (TSS) mg/l 100

Total Dissolved Solids (TDS) mg/l 1,000

Total of surface active substances mg/l 10

Hydrocarbon including fat and mineral oil mg/l 20



Pollutants Units Vietnamese requirement QCVN 14:2008/BTNMT- Max limit value

Ammonical Nitrogen mg/l 10

Nitrate Nitrogen mg/l 50

Sulphide (as H2S) mg/l 4

Phosphates as P mg/l 10

Total Coliform bacteria MPN/ 100 ml 5,000

Dosmetic wastewater in Plant area and industrial wastewater will be treated in ETP to meet Vietnamese Standard QCVN 24:2009/BTNMT. Sanitary wastewater in Jetty area will be treated and meet QCVN 14:2008/BTNMT before being combined with other effluents and discharged to the sea. Seawater cooling discharge Cooling water is not considered production wastewater, as the system is not used in a technological process, only in thermal exchange. Vietnamese standards do not regulate cooling water discharge temperature. However, the project will strictly comply with Vietnamese Standard QCVN 24:2009/BTNMT which requires that the temperature of cooling water discharged into a received environment is equal to or lower than 40ºC. The IFC General EHS Guidelines specifies that cooling methods should be used to reduce the temperature of wastewater from utilities operations, to ensure the discharge water temperature does not result in a maximum temperature increase greater than 3ºC at the edge of a scientifically established mixing zone, which takes into account ambient water quality, receiving water use, potential receptors and assimilative capacity. After cooling process, one part of seawater cooling is used for FGD system to treat flue gas. This water will be treated to meet industrial water discharge standard in Table 0.3. Coastal water quality National standards on coastal water quality QCVN 10:2008 were promulgated under Decision No.16/2008/QD-BTNMT on 31 December 2008 by MONRE. These national standards are applied to evaluate and control coastal water quality for purposes of sport, aquatic entertainment, aquaculture and others. Coastal water is defined as water at gulf/bay, port/harbor and areas in the range of 3 nautical miles from the shore (5.5km). Allowable limits of parameters in coastal water are listed in Table 0.5.



Table 0.5 Allowable limits of parameters in coastal water (QCVN 10:2008/BTNMT)

ALLOWABLE LIMITS No.

Parameter

Unit Aquaculture &

aquatic reservation

area

Swimming & aquatic sport

area

Others

Project Standards

1 Temp. oC 30 30 - 30

2 pH - 6.5 – 8.5 6.5 – 8.5 6.5 – 8.5 6.5 - 8.5

3 TSS mg/l 50 50 - 50

4 DO mg/l ≥ 5 ≥ 4 - ≥ 4

5 COD mg/l 3 4 - 4

6 NH4+ as N mg/l 0.1 0.5 0.5 0.5

7 Fluor (F-) mg/l 1.5 1.5 1.5 1.5

8 Sulphide (S2-) mg/l 0.005 0.01 0.01 0.01

9 Cyanide (CN-) mg/l 0.005 0.005 0.01 0.005

10 Arsenic (As) mg/l 0.01 0.04 0.05 0.04

11 Cadmium (Cd) mg/l 0.005 0.005 0.005 0.005

12 Lead (Pb) mg/l 0.05 0.02 0.1 0.02

13 Chromium III (Cr3+) mg/l 0.1 0.1 0.2 0.1

14 Chromium VI (Cr6+) mg/l 0.02 0.05 0.05 0.05

15 Copper (Cu) mg/l 0.03 0.5 1.0 0.5

16 Zinc (Zn) mg/l 0.5 1 2 1

17 Manganese (Mn) mg/l 0.1 0.1 0.1 0.1

18 Iron (Fe) mg/l 0.1 0.1 0.3 0.1

19 Mercury (Hg) mg/l 0.001 0.002 0.005 0.002

20 Hydrocarbon mg/l N.D 0.1 0.2 0.1

21 Total Phenol mg/l 0.001 0.001 0.002 0.001

22 Coliform MPN/100ml 1000 1000 1000 1000

These coastal water quality standards will be used to assess the impact of effluents discharge. Noise NSRP noise limits are the most stringent of Vietnamese and IFC requirements (Table 0.6).



Table 0.6 Noise limits (dBA)

Vietnamese Noise Standards

TCVN 5949:1998

IFC Noise Level Guidelines

Project Noise Standards

Time One Hour LAeq (dBA)

One Hour LAeq (dBA)

Receptor 06:00 –

18:00

18:00 –

22:00

22:00 –

06:00

07:00 -

22:00

22:00 -

07:00

06:00 –

18:00

18:00 –

22:00

22:00 –

06:00

Quiet Areas, including hospitals, libraries, schools

50 45 40 - - 50 45 40

Residential Areas, hotels, offices

60 55 50 55 45 55 45

Residential areas intermingled with trade, service and manufacturing activities

75 70 50 70 70 70 50

Industrial, Commercial - - - 70 70 70

Noise limits for different working environments are provided in Table 0.7.

Table 0.7 Noise limits for various working environments

Location / Activity Equivalent Level LAeq 8 Hrs in dB(A)

(TCVN 3985:1999)

Maximum LAmax. Fast in dB(A)

Heavy Industry (no demand for oral communication) 85 110 Light industry (decreasing demand for oral communication) 50 - 65 110

Open offices, control rooms, service counters or similar 45 - 50 -

Individual offices (no disturbing noise) 45 - 50 - Classrooms, lecture halls 35 - 40 - Hospitals 30 - 35 40 Vibration

Vibration caused by the construction and operation of the facility is regulated by TCVN 6962:2001. The allowable limits for vibration generated by light industrial facilities in nearby residential areas are shown in Table 0.8.

Table 0.8 Allowable vibration limits (TCVN 6962:2001)

Vibration limits in construction activity (dB(A))

Vibration limits in production activity (dB(A))

Receptor 07:00 – 19:00 19:00 – 07:00 06:00 – 18:00 19:00 – 06 :00

Quiet Areas, including hospitals, libraries, schools 75 Basic Level1 60 55

Residential Areas, hotels, offices 75 Basic Level1 65 60 Small industrial factories intermingled with residential areas 75 Basic Level1 70 65

Notes: 1: Basic level is vibration level measured when facilities are not working in assessed area



Occupational exposure limits

Predicted ground level concentrations of pollutants can be compared against occupational exposure limits for guidance as to their relative safety.

Vietnamese legislation provides limits for in plant pollution in Decision No.3733/2002/QĐ-BYT, 21 Standards for hygiene, 5 rules and 7 parameters for labour hygiene.

The IFC EHS Guidelines refer to the occupational exposure limits for inside the plant boundary set by the American Conference of Government Industrial Hygienists (ACGIH). There are Threshold Limit Values (TLVs) for 8 hour and 15 minute exposure levels.

Threshold Limit Values for the main relevant pollutants are listed in Table 0.9.

Table 0.9 Occupational exposure limits

Occupational exposure limits based on Decision

No.3733/2002/QĐ-BYT -2002

Maximum average concentration

(mg/m3)

Occupational exposure limits based on World Bank Guidelines-2008


(ppm)

Project standards


Pollutants

STEL1 TWA2 STEL1 TWA2 STEL1 TWA2 H2S 15 10 15 10 15 mg/m3 10 mg/m3 SO2 10 5 5 2 10 mg/m3 5 mg/m3 NO 20 10 - 25 20 mg/m3 10 mg/m3 NO2 10 5 5 3 10 mg/m3 5 mg/m3 Particulates - - Respirable – 3

Inhalable - 10 Respirable – 3 Inhalable - 10

CO 40 20 - 25 40 mg/m3 20 mg/m3 O3 0.2 0.1 - 0.05-0.2 0.2 mg/m3 0.1 mg/m3 Benzene 15 5 2.5 0.5 2.5 ppm 0.5 ppm Toluene 300 100 - 20 300 mg/m3 92 mg/m3 Xylene 300 100 150 100 300 mg/m3 100 mg/m3

Notes: 1. Short Term Exposure Limit (STEL), usually 15 minutes

2. Time Weighted Average (TWA), the recommended limit a person can be exposed to over a period of time without causing harm, usually 8 hours

World Bank standards will take precedence, except for where the Vietnamese Standards are the more stringent, or where there is no World Bank Standards for a substance which is regulated by Vietnamese Standards. Emergency response planning guidelines Ground level concentrations under emergency conditions should be compared to the Emergency Response Planning Guideline (ERPG) values developed by the American Industrial Hygiene Association (AIHA). Emergency Response Planning Guideline Values listed in Table 0.10.



Table 0.10 Emergency response planning guideline values (2009)

Species ERPG-1 ppm

ERPG-2 ppm

ERPG-3 ppm

H2S 0.1 30 100 SO2 0.3 3 15

Benzene 50 150 1000 NO2 1 15 30 CO 200 350 500

ERPG-1 is the maximum airborne concentration below which it is believed that nearly all individuals could be exposed for up to 1 hr without experiencing other than mild transient adverse health effects or perceiving a clearly defined, objectionable odour. ERPG-2 is the maximum airborne concentration below which it is believed that nearly all individuals could be exposed for up to 1 hr without experiencing or developing irreversible or other serious health effects or symptoms which could impair an individual's ability to take protective action. ERPG-3 is the maximum airborne concentration below which it is believed that nearly all individuals could be exposed for up to 1 hour without experiencing or developing life-threatening health effects. 0.2.3 Technical basis and related documents The technical documents used in this report are supplied mainly by NSRP-LLC and the FEED design consultants. The environmental data is carried out, measured, analyzed and assessed by CPSE. Specially, the economic and social data is collected from the local authorities and related departments. Detail main used documents are summarized as follows: FEED documents of NSRP project are provided by FWEL during December, 2008 - December,

2009.

Measured Meteorological data of Project area are provided by NSRP-LLC.

Measured Meteorological data in Tinh Gia Station are provided by Southern Hydrometeorological Center.

Baseline environmental field surveys and analytical data in the dry season and rainy season (2008-2009) are conducted by CPSE.

Environmental vegetation cover surveys and biodiversity assessment for the project area and the vicinity in the radius of 10km are carried out by CPSE in cooperation with national biological experts in August 2008.

Coral reef field surveys and investigation for the Hon Me archipelagoes are carried out by CPSE in cooperation with Institute of Marine Environment and Resources in Hai Phong in April 2009.

Social investigation and due diligence assessment are carried out by CPSE in cooperation with national and international consultants from August 2008 to January 2010.



0.3 METHODOLOGY FOR EIA IMPLEMENTATION According to official letter No.321/TTg-DK dated 4 March 2008 of Vice Prime Minister about specializing for refinery and petrochemical projects, this EIA report is established at the same time of FEED preparation. The structure of EIA report is complied with Appendix IV of Circular No. 05/2008/TT-BTNMT of MONRE on the Guidance on Strategic Environmental Impact Assessment, Environmental Impact Assessment and Commitment of Environmental Protection. The main methods used in the preparation of this EIA report are as follows:

1. Statistical method: is used to treat the environmental analytical data, and the meteo-hydrological and socio-economic data;

2. Modeling method: is used to calculate and simulate the air emission processes, oil drifting, dumping material dispersion and wastewater dilution and dispersion caused by project activities. Some mathematic models are used for preparing this report including:

- Atmospheric Dispersion Modeling System (ADMS) from CERC (Cambridge Environmental Research Consultants) with the United Kingdom Meteorological Office, National Power plc and University of Surrey is used to calculate maximum ground concentration of CO, SOx, NOx, PM, etc. from process stacks and flares.

- Oil Drift Model is used to calculate and simulate oil drifting in the case of oil spill occurred in Nghi Son bay.

- COMIX model is used to stimulate thermal dispersion process on water column affected by effluent discharge.

- Mud and fluid distribution model is used to stimulate distribution of dredged materials

3. Field survey and measurement method: is used to take samples, field measure and analyze in the laboratories (air, water, soil, sediment and biology samples) at the project area. Moreover, this method is used to survey the vegetation cover and determine biodiversity (fauna and flora) of the project area;

4. Scuba diving method: is used to survey and take coral samples as well as undertake underwater video and photograph survey;

5. Social investigation method: is used to interview the authorities, departments and local residents at the project area.

6. Comparative method: is used to evaluate environmental quality of air, soil, water, sediment and biology in comparison with existing current Vietnamese and International environmental standards;

During preparation process this report, the project owner has co-operated closely with CPSE and FEED Contractor (Foster Wheeler Energy Limited (FWEL) and Royal Haskoning (RH)) and Petrovietnam in order to ensure the compliance to environmental standards and the accuracy and consistency from the used information. Furthermore, the project owner has co-operated closely with the local authorities, especially Nghi Son Economic Zone Management Board, Nghi Son Refinery Management Board, Department of Natural Resource and Environment, Agricultural and Rural Development Department, Thanh Hoa Port Authority, Construction Department, Tinh Gia People Committee and Commune People Committee of Hai Yen, Mai lam and Tinh Hai in assessing social impacts of the NSRP project.



0.4 EIA IMPLEMENTATION ORGANIZATION According to the signed contract for provision of “Environmental impact assessment (EIA) and Environmental Social Impact Assessment (ESIA) for Nghi Son Refinery and Petrochemical Complex Project” dated 16 July 2008 between Nghi Son Refinery & Petrochemical Limited Liability Company (NSRP-LLC) and Research Development Center for Petroleum Safety and Environment (CPSE), CPSE is given organization having responsibility to prepare EIA, ESIA and OSCP for NSRP.

CPSE was established in November, 1993. CPSE was given licensed No.256 for registration of the scientific and technological activities by Ministry of Science, Technology and Environment (MOSTE), dated March 16, 1994 and was licensed on constructional consultant no 150 (July 13, 1998) by Ministry of Construction. Besides, CPSE is the first organization of Vietnam National Oil and Gas Group to achieve ISO 9001 certificate of quality management system issued by AFAQ-ASCERT International dated July 2, 1999 and accreditation certificate of NDT laboratory No. 157/00CN02 and 157/00CN03, number of laboratory: VR LAB. 08, issued by Vietnam Register Bureau, dated December 4, 2000.

CPSE is one of expertise organization in safety and environment field. Up to present, CPSE has been prepared hundreds of environmental impact assessment reports, oil spill response plan reports and risk assessment for petroleum industry and other industrial branches. The contact address of CPSE consulting service is as below:

Research Development Center for Petroleum Safety and Environment G1, 2nd floor, Thanh Da Hotel, Ward 27, Binh Thanh District, HCMC Tel: 3 55 66 075/ 3 55 66 077 Fax: 3 55 66 076 Director: Ph.D Vu Cong Thang

EIA process starts from August 2008 to March 2010 with co-operation of many national experts and international consultants of CPSE. Two International Environmental Consult Companies participate in preparing this EIA report including:

1. SNC – LAVALIN INC at 455, René-Lévesque Blvd. West, Montreal, Quebec, Canada H2Z 1Z3;

2. EXPERCO INTERNATIONAL LTEE at 150 Marchand Street, Suite 600, Drummondville (Québec) J2C 4N1 CANADA

Main task of SNC – LAVALIN INC is to assess society and make a plan for environmental and social management programs as well as environmental monitoring program. This company will also be responsible for reviewing and checking completely EIA and ESIA reports as requirement of MONRE and IFC. While, main mission of EXPERCO INTERNATIONAL LTEE is to conduct a social investigation and assess compensation, resettlement issues and public consultation as requirement of IFC. List of researchers taking part to prepare this EIA report is list in Table 0.11.



Table 0.11 List of participants taking part EIA preparation for NSRP

No Name Position/Specialty Responsibilities in the project

1 Mr. Toshio Esumi HSE Senior Engineer – NSRP-LCC Review report

2 Ms. Do Thi Thu Ha HSE Senior Engineer – NSRP-LCC Review report

3 Ph.D Vu Cong Thang Director of CPSE Chief editor

Group for EIA report preparation

4 Mr. Dao Duy Manh Manager of Environmental Management Dept., CPSE - Engineer of Petro-chemistry

- Organize human and material resources - OSCP review

5 Mrs. Pham Thi Dung Deputy Manager of Environmental Management Dept., CPSE - Master of Science – Environmental Technical Engineering

- Team Leader - Organize preparation - Review and edit EIA report

6 Mrs. Le Thi Ngoc Mai Deputy Manager of Environmental Management Dept., CPSE – Master of Science – Ecological Environment

- Organize field survey, data integrated - Review and edit EIA report

7 Mr. Nguyen Ngoc Son Expert of Environmental Management Dept., CPSE - Geology bachelor - Engineer of IT

8 Mr. Tran Phi Hung Expert of Environmental Management Dept., CPSE - Engineer – Petrochemical Engineer

9 Mrs. Tran Thi Tu Anh Expert of Environmental Management Dept., CPSE - Engineer – environmental chemistry

10 Mrs. Thai Cam Tu Expert of Environmental Management Dept., CPSE - Master of Environmental Technical Engineering

11 Mrs. Dinh Thi Nguyet Minh

Expert of Environmental Management Dept., CPSE - Geology bachelor

12 Nguyen Dinh Phong Expert of Environmental Management Dept., CPSE - Environmental Engineer

- Field survey, - Data collection - Mapping - Prepare partly report

13 Mrs. Do Thi Son Huong Deputy Manager of Safety Management Dept., CPSE – Master of Economic

Prepare risk assessment and working environment

14 Mrs. Nguyen Thi Thuy Expert of Environmental Management Dept., CPSE - Engineer of IT

15 Mr. Dinh Quang Bao Expert of Environmental Management Dept., CPSE - Engineer of IT

Data treatment and modeling

16 Mr. Duong Dinh Nam Expert of Environmental Management Dept., CPSE - Environmental Engineer

Prepare OSRP

Group for Environmental Baseline Survey – Field sampling and analysis (physio-chemical and biological parameters) – prepare baseline survey report 17 Mr. Tran Khanh Tung Manager of Environmental Chemistry

Dept. CPSE - Petrochemical Engineer Organize human and material resources in Envi. Chemistry Dept.- Review baseline survey report




18 Mrs. Bui Hong Diem Deputy Manager of Envi. Chemistry Dept. CPSE - Petrochemical Engineer

Review Baseline survey report

19 Mr. Nguyen Van Mai Deputy Manager of Envi. Chemistry Dept. CPSE - Engineer – Chemistry Engineer

Organize human and material resources in Environmental Chemistry Dept.

20 Mr. Phan Nhu Dinh Deputy Manager of Envi. Chemistry Dept CPSE - Petrochemical Engineer

Team leader – baseline surveys

21 Mr. Truong Thong Expert of Environmental Chemistry Dept. CPSE – Biological Engineer

Prepare partly Baseline survey report

22 Mrs. Nguyen T.Van Anh Expert of Environmental Chemistry Dept CPSE - Chemistry Engineer

Prepare partly Baseline survey report

23 Mrs. Hoang Minh Thao Manager of Biology lab. Organize human and material resources in Biology Lab. – Review and check biological result.

24 Mr. Doan Dang Phi Cong

Deputy Manager of Biological Lab. Master of biology

25 Mr. Dinh Van Hai Expert of Biological Lab. Bachelor of biology

Measure, sampling air, water, sediment and biology. Analysis environmental parameters in Lab.

… And many Engineers, experts carried out field sampling and analysis in lab.

Consultant and Collaborator

26 Prof.Ph.D Dang Huy Huynh

National Biological Expert - Fauna Field survey - Review terrestrial fauna

biodiversity report 27 Ph.D Tran Ngoc Ninh National Biological Expert - Flora Field survey

- Evaluation of biodiversity in term of terrestrial Flora ecosystem

28 Ph.D Le Tran Chan National Biological Expert - Flora Field survey - Evaluation of

biodiversity in term of terrestrial ecosystem (Flora)

29 M.Sc. Le Xuan Tuong Biological Expert - Assessment of existing biodiversity of terrestrial fauna

30 Prof. Ph.D Pham Thuoc National Biological Expert - Evaluation Marine resources

31 Ph.D Do Cong Thung and others

National Coral Expert - Field survey and coral investigation

- Evaluation on coral in Hon Me archipelago

Report review

32 Mr. Jean Noel Duff International Consultant (EIA report) – SNC Lavalin

- Social assessment - Review EIA report




33 Mr. Pierre Arnoux International Consultant (compensation and resettlement) – SNC Lavalin

- Compensation and resettlement assessment

- Public consultation - Review report

34 Mr. Dang Huu Luu National Resettlement Expert - Carry out Social investigation

- Due diligence survey and assessment

- Public consultation



Section 1.

PROJECT DESCRIPTION

1.1. PROJECT NAME

Nghi Son Refinery and Petrochemical Complex Project (NSRP)

1.2. PROJECT OWNER Project Owner of the NSRP project is the Joint Venture among Petrovietnam (PVN), Idemitsu Kosan Co., Ltd.(IKC), Mitsui Chemicals Inc (MCI) and the Kuwait Petroleum International (KPI). The Joint Venture was given the Investigation Certificate No 262022000036.by the Nghi Son Economic Zone Management Board on 14 April 2008. The official name and contact address of project Owner are listed as below:

Project Owner name: NGHI SON REFINERY AND PETROCHEMICAL LIMITED LIABILITY COMPANY (NSRP-LLC)

General Director: Mr. HIDETO MURAKAMI

Address: 05 th floor PetroVietnam Building

18 Lang Ha Street., Ba Dinh District

Hanoi – Vietnam

Tel. number: +84 (43) 377 26 4 26

Fax. Number: +84 (43) 377 26 4 27

1.3 GEOGRAPHICAL LOCATION The NSRP project is located in the Nghi Son Economic Zone, Tinh Gia District, Thanh Hoa Province. It is 200 km south of from Hanoi and about 80 km north of Vinh City (Nghe An Province). Total onshore area is about 394 ha and offshore area is about 259ha (Figure 1-1), including: 1. Onshore constructions:

Main Refinery Plant (Area B, 328ha) Onshore Pipeline (Area E, 30ha) Marine harbour (Area J, 36ha)

2. Offshore constructions: Exported berths, access channel, breakwater and intake channel (193ha) Crude oil pipeline (35ha) SPM (31ha)



Figure 1-1



Figure 1-2 Locations of areas in NSRP

Table 1-1 Locations of main area of NSRP

Area Point Latitude N Longitude E C 19o 21’ 17” 105o 45’ 33” F 19o 21’ 31” 105o 46’ 49” G 19o 22’ 18” 105o 46’ 39”

Refinery Plant (Area B)

H 19o 22’ 10” 105o 45’ 53” V 19o 22’ 07” 105o 46’ 41” U’ 19o 22’ 13” 105o 47’ 11” G’ 19o 22’ 24” 105o 47’ 08”

Crude Oil Pipeline (Area E)

G 19o 22’ 18” 105o 46’ 39” T 19o 21’ 38” 105o 47’ 25” G’ 19o 22’ 24” 105o 47’ 08” R 19o 22’ 25” 105o 47’ 14”

Marine Harbour (Area J)

S 19o 21’ 41” 105o 47’ 33” SPM 19o 21’ 59.48” 106o 05’ 57.57”

Detailed description of each area position and relationship to surrounding objects are presented in below section.



1.3.1 Plant location Plant site is 328ha located in area of 3 communes: Mai Lam, Hai Yen and Tinh Hai. The elevation of the existing ground varies from +0.5m to +3.5m (National Datum). A small section of the plant site is separated by Coc Mountain which has a peak elevation of +83m. The majority of the land planned to be occupied by the NSRP Complex is agricultural land and homesteads. Plant site is contiguous to:

In the North side, the plant is next to Tinh Hai and Mai Lam Communes; In the South side, the plant is next to populated area of Hai Yen Commune; In the East side, the plant is next to populated area of Hai Yen Commune (Area C); In the West side, the plant is located next to Provincial Road 513 connecting from National

Highway 1A to Nghi Son integrated Port. Close to right side of 513 road is Cam and Chuot Chu Mountains.

In general, plant site is near by residential areas of Hai Yen, Mai Lam and Tinh Hai Communes. When project comes into operation, there still have local houses living close to plant boundary toward the northern part. The NSRP-LLC has proposed to Vietnam Government to move all houses in the East side of the plant before project entering operation phase. However, according to master plan of NSEZ to 2025, all local houses living around plant will be allocated to farther area. At that time, the farthest distance from plant to residential area will be about 1.7km toward to the North. The North side of the Plant is 1.2 – 1.5km away from Lach Bang River system. Main aquacultural area of Tinh Gia District locates along Lach Bang banks. There is a rivulet, namely Dap Ngoai starting from Chuot Chu Mountain to Lach Bang River runs across Plant site, but it will be filled up. And 6-7km away from the South side of the Plant, there is Yen Hoa River springs from Xuoc Mountain and Bang Me Mountain belonging to Hai Thuong and Hai Ha Communes to Nghi Son harbour area (PTSC port now). In project area, there is a Provincial Road namely 513 connecting PTSC Port to National Road 1A with 10km in length. Moreover, communal roads run nearly parallel with seashore from Hai Yen Commune to Tinh Hai and Hai Binh Communes. At present, in radius of 7.5km of project site, there is a Paper Powder Mill in the Northern part of Mai Lam Commune, Nghi Son Cement Factory, PTSC Port and Vinashin Shipyard in the South which belong to Hai Ha and Hai Thuong Communes. In the future, a 1,800MW Nghi Son Power Center will also be established in the opposite of PTSC Port. In order to secure the safety in the area during construction and operation phase and to get space required for temporary site gathering equipment and materials in the construction phase, NSRP has proposed to the Government and People’s Committee of Thanh Hoa Province to make clearance of area C (between area B – the Plant site and area J – the Harbour) for this Project. 1.3.2 Onshore Pipeline System Coordinates of onshore pipeline system layout are presented in Table 1-1. A pipeline system (Figure 1-2, Area E) will be installed to transfer crude oil to the Refinery and route products from the Plant to the Harbour. Total area of onshore pipeline system is about 30ha and 1.5km in length, 350m in width. Topography of this area is very flat and mainly residential land, product land (peanut, sesame, etc.) and small part of protective forest land of Hai Yen Commune.



1.3.3 Harbour Location The Nghi Son Harbour area will be located between the geographical coordinates:

N19° 22' 12”, E 105° 46' 12”, and N 19° 21' 18”, E 105° 48' 54”.

Detailed coordinates of the Harbour layout are presented in Table 1-1. Harbour area is located in Trung Hau Ward, Hai Yen Commune. This harbour is used to transport super size and super weight equipments in construction phase and export products by seaway. This area is along the shore consisting of protective forest to prevent erosion and without population. The harbour location is sited at the Refinery Landfall to the east of plant site and north of an existing Nghi Son Cement jetty (Figure 1-3). Total onshore area of the harbour is about 36 ha (area J in Figure 1-2).

The harbour access route will generally run in an east-northeast direction passing some kilometers away from the offshore Hon Me Archipelagoes.

Figure 1-3 General Layout of Marine Facilities



1.3.4 SPM Location The offshore SPM is located at coordinates N19o 21’ 59.48”; E 106o 05’ 57.57” and in a deeper natural water depth of 27m at the east side of Hon Me Island at about 33.5 km from the harbour site (Figure 1-3). 1.3.5 Crude Oil Pipeline Location A pipeline system will be built to bring the crude oil import from SPM to the refinery. Approx 35 km double crude oil pipeline links the crude oil tank farm and the SPM of which approx 33.5km is sub-sea and the 1.5 km rest onshore. The onshore crude pipeline route will go in the same pipeline corridor of product pipeline system.

1.4 MAIN CONTENTS OF NSRP PROJECT The Nghi Son Refinery and Petrochemical (NSRP) Project is designed to process 200,000 BPSD. A maximum of 0.5% by volume water is assumed to be present in the crude. As designed configuration, NSRP can process of 100% Kuwait Export Crude (KEC) oil or mixture of 85% Kuwait Export Crude Oil and 15% Murban Crude Oil. The design will incorporate features for optimizing energy utilization and heat recovery consistent with product fractionation.

All technologies applied for NSRP are state-of-art and worldwide application in refinery and petrochemical industry. The project has been designed to comply with most stringent of Vietnamese Standards and World Bank/IFC guidelines. The modern technology employed for pollution abatements are as follows:

State of the art Flue Gas Desulphurisation for boiler flue gases (do not use chemicals and produce pollutants);

RFCC CO Incinerator

RFCC Flue Gas Scrubber (De-SOx)

RFCC flue gas DeNOx

SCOT Tail Gas Treatment in the Sulphur Recovery Unit to attain sulphur recovery

Use of Low NOx and Ultra-Low NOx burners for process heaters and HMU

Tertiary treatment of aqueous effluent

Location of effluent discharge sea outfall pipeline based on computer modeling for thermal plume

The Refinery capacity is based on an average of 8,320 hours operation per year giving an operating factor of 0.95. The target operating factor will be 0.97. The design of NSRP includes all process units, supported utilities, offsite facilities and infrastructure (Figure 1-4).



Figure 1.4 Nghi Son Refinery and Petrochemical Complex Plot Plant


NSRP LLC- CPSE/SNC Lavalin June, 2010

The refinery and petrochemical complex consists of 15 licensed process units by world-wide famous suppliers (Figure 1.5 and Table 1.2).

Figure 1.5 Licensed Process Units

Table 1.2 process units and designer/Licensor supplier

No. Process unit Designer/Licensor Refinery Process Units

1 Crude Distillation Unit (CDU) Foster Wheeler 2 LPG Recovery Unit (LRU) Foster Wheeler 3 LPG Treatment Unit (LTU) UOP 4 Kerosene Hydrodesulphuriser (KHDS) Axens 5 Gas Oil Hydrodesulphuriser (GOHDS) Axens 6 Residue Hydrodesulphuriser (RHDS) Chevron Lummus 7 Residue Fluid Catalytic Cracker (RFCC) Axens 8 RFCC Light Gasoline Treater Unit UOP 9 RFCC LPG Treater Unit UOP 10 Propylene Recovery Unit (PRU) Axens 11 Indirect Alkylation Unit (InAlk) UOP

Petrochemical Process Units 12 Polypropylene unit (PPU) Misui Chemicals 13 Naphtha and Aromatics Complex (NAC) UOP



No. Process unit Designer/Licensor Hydrogen Units

14 Hydrogen Manufacturing Unit (HMU) Foster Wheeler 15 Hydrogen Compression and Distribution system (HCDS) Foster Wheeler

Sulphur Processing Units 16 Sour Water Stripper unit (SWS) Foster Wheeler 17 Amine Regeneration Unit (ARU) Foster Wheeler 18 Sulphur Recovery Unit (SRU) JACOBS 19 Tail Gas Treating Unit (TGT) JACOBS

The utility facilities include tanks system for feedstocks plus intermediate and final products. In addition, it is designed to meet the refinery’s demands for cooling water, fuels, power, steam, water, chemicals instrument and plant air, inert gas, ETP, flare, etc. Offsite facilities include SPM, pipelines, product jetties, road tanker for loading and unloading feedstock and products. 1.4.1 REFINERY AND PETROCHEMICAL CAPACITY 1.4.1.1 Material Balance Overall material balance for Nghi Son refinery is based on processing of 100% Kuwait Export Crude (KEC) oil feedstock with 200,000 barrels-per-stream-day (BPSD). Overall Refinery Mass Balance for Base Case – RFCC Max Propylene Operation Mode is shown in Table 1.3.

Table 1.3 Overall Refinery Mass Balance for Base Case – RFCC Max Propylene Operation Mode

Parameters Output (Ton/day) Crude Oil 27,867 Fuel Gas to Process Unit Furnaces 1,242 LPG to Export 104 LPG to Gas Turbines 555 LPG to Heat Recovery Turbines 115 Benzene 710 Paraxylene 1,974 Gasoline 92 RON 3,314 Gasoline 95 RON 3,314 Kerosene / Jet 1,707 Polypropylene 1,075 Diesel – Premium 6,357 Diesel – Regular 4,238 Fuel Oil to boilers and RFCC CO boiler 1,003 Carbon on RFCC Catalyst 805 Sulphur Product 717 Loss 637 Source: Provided by NSRP LLC, June 2010.



1.4.1.2 Designed Capacities for Process Units The designed capacities for individual process units have been determined based on:

The annual material balances presented above plus consideration of appropriate on-stream factors – for determination of stream-days

Design margins – to allow for design uncertainties and flexible operation. The refinery is required to operate continuously for a minimum period of four (04) years, between major turnarounds albeit that some process units may require ‘interim’ shutdowns for catalyst change-out, etc. Based on the turnaround frequency and other factors, on-stream factor of plant is 0.95 (8,320 hours per year). The design of the Nghi Son refinery and petrochemical project is based on established technologies whose performances are both predictable and well proven in operation, meaning that no significant variations are expected to be found between predicted performance and actual performance in the field. As a result, the operation of the refinery – and hence the generation of income – is very unlikely to be constrained by an unexpected bottleneck in a part of the process scheme. However, +10% margin on capacity is included for design purposes. Operating flexibility is accounted for in two main ways:

The specification of alternative operating cases/modes for specific process units (e.g. gasoline and propylene modes for the RFCC, and ‘start-of-run’ and ‘end-of-run’ cases for other catalytic units);

The incorporation of design margins in the design of specific items of equipment or sub-systems (e.g. pump capacity) to provide sufficient flexibility for regulatory control and/or on-line maintenance.

Nameplate capacity is defined on the conventional basis of barrels-per-stream-day (BPSD) measured at 15°C which represents actual maximum unit throughput when the unit is in full operation under design conditions. The main unit capacities are presented in Table 1.4.

Table 1.4 Main Unit Capacities of Nghi Son Refinery and Petrochemical Complex

CAPACITY UNITS

Daily (BPSD) Annual (KTA)

REMARKS

Crude Distillation Unit 200,000 9,660

LPG Recovery Unit - 2,413

Saturated LPG Treater 6,500 201

Kerosene Hydrodesulphuriser 20,000 872

Gas Oil Hydrodesulphuriser 60,000 2,906

Residue Hydrodesulphuriser 105,000 5,695

Residue Fluid Catalytic Cracker 80,000 4,135

RFCC LPG Treater 43,000 1,326

RFCC Light Gasoline Treater 24,000 888

Indirect Alkylation 21,500 707 Based on FEED

Naphtha Hydrotreater 54,100 2,130 Incl. raffinate recycle

Isomerisation (Penex) 23,400 843 Incl. DIH recycle



CAPACITY UNITS

Daily (BPSD) Annual (KTA)

REMARKS

Catalytic Reformer 39,700 1,615 Based on HN FEED

Aromatics (Benzene) - 248 Benzene product

Aromatics (Paraxylene) - 794 PX product

Polypropylene 1,154 TPD 400 PP product

Hydrogen Manufacturing Unit (Note A) 195.8 Nm³/h 145 Hydrogen product (Note A)

Amine Regeneration Unit 789 m³/h - Lean amine circulation (Note B)

Sour Water Stripper – Train 1 184.4 m³/h - Sour water FEED (Note B)

Sour Water Stripper – Train 2 90.2 m³/h - Sour water FEED (Note B)

Sulphur Recovery Unit 3 x 320 TPD - Sulphur product (Note C)

Tail Gas Treating Unit 2 x 640 TPD - Note D Source: FEED Doc. 3550-8110-PD-0005 provided by FWL on 28 December 2009 Notes

A. Expressed as 100% hydrogen. The centralised Hydrogen Compression and Distribution System (HCDS) distribute hydrogen to consumers.

B. Volumetric flow rate @ 15 °C. C. SRU has 3 x 40% trains (Σ 120%). D. TGT is part of the SRU and is configured as 2 x 80% trains.

The design capacities of the main process units have been established as following:

1. Crude Distillation Unit (CDU)

The nameplate capacity of the Crude Distillation Unit is 200,000 BPSD which corresponds to the nameplate capacity of the refinery. No additional design margin is included to cover, for instance, handling of different feedstocks or rerunning of off-spec products.

2. LPG Recovery Unit

The LPG Recovery Unit processes feed streams from the CDU and several other units. The nameplate capacity for the unit (2,404 KTA) is based on a summation of the various feed streams on the assumption that all units are operating at their design capacity, and considering differences between start-of-run and end-of-run.

3. Saturated LPG Treater Unit

The nameplate capacity of this unit (6,500 BPSD) corresponds to the mixed LPG yield from the LPG Recovery Unit.

4. Kerosene Hydrodesulphuriser Unit

The nameplate capacity of the KHDS unit (20,000 BPSD) is based on processing all the straight-run kerosene produced by the CDU.

5. Gas Oil Hydrodesulphuriser Unit (GOHDS)

The nameplate capacity of the GOHDS unit (60,000 BPSD) is based on processing all the straight-run gas oil produced by the CDU plus all the light cycle oil (LCO) produced by the RFCC.



6. Residue Hydrodesulphuriser Unit (RHDS)

The nameplate capacity of the RHDS unit (105,000 BPSD) is based on processing the entire atmospheric residue produced in the CDU. However, since the RHDS unit has an annual catalyst replacement cycle during which atmospheric residue feed is stored, the selected nameplate capacity includes an adequate margin to permit drawdown of the stored feed over an extended period for co-processing with direct feed from the CDU.

7. Residue Fluid Catalytic Cracker Unit (RFCC)

The nameplate capacity of the RFCC unit (80,000 BPSD) is set equivalent to the yield of atmospheric residue from the CDU less the conversion loss in the RHDS based on start-of-run conditions. Note that the nameplate capacity does not quite match the actual stream-day output of the RHDS because the RHDS nameplate capacity is marginally increased to account for downtime for catalyst regeneration.

8. RFCC LPG Treater

The nameplate capacity of the RFCC LPG Treater corresponds to the production rate of amine treated mixed LPG from the RFCC gas plant when the RFCC is operating in maximum propylene mode.

9. RFCC Light Gasoline Treater

The nameplate capacity of the RFCC Light Gasoline Treater corresponds to the production rate of light gasoline from the gasoline splitter in the RFCC when the RFCC is operating in maximum gasoline mode.

10. Polypropylene Unit (PPU)

The nameplate capacity of the PPU corresponds to the design production rate of propylene from the propylene recovery section of the RFCC. The resultant polypropylene product output of 400 KTPA falls within the maximum capacity limit of a single train PPU.

11. Naphtha and Aromatics Complex (NAC)

The design throughput of the NAC is based on the yield of fresh full-range naphtha from the naphtha stabiliser in the LPG Recovery Unit. This stream comprises straight-run naphtha from the CDU plus naphtha from the GOHDS and the RHDS units. This stream is fed to the Naphtha Hydrotreater (NHT) unit together with a raffinate stream recycled from the Aromatics Extraction (Sulpholane) unit. The resultant nameplate capacity of the NHT is 54,100 BPSD.

12. Hydrogen Manufacturing Unit (HMU)

The determining case which establishes the nameplate capacity of the HMU is the upset scenario when the Catalytic Reformer (and hence the whole of the Aromatics Complex) is shutdown while the remainder of the refinery, including the KHDS, GOHDS and RHDS units, is operating at minimum throughput of 50% under end-of-run conditions. In this case, the HMU is the only source of hydrogen treat gas for the refinery and the requirement is 195.8 Nm³/hr of hydrogen (on a 100% purity basis). During normal refinery operation at 100% throughput, the Catalytic Reformer provides a significant yield of hydrogen which allows the HMU to operate at approx. 75% of design capacity.



13. Indirect Alkylation Unit (InAlk)

The nameplate capacity of the InAlk unit is set to match the yield of C4 from the C3/C4 Splitter in the RFCC unit when the RFCC is operating in maximum propylene mode.

14. Amine Regeneration Unit (ARU)

The common ARU handles the circulating amine solvent demands of all amine absorbers/extractors within the refinery with the exception of those located in the RFCC complex (which are served by a separate RFCC amine system). The nameplate capacity is based on a summation of solvent demands defined by the designers of each absorber/extractor.

15. Sour Water Stripper Unit (SWS)

The SWS is configured as two independent trains. The design feed rate of sour water to each train is based on a summation of the various sour water feed component streams plus a +10% capacity margin for SWS-1 and 30% margin for SWS-2 to allow for design uncertainty and to provide operating flexibility.

16. Sulphur Recovery Unit (SRU)

The SRU is configured as three (03) parallel Claus trains. The overall sulphur production rate is based on a calculation of the sulphur yield from processing 200,000 BPSD of fresh Kuwait Export Crude Oil plus an allowance for the additional sulphur yield from the RHDS unit due to co-processing of cold residue feed, less an allowance for sulphur ‘lost’ in products. The estimated theoretical yield of sulphur is 800 TPD. The SRU is configured as 3 x 40% trains (i.e. 320 tpd each). The tail gas treating and incinerator section is configured as 2 x 80% trains (i.e. each train handles tail gas equivalent to 640 TPD of sulphur production). Sulphur feed to the SRU arrives in the form of acid gases from both the common ARU and the ARU in the RFCC, plus acid gases from the SWS trains.

1.4.2 FEEDSTOCK AND PRODUCTS 1.4.2.1 Feedstock

The feedstock of Nghi Son refinery and petrochemical Complex is 100% Kuwait imported Crude Oil. The oil quality is good for refining. The Kuwait Crude Oil specifications are presented in Table 1.5.

Table 1.5 Technical Characteristics of the Kuwait Crude

Parameters Unit Crude Balance*

Gravity API 29.9 30.2 Specific gravity 60/60 0.8765 0.8752 Density Kg/dm3 0.8760 K Factor 11.84 Sulfur WT% 2.65 2.64 Mercaptan Sulfur ppm 135.0 H2S ppm <1 Nitrogen ppm 930.0 956.2 Basic Nitrogen ppm 372.0 394.6 Con Carbon WT% 6.11 6.21



Parameters Unit Crude Balance*

Ash WT% 0.00 Asphaltenes WT% 2.50 Wax Content WT% 3.80 Iron ppm 0.7 Nickel ppm 10.1 10.9 Vanadium ppm 31.1 31.5 Sodium ppm 3.3 Pour Pt. Deg C <-36 Salt PTB 10.5 Reid Vapor Pressure kPa 26.2 TAN mgKOH/g 0.18 Water VOL% 0.000 Kin.Viscosity@

15.5oC 20oC

37.8oC 40oC 50oC 60oC

cSt cSt cSt cSt cSt cSt

22.73

11.41 8.88

27.02 22.65 12.36 11.57 8.79 6.89

Source: FEED Doc. 3550-8110-PD-0003 REV D3 provided by FWL on 28 December 2009 Note: (*) Analytical values are gotten from phases after crude oil distillation process. Feedstock chosen to process is Kuwait Export Crude Oil, mixing of many kinds of crude oil from many oil fields. Furthermore, Kuwait is one of project’s partner contributing financial to the Project. So, Kuwait ensures that the Complex will be supplied enough crude oil to operate for 25 years. Hence, it may be affirmed that Kuwait Export Crude Oil is a stable and long-term source of supply.

1.4.2.2 Project Products Products of NSRP are as follows:

Liquefied Petroleum Gas (LPG) Gasoline – RON 92 & 95 Kerosene and Jet Fuel Diesel – Premium and Regular Fuel Oil Benzene Paraxylene Polypropylene Sulphur

In general, pollutants concentrations in products of the Project are lower than Vietnamese Fuel Standards in force.

Table 1.6 Products Quality Standard of the Project

Characteristic Project Standard TCVN LPG S ppm weight 100 140

RON 92/95 90/92/95 Gasoline S ppm weight 50 500



Characteristic Project Standard TCVN Pb g/l 0 0.013

Benzene % volume 1.0 2.5 Kerosene S % weight 0.1 0.3

Diesel S ppm weight 50/350 500/2,500 Fuel Oil S % weight 1.0 2.0/3.5

Source: NSRP LLC, June 2010 1.4.3 TECHNOLOGY PROCESS

The overall diagram of Base case mass balance of NSRP project is showed in Figure 1.6. 1.4.3.1 Refinery Process Units

1.4.3.1.1 Crude Distillation Unit (CDU) The design of the CDU is consistent with the overall refinery objective of maximising distillates and minimising residue. The design incorporates flexibility in distillate production, will allow for minor variations in feed quality, and will enable consequent flexibility in refinery blending operations.

Design case CDU feedstock is based on 100% Kuwait Export crude. A maximum of 0.5% by volume water is assumed to be present in the crude. Design Cases is considered as follows:

Base Case: CDU will be designed for TBP cut points and products specifications.

Maximum Kerosene Case: CDU will be capable to produce a wider range of kerosene draw of acceptable quality in order to take advantage of market changes. This corresponds to an increase in kerosene production of 17%.

Minimum Kerosene Case: CDU will be able to increase wild naphtha production at the expense of kerosene cut in order to maximise profits in the Aromatics Complex.

Cold Reflux Case: CDU will have the flexibility to operate with 5 wt% cold reflux ratio (cold naphtha/hot top pumparound). This facility consists of wild naphtha stream from the column overhead receiver routed into the top pumparound return.

CDU will operate under this scenario during start-up, cleaning and off-design operation.

Crude oil will be preheated against product and pumparound streams before being routed to a fired heater. Primary fractionation will be carried out in the preflash vessel/ main crude column fractionator and associated side stream strippers. Overhead naphtha will be further stabilised in the naphtha stabiliser column in the LPG Recovery Unit. Products will be cooled and rundown to product blending, intermediate storage, or further processing as appropriate. The CDU unit will produce the following streams:

A sour overheads gas stream routed to the LPG Recovery Unit. A full-range unstabilised naphtha stream routed to the LPG Recovery Unit for further processing. A kerosene stream routed to the Kerosene Hydrodesulphuriser Unit (KHDS) and to product blending. A combined gas oil stream routed to the Gas Oil Hydrodesulphurisation Unit (GOHDS) or to GOHDS

intermediate tankage. An atmospheric residue stream routed to the Residue Hydrodesulphurisation Unit (RHDS) or to RHDS

intermediate tanks.


Figu

re 1

.6 O

vera

ll M

ass

Bal

ance

Bas

e ca

se




1.4.3.1.2 LPG Recovery Unit (LRU) The LPG Recovery Unit is designed as a common saturated gas plant to collect and process saturated feed streams (offgas, LPG and naphtha). These streams will be feeded by many sources such as CDU, Naphtha Hydrotreater, CCR, Isomerisation Unit and three (03) Hydrodesulphuriser Units (KHDS, GOHDS & RHDS). The LPG Recovery Unit is designed to:

Collect off-gas, LPG and Naphtha streams from the CDU and other Process Units;

Produce an Off-gas stream for use in the Refinery Fuel Gas System after hydrogen sulphide removal;

Produce a mixed LPG product stream, after removal of hydrogen sulphide and water washing, for routing to the licensed Saturated LPG Treatment Unit which removes mercaptan sulphur components;

Receive the sweet mixed LPG stream from the above Treatment Unit for stabilisation in a Deethaniser and subsequent separation in a Depropaniser to produce C3 and C4 LPG streams, which are routed to LPG storage;

Produce stabilised full-range naphtha which is routed as feedstock to the Naphtha Hydrotreater Unit;

Produce a sour water stream which is routed to the Sour Water Stripper Unit;

Produce a rich amine stream which is routed to the Amine Regeneration Unit.

1.4.3.1.3 Saturated LPG Treater Unit (LTU) The unit is designed to process mixed LPG feedstock from the amine extractor in the LPG Recovery Unit to produce treated LPG with a maximum total mercaptans sulphur content of 5 ppm wt. The unit design includes facilities for spent caustic treatment and recycle. The treated LPG product returns to the LPG Recovery Unit for C3 / C4 separation. The following by-products are expected to be produced in the Saturated LPG Treater Unit:

Foul Air to the CDU Heaters or RFCC CO Boiler or Incinerators located at the Sulphur Recovery Unit or HC Flare;

Disulphide Oil (DSO) to Naphtha Hydrotreating Unit (NHT) or Slop Tank; Spent Caustic and Wastewater to the Effluent Treatment Plant.

1.4.3.1.4 Kerosene Hydrodesulphuriser Unit (KHDS) The Kerosene Hydrodesulphuriser Unit (KHDS) processes the kerosene fraction from the Crude Distillation Unit (CDU) and produces desulphurised Kerosene /Jet Fuel with max. 50 ppm wt sulphur content and max. 0.003 %wt mercaptan sulphur content. The Unit also produces a number of by-product streams:

Unstabilised Naphtha, which is sent to the Crude Distillation Unit Sour off-gas sent to the LPG Recovery Unit. Sour water sent to the Sour Water Stripping Unit (SWS-1).



1.4.3.1.5 Gas Oil Hydrodesulphuriser (GOHDS) The Gasoil Hydrodesulphuriser Unit (GOHDS) processes atmospheric Gas Oil from the Crude Distillation Unit (CDU) and Light Cycle Oil from the RFCC. The unit desulphurises these feeds to produce low sulphur (max 50 ppm wt) diesel blendstock. The Unit also produces a number of by-product streams:

Unstabilised Naphtha sent to the Crude Distillation Unit; Treated off- gas sent to the LPG Recovery Unit; Sweet gas to the HCDS for hydrogen recovery in a PSA; Sour water sent to the Sour Water Stripping Unit (SWS-1).

This unit will incorporate to amine absorber for removal of H2S from sour offgas and recycle gas. The amine solvent will be MDEA. Lean amine will be supplied from a central Amine Regeneration unit. 1.4.3.1.6 Residue Hydrodesulphuriser Unit (RHDS) The RHDS is designed to process atmospheric residue from the Crude Distillation Unit to produce a feedstock suitable for processing in a downstream RFCC. The unit produces the following product streams:

Desulphurised atmospheric residue to the RFCC Unstabilised Naphtha to the LPG Recovery Unit Desulphurised RHDS diesel to the diesel pool.

The Unit also produces the following by-products:

Off-gas from the product recovery section to the LPG Recovery Unit Off-gas from the reactor section to HCDS for hydrogen recovery.

This unit will incorporate to amine absorber for removal of H2S from sour offgas and recycle gas. The amine solvent will be MDEA. Lean amine will be supplied from a central Amine Regeneration unit. 1.4.3.1.7 Residue Fluid Catalytic Cracker Unit (RFCC)

The RFCC is designed to process the RHDS residue stream received from the Residue Hydrodesulphuriser (RHDS). The RFCC is designed for two modes of operation: maximum olefin (propylene) and maximum gasoline.

The Unit produces the following product streams:

An amine treated LPG stream. This LPG stream will be caustic treated (RFCC LPG Treater) to remove Mercaptans. The mercaptan free LPG will be routed back to the RFCC C3/C4 splitter.

After mercaptan removal, the LPG stream will be split to produce a propylene stream to the Polypropylene Unit, a mixed butane stream to Indirect Alkylation Unit, and a propane stream to the LPG pool.

Light FCC gasoline (LFG) to the gasoline pool via caustic merox treating.

Heavy FCC gasoline (HFG) to the gasoline pool.



Light cycle oil (LCO) product to the Gas Oil Hydrodesulphurisation Unit and/or fuel oil

Clarified Oil (CLO) product to refinery fuel oil The Unit also produces the following by-products:

Treated off-gas sent to the refinery fuel gas system; Sour water sent to Sour Water Stripping Unit (SWS-2); Regenerator flue gas which is sent to atmosphere via a stack.

The RFCC unit includes dedicated amine absorber/extractor/regenerator facilities to serve the RFCC complex only. 1.4.3.1.8 RFCC LPG Treater This Unit is designed to process LPG feedstock from the RFCC unit after amine scrubbing. The Unit produces treated LPG with a maximum total mercaptans content of 3 ppm wt with maximum total sulphur of 10 ppmw. Spent caustic treatment includes the spent caustic from RFCC Light Gasoline Treater Unit for treatment.. Regenerated caustic shall be recycled back to the extraction section. The following by-products are produced by the RFCC LPG Treater:

Foul Air to the CDU Heaters or RFCC CO Incinerator or Incinerators located at the Sulphur Recovery Unit (SRU) or HC Flare.

Disulphide Oil (DSO) to Naphtha Hydrotreating Unit (NHT) or Slop Tank. Spent Caustic & Waste water to the Effluent Treatment Plant.

1.4.3.1.9 RFCC light Naphtha Treater The primary objective of the Residue Fluidised Catalytic Cracker (RFCC) Light Gasoline Treater Unit is to reduce the Mercaptan and total sulphur content and remove H2S from the light gasoline obtained from the RFCC. The product will meet the quality requirement to produce treated light gasoline with a maximum total sulphur specification of 35 ppmw (for feed containing 55 ppmw RSH-S) and 25 ppmw (for feed containing 15 ppmw RSH-S). The following by-products are expected to be produced the RFCC Light Gasoline Treater:

Spent Caustic & Waste Water to the Effluent Treatment Plant. 1.4.3.1.10 Propylene Recovery Unit (PRU) The Propylene Recovery Unit (PRU) is designed to recover high-purity propylene from the mixed C3 feedstock received from the RFCC. The propylene product is fed forward to the Polypropylene Unit (PPU). The PRU also produces a propane by-product stream which is routed to LPG product blending and storage.



1.4.3.1.11 Indirect Alkylation Units (InAlk) This Unit comprises three separate process units: a Selective Hydrogenation Process (SHP), a Nitrile Removal Unit (NRU) and an Indirect Alkylation Unit (InAlk) designed to maximise the production of high octane alkylate suitable for gasoline blending based on maximising octane-barrels. The feed to the units is the mixed butane/butene product from the RFCC. This stream is first processed in the SHP to remove dienes and then into the NRU to remove nitriles before passing to the InAlk unit where isobutylene is reacted with light olefins to yield iso-octane rich alkylate product. The hydrogen requirement for the SHP and InAlk units is taken from the Hydrogen Compression and Distribution System. The InAlk unit also produces a mixed C4s stream (unreacted butanes) which is sent to the LPG pool. The product of InAlk will meet the specifications of Alkylate and LPG (Butanes). The following by-products are expected to be produced in the InAlk unit.

Off-gas to the LRU or RFCC Amine Absorber; Waste water to Sour Water Stripper (Train 1); Oil contaminated water to Effluent Treatment Plant.

1.4.3.1.12 Hydrogen Manufacturing Unit (HMU)

The objective of the Hydrogen Manufacturing Unit (HMU) is to produce high purity hydrogen for the hydrodesulphurisation units; and for use in the Indirect Alkylation, Selective Hydrotreater, Polypropylene Unit, Tail Gas Treatment Units, Isomer and Tatoray within the NSRP Complex. The Hydrogen Manufacturing Unit (HMU) utilises steam-methane reforming of hydrocarbon feedstock (refinery fuel gas and LPG) to produce a hydrogen-rich gas product which is purified in a Pressure Swing Adsorption (PSA) to yield hydrogen with a minimum purity of 99.9 %vol hydrogen. The hydrogen product is routed to the RHDS unit with the balance of production distributed throughout the complex via the Hydrogen Compression and Distribution System (HCDS). The HMU generates a substantial quantity of high pressure steam from waste heat and this steam makes a significant contribution to the refinery steam balance. 1.4.3.1.13 Hydrogen Compression and Distribution system (HCDS)

The Hydrogen Compression and Distribution System (HCDS) receive high-purity hydrogen from two sources: the Hydrogen Manufacturing Unit (HMU) and the PSA section within the Catalytic Reformer (CCR) in the Naphtha and Aromatics Complex. In addition, a PSA unit shall be installed within HCDS which shall recover pure H2 from the RHDS & GOHDS H2 rich off-gases.

The objective of the HCDS is to compress and distribute high purity hydrogen to the following units normally at the required battery limit pressures:

Kerosene Hydrodesulphuriser Gas Oil Hydrodesulphuriser Selective Hydrogenation / Indirect Alkylation Units Isomar Tatoray



Normally the Hydrogen requirement to the Polypropylene (PP) Unit shall be met by the H2 from the CCR Patforming PSA Unit. The hydrogen treat-gas requirements within the Naphtha & Aromatics Complex (i.e. the Naphtha Hydrotreater and Isomerisation units) are fed directly by hydrogen-rich gas produced in the CCR, hence, these units are not normally served by the HCDS. 1.4.3.1.14 Sour Water Stripper unit (SWS)

The objective of the SWS Unit is to treat refinery sour water streams such that the quality of stripped water enables it to be reused as wash water within the refinery and/or discharged to the Effluent Treatment Plant for final clean-up. The sour gases (H2S and NH3) stripped from the sour water in the SWS are routed to the Sulphur Recovery Unit for further treatment.

Due to considerable difference in output and sources, the SWS is configured as two separated trains in order to prevent contamination from products and towards an environmental friendly process; the routings of the most significant sour water streams are indicated here:

SWS Train 1: Used to treat sour water production generated from CDU, LRU, NHDS, GOHDS, SRU/TGTU SWS Train 2: Dedicated RFCC (Figure 1.7)

To user

Effluent Treatment Plant Effluent Treatment Plant

Steam

Sour water Sour water

Steam

Sour gases to SRU Sour gases to SRU

SWS Train 2 SWS Train 1

Figure 1.7 Sour Water Stripper unit outline Input constituents and loading of sour water are presented in Table 1.7.

Table 1.7 Feed Sour and loading in SWS unit

Train 1 Train 2

Parameter CDU (kg/h)

LRU (kg/h)

NHDS (kg/h)

GOHDS (kg/h)

RHDS (kg/h)

SRU/TGTU (kg/h)

Total (kg/h)

RFCC (kg/h)

H2O 27,404 786 10,727 24,696 72,411 24,127 160,151 58,896 H2S 6 14 3 349 3,012 3 3,387 50 NH3 4 6 0.2 175 1,391 2 1,578 74 H2S ppm 20,513 850 NH3 ppm 9,560 1,250 Source: NSRP – LLC, June 2010

Products standard: H2S 10ppm; NH3 50ppm.



1.4.3.1.15 Amine Regeneration Unit (ARU) Sour steam and LPG contain H2S and NH3 at high concentration will be treated in amine absorber by methyldiethanolamin (MDEA) 40% of weight. There are 07 amine absorbers in the Complex. Each of GOHDS, RFCC and TGTU units has 01 amine absorber; 02 absorbers in LRU unit and 02 absorbers in high pressure and low atmospheric pressure RHDS. Amine Regeneration Unit (ARU) is designed to strip hydrogen sulphide (H2S) from the contaminated amine steam returned from amine absorbers/extractors located within the Refinery. Gases released from LTU tower and LPG are treated in amine absorbers to extract H2S and contaminated amine steam mixed in LRU unit and routed to ARU to treat. Acid gas (containing H2S) is routed to Sulphur Plant for producing Sulphur element. High quality regenerated solvent is returned to consumpt in the Refinery. ARU treats contaminated amine steam from absorbers in following unit:

Gasoil Hydrodesulphuriser Unit (GOHDS); Residue Hydrodesulphuriser Unit (RHDS); LPG Recovery Unit;

Note that RFCC off-gas absorbers/treaters will be also treated in ARU with RFCC and shown in design basis of RFCC designer/licensor. Tail gas will be also treated in Amine Absorber (Figure 1.8) with SRU and TGTU and shown in design basic of designer/licensor.

Steam Contaminated Amine

Off Gases

Treated Off Gases

Amine Regeneration Unit

Acid Gas to SRU

Amine Absorber for treating gases from GOHDS, RHDS…

Figure 1.8 Amine Absorber outline Properties and loading of contaminated amine steam and quality of output off gas are presented in Table 1.8 and 1.9.

Table 1.8 Constituent and loading of contaminated amine steam in ARU

Parameter Off Gas Absorber LPG Absorber GOHDS RHDS Loading (kg/h) 109,953 14,757 77,915 587,870 H2S (kgmol/h) 122.88 12.03 98.98 742.03

Source: NSRP – LLC, June 2010



Table 1.9 Quality of output off gas in ARU

Parameter % Weight H2S 90.53 SO2 0 NH3 0.06

Loading (kg/h) 35.144 Source: NSRP – LLC, June 2010 1.4.3.1.16 Sulphur Recovery Unit (SRU) and Tail Gas Treating Unit (TGTU) The objective of the Sulphur Recovery Unit (SRU) is to process acid and sour water stripper gases generated within the refinery to produce elemental sulphur. SRU and TGTU have designed capacity of 800 tons of sulphur/day, with sulphur recovery efficiency of 99.9%, SOx concentration in off gas of 150 mg/Nm3. Molten sulphur product is sent to the Sulphur Forming and Storage Facility. The SRU is configured as follows:

3 x 40% Claus trains; 2 x 80% TGT trains; 2 x 100% incinerator trains.

The acid gas feed to the SRU is taken from the Amine Regeneration Units (ARU) of RFCC and desulphurisation system in offgas, the sour water stripper gases from the Sour Water Strippers (SWS). Product sulphur will be stored in an above ground tank and exported to the Sulphur Forming & Storage Unit. The objective of TGTU is to recover the majority of the sulphur remaining in the SRU tail gas as H2S and return for reprocessing in the SRU. The treated tail gas is then sent to an incinerator (thermal oxidizer) to convert any trace sulphur remaining to sulphur dioxide before venting to atmosphere. Sulphur recovery and tail gas treater outline is shown in Figure 1.9.



Acid gas from SWS 1 & 2

Amine acid from ARU &

RFCC

Acid gas from FGD

SRU‐1

SRU‐2

SRU‐3

TGTU‐2

TGTU‐1

Incinerator 1

Incinerator 2

Sulphur liquid to SFU

Stack

Sulphur tanks A

33.3% for each SRU

320 tons/day

80% for each TGTU

640 tons/day

80% for each incinerators

640 tons/day

Normal operation Design capacity (SRU tail gas) (TGTU tail gas)

Sulphur tanks B

Figure 1.9 Sulphur recovery and tail gas treater

Properties and loading of feedstock in SRU and TGTU are presented in Table 1.10.

Table 1.10 Properties and loading of feedstock in SRU and TGTU

Parameter ARU SWS FGD

H2S (wt%) 90.53 50.55 0

SO2 (wt%) 0 0 98

NH3 (wt%) 0.06 26.43 0

Loading (kg/h) 35,114 6,077 1,000 Source: NSRP – LLC, June 2010 Main chemical reactions (*) in SRU – TGTU are as follows:

1) Pyrolysis phase: H2S + 3/2O2 → H2O + SO2 2) Catalyst transformation: 2H2S + SO2 → 3/2S2 + 2H2O (Claus Reaction) 3) Gas separation: 2NH3 → N2 + 3H2

CH4 + 2O2 → CO2 + 2H2O 4) TGTU: SO2 is transformed into H2S and absorbed by amine 5) Heater: 1/xSx + O2 → SO2

H2S + 3/2O2 → SO2 + H2O Note: (*) Source: New Pollution Control Regulations and Technologies (Air Environment– version 2008) published by Japanese Association of Environmental Protection in Industry Field.



1.4.3.2 Petrochemical Process Units 1.4.3.2.1 Naphtha and Aromatics Complex (NAC)

The Naphtha and Aromatics Complex (NAC) is designed to process a full-range naphtha feedstock to produce Paraxylene and Benzene products at purity suitable for sale, plus aromatic gasoline and isomerate streams suitable for gasoline blending. The design philosophy of the complex is to maximize economic Paraxylene production. The Aromatics Complex consists of the following process units:

Naphtha Hydrotreater (including naphtha splitter) CCR Platformer / CCR Regenerator section (incl. reformate splitter) Sulfolane (Aromatics Extraction) Benzene / Toluene Fractionation Isomar (Xylenes Isomerisation) Tatoray (Toluene Transalkylation) Xylene Fractionation Parex (Paraxylene Separation) Penex (Isomerisation)

The NAC feedstock is full-range naphtha produced in the LPG Recovery Unit. Fresh naphtha feedstock (and recycled raffinate from the Sulpholane Unit) is processed in the Naphtha Hydrotreater. Treated naphtha product is then sent to the Naphtha Splitter where it is fractionated into two streams: light naphtha as feed to the Penex Unit and heavy naphtha to the CCR Platformer. The latter is sent to the CCR Platformer and the resultant reformate is then routed to the Aromatics units for production of Paraxylene, Benzene and gasoline blending components.

The primary products from the Naphtha and Aromatics Complex are:

Paraxylene – sent to paraxylene product storage; Benzene – sent to benzene product storage; An isomerate stream – sent to gasoline blending.

By-products include:

A raffinate stream from the Sulpholane unit – which is totally recycled to the Naphtha Hydrotreater;

A toluene stream – can be produced, if required, for gasoline blending;

A C9/C10 aromatics stream (Aromatic Gasoline) from the Heavy Aromatic column overheads – to gasoline blending;

A heavy aromatics stream (C10+) from the Heavy Aromatic column bottoms – to refinery fuel oil blending;

LPG from the CCR Platformer – to the LPG Recovery Unit;

A hydrogen-rich gas stream from the CCR Platformer PSA unit – part of which is consumed internally within the NAC with the remainder routed to the refinery’s Hydrogen Compression and Distribution System.



1.4.3.2.2 Polypropylene Unit

The Polypropylene Unit is designed to produce Polypropylene from propylene feedstock and hydrogen.

Propylene feed is obtained from the Propylene Recovery Unit within the RFCC Unit. Normally hydrogen feed gas is supplied from the CCR Platforming PSA Unit.

The main product from the PP is polypropylene homopolymer. A minor purge gas stream is recycled back to the Propylene Recovery Unit.

Polypropylene product is bagged and loaded into containers on-plot for despatch by road to the dockside where containers are transferred to ships. 1.4.4 PLANT UTILITIES 1.4.4.1 Crude Oil Storage Tanks The Crude Oil will be loaded via 48” Sub-sea pipeline with flow rate of around 14,100m3/hr from the SPM to the refinery’s Crude Storage Area. Crude oil storage capacity: 300,000 - ton tanker may have loading capacity of 342,276 m3. There are 08 Crude Oil storage tanks with each capacity of 120,000m3 including 3.6 tanks for crude unloading, 3.4 tanks for CDU feedstock and 1 tank for back-up for off-line maintenance and inspection (Table 1-11). The maximum height of the tank should be restricted to 20 m and tank diameter is about 90 m. External Floating Roof Tanks will be used for the service.

Table 1-11 Total number of Crude Oil tanks Required for NSRP

Parameter Unit Capacity (m3)

Number of Tanks (120,000 m3/tank) Nos 8 Total Installed Capacity m3 960,000 Total Effective Capacity m3 768,000 Number of tanks for the parcel receipt Nos 3.6 Number of crude oil supply tanks (for CDU) Nos 3.4 Number of spare tanks Nos 1 Frequency of visiting ship Day/time 10.9 Shipment window Day 5.4

Source: FEED document provided by FW in October 2009 The Crude Storage facility provides capacity for 10 days operational demand plus capacity for simultaneous receipt of one crude oil shipment parcel. The 10 days window includes 02 days for continuously crude oil pumping to tank area, 02 days for water depositing, 01 day for dewatering and testing crude oil quality and 05 days for any delays in ship arrival (bad weather or operational delays).

Maximum liquid level is 90% of tank height and low liquid level (Dead Level) is 10% of tank height. So effective working capacity is (90%-10%) of tank capacity. Total nominal capacity required for unloading crude oil from VLCC is 427,845 m3. It is required 4 tanks for operation.



1.4.4.2 Product Tankage Farm 1.4.4.2.1 Product storage tank

Product tankage is based on storing the blended final product and exporting by means of Ship/Truck loading by providing a sufficient storing volume which will not hamper the product off take / Intake.

Ship loading pumps are provided for all product tanks and in addition truck loading pumps are provided for gasoline and diesel. The quantity and required capacity of product tanks are given in Table 1.12.

Table 1-12 Quantity and Capacity of Product Tanks

Storage tank Quantity of tank Type of Tank Total Working Capacity (m3) Gasoline 92 2 Floating roof tank 86,600 Gasoline 95 2 Floating roof tank 86,600 Jet fuel ship 3 internal floating roof tank 26,735 GO (Prem) ship 3 Cone roof tank 115,572 GO (IND) ship 2 Cone roof tank 75,500 Benzene 2 internal floating roof tank 16,641 PX (Para-Xylene) 2 internal floating roof tank 34,000

Source: FEED document provided by FW in October 2009

Provision is made to export fuel oil from the refinery Fuel Oil system when the FGD unit is shutdown or if fuel oil product is accumulating.

Provision to import Gasoline will be provided. Import is achieved by using the export line with bypass around product ship loading pump and will be routed to either 92 or 95 tanks depending on whichever is available. Facilities to send this for reblending gasoline in blender will be provided. 1.4.4.2.2 Product blending component storage tanks

Product Blending Component tankage stores the product components that are required for blending to final products.

Table 1-13 Quantity and Capacity of Product Blending Component Tanks

Storage tank Number of tank Type of Tank Total Working Capacity (m3)

Isomerate 2 Dome roof tank 22,025 Alkylate gasoline 2 Floating roof tank 17,114 Light FCC Gasoline 2 Dome roof tank 17,978 Heavy FCC Gasoline 2 Floating roof tank 19,129 Aromatics Gasoline 1 Cone roof tank with internal floating roof

tank 7,650

RHDS Diesel 2 Cone roof tank 33,106 Kerosene 1 Cone roof tank with internal floating roof

tank 8,900

Source: FEED document provided by FWL in October 2009



1.4.4.2.3 Intermediate Storage tanks

Inter-unit tankage stores intermediate products or supplies feedstock when downstream or upstream units are corrupted. These storages supplies for the unscheduled and emergency shutdowns, except residue crude and desulphurised residue crude tanks. The residue crude and desulphurised residue crude tanks provide ullage during shutdown of RHDS for annual catalyst change over besides supporting unscheduled shutdowns. The storage capacities for the intermediate products are based on anticipated unscheduled shutdown duration for the associated units and the impact of shutdown of these units on the remainder of the refinery. Quantity and required inter storage tanks are given in Table 1-14.

Table 1-14 Quantity and Capacity of Intermediate Storage Tanks

Storage tank Number of tank Type of Tank Total Working Capacity (m3)

Full range naphtha 2 Cone roof tank with internal floating roof tank

29,960

GO HDS Feed 4 Cone roof tank 34,275 Reduced crude/desulfurized crude

6 Floating roof tank 244,800

Desulfurized Heavy Naphtha 1 Cone roof tank with internal floating roof tank

12,032

Full Range Reformate, Light Reformate and Heavy Reformate

3 Cone roof tank with internal floating roof tank

31,000

Propylene 6 Sphere tank 15,873 Butane/Butene 6 Sphere tank 23,345 Propane/Butane 8 Sphere tank 21,464

Source: FEED document provided by FWL in October 2009 Tank levels are always maintained at about 50% level of working volume to provide ullage for upstream/downstream process units. It is understood that any unscheduled shutdown spanning as per the anticipated number of days can result in 50% turndown of the refinery. 1.4.4.3. Other Receiving and Storage 1.4.4.3.1 Catalyst and chemical storage

Chemical storage receives commercial caustic flakes/ beads, prepare and distribute (14.35 % weight) caustic solution to various refinery process units and utility systems.

The Unit supplies Caustic solution which is a widely used chemical in the refinery and petrochemical complex. Other chemicals and additives including but not limited to amines, inhibitors, hydrochloric acid, ammonia, sulphuric acid etc, are also consumed in a few units and their storage would be part of the corresponding unit and are not covered here. 1.4.4.3.2 Slop storage tanks

Slop tanks are used to receive the off-spec product from Refinery and Offsite facilities. Separate tanks are provided for straight run products and cracked products. Straight run product slop liquid is re-processed in the CDU (Crude Distillation Unit) and cracked slops are sent to the RFCC Unit (Residue Fluid Catalytic Cracker Unit) for re-processing.

The type of slop tanks are floating roof tank. The number and capacity of the slop tanks are presented in Table 1-15.



Table 1-15 Number and Capacity of Slop Tanks

Tank Number of Tank Type of Tank Storage Capacity

m³ Straight Run Slop Tank 1 floating roof tank 12,000 Cracked Gasoline Slop Tank 1 floating roof tank 12,000 Spare Tank 1 floating roof tank 12,000 Sour Water Storage Tank 1 floating roof tank 12,000 Total 48,000 Source: FEED document provided by FWL in October 2009 1.4.4.3.3 Sulphur forming and storage unit (SFSU) The objective of SFSU is to solidify the molten sulphur from the Sulphur Recovery Unit (SRU) and to stockpile, reclaim, transfer, weight and shipload the solidified sulphur. All the facility under this Unit will be located in the Jetty area. The molten sulphur will be supplied from the SRU located in the Refinery area. The product from this unit will be exported through a dedicated sulphur loading berth at the solid products export jetty. 1.4.4.4 Gas Recovery System There are 02 gas recovery system in the Complex. A system is designed to recover gas from tanks containing Isomer, light Naphtha FCC, Benzene, Paraxylene and gas released from RON92 and RON95 gasoline export process into tank trucks. Other similar gas recovery systems are designed to serve for export process into tankers. Operation of gas recovery system is based on physical absorption by activated carbon combined with absorption process by solvent to recover hydrocarbon. Gas released from absorption tower will not contain hydrocarbon and be emitted into atmosphere at safe location. At least 99.5% of hydrocarbon gas will be recovered by this system. 1.4.4.5 Fuel System Fuel gas generated from process units will be recovered by main fuel gas pipeline system and routed to high and low pressure fuel gas extractors. Based on economy and need of process units, fuel system of the Refinery will be divided into fuel gas system and fuel oil system. In normal operation, total volume of used gas is much more than generated gas. The shortage will be supplemented with LPG. Fuel oil system is designed to receive product flow of fuel oil, such as LCO from RFCC, Diesel from RHDS, CLO from RFCC, Diesel from GOHDS, Kerosen, AGO and heavy Aromatics, these flows are blended at different ratio to form specific fuel oil products, such as Refinery Fuel Oil (RFO), Ultra Fuel Oil (UFO) and Export Fuel Oil (EFO). Blending systems are installed to mix fuel oils. A seperated system used to blend RFO 0.24%S and UFO/EFO 1%S is located near fuel oil tank to supply to demand units. Fuel storage and distribution systems for each kinds of fuel are shown in Table 1.16.



Table 1.16 Fuel storage and distribution systems

Maximum Polypropylen case

Maximum Gasoline case

Fuel

Destination

MW ton/day MW ton/day LPG 356 670 136 256

GTG 294 555 104 196 HRSG 61 115 32 60

Process unit heater 0 0 0 0 Fuel gas Process unit heater 634 1,242 559 1,085 Fuel oil 0.24%S Process unit heater 0 0 77 154 Fuel oil 1%S 459 1,003 717 1,565

Ultra unit boiler 431 941 688 1,503 CO boiler 28 62 28 62

Total used fuel 1,449 2,915 1,489 3,060 Source: NSRP-LLC, June 2010

It is envisaged that blenders will be provided, but separate blenders to be provided for low sulphur (Refinery Fuel Oil) and for high sulphur fuel (Utility Fuel Oil) in the utility area near by corresponding tanks to meet the requirement, the typical blenders are as follows:

1. RHDS Diesel + RFCC LCO from storage are blended and stored in tanks. This will supply oil to GT and Refinery Heaters.

2. NAC Heavy Aromatics + RFCC CLO are blended and stored in tanks as Utility Fuel Oil. This will supply oil to

Utility Boilers.

Provision is made to export fuel oil via the jetty when the refinery has an excess of fuel oil or the FGD is shutdown. During start-up Refinery Oil products are not available from the refinery. In order to meet the start-up demand, imported diesel (via Diesel Oil Line) is used for GT/Refinery Heaters and imported fuel oil (via Black Oil Line) is used for Utility Boiler. Fuel gas from various process unit sources is collected via fuel gas collection headers and fed to High Pressure Knock-out drum and Low Pressure Knock-Out drum. Unsaturated high pressure gas is collected in the HP drum and saturated low pressure gas is collected in LP drum. Any droplets of liquid condensation that form in the pipelines will be removed from the gas in fuel gas-mixing / knock out drums. This liquid is flashed to the flare header. Crude Distillation Unit (CDU), Xylenes Fractionation (Aromatics Complex) and BT Fractionation (Aromatics Complex) will run normally on refinery fuel gas with provision for oil firing during Start up operations. Therefore, during Refinery start-up, as there is no fuel gas production from process units, all the gas only fired refinery furnaces are supplied by vaporizing LPG in to the Fuel Gas distribution system. LPG Vaporiser system with LPG Superheaters have been provided in the fuel gas system to meet the requirements of normal fuel gas demand and start up requirements.



1.4.4.6 Flushing Oil System

The flushing oil system will supply of flushing oil (typically Straight Run Gas Oil) to the Refinery Process Units and Utility Systems handling fluids with viscosity > 43 cSt @ 40 °C.

Flushing Oil is required for the following main purposes:

Flushing of equipment under maintenance Start up/ Shut down Unit Circulation

Flushing Oil for pump seal flushing systems and Instruments flushing would be provided by independent systems in respective units and are not considered in this basis. However, it is envisaged that a quantity of 10m³/hr will be continuously supplied to make up the flushing oil requirements for systems handling the Pump Seal and Instrument Flushing.

During commissioning and start-up, diesel will be provided from one of the GOHDS feed tanks as an alternate source of Flushing Oil. 1.4.4.7 Waste oil recovery, storage and pump systems Waste oil generated from process units and support constructions will be collected and treated in the Refinery. Waste oil generated from RHDS, NHDS, PENEX, CCR, Aromatic, flare system and export berths… will be collected to waste oil tank, then routed to crude oil distillation unit to process. Waste oil generated from RFCC and InALK will be collected to Catalyst Cracking Unit to process. 1.4.4.8 Power and Steam Generation System The purpose of the steam and power generation system is twofold:

To supply all electric power to meet the demands of the Refinery Complex; To supply steam to meet the demands of the Refinery Complex.

The refinery requires a segregated power generation system resulting in two electrical islands in order to reduce the refinery wide flare loads Power Generation

On-site electrical power generation is provided by the following sources: Gas Turbine Generators (GTG) Steam Turbine Generators (STG)

Refinery users are divided into two islands, namely Island -1 and Island -2.

System -1: 03 steam turbines – capacity norm of 35.6 MW/turbine. Total power demand in system -1 is 106 MW

System - 2: 03 steam turbines – capacity norm of 41.4 MW/turbine. Total power demand in system -2 is 124 MW

Plant of two gas turbine generator - Capacity Norm of 61.896 MW/turbine.



Steam Generation System The power generated from the STGs is insufficient to meet overall power demands and hence the balance power is to be generated by the GTGs provided in each island. HP and MP steam are exported from the STGs/ HRSGs to a common header from where they are distributed to the refinery complex. Condensate is generated in the STGs to balance the power demand, after the generation of HP and MP pressure levels. LP steam is in excess in the refinery and is used to augment the power generation from the HP-Condensing STG in Island-2. Condensate that is generated in STGs is cooled against sea water and sent to Demineralised Water plant for polishing prior to re-use. HP, MP and LP steam is used in the refinery complex for different purposes such as running steam turbine drives, providing heat to the process and also direct use in the process (for reactions, stripping etc.). Steam used in drives is exhausted to lower pressure levels based on overall steam balance. Steam consumed in the process is typically lost or recovered as sour water which is treated elsewhere in Sour Water Strippers. Steam used for process heating of exchangers is recovered as condensate at the respective pressure levels and is finally recovered as suspect condensate after flashing to recover LP steam. Suspect condensate is treated in the condensate treatment section of the Demineralised Water plant and is recycled as Demin Water to the Deaerators, from where Boiler Feed Water (BFW) is generated for supply to the Steam Generators. Any shortfall in the water supply to deaerator is made up by demineralized water.

On-site steam generation is achieved at two pressure levels – HHP Steam and HP Steam.

Conceptually, in each of the electrical islands, the steam turbine generator (STG) is the main generator. HHP steam is generated in an utility boiler package which then drives the STG. STG is operated between HHP and condensate, with pass outs at HP, MP and LP pressure levels to generate power. The utility boiler package is fired using high sulphur utility fuel oil, which is a blend of clarified oil and heavy Aromatics. Refinery fuel oil is also available as additional fuel for the utility boiler package. Flue gases from Utility Boilers are routed to flue gas Desulphurisation unit, where SOx content is limited to 65 mg/Nm3 before atmospheric discharge to stack. In each island, power is also generated in gas turbine generators (GTG), which are fired on mixed LPG as primary fuel with low sulphur GT fuel oil (a blend of light cycle oil and RHDS Diesel) as back up for start up. Each GTG is connected to a heat recovery steam generator (HRSG) which produces HP steam using the hot exhaust gases from the gas turbine. Supplementary firing is done in HRSG with LPG with a limitation of 850°C on burner duct exit temperature. Flue gas from HRSGs is routed directly to stack. 1.4.4.9 Nitrogen Supply System

Nitrogen Supply System generates Nitrogen for distributing to various users and Liquid Nitrogen for storage. The stored Liquid Nitrogen is vaporised at different pressure levels to supply continuous or intermittent demands. Nitrogen is required during start-up and shut down for purging and pressurising of systems, circulation during start up and cooling down during shut down, catalyst regeneration, blanketing during long shutdown and seal purging of compressors in the units. It is also required in the offsites for blanketing of storage tanks and purging of flare header. One of the critical consumers is CCR unit which requires an independent source of nitrogen supply at a higher pressure level.



This system consists of following units:

Nitrogen generation package is a cryogenic nitrogen generation unit. In this unit, atmospheric air is separated into an oxygen rich waste gas stream and a nitrogen product stream.

Liquid nitrogen storage tank & vaporizers store the liquid nitrogen product from the generation units is stored in the cryogenic storage tanks. The storage tanks serve as backup source of nitrogen for the refinery.

Liquid nitrogen cryogenic pump 1.4.4.10 Water Supply System Treated water will be supplied through pipeline system and metered flow at barrier of the Refinery, then routed to process water, domestic water and fire fighting water storage tanks. Designed capacity of this system is 1,560m3/hour.

Table 1.17 Water demand for the Complex

Capacity (m3/hour) Total supplied water 1,162 Domestic water 14 Process water 178 Demineralized water 970

Source: NSRP-LLC, June 2010

Based on initial estimation, fire fighting water inside the complex will be stored in separately tank with total volume of 17,220m3. The demineralisation plant is fed by service water and produces demineralised water for use within the refinery. The primary consumer is make-up to the boiler feed water system for steam generation. A Demineralised Water Tank provides buffer storage. 1.4.4.11 Intake system 1.4.4.11.1 Structure Intake system is a construction built along seashore with an intake channel routing water to water storage structure of the Refinery.

Intake channel is built at seashore from low crested breakwater paralleling to main breakwater in the North. At here, silt deposit process will occur and make the channel to be dredged periodically at suitable depth so that it does not affect on current. Sea water from intake channel will be routed to water storage structure.

Water storage structure consists of a slope section, intake forebay/sediment settlement and water channel.

Sea water from intake channel flows into the intake forebay by slope section. Intake forebay is transition area between intake channel and water drum. It plays as a settlement tank to reset suspended solids and needs to be periodically dredged. The in front side of intake forebay have pillars which route seawater flowing directly to water drum.

Flow through works: 154.000 m3/h Number of intake channels: 8 Number of drum screens: 4 Velocity of water through intake: 0.1 - 0.5m/s



Intake system includes following parts: Intake channel and low-crested breakwater: The intake channel is approximately 350m in length and 70m wide at the level of -7.92m (-6.00 m CD). It allows seawater to be extracted at all stages of the tide, including Lowest Astronomical Tide (LAT). The intake channel is bordered by the main harbour breakwater and a low-crested breakwater. The slopes of the breakwaters bordering the channel are constructed at a gradient of 1:2 and 1:1.5, respectively. Intake forebay: The forebay is the transition between the intake channel and the coarse and fine screens. It is designed with a finished floor level at -8m, again to allow the collection of fine sediment that has not settled in the channel. On the seaward side of the forebay there will be a 6m wide roadway supported on reinforced concrete columns. Intake screens: There are 8 screening channels, each fitted with stop gates, coarse screens. Each channel is 3.45m wide and each pair of channels feeds 1 x 10m diameter. Water quality is maintained by cooling water system. It is auto injecting of following chemicals:

Biocide Anti-inhibitor Anti-additivies pH adjustment substances

Demineral water is used to dilute chemicals and other dissolved chemicals which will be added at the output of cooling water system in order to mix entirely at the input of cooling water circulation pumps. 1.4.4.11.2 Cooling Water Cooling water is used for following system:

Indirected cooling system with fresh water; Condenser in Steam & Electricity unit, RFCC and RHDS; Sulphur extractor unit by absorbing SO2 and treating waste sea water. Sea water flow from Steam & Electricity

unit is used for this purpose.

Designed capacity of intake structure is 123,899 tons/hour (Table 1.18).

Table 1.18 Water demand for NSRP

Unit Capacity (ton/hour) Total input 100,677 Indirected cooling water

- Cooling water system 38,576 Directed cooling water

- Condenser of vapor turbine generator– System 1 21,631 - Condenser of vapor turbine generator– System 2 25,133 - Condenser of fans in RFCC 7,041 - Condenser of air compressors in RFCC 6,061 - Condenser of recirculated air compressors in RHDS 2,235




Cooling water is used for removing excess heat from process units within the refinery and petrochemical complex. It is supplied from a closed loop fresh water cooling water system which is indirectly cooled by sea water supply. The cooling water is cooled from 47°C to 34°C by transferring heat to sea water in the sea water exchangers. The sea water is filtered to remove fine particles before entering the exchanger where it cools the closed circuit. Then, it is returned to sea. Sea water outlet temperature is restricted to 40°C to be in compliance with environmental regulations. 1.4.4.12 Chemicals, Catalysts, and Packing Catalysts, absorbents, chemicals and similar materials are used to support refinery operations: some are consumed continuously while others are subject to periodic replacement. Appropriate stocks of these materials are held on-site to enable continuous refinery operation. Materials handled include:

Catalysts & inert support materials Lubricating oil & greases Caustic soda Transformer oil Amine (MDEA) Corrosion inhibitors DMDS Antifoam agents Activated carbon

List of main chemicals and catalysts is given in Table 1.19.

Table 1.19 List of Main Catalysts and Chemicals used for NSRP

Unit Material Purpose/component etc. Amount De-Emulsifer Chemical 97.08 Ton/year Caustic Soda Chemical 40 Ton/ year Anti-foulant Chemical 266.96

CDU

Corosion Inhibiotr Chemical 71.39 KHDS Ni-Mo catalyst HDS 20.1 Ton/4 year

Ni-Mo Catalyst HDS reaction 503 Ton/4 year Corrosion inhibitor Chemical 3994 Litter/ year

GOHDS

Fouling inhibitor Chemical 32448 Litter/ year Catalyst (ICR 161NAQ) HDM 30 Ton/ year Catalyst (ICR 161LAQ) HDM 30 Ton/ year Catalyst (ICR 161KAQ) HDM 298 Ton/ year Catalyst (ICR 167KAQ) HDM 243 Ton/ year Catalyst (ICR 170KAQ) HDM 175 Ton/ year Catalyst (ICR 131KAQ) HDS 446 Ton/ year Catalyst (ICR 153KAQ) HDS 418 Ton/ year Catalyst (ICR 156 SSA) Hydroprocess catalyst 63 Ton/ year

RHDS

DMDS Sulphiding agent 139 Ton/ Batch Nickel Passivator Chemical 14.6 Ton/ year corrosion inhibitor Chemical 40.8 Ton/ year Zeolite catalyst Cracking catalyst 19 Ton/ year

RFCC

Caustic Soda Chemical 5.5 m3/day



Merox WS catalyst Oxidizer (Liquid) 11.5 litter/day Catalyst (SPA-1) Solid phosphoric acid 118.5 m3/1.25 to 2 year Catalyst (S-100 ) Ni & Mo 185 m3/4 year

InAlk

Catalyst (H-15 SHP) Ni:for selective hydrogenation 15.8 m3/3 year Catalyst (KG55) silica alumina 1.61 m3/4 year Catalyst (KF647-3Q) Ni/Mo 3.22 m3/4 year Catalyst (KF542-5R) Ni/Co/Mo 3.22 m3/4 year Catalyst S-120 Co & Mo on Alumina support 44.8 m3/4 year Penex catalyst (I-84) Amorphous, chloride alumina 101.12 m3/5 year Penex chemical Perchloroethylene 38.2 Ton/3 month Penex chemical Caustic Soda 36 ton/week CCR Adsorbent (CLR-011) Activated Alumina 100.8 m3/6 month CCR Catalyst (R-264) Pt 0.25% for Reforming 194.8 m3/6 month Chloriding agent Perchloroethylen 117 ton/6 month Clay catalyst Xylene Fractionation 231 m3/4 to 6 month Parex Absorbent Zeolite 1186 m3/12 year Isomer Catalyst (I-300) Pt on zeolite 58.6 m3/4 year Tatoray Catalyst (TA-20) Zeolite catalyst 83 m3/5 year Sulforane chemical for Extractive distillation 231 t/initial make-up

NAC

Clay catalyst B/T Fractionation 80.8 m3/6 to 12 month PPU Catalysts and chemicals (Refer to detail list) HMU Co/Mo Catalyst HDS 20.9 m3/4 year Zinc Oxide catalyst Sulphur absorber 294 m3/4 year Nickel Oxide catalyst Prereforming 75.35 m3/2 year Iron/chromium oxide cat. HTS reactor 119.7 m3/4 year ARU MDEA Sulphur recovery 1300 ton

Catalyst (CR-35) Claus reaction 116.3 ton/5 year SRU Catalyst (CRS-31) Claus reaction 56.7 ton/5 year

TGTU Catalyst (TG-107) Scot Catalyst 76.57 ton/5 year Cooling water system Sodium Nitrate Corrosion inhibitor 147 ton/year All units which provide reactors Ceramic balls Catalyst support by contractor Source: NSRP-LLC, June 2010 Most of chemicals, materials and equipments will be transported by ship through sea way in the East of the Complex. Other materials will be transported by trucks on National Road 1 and Provincial Road 513. Appropriate storage and handling facilities are provided including mechanical handling systems for the receipt, segregation, storage and transfer of materials, secure warehouse facilities, stock control systems, safety facilities, etc. Bulk stocks are held in a central warehouse. Daily consumption is then distributed to on-site chemical stores located within the Refinery. The chemical supply system will provide caustic soda solution to various users in the Complex. Fresh caustic solution is received by road tanker and is diluted on-site prior to distribution to individual consumers. 1.4.4.13 Flare System Flare system is designed to discharge safely off gas generated from process units in the Refinery. Design of flare is based on following cases:



Separate incidents, e.g. output clogging of a system; Incidents occur in process units, e.g. loss of support sources; Incidents affect whole the Refinery, e.g. loss of electricity/support.

All potential discharge sources from process units and support area will be calculated in the flare design. In the Complex, electricity distribution system is divided into 02 separated systems in order to reduce total load of flare in case of loss of electricity. Initial height of flare is 180m with thermal radiation standard:

1. Thermal radiation in restricted area is 6.31 kw/m2 (API Standard). Minimum radius in restricted area is 60m to avoid injuring people in case of incidents.

2. Thermal radiation in limited area is 3.18 kW/m2. Radius in limited area is established in the Plant site. Common flare system consists of HC flare and acid gas flare: Hydrocarbon flare system (main flare)

Discharges from all relief valves (except Acid Gas Service) are routed to the HC Flare system. A separate small diameter HC Purge Flare is provided to dispose of the continuous purge and low flow discharges and the HC Flare is purged with Nitrogen with pilots ignited. The low level flaring will result in burn-back and damage to the tip if routed to the larger main HC flare. The design capacity of HC Purge flare is 10% of the design capacity of the HC Flare or AG Flare capacity whichever is greater. Flaring gas will be routed to the HC Purge Flare / HC Flare by maintaining the different head in the HC Purge Flare seal drum and HC Flare Seal Drum.

The HC Purge Flare is steam assisted to provide a completely smokeless flare. When sour gas is flaring, smokeless steam will be stopped to avoid flame out due to low calorific value of acid gas. Lighter Flare also use steam assisted to create a completely smokeless flare during maintenance period of HC Purge Flare Stack or other emergency situations.

The HC Flare and Lighter Flare are demountable and housed in the same derrick structure.

Acid gas flare system The AG Flare system disposes of hydrocarbon releases which are toxic, potentially corrosive or difficult to combust. These include streams containing appreciable quantities of hydrogen sulphide. Hydrocarbon discharges containing more than a nominal 10 percent (vol) of hydrogen sulphide are routed to this flare system. Input of this flare is from CDU, GOHDS, KHDS, PRU, SRU, TGTU, ARU and SWS units. The flared gas may have a low heat of combustion. Assist (supplementary) fuel gas is added upstream of the knock-out drum via flow ratio control to achieve an acceptable degree of combustion. The same control loop will be used to stop smokeless steam injection to the HC Purge Flare when acid gas is flaring at high rate. The flare is made of carbon steel. Receiving head is heated with steam to maintain minimum temperature of 1100C in order to reduce condensation and erosion or dregs. High temperature will support H2S dispersion process in case of blazing up. The system will be directly connected to supported flare to burn acid gas. During HC Purge Flare maintenance, acid gas will be routed to main flare. HC Purge Flare is designed as a sour flare stack with steam tracing and insulation to avoid corrosion from acid gas.



Figure 1.10 HC/AG flare system



1.4.4.14 Fire and Gas Detection and Protection System The Project fire protection system is based on the assumption that there is no outside help to the refinery and tank storage areas or the jetty and thus the fire fighting facilities on the sites will need to be self supporting. The fire-fighting system of NSRP will consist of:

HC, toxic gas, smoke, fire detectors and other fire alarm devices; Water Hydrants; Fixed and Semi-Fixed Foam Systems; Safety Showers.

1.4.4.15 Waste treatment system 1.4.4.15.1 Off gas treatment system 1. Flue gas desulphurization system with sea water

Purpose of flue gas desulphurization (FGD) is to remove SO2 out of off gas from boilers before release into atmosphere. Off gas must meet allowed limits, FGD system is designed with capacity of 943,000 Nm3/hour. 2. RFCC De-SOx and De-NOx system Purpose of this system is to remove SO2 and NO2 out of emission gas generated from RFCC before discharging. Treated gas must meet allowed limits. Treatment technology used for this system is as follows:

De-SOx unit: absorption by humid NaOH De-NOx: deoxidation by ammonia and catalyst (stable catalyst)

De-SOx and De-NOx systems will be presented in detail in Section 4 – Mitigation Measures. 1.4.4.15.2 Effluent Treatment Plant 1. Effluent collection system Waste water is classified, collected and managed up to their nature/feature by following system: Clean process water Clean water is disposed directly without treatment. Disposal and regeneration effluents from demineralization unit are considered as clean flow after neutralized and may be directly discharged through sea water circulation pipeline. Clean storm water (CSW) Storm water collected from areas of the Refinery is not contaminated in normal operation. Storm water drainage system is designed to meet disposal standard without treatment. Accidentally oil contaminated waste water (AOC) Surface effluents (rain water, cleaning water) collected from areas in risk of being contaminated. Drainage system has a preliminary cleaning tank designed to reduce treatment.



Continuous oil contaminated waste water (COC) All effluents having oil content over 10mg/l need to be separated oil and treated by biological method. Domestic waste water Having specific biological treatment plant. Besides, special effluents will be collected into specific system before routed to ETP, including:

Close Benzene contaminated waste water collection system in order to avoid dispersion of Benzene into atmosphere.

Spent caustic effluents collection system to moderate flow and prevent dispersion of H2S. Oil contaminated waste water collection system from bottom of crude oil tanks will connect to specific API

system to remove oil. This system will serve other tanks if necessary. Waste water from fire fighting activity will be also routed to AOC or CSW. All effluents from these systems will be temporarily stored in case of fire incidents, so they are kept in the Refinery.

2. Effluent Treatment Plant (ETP) ETP is designed to receive and treat effluents in accordance with Project Standards:

Effluents from process and support units in the Complex; Effluents from storage tank; Effluents from operation, maintenance and devices in administrative house area; Effluents from devices at habour area.

ETP is not designed to receive following flows:

Overflow clean water; Waste water from demineralization unit and other clean flows are considered as meeting standard.

Besides, ETP will treat a great number of waste water in hydrotest process, high contaminated waste water generated from irregular maintenance, fire fighting water and process water not meeting project standard will be required to access based on specific case. Designed capacity of ETP is 631m3/hour. Detailed treatment process and overall ETP site will be presented in Section 4 – Mitigation measures. Location of ETP is given in Figure 1.4. 3. Separated collection and treatment system for export berth Storm water from floor area will be routed to the sea through a slope. On port area, clean storm water is allowed to discharge directly into the sea. Overflow water may be contaminated by oil and waste water from equipment maintenance process at export berth will be collected in sumps. These sumps are enough large to contain the first contaminated water as well as overflow water in case of typhoons. Collected oily water will be treated before discharging into the sea or routed to main treatment plant (identified by the Contractor). Domestic waste water will be collected and treated by each batch before discharge.



1.4.4.15.3 Incinerator Purpose of the oil residue incinerator is to burn residue oil (cleaning water/sludge from API, CPI, FFU/DAF), biological and chemical sludges from tertiary treatment process (iron sludge and activated carbon), waste oil and plastic powder from PPU into suitable ash for disposal. Incinerator is designed to burn 57,360 kg dehydrated sludge and 2,000 liters waste oil and plastic powder in a day. 1.4.4.15.4 Waste storage area Waste storage area will be arranged by the Refinery for easy transport and storage of hazardous and non-hazardous wastes before delivering to approved waste management area. Waste storage area is designed in accordance with waste generation rate and maximum storage duration of 90 days. Additional storage area will be provided for hazardous waste untreated properly. Waste storage area inside the complex is sited near western fence and Coc mountain (Figure 1.4). 1.4.4.16 List of main equipments of the Refinery List of main equipments will be attached in separate annex of List of Equipments of the Project. At present, the e Project is in tender phase. After EPC contract is signed, the Contractor will implement detail design and choose equipment suppliers. NSRP LLC has committed that all equipments used for the Project are new, modern and provided by world-wide famous and prestigious suppliers. 1.4.5 OFFSITE FACILITIES 1.4.5.1 Marine Facilities The development of harbour is divided into three phases follows: Phase 1: A temporary construction jetty (TCJ) will be constructed. This facility will be used for the development of the refinery and thus for the import of future refinery equipment and material. Phase 2: The marine harbour elements will be constructed, comprising (Figure 1-11):

The north breakwater; Four berths (02 berths / jetty) for export of white products (2a, 2b, 4a and 4b); One berth for the export of LPG (3); Berthing facility for service vessels/tugs; One berth for transfer of sulphur (dry bulk) (1a); One berth for the transfer of polypropylene (containerized) (b); Harbour access channel and turning basin (dredged by Vietnamese Government); Harbour revetments; Navigational aids; SPM; Intake and outfall structure for cooling water.

After this stage, the harbour will be able to accommodate vessels up to 30,000 DWT.



Figure 1-11 NSRP Port Layout

The Nghi Son harbour layout comprises the following main elements: Onshore area (Refinery site); Main breakwater (north of harbour basin); Access channel (outer section, bend and inner section); Turning basin; Product berth areas (1, 2, 3, 4); Service (vessel) berths; Construction berths; Future developments (future jetties and breakwater).

Some main bathymetric information in the port area is summarized below:

Harbour basin: The depth contours run approximately parallel to the shoreline up to a depth of about CD – 9 m. The harbour basin (up to and including turning basin) will be built in depths ranging from about CD + 0 to CD – 5 m;

Main breakwater: The northern breakwater head is located at a seabed level of about CD – 5.5 m;

Access channel: The end of the access channel (adjoining the turning basin) is located in a natural depth of about CD – 4.5 m. The start of the access channel is located at a seabed level of CD – 13.2 m. From depths of CD – 9 m to – 13.2 m the depth contours are oriented more obliquely to the shoreline.



In the future, the largest vessel expected in the harbour will be a 50,000 DWT vessel. In the present design of the harbour layout, additional space reservation (e.g. larger required channel width) is taken into account. Additional capital dredging will be required for widening and deepening the access channel, turning basin and Berth 4. 1.4.5.1.1 Access channel

An access channel with 6,200 m length is designed to facilitate entry of vessels up to 30,000 tonnes. The access channel is split into two straight sections by a bend located at a distance of about 2.2 km offshore:

Outer channel section:

This is the section from deep water in west-south-westerly direction (247°) towards the harbour up to the bend. It has a length of approximately 4,375 m. Over the last 600 m the channel widens up to the required bend width.

Inner channel section:

In the bend the channel direction turns to the direction of 273°. From the end of the bend up to the turning basin the channel width is maintained equal to the bend width in order to avoid any alignment transitions in this section (i.e. narrowing from bend width to straight channel width and subsequently widening again into the turning basin). As the channel width of this straight section is larger than required, additional channel widening into the turning basin is not applied. The inner section length including bend is approximately 1825 m.

The access channel will have the following dimensions:

Inner channel length: 1,180 m Channel bend: 645 m Outer channel length: 4,375m Channel bend width: 150 m Radius of the bend: 1,215 m Channel width: 120 m Channel depth: -13.2m Overdepth: 1.0m

In the future the largest vessel will increase to 50,000 DWT. Consequently, the required nautical depth increases to CD – 16.2 m, channel width increases to approximately 150 m and additional capital dredging will be required. An over-depth of 1.0 m is recommended and applied in the design. This means that in principle maintenance dredging is not required in the first 4 years after completion of the port. Dredging quantity is estimated of 4,855,282 m3 1.4.5.1.2 Turning basin The centre of the turning basin is located at approximately N 19o 22’ 0.78”, 105o 47’ 56.24”E. The diameter of the turning basin is 360 m. The nautical depth of the turning basin is CD – 12.1 m. In the future the nautical depth of the turning basin will increase to CD – 14.85 m for the 50,000 DWT vessels.



An over-depth of 0.5 m is recommended and applied in the design of the harbour basin areas. This means that in principle maintenance dredging is not required in the first 04 years after completion of the port. 1.4.5.1.3 North breakwater

Breakwaters are used to create sheltered areas where marinas, ports or entrance channels are located. The breakwater function is to reduce waves in the sheltered area to an acceptable level.

The general characteristics of the breakwater are: • Length of the breakwater: 1,800m • Crest level: CD +9m • Crest width: 12m • Slopes of 1:2.5 • Average water depth of CD -3m • Average layer thickness of soil improvement of 5m • Primary armour layer thickness for the trunk (3.0-6.0 tonne rock): 2.4m • Primary armour layer thickness for the head (4.0-7.0 tonne rock): 2.6m • Secondary armour layer thickness (0.3-1.0 tonne rock): 1.2m • Quarry run core

1.4.5.1.4 Harbour revetments

Shore protection is anticipated alongside the shore, including underneath both jetties alongside the shore. Rock revetments protect the slope (from the sea bed up to the reclamation level) against erosion by wave action. 1.4.5.1.5 Berth pockets There are 07 product berths (Table 1-20) for exporting liquid products or dry bulk and containers. Five berths are located at a jetty with loading platforms. The two others are individual loading platforms. These berths shall provide all facilities and installations or safe and reliable operations at the required capacity. The berths shall be suitable for a range of vessels up to 30,000 DWT and up to 50,000 DWT in the future development.

Table 1-20 Dimensions of Berth Pockets

Berth pocket Length (m) Width (m) Nautical depth (m CD) 1a 203 42 – 9.25 1b 188 43 – 8.50 2a/2b 170 22 – 8.25 3 133 31 – 6.40 4a/4b* 252 (281) 50 (65) – 12.1 (14.85)

Note: * Based on 30,000 DWT vessels. Between brackets are the values based on the future 50,000 DWT vessel The areas between the berth pockets and the tuning basin must have sufficient depth to allow safe vessel maneuvering from and to the berths and avoid grounding. Similar as for the turning basin, an over-depth of 0.5 m is applied in the other harbour basin areas. Two jetties are envisaged alongside the shore: The first (berths 1a and 1b) is for the export of solids (sulphur and polypropylene) and the second (Temporary Construction Jetty TCJ) is temporary and will be used for the offloading of the construction materials for the refinery.



Three jetties are located in the harbour basin (jetties 2, 3 and 4) and a fourth jetty is optional (jetty 5). Jetty 2 is for small vessels, 3,000 – 10,000 DWT (two berths 2a and 2b), jetty 3 is for tankers that carry pressurised LPG, 1,000 – 3,000 DWT. Finally, jetty 4 (and the optional jetty 5) are used for the biggest vessels, up to 30,000 DWT (two berths 4a and 4b). Berth 1a/1b: are envisaged alongside the shore. Berth 1a (north) is designed to accommodate dry bulk carriers

exporting sulphur, ranging from 10,000 to 15,000 DWT. Berth 1b (south) is for exporting polypropylene, ranging from 5,000 to 10,000 DWT.

Berth 2a/2b: are use to handle gasoline, jet fuel, diesel, fuel oil, para-xylene and benzene. The tanker sizes range from 3,000 to 10,000 DWT.

Berth 3: shall be used for exporting LPG ranging from 3,000 to 5,000 DWT.

Berth 4a/4b: are used to handle oil product tankers, meant for the transport of white products. The products are gasoline and diesel. The tanker sizes range from 5,000 to 30,000 DWT.

Berth S2 (future expansion): is designed to handle oil product tankers, meant for the transport of white products. The tanker sizes range from 3,000 to 50,000 DWT.

Dredging volume The required dredging volume to the nautical depth and the overdepth at harbor basin is estimated of 5,512,531m3. Hence the total volume of capital dredging for harbor basin and access channel adds up to about 10.4 million m3.

1.4.5.2 Single Point Mooring (SPM) The Single Point Mooring (SPM) has been located 35 km from the shoreline to avoid dredging a very large approach channel and affect environmental sensitive areas (coral reef). Crude will be unloaded via 300,000 DWT tankers. The offshore element typically consists of a mooring and fluid transfer system (SPM), connected by means of a subsea pipeline to the facility onshore. The SPM mooring system enables the vessel to freely weathervane in response to the wind, wave and current conditions, thus enabling it to offload even under relatively adverse conditions. The SPM system which is a kind of Catenaries Anchor Leg Mooring (CALM) system, uses for imported crude oil from Very Large Crude Carrier (VLCC) tankers and sends to plant storage area via 48” Sub-sea pipeline. The design life of SPM system is 25 years. The SPM main components include the following facilities (Figure 1.12):

Mooring buoy; Anchoring System; Anchor legs; Pipeline End Manifold (PLEM); Floating Hose Strings; Under Buoy Hose Strings.



Figure 1-12 SPM main Components

The single point mooring (SPM), the riser from the SPM, and the subsea pipeline end manifold (PLEM) will be coated and cathodically protected. 1.4.5.3 Crude oil pipeline

Crude oil pipeline has been located to avoid the environmental sensitive area (coral reef) of Hon Me Islands (Figure 1.3).

Crude oil pipeline is a 48” double pipelines (distance between the pipeline is about 43.5m). The pipeline route starts at pig trap locations at the plant crude oil storage area and end at offshore SPM. Crude oil is transferred from tankers through the SPM to the double pipelines running towards the plant storage area. Total length of crude pipeline system is 35km in which there are 33.5km offshore and 1.5 km onshore. The pipelines are divided into three (03) sections as follows:

The onshore pipelines which will run along their subsea route, are buried.

Near shore sections of the pipelines route will be trenched and backfilled to protect the pipelines against human activities and weave/current forces.

Offshore pipelines will terminate at PLEM flanges to provide connection to the SPM. Onshore sections of the pipeline are buried. The pipeline pressure is designed against pipeline incidental pressure. Pipeline design pressure will be considered as a multiple of maximum allowable operating pressure MAOP with a safety factor not less than 10%. 1.4.5.4 Product Pipeline Product pipelines are used for exporting liquid products. The pipelines will accommodate on pipe bridge. The pipelines will be coated externally with two layers and put on pipeline rest.



There are 09 product pipelines (01 pipeline per product) for liquid product loading from the plant to the Jetties and 01 pipeline for the return of LPG vapour to plant. Based on product specification and exported volume through the jetties, product pipeline sizes (Table 1-21) are designed at 12” for LPG, 14” for jet fuel and Benzene, 16’’ for fuel oil and Paraxylene and 24” for Gasoline (92 & 95) and Diesel (Premium & Regular). 1.4.5.5 Ship Loading System Ship loading system is provided to export 95% of LPG, Gasoline, Diesel & Fuel Oil and 100% of remaining products by ships. Liquid products There are 11 dedicated single product loading arms and 12 shared loading arms are required. Loading Rates and Pipeline Sizes are given in Table 1-21.

Table 1-21 Loading Rates and Loading Ship Capacity

Product Loading

Rates (m³/h)

Product pipeline Size

(inch)

Normal Loading ship capacity (DWT)

Maximum Loading ship capacity (DWT)

LPG 600 12 1,000 - 2,000 3,000 Gasoline 92 3,000 24 3,000 - 30,000 30,000 Gasoline 95 3,000 24 3,000 - 30,000 30,000 Jet Fuel 600 14 3,000 -5,000 5,000 Premium Diesel 3,000 24 3,000 -30,000 30,000 Regular Diesel 3,000 24 3,000 - 30,000 30,000 Fuel oil 500 16 3,000 -5,000 5,000 Benzene 750 14 3,000 6,000 Paraxylene 1,200 16 5,000 10,000

Source: FEED document provided by FW in October 2009 All liquid products are to be transferred from the NSRP Refinery to the jetties in dedicated product pipelines. All product dispatch through jetty will be made directly by pumping from respective storage tanks at refinery. Solid products The solid sulphur from the bulkhall will be reclaimed and moved to the ship by the export conveying system (including sulphur export weigher) to feed to the ship loaders. Polypropylene will be received in pallets from refinery and will be exported by 10,000 DWT ships from solid export berth. 1.4.5.6 Product Truck Loading System The truck loading is designed for 5% of liquid products. The Product Truck Loading System is located inside the Refinery. The Truck Loading facilities are designed to achieve the following:

Receive finished products (LPG (future), Gasoline RON92, Gasoline RON 95, Premium Diesel, Regular Diesel and Fuel Oil (future)) from tanks within Product tankage area.



Load products into trucks using top loading /bottom loading (for LPG future) system.

Loading will be done for 12 hours per day and 6 days a week for LPG and 12 hours per day and all 07 days of a week for other products.

The truck size is required 16m3/truck for all products, except 20m3/truck for LPG in the future. Estimated number of trucks is required of 72 trucks per day. 1.4.6 Refinery Layout

Overview layout of the NSRP is presented in Figure 1.13 and arranged as follows:

Figure 1-13 Overview Layout of NSRP Refinery and Petrochemical Complex

Areas of facilities are assigned as followings:

1. Administration area: 14ha

2. Technology area: 88ha

3. Support area, flare and ETP: 41ha

4. Tankage area: 118ha

5. Processing/Packing area: 14ha

6. Other areas: 39ha

7. Barrier area: 10ha

8. Planting area: 49ha



Plot plan philosophy is as follows:

1. Process area Process Unit should be located on the good soil condition area in order to minimize the civil cost and

schedule. (e.g.; ARDS, GOHDS, RFCC)

The units which affect operating condition each other should be located near by in order to operate all units in short time.

To reduce the heat disbenefit by the heat dissipation and to reduce the cost of pipes, the associated units

are located near by.

The facilities which need the chemicals or catalysts on stream should be located along to the road to be able to access the vehicle easily. And the facilities which produce waste product are equally treated.

The road which is around process area should be designed straight for transfer heavy machines,

equipments and fire engines to be easy access. Process area requires around the process unit road. And also one main centre road needs for

maintenance, transfer large equipments and fire fighting. 2. Tankage area

Crude Oil tanks should be located on the northeast in order to minimize Crude pipeline between the tanks and the SPM.

Product tankage should be located on East side area in Area-B in order to minimize product pipeline

between the tanks and the Jetty.

Intermediate tankage should not be located far from the process area in order to minimize the pipeline between intermediate tankage and process unit.

LPG tankage should be located far from process unit to minimize explosion hazard.

Similar property tankage should be located in one dike in order to reduce total tankage number. Normally

similar property tankage is used common when tankage is maintained.

3. Administration area, Control building and Truck loading area

Administration and Control Building should not be located on down the wind from process area in order to avoid toxic from Process Area.

Administration and Truck loading area should face a public road in order to get easy access without

passing through the plant area.

Administration Area should be minimizing in order to reduce refinery total area.



1.4.7 PROJECT CONSTRUCTION It is anticipated that EPC Contract will be awarded to a Consortium of Contractors to undertake the Engineering, Procurement and Construction (EPC) of the NSRP Project. The Consortium will consist of a number of experienced international EPC Contractors well recognized as leaders in the EPC Contracting Industry. 1.4.7.1 Onshore Constructions Massive land development is being carried out by the Vietnamese Government to ensure appropriate quantity and quality of ground is available for the development of the Project. This includes relocation of dwellings, site filling and site preparation. The construction activities for these works are mentioned in other reports prepared by authorities so that they are not included in this EIA Report. There are no existing foundations or underground obstructions including rock formations in the plant site area. Soil improvement measures may be required prior to construction. Foundation for project consists of following types:

Major equipments, buildings and structures foundation will be piled; Minor equipments, pipe supports will be on ground bearing foundations.

For tankage area, construction method may be summarized as follows:

Tank foundations are to be prepared by the Civil contractor. The Civil contractor will present the prepared ground to the Tank contractor for review and acceptance.

The tank manufacturer will prepare pre-assembled sections of the tank, including roof, in a preassembly workshop away from the NSRP refinery site. Each pre-assembled section consists of flat plates which are formed and welded into circular courses of around 2.5 m each in length. Each course will be fitted with nozzles, ladder and platform clips etc. as required.

The preassembled circular courses and all other raw materials including piping, flanges, welding consumables, lining materials, painting materials etc are delivered to a lay down are at the NSRP site.

The bottom plate (floor plate) and annular plate are welded in situ, in sections.

The first circular course is lifted into place and welded to the bottom plate and annular plate in situ.

Each circular section is lifted into place and welded to the section below.

As the height of the tank increases, scaffolding is erected to provide access for welding and NDE of the circumferential joints and for fitting of piping etc.

The final top section and fixed roof or floating roof will be fitted.

Each circumferential and longitudinal weld will be subjected RT, UT, magnetic particle, and dye penetrate as required by the code and project requirements.

All external fittings, stairways, ladders, platforms, hand railing are installed.

Water Spray Cooling Systems, Tank Foam Systems, Tanks Roof Drain Systems, and Floating Roof Seal System are fitted and tested.

All internals, mixers etc are fitted.



Fill tank with hydrotest water and test with positive air pressure when required by code requirements.

Prepare the internal surfaces of the tank for lining and carry out lining per code and project requirements.

Prepare the external surfaces of the tank, prime and finish paint in accordance with project requirements.

Note: Different tank manufacturers will have varying methods for site fabrication of storage tanks. Fabrication method statements will be reviewed and agreed prior to tank manufacturer commencing work. The onshore section of the 48” crude inlet pipeline will include electrical isolation facilities at the refinery boundary interface and at the interface with the subsea section. All product pipelines connecting from the plant to the jetties are buried and coated externally with 3 layer polyethylene pipe coating systems. Each pipeline will have above ground isolation joints at each end and be provided with impressed current cathodic protection. Estimated number of equipments used in construction phase is presented in Table 1.22 and 1.23

Table 1.22 estimated number of equipments used in construction phase

Device Maximum quantity (piece) Average quantity (piece) Heavy crane and equipment 3 2 Chain roller and crane (200-600 tons) 6 4 Chain roller and crane (100-200 tons) 16 10 Mobile crane (up to 100 tons) 35 23 Transport truck and bulldozer 15 10 Unloading truck 10 7 Shovel 12 8 Excavator 25 17 Water tanker 8 5 60-seat bus 183 122 Others 150 100

Total 463 308 Source: Technical Document No.3550-8710-PR-003 provided by FWEL, August 2009

Table 1.23 Estimated number of soil diggers

Device Maximum quantity (piece) Average quantity (piece) Unloading truck 254 170 Excavator 48 32 Bulldozer 51 34 Roller / Press 32 21 Grader 10 7 Watering cart 30 20

Total 425 284 Source: Technical Document No.3550-8710-PR-003 provided by FWEL, August 2009



1.4.7.2 Offshore Construction Crude pipeline system The pipeline construction methodologies are much different between offshore pipeline and shore approaching. For offshore crude pipeline, following procedures are applied:

Pipe delivery and preparation including field joint coatings, cathodic protection, line pipe delivery to the barge and preparation for welding;

Pipeline Fabrication: The work stations are arranged approximately every 12m along the side of the barge, matching the length of individual pipe sections such that a welded joint can be found in every station;

Pipelay operations including overbend control, sagbend control and buckle detector;

Initiation of pipelay including pipely startup and dead man anchor start-up.

For shore approaching, the laybarge will set up over the right-of-way centreline with its stern towards the beach. This will depend on the laybarge draft and its operation period. Dredging may be carried out to provide an approach channel for the barge so it can come closer to the shore. Especially, shallow water anchor handling vessels may be used to set the barge's anchors. Main procedures for shore approaching include as below:

Trenching and backfilling Pipe pulling operation Anchorage construction (for pull-to-shore)

PLEM tie in Tie in activities at the offshore end of the pipeline will depend on the installation phase of the SPM and PLEM. Main procedures are applied for PLEM tie in as follows:

Lay-down Near PLEM

It is important to ensure that the end of the pipeline lands on the seabed at the target location. The engineering design and barge positioning systems will control the approach direction of the pipe route such that the heading of the pipeline at lay down is correct. It then remains to ensure that the length of pipeline laid is such that the end of the pipeline arrives in the right place. This is achieved by using the laybarge navigation and positioning systems to accurately monitor the location of the barge.

Lay-down Head

The lay down head for the oil pipeline is designed to take the full pipeline test pressure. The 48” lay down head will be fitted with valve and check valve. This arrangement will allow air from the pipeline to escape. However, it will prevent seawater from the outside to enter the pipeline. During lay down of the pipeline the valves are closed.

Spool Tie-in

The spool piece and the PLEM will be connected using flanged joints. After flooding and any testing of the pipeline in accordance with project requirements, the flanged lay down head will be unbolted and recovered to the surface. Divers will take accurate measurements between then pipeline end flange and the PLEM tie-in flange.



Northern breakwater

A land based construction method is considered most likely for the construction of the breakwater. The core of the breakwater is constructed using dumper trucks in a land based construction method. Starting from land, trucks dump their load into the water. Excavators are used for rock placement and shaping. The construction seawards is continued using the already placed section as construction road. The armour layers of the breakwater are placed by large land based cranes.

H

arbour revetments

Rock armour is installed at the slope for protecting, in different layers. The largest rock is the primary armour layer of the revetment while the internal layers are appropriate sized to prevent migration of underlayer material through the armour layer. The core and the filter are made of granular material (quarried rock).

The revetments are built using a land based construction method. The rock for the revetments is placed by long reach excavators or cranes from the new reclaimed/profiled strip of land. Approach channel and harbour basin

It is necessary to dredge the approach channel and harbour basin in order to make it suitable for navigation of vessels to be accommodated (3,000 up to 30,000 DWT).

The equipment for dredging is cutter suction dredger (CSD). This device has a cutter head at the suction inlet, to loosen the sea bed material and transport it to the suction mouth. The cutter can be used for hard surface materials like gravel or rock. It can dredge in willow water. The dredged material is usually sucked up by a wear-resistant centrifugal pump and discharged through a pipe line or to a barge. Jetties

The Construction Jetty is currently estimated to be 300 metres wide and will include one or more, finger jetties to accommodate a number of flat top, low draft, barge carrying bulk cargoes.

A marwilling area, approximately 300 metres wide, will be constructed immediately behind the construction jetty to allow expeditious offloading and turnaround of ships and to consolidate materials and equipment for transportation to site.

Haul roads will be constructed from the construction jetty to site for the transportation of materials and equipment to site, and will be designed and constructed with heavy and large loads

Both jetties 1 and the temporary construction jetty (TCJ) consist of a deck on piles extending from the shore. Underneath the deck, the slope to the shore is protected by a rock revetment.

The three jetties that are not attached to the shore consist of an approach bridge, a jetty head and berthing and mooring dolphins. The jetty head (also called the platform) and access bridge structures mainly consist of a concrete deck founded on (most likely steel tubular) piles.

Marine based construction is considered most likely for the access bridges given the size of the spans. For the platforms the length of the spans is considerably smaller, a land based construction method is possible.

The piles of the jetties (both access bridges as platforms) are driven into the sea bed using floating equipment. This floating equipment consists of a rig with a diesel of hydraulic pile hammer and an additional crane to lift the piles into position for the piling crane.



1.4.7.3 Supply source of constructional materials

As mentioned in the scope of this report, all activities of compensation, site clearance and leveling are carried out by the Vietnam Government and it is out of scope of this EIA. Materials for site leveling are taken from borrow pits which is nearby project area (as Chuot Chu, Dong Vang montains, etc.). The major exploitation equipment is Excavators and graders. Transportation mode is by trucks of 10-15 tons.

In the construction phase, EPC contractor will select suppliers of chemicals, materials and equipment for the project, so NSRP-LLC can not get detail information at this stage. Almost chemicals, materials and equipment will be transported by ships through eastern project side. Other materials will be transported by trucks through national road 1A and provincial road 513. 1.4.7.4 Accommodation Facilities for Construction and Operation Workers

Currently, there is no emerging philosophy for NSRP to develop such facilities as early works for free-issue to EPC Contractor and its Construction Subcontractors. Estimated number of labour force in construction and operation phases will be presented in Table -24.

Table 1-24 Estimated number of employees working for NSRP

Construction phase (person) Work force Average Maximum

Operation phase (person)

Direct and indirect labour 21,862 32,795 1,700* Source: Technical Document No.3550-8710-PR-003 provided by FWEL, August 2009 Note: *1700 employees in operation phase include: 900 persons managed directly by NSRP LLC; 600 persons managed by NSRP LLC’s Contractor and 200

international specialists. The currently estimated total manpower figures for EPC, Construction Subcontractors, NSRP and its PMC are nearly 33,000 at peak and the requirement for space to accommodate this number of persons is estimated to be 730,000 m2. The optimum location of accommodation camps is driven by a number of key considerations, including topography and suitability of available land, distance from Site, QRA issues associated with the introduction of hydrocarbons at Site during commissioning and later and safety and difficulty issues associated with routes and roads.

EPC Contractor is responsible for building accommodation camps as requirement of NSRP LLC. Accommodation Camps will include, but not limited to, the following:

Temporary access and egress roads. Temporary lighting. Drainage Facilities. Security gatehouses and associated facilities, including road and pedestrian barriers, fencing and lighting.. Parking areas for mass transportation buses, cars, motobikes and bikes. Kitchens, Canteens and Mess Halls. Camp Management offices. Sleeping quarters. Bathrooms and toilet facilities. First-Aid and Medical Treatment Facilities. Fire-Fighting. Emergency Response and Evacuation Facilities, including vehicles, Temporary Utility Distribution Facilities for electrical power, potable water and telecommunications.



Potable Water Storage Facilities. Waste Water and Sanitary Sewage Collection, Treatment and Disposal Facilities.

An accommodation is being built in Xuan Lam – Nguyen Binh Communes with area of 25ha by NSRM; and 15km far from the Plant. NSRP LLC will hire this accommodation to serve for the staff in construction and operation phases. 1.4.8 CONSTRUCTION SCHEDULE NSRP aims to have the mechanical completion of the refinery and petrochemical complex in the year 2013. Duration for the FEED work is estimated to be 16 months from the effective date of FEED contract to the completion of FEED package including total cost estimation and preparation of EPC-ITB documents. The overall project schedule is shown in Figure 1-25.

Table 1-25 Overall Project Schedule

1.4.9 TOTAL CAPITAL AND ESTIMATED COST FOR ENVIRONMENTAL TREATMENT

AND MONITORING FACILITIES Total project capital: approximately 6 billion USD.

Estimated cost for environmental treatment and monitoring facilities including:

Invest and install air pollution control: 225,500,000 USD Invest and install anti-noise system: 500,000 USD Invest and construct effluent treatment plant (ETP): 110,000,000 USD Invest and construct environmental monitoring system: 325,000,000 USD

Implementation cost for environmental monitoring program of the Project is estimated as follows:

Construction phase: 100,000 USD/year Operation phase: 100,000 USD/year

Project management mode: by Project owner

Project implementation time: project comes into operation in 2013.



Section 2.

NATURAL ENVIRONMENT AND SOCIO-ECONOMIC CONDITION

This section presents briefly existing natural environment and socio-economic condition as well as biological resources at the project area and its vicinity via desk literature, survey and investigation on Metocean, natural resources and socio-economic situation. In addition, this section shows the analytical results of air, water, groundwater, sediment quality, biological parameters at the project area and its vicinity. These information are baseline data for environmental monitoring program as the project comes into construction and operation phase. 2.1 NATURAL ENVIRONMENT CONDITION 2.1.1 OFFSHORE 2.1.1.1 Marine Topography and Geology Coastal topography features in Nghi Son area Coastal topography in Nghi Son area is rather even and flat with small and narrow plains interspersed by mountain blocks as Tron island, Lach Bang cap, Nghi Son island… Shape of seashore is curved toward the land. Specific dynamic of this shape is mainly caused by waves creating sand dunes along the coast. Development of coastal topography in this area is based on structural foundation of new tectonics Viet-Laos which belongs to fold curl PZ-MZ Viet Laos zone. Coastal side is sloping and leaning to the East with average depth of – 17m, deepest area is hollow range in the West of Vang island spreading in North-South direction, with width of 500 – 1,000m and depth of -29m. Away from the seashore by 14.5km is Hon Me archipelago with many small islands, the biggest island is 17 km2 in area namely Me island. Sediments created on surface of the seabed is clayey sand, fine sand; area nearby Hon Me island have sediments commingled by organisms (coral) with thickness of 1.5 – 2m [14]. Seabed topography in harbour area Results of Coastal and Marine Geology is drawn from several boreholes in the port area, near berth, near access chanel [Ref.1] shows that: Soil types in harbour basin

Upper layer below seabed, comprising loose to medium dense, fine to silty sand, has a varying thickness of 2 to 5.5 m;



The layer below comprises mainly stiff to very stiff clay. At the zero meter depth line this is stiff sandy clay to stiff clay.

Further offshore a small layer clayey sand is encountered a top the clay layer;

Underneath, medium dense silty sand is present down to depths which are irrelevant for dredging.

Soil types in harbour access channel The overall soil types in the access channel to the harbour at borehole AC154 are the following:

Upper layer below seabed, comprising medium dense silty sand, has a thickness of about 2 m; The layer below (3 m) comprises firm sandy clay; Then a layer of stiff clay is encountered (5.5 m); Underneath, medium dense silty sand is present down to depths which are irrelevant for

dredging.

Figure 2.1 Rough indication of cross shore soil profile Hon Me archipelago in Nghi Son Gulf include Hon Me, Hon Mieng, Hon So, Hon Bung, Hon Hop, Hon Vat islands and some other small islands. Hon Me island is the biggest one, with width of 2.27km in East-West and North-South direction. The highest top of Hon Me island is 251m in height. This archipelago creates a natural wall preventing Nghi Son island from a partial force of waves in the East and Northeast direction. There is a hollow basin in this area with natural height of -30m to -32m, radius of 200-300m and 12.5km far from the shore. In the North of Hon Me island, depth is -20 to -22m and gradually shallow with natural height of -18 to -19m. Harbour system is located in the North of Nghi Son island and the North of an existing cement jetty. Harbour is in front of the Complex. Harbour access is in East and Northeast, along offshore area of Hon Me island. SPM is located under natural sea water level, in the East of Hon Me island and 33.5km far from harbour position.



Seabed topography along crude oil pipeline is sloping gently, 600m far from the shore but the depth is only -3m. Seabed sediments along the route are mainly alluvium sand. According to survey results of seabed topography in NSRP harbour show that:

Main breakwater: starts from the shore (CD+3m) to the crest at seabed in depth of CD-5.5m.

Harbour basin: boundary lines run parallel with the seashore at CD-9m. Harbour basin including turning basin will be constructed at a height of CD+0 to CD -5m.

Access channel: final part of access channel (bounded with turning basin) locates in area of

CD-5m in depth. First part of access channel locates in seabed area in depth of CD-13.2m. According to research results of seabed sediments [15], sediments from seabed to depth of -10m are mainly sands, stiff clay layer locates in depth of CD-20m to CD-40m and under CD-50m. Layers of sand are mainly fine and have similar particle size distribution. Plastic level of stiff clay layer under CD-50m decreases gradually. Technical geology survey results show that surface soil layer is about 2m in thickness with very loose sandy clay and bottom layer consists of very stiff clay. 2.1.1.2 Bathymetric condition 1. Wave regime feature at Hon Ngu station [2] Thanh Hoa sea in general and Nghi Son – Hon Me in particular locate in Tokin Gulf and are seashore suffered from many typhoons in year. Wave condition in this area is the same as Hon Ngu island. Wave direction According to observed data at Hon Ngu station (during 1961-2007), sea waves exist in this area in many directions and different frequencies. Frequencies of waves moving in the North (16.2%) and the Northeast (15.9%) are highest; and lowest in the West (5%) and the South (1.5%). Waves in the East and the Southeast have frequency of 6.3% and 9.1% in respectively.

Table 2.1 Wave height in directions at Hon Ngu station during 1961-2007

Direction Height (m) E NE N NW W SW S SE

January H max 3.00 3.4 3.50 1.80 1.00 1.1 1.7 3.0 H average 0.76 0.96 0.73 0.61 0.65 0.77 0.67 0.56

February H max 2.10 3.80 6.30 2.10 1.50 0.50 1.30 1.50 H average 0.70 0.91 4.03 0.65 1.00 0.50 0.53 0.53

March H max 6.00 3.00 2.30 2.00 0.50 0.63 0.50 1.30 H average 3.87 0.72 0.54 0.55 0.38 0.46 0.41 0.58

April H max 3.40 6.00 3.00 1.00 1.00 1.35 1.50 1.70 H average 0.70 2.16 0.56 0.36 0.50 0.51 0.58 0.60



Direction Height (m) E NE N NW W SW S SE

May H max 2.30 3.40 6.00 1.50 1.00 1.50 13.0 2.00 H average 0.65 0.66 0.52 0.51 0.43 0.43 0.53 0.56

June H max 2.10 3.00 2.80 2.00 1.00 1.50 1.30 1.50 H average 0.52 0.65 0.49 0.47 0.46 0.50 0.56 0.55

July H max 1.70 3.00 2.50 1.90 1.00 2.00 2.20 2.10 H average 0.65 0.76 0.63 0.57 0.52 0.47 0.56 0.55

August H max 3.00 6.00 3.60 2.30 1.25 1.25 1.30 2.50 H average 0.63 0.76 0.63 0.55 0.42 0.40 0.51 0.49

September H max 4.00 6.00 6.40 5.76 1.36 1.80 2.25 2.50 H average 0.73 0.98 0.72 0.66 0.50 0.48 0.58 0.59

October H max 5.60 7.50 7.50 3.28 1.50 1.30 6.00 5.00 H average 0.78 1.11 0.89 0.69 0.44 0.51 0.87 0.71

November H max 2.50 3.80 4.00 2.50 0.75 0.50 1.50 2.10 H average 0.79 0.98 0.91 0.65 0.54 0.50 0.65 0.66

December H max 2.00 3.50 3.50 2.00 1.00 0.00 0.75 0.80 H average 0.68 0.95 0.92 0.63 0.56 0.00 0.43 0.48

Year H max 6.00 7.50 7.50 5.76 1.50 2.00 6.00 5.00 H average 0.96 0.97 0.96 0.58 0.53 0.46 0.57 0.57

Source: Report of Hydro-Meteorological at Nghi Son and Hon Me Island [2] Wave height Average wave heights in area vary in range of 0.5 – 1.0m. According to statistical data for years, waves in the North and the Northeast have average height of 1.0m and maximum value is 7.5m. Waves in the West and the Southwest are minimum with average height of 0.5m and maximum height of 2.0m. Waves in the South and Southwest is rather high with average height of 0.6-0.7m and maximum value of 5.0-6.0m. Maximum wave heights, rare frequency with the return periods of 5, 10, 20, 30, 50 and 100 years Referring to statistical data of wave regime at Hon Me station during 1961-2007 shows that:

Wave height of 2.0 – 2.5m: occur frequently. Wave height of 5.5 – 6.5m: unusual, frequency one of 10 – 30 years. Wave height of 7.0m: frequency one of every 50 year. Especially, waves at height of 8.5m or more: very rare, frequency one of every 100 year.

Dominant high waves are mainly in North and North-Northeast directions. Other wave directions in surveyed area are lower frequency than above directions. The highest waves often occur in typhoon season (May to October), especially in July and August.



Wave frequency Above results show that in winter, dominant waves in North and Northeast direction occur with

frequency of 50%. Wave height of 1.0 – 2.0 occupies about 30%. In the summer months, dominant waves are in Southeast and Southwest with frequency of 30%

and 15% at respectively. Waves in these months have height of 1 – 2m and frequency of 30 – 35%. According to wind roses data, it may consider that in January, February and March, waves in

surveyed area are mainly in calm conditions and have frequencies of 37.7%, 34.9% and 46% respectively. Dominant wave directions in these months are North and Northeast. In the summer months, waves are calm at high frequency of 50 – 55%, with popular direction of Southeast and Southwest, but only 2 – 3% in the South.

2. Tide

Presently, there is not available measurements data of water level at Nghi Son area. Therefore, water level data of this area has to base on two nearby Hon Ngu and Van Thang (50-60km) stations (Figure 2.2). Table 2.2 is given tidal data of Hon Ngu station [Ref.2].

Figure 2.2 Hon Ngu station location



Table 2.2 Tidal data at Hon Ngu station

Parameter Annual Tidal Level1 (m)

Statistical Tidal Level 2 (m)

Highest astronomical tide, HAT 3.07 3.10

Mean high water spring, MHWS 2.81 2.69

Mean high water, MHW 2.50 2.42

Mean sea level, MSL 1.72 1.74

Mean low water, MLW 0.73 0.85

Mean low water spring, MLWS 0.35 0.53

Lowest astronomical tide, LAT 0.00 0.17 Source: Source: Report of Hydro-Meteorological at Nghi Son and Hon Me Island [2] Notes: 1. This data represents data derived from the harmonic and statistical analysis of the usable/reliable 1 year

observations in 1972 and world tidal model data.

2. This data represents long term averages and is derived from the harmonic and statistical analysis of the usable/reliable 18.6 years of water level observations and world tidal model data.

Preliminary conclusions are drawn as below:

Tide has a diurnal regime with one high and one low water per day.

Tide also displays a spring-neap cycle of approximately 14 days.

The preliminary water levels at Nghi Son are:

- HAT 3 – 3.5 m +LAT

- Spring tidal range is in the order of 2.5 m

- Mean tidal range is in the order of 1.75 m

Specific sea level Specific sea levels in Nghi Son Gulf are based on measured sea levels at Hon Ngu station (Table 2.3).

Table 2.3 Sea levels at Hon Ngu station during 1961 – 2001

Month Parameter

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Year

HMean 183 180 174 175 175 174 175 183 199 209 203 190 185

Hmax 306 307 308 304 327 303 331 362 368 365 346 336 368

Hmin 21 26 36 28 26 4 12 1 46 63 45 26 1

Source: Report of Hydro-Meteorological at Nghi Son and Hon Me Island [2]



An approximation is used to define characteristics of monthly and annual sea water levels in Nghi Son gulf. Annual average sea water level is about 188cm, the maximum is 374cm and the minimum is about -1cm. Sea water level get maximum value in storm season and predominant period of Northeast monsoon season; and the minimum value is in Southwest monsoon season.

Table 2.4 Characteristics of sea level in Nghi Son gulf

Month Parameter

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Year

Haverage 186 182 176 177 177 176 177 185 201 212 206 193 188

Hmax 311 312 313 309 332 308 336 368 374 371 352 342 374

Hmin 19.7 24.8 35 26.8 24.8 2.31 10.5 -0.8 45.2 62.6 44.2 24.8 -0.8 Source: Report of Hydro-Meteorological at Nghi Son and Hon Me Island [2] 3. Current regime

Current velocity in project area is not strong and in range of 0.1 – 0.3 m/s. In this area, current is obviously affected by tide and strongly changed by space. In the spring tide, current velocity in some positions may get value of 0.8 m/s. Dominant current direction in the winter (Northeast monsoon season) is from the North to the South. In the summer season (Southwest monsoon season), main direction is from the South to the North. The following observed current data of Tedysouth 2003 shows that:

Current velocity in project area (nearshore) (Station V6, Figure 2.3) is not strong and in range of 0.1 – 0.3 m/s;

Offshore average current velocities (Station V1, Figure 2.3) seem to be limited to 0.4 –0.5 m/s;

In spring tide, current velocity in some positions may get value of 0.8 m/s;

The major current direction in the Winter season (Northeast monsoon season) is from the North to the South;

In the Summer season (Southwest monsoon season), main direction is from the South to the North;

The nearshore currents are apparently influenced by contraction around Nghi Son island.



Figure 2.3 Wave data stations - NSRP Apparent scour holes indicate the occurrence of large current velocities near the bed which do not appear in the two weeks of observations that are available at present. Briefly, it can be stated that the undisturbed, tide-driven currents are weak to moderate up to 0.6 m/s. There are indications, however, of larger (surface) current velocities that are likely to be related to contraction of the current around obstacles and to wind effects. Especially during typhoons strong wind-driven currents may occur. For the design a current velocity of 0.6 m/s shall be used. 2.1.1.3 Extreme climatic conditions 1. Tropical storm The paths of the typhoons in gulf of Tonkin area as recorded in the period of 1951- 2007 are presented in Figure 2.4.



Figure 2.4 Cyclone tracks 1951-2007 for gulf of Tonkin The maximum radius of the 30 kts isotach of tropical storms that have occurred in the gulf of Tonkin is typically between 50 and 200 km with maximum values up to 300 km. The maximum radius of the 50 kts is smaller with typical values between 20 and 60 km. 2. Cyclone at Nghi Son region The number of tropical storm centers passing by Nghi Son within a certain distance R in the period 1951 – 2007 is summarized in Table 2.5.

Table 2.5 Number of cyclone centers passing Nghi Son gulf

Cyclones Typhoons

Radius Total Per year Total Per year

0.5 56km 1.0 111km 1.5 167km 2.0 222km 2.5 278km

21 50 89

117 149

0.4 0.9 1.6 2.1 2.6

5 11 24 30 35

0.1 0.2 0.4 0.5 0.6

Source: Report of Hydro-Meteorological at Nghi Son and Hon Me Island [2] Note: Observation in period 1951 - 2007 The result from Tabble 2.5 show that every year about 02 cyclones directly hit the Nghi Son area and that once every two years a typhoon directly hits that area.



Local cyclones may not necessarily be responsible for the largest waves in a particular. Very distant cyclones may have more profound effect on the wave states. The distribution of the residence time of cyclone centres is in the 2.5° area. The majority of the cyclones in the last 57 years had a residence time smaller than 40 hours. These residence times are the periods that the cyclones will be directly affecting the downtime of the SPM system. The periods of indirect effect - e.g. a period with relatively large wave heights - is likely to be longer. 3. Sea level rising by typhoons Statistical data in 44 years (1951 - 1995) show that Nghi Son Gulf is more influenced by typhoons and tropical low pressure than other sea areas of Vietnam with more than 50 times (28% of total typhoons landed to Vietnam) in this period. Typhoon number 2 in year 1981 namely Kelly landed to Nghe An territorial sea at maximum velocity of 38 m/s. Its average velocity is 22.2 km/h. Landing direction of the typhoon is at right angle to seashore and this is the reason why it makes sea level rise more quickly. As compared to Kelly, Nancy – typhoon number 7 in 1982 is more powerful and landed to Thanh Hoa – Nghe An region causing strongly effects to project area. Wind strength of the Nancy is at level 12 and pulling level is more than 12. Air pressure at typhoon center reduces to 970 mbar. At the time of its landing, wind speed observed at Vinh Meteorology Station got maximum value at 40 m/s. From 1995 to 2007, there were some typhoons landing or causing effects on project area, but less powerful than Kelly and Nancy typhoons. In conclusion, in Thanh Hoa and the North of Nghe An areas during 1951 to 2007, there are 02 strong typhoons landing to project area and cause sea level rise unusually (approximately 3.0m). Calculations by numerical value method show that maximum sea level raised by typhoons in Nghi Son Gulf is more than 2.5m. 4. Swell Since January 2008 also swell data is available from a denser (0.5 deg x 0.5 deg) grid of the NWW3 model.

Table 2.6 Swell height and period frequency distribution

Swell period (s) Hs (m)

8-9 9-10 10-11 11-12 12-13 13-14 14-15 Total Exceed

0.0-0.2 1.71% 2.56% 2.56% 0.92% 0.65% 0.1% 0.07% 8.56% 25.20% 0.2-0.4 1.36% 1.98% 3.14% 5.12% 1.43% 0.14% 13.16% 16.64% 0.4-0.6 0.38% 0.82% 0.41% 0.55% 0.89% 3.03% 3.48% 0.6-0.8 0.07% 0.20% 0.27% 0.44% 0.8-1.0 0.17%

>1 0.17% 0.17% 0.17% Total 3.68% 5.56% 6.10% 6.58% 2.97% 0.24% 0.07% 25.20%

Exceed 25,2% 21.52% 15.96% 9.85% 3.27% 0.31% 0.07% Source: Report of Hydro-Meteorological at Nghi Son and Hon Me Island [2] Conclusions as drawn in [2] are:



25.2% of the considered period swell waves actually have periods of 8 seconds or larger.

The swell waves have due to the East (to East - Southeast) direction a more easterly direction than the locally generated waves. This difference in direction is partly caused by the different location of generation and partly by the more shoreward location of the output point of the finer NOAA wave model (19°N, 106°E of the finer NOAA model as opposed to output point 19°N, 106.25°E of the regular NOAA model).

2.1.1.4 Existing Natural Environment To assess environmental quality in the project area, CPSE has conducted field survey samplings in the rainy season (August 2008 and June 2009) and dry season (February 2009) and analyzed of sea water quality, sediment and biology samples at offshore project constructions and its vicinity. The sampling site are showed in Figure 2.5 and 2.6. Number of sampling stations, analysed samples and parameters are presented in Table 2.7. Detailed coordinates of offshore sampling stations are listed in Table 2.8. The sampling method, analysis and detailed analytical results are showed in separately report of the environmental baseline study report for the Nghi Son Refinery and petrochemical Project (Appendix III).

Table 2.7 Summary of samples number in sampling surveys – NSRP

Sample types Number of stations Samples/station x 2 times Total samples Offshore

Sediment 26 3 x 2 156 Benthos 26 3 x 2 156 Surface water 26 2 (3 if sea depth is more than 15m) x 3 182 Zooplankton 26 1 x 2 52 Phytoplankton 26 1 x 2 52

Onshore Sediment 2 3 x 2 12 Benthos 2 3 x 2 12 Surface water 2 2 x 2 8 Zooplankton 2 1 x 2 4 Phytoplankton 2 1 x 2 4 Underground water 7 1 x 2 14 Soil 9 2 x 2 36 Air 8 3 times/day, 3 consecutive days x 3 144

Coastal Sediment 17 3 x 2 102 Benthos 17 3 x 2 102 Surface water 17 2 (3 if sea depth is more than 15m) x 3 72 Zooplankton 17 1 x 2 34 Phytoplankton 17 1 x 2 34

TOTAL 1,176 Source: CPSE, December 2009



Figure 2.5 Sampling locations in NSRP area

expansion ar ea

t r ¹ m biÕn ap

220/110KV

cÇul au

®uêng hÇm qua nói

hå

quÕ s¬n

f ut ur e

x·

mai l ©m

wsw

w

sw

sssw sse

e

ese

se

wnw

nnnw

nw

nne

ene

ne

§uêng èng xuÊt s¶n phÈmvÞ t r Ý mai l ©m

hßn v¸ t

gul f

§ª ch¾n c¸ t

l uång vµo bÕn xuÊt s¶n phÈm

bÕn sè 1&2 c¶ng Nghi s¬n

bÕn xuÊt s¶n phÈm l áng

bÕn phôc vô x©y dùng - xuÊt s¶n phÈm r ¾n

bÕn t Çu phôc vô cña c¶ng

nói xuí c

nói chuét t r ï

nhµ m̧ y xim̈ ng nghi s¬n

t r ¹ m biÕn ̧ p - power st at ion 110/22KV

®¶o

nghi

s¬n

t onkin

hßn géc

hßn miÖng

vòNG NEO TÇUD = 1000 M

SCALE:ASA

t æng mÆt b»ng khu l iª n hî p l äc hãa dÇu nghi s¬n

l uång vµo bÕn nhËp dÇu t h«

h¶i yÕn vil l age nhËp dÇu t h«t uyÕn ®uêng èng

s«ng b¹ ng

hßn b«ng hßn häp

bÕn nhËp dÇu t h«

hßn vang

hßn mªhonme

over al L sit e pl an of nghi son r ef inEr y and pet r ochemical compl ex

ent r ance channel of impor t ber t h

submar ine cr ude oil pipel ine

bong isl and

pr oduct expor t pipel ine

l iquid pr oduct expor t ber t hs

nghi son isl and

t ug ber t hs

ber t h f or const r uct ion wor k and sol id pr oduct expor t

ber t h exist no1 and No2

embankmentent r ance channel of pr oduct expor t ber t hs

®«ng

biÓn

nghi son cement f act or y

TRu mount ain

power st at ion220/110KV

que sonl ake

më r éng

khu vùc

mai l am vil l age

x· h¶i yÕn

isl and hop

isl and goc

isl and mieng

isl and vat

isl and vang

Hai t huong

mai l am Sit e

DWG: No3-01

Caùc traïm laáy maãu nöôùc maët, traàm tích ñaùy vaø sinh hoïc - Ngoaøi khôi (Toång soá: 12 traïm)Caùc traïm laáy maãu nöôùc maët, traàm tích ñaùy vaø sinh hoïc - Treân bôø (Toång soá: 09 traïm)Caùc traïm laáy maãu nöôùc ngaàm (Toång soá: 05 traïm)Caùc traïm laáy maãu khí vaø tieáng oàn (Toång soá: 08 traïm)Caùc traïm laáy maãu ñaát (Toång soá: 08 traïm)

K1K2

K3

K4

K5

K6

K7

K8

K9

K10

K11

K12

B1

B2

B3B4

B5

B6

B7

B8

B9

A1

A2

A4

A3

A5

A6

A7

A8

G1

G2

G3

G4

G5

D1

D2D3

D4

D5

D7

D6

D8

Bang River Bang River Bang River

Xuoc Mountain

Nghi Son Cement Factory

Submarine crude oil pipeline

Product export pipeline

Liquid product export berths

Tug berths

Berth for construction work and Solid product export

Berth exist No.1 and No.2

Entrance channel of product export berths Embarkment

Nghi Son island

Crude oil import berth

Bong island Hop island

Goc island

Entrance channel of import berth

Me island

Vang island

Mieng island

Vat island

Tonkin

Gulf

Surface water, sediment and biology sampling stations – Offshore (Total: 12 stations) Surface water, sediment and biology sampling stations – Onshore (Total: 12 stations) Groundwater sampling stations (Total: 05 stations) Air and noise sampling stations (Total: 08 stations) Soil sampling stations (Total: 08 stations)



Figure 2.6 Sampling locations in SPM area and offshore pipeline

E1

E2

E3

E4

E5

E6

E7E8

E9

E10

E11

E12

E13

E14

E15

E16E17

E18

E19

E20

E21

E22 E23

E24



Table 2.8 Coordinates of offshore sampling stations – NSRP

Coordinates Station name Sampling position

Y (m) X (m)

K-1 595662 2143171 K-2

Access to old SPM (near Hon Me island) 594440 2139681

K-3 Old SPM (near Hon Me island) 596385 2143282 K-4 Hon Mieng island 595199 2142263 K-7 Estuary between Nghi Son Cement jetty and NSRP harbour 586110 2139096 K-8 Near Nghi Son fishing village 585387 2138651 K-9 Turning basin of NSRP harbour 585714 2135279 K-10 586340 2134219 K-11 587569 2132741 K-12

Access channel of NSRP harbour

588187 2132357 E-1 585762.76 2143557.49 E-2 588461.64 2144867.48 E-3 592060.14 2146614.13 E-4 595984.88 2148519.14 E-5 610800.35 2150864.72 E-6 619621.00 2152261.20 E-7 610969.00 2147829.16 E-8 623391.97 2147257.12 E-9 613487.41 2144316.58 E-10 623522.01 2141907.16 E-11 605454.85 2145306.70 E-12 615673.93 2141840.15 E-13 621035.21 2153675.41 E-14 624806.18 2148671.33 E-15 624936.22 2143321.37 E-16 622107.80 2140492.95 E-17

Along crude oil pipeline and 04 proposed positions at SPM of the Project

614259.72 2140425.94 E-18 584413.33 2141702.50 E-19 588911.45 2142585.81 E-20

Along access channel

592509.95 2144332.47 E-21 593863.2 2140144.1 E-22 595216.1 2139207.4 E-23 598120.3 2139050.7 E-24

Around Hon Me island

598088.3 2141721.9 Source: CPSE, March 2010 Grid: UTM Datum: VN2000



1. Sea water quality Sea water quality in the project area and its vincinity is assessed based on comparison of analytical results of sea water quality (Table 2.9, Table 2.10 and Table 2.11) in the rainy season (August 2008 and June 2009) and in the dry season (February 2009) in area of offshore constructions and National Technical Regulation QCVN10:2008/BTNMT on coastal sea water – Column 3.

Table 2.9 Analytical results of physical characteristics in sea water

in the dry season (February 2009) and the rainy season (August 2008 and June 2009) samplings

pH DO (mg/l) Salinity (‰) Temperature (oC) Sample Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season

E - 1 7.7 7.6 5.7 5.6 33 30 25 27

E - 2 7.8 7.7 5.9 5.6 32 30 25 27

E - 3 7.7 7.8 5.8 5.6 32 31 25 26

E - 4 7.6 7.5 5.6 5.6 32 31 24 26

E - 5 7.7 7.6 5.5 5.6 32 31 25 27

E - 6 7.7 7.7 5.4 5.5 31 31 25 27

E - 7 7.7 7.6 5.4 5.6 32 31 25 27

E - 8 7.6 7.4 5.4 5.5 32 30 22 26

E - 9 7.7 7.7 5.6 5.6 32 31 24 26

E - 10 7.7 7.5 5.6 5.7 32 30 25 26

E - 11 7.8 7.7 5.4 5.5 32 31 25 27

E - 12 7.6 7.6 5.5 5.5 32 31 24 26

E - 13 7.5 7.5 5.6 5.7 33 31 25 26

E - 14 7.7 7.6 5.6 5.7 33 31 23 26

E - 15 7.7 7.6 5.6 5.6 32 31 23 26

E - 16 7.7 7.7 5.6 5.6 33 31 24 26

E - 17 7.7 7.8 5.6 5.6 32 31 24 26

E - 18 7.6 7.5 5.6 5.6 33 30 25 26

E - 19 7.5 7.6 5.5 5.5 33 30 23 27

E - 2 7.7 7.7 5.4 5.5 32 31 23 26

E - 21 7.7 7.3 5.6 5.6 32 31 24 26

E - 22 7.6 7.3 5.6 5.6 32 31 24 26

E - 23 7.6 7.4 5.5 5.5 32 29 23 27

E - 24 7.6 7.4 5.5 5.6 33 29 23 26

K - 1 7.7 7.7 5.9 6.1 33 32.8 24 26

K - 2 7.6 7.7 5.5 6.1 33 32.8 24 26

K - 3 7.8 7.8 5.4 5.9 33 32.5 24 26

K - 4 7.9 7.8 5.5 5.9 33 32.7 24 26

QCVN 10:2008 6.5 – 8.5 ≥5

Source: CPSE, March 2010



Table 2.10 Analytical results of chemical characteristics of sea water In the dry season (February 2009) and the rainy season (August 2008 and June 2009) samplings

Concentration (mg/L)

Sample TSS THC(*) NH4+ SO42- NO2- NO3- Total N Total P Phenol CN- BOD COD

Dry season 13 0.012 0.026 2150 0.016 0.012 0.41 0.012 <0.001 < 0.007 0.75 1.9

E-1 Rainy

season 14 0.013 0.034 2250 1350 0.016 0.49 <0.007 <0.001 < 0.007 0.63 1.9

Dry season 15 0.014 0.020 2230 <0.0004 0.006 1.04 <0.007 <0.001 < 0.007 0.66 1.8

E-2 Rainy

season 14 0.014 0.072 2130 1400 0.005 0.98 <0.007-0.010 <0.001 < 0.007 0.98 2.1

Dry season 16 0.013 0.018 2200 0.019 0.01 0.41 0.012 <0.001 < 0.007 0.9 2.2

E-3 Rainy

season 16 0.013 0.013 2210 1350 0.017 0.43 0.021 <0.001 < 0.007 0.66 1.8

Dry season 16 0.011 0.022 2120 0.001 0.009 0.76 0.014 <0.001 < 0.007 0.76 2.0

E-4 Rainy

season 15 0.012 0.013 2180 1333 0.008 0.78 0.034 <0.001 < 0.007 0.70 1.8

Dry season 15 0.01 0.015 - 0.069 0.014 1.1 0.021 <0.001 < 0.007 0.96 2.2

E-5 Rainy

season 13 0.011 0.018 - 0.001 0.029 1.12 0.026 <0.001 < 0.007 1.0 2.3

Dry season 14 0.012 0.010 - <0.0004 0.008 0.45 <0.007 <0.001 < 0.007 0.78 2.0

E-6 Rainy

season 13 0.012 0.017 - <0.0004 0.009 0.47 <0.007 <0.001 < 0.007 0.58 1.6

Dry season 16 0.014 0.016 - <0.0004 0.01 0.67 <0.007 <0.001 < 0.007 0.59 1.7

E-7 Rainy

season 15 0.013 0.022 - <0.0004 0.011 0.68 <0.007 <0.001 < 0.007 0.78 2.1

Dry season 15 0.015 0.007 - <0.0004 0.008 0.5 <0.007 <0.001 < 0.007 0.76 2.0

E-8 Rainy

season 15 0.014 0.009 - <0.0004 0.008 0.52 <0.007 <0.001 < 0.007 0.98 2.2

Dry season 14 0.013 0.019 - 0.033 0.02 0.57 <0.007 <0.001 < 0.007 0.59 1.7

E-9 Rainy

season 14 0.013 0.011 - <0.0004 0.016 0.58 <0.007 <0.001 < 0.007 0.87 2.0

Dry season 14 0.013 0.011 - <0.0004 0.007 0.44 <0.007 <0.001 < 0.007 0.61 1.7

E-10 Rainy

season 13 0.014 0.011 - <0.0004 0.009 0.45 <0.007 <0.001 < 0.007 0.63 1.8

Dry season 14 0.013 0.033 - <0.0004 0.005 0.42 <0.007-0.007 <0.001 < 0.007 0.63 1.8

E-11 Rainy

season 15 0.014 0.016 - <0.0004 0.020 0.46 <0.007 <0.001 < 0.007 0.79 2.0

Dry season 15 0.013 0.008 - <0.0004 0.008 0.44 <0.007 <0.001 < 0.007 0.72 1.9

E-12 Rainy

season 14 0.014 0.013 - <0.0004 0.013 0.45 <0.007 <0.001 < 0.007 1.10 2.4

Dry season 16 0.013 0.009 - <0.0004 0.008 0.61 <0.007 <0.001 < 0.007 0.71 1.9

E-13 Rainy

season 13 0.013 0.009 - <0.0004 0.010 0.63 <0.007 <0.001 < 0.007 0.77 1.9

Dry season 15 0.013 0.011 - <0.0004 0.008 0.45 <0.007 <0.001 < 0.007 0.76 2.0

E-14 Rainy

season 15 0.013 0.010 - <0.0004 0.015 0.57 <0.007 <0.001 < 0.007 0.84 2.0

E-15 Dry season 15 0.013 0.012 - <0.0004 0.009 0.43 <0.007 <0.001 < 0.007 0.65 1.8



Concentration (mg/L) Sample

TSS THC(*) NH4+ SO42- NO2- NO3- Total N Total P Phenol CN- BOD COD

Rainy season 14 0.014 0.011 - <0.0004 0.009 0.45 <0.007 <0.001 < 0.007 0.69 1.9

Dry season 15 0.013 0.01 - <0.0004 0.007 0.5 <0.007 <0.001 < 0.007 0.64 1.8

E-16 Rainy

season 14 0.015 0.009 - <0.0004 0.009 0.52 <0.007 <0.001 < 0.007 0.70 1.9

Dry season 15 0.012 0.011 - <0.0004 0.009 0.65 <0.007 <0.001 < 0.007 0.67 1.8

E-17 Rainy

season 14 0.013 0.014 - <0.0004 0.012 0.66 <0.007 <0.001 < 0.007 0.96 2.1

Dry season 15 0.013 0.0391 2200 0.017 0.011 0.64 0.035 <0.001 < 0.007 0.8 2.0

E-18 Rainy

season 11 0.018 0.051 2150 0.005 0.026 0.58 0.029 <0.001 < 0.007 0.61 1.8

Dry season 15 0.012 0.018 2250 0.002 0.008 0.81 0.008 <0.001 < 0.007 0.94 2.2

E-19 Rainy

season 13 0.013 0.025 2100 0.002 0.031 0.73 0.003 <0.001 < 0.007 1.1 2.3

Dry season 16 0.014 0.021 2190 0.022 0.011 0.53 0.012 <0.001 < 0.007 1.03 2.3

E-20 Rainy

season 15 0.014 0.097 2200 0.063 0.084 0.75 0.010 <0.001 < 0.007 0.66 1.8

Dry season 12 0.013 0.027 2280 0.045 0.015 0.61 0.014 <0.001 < 0.007 0.78 2.0

E-21 Rainy

season 11 0.013 0.011 2550 0.002 0.018 0.59 0.248 <0.001 < 0.007 1.3 2.0

Dry season 13 0.012 0.026 2100 0.039 0.02 0.56 0.016 <0.001 < 0.007 0.68 1.8

E-22 Rainy

season 11 0.014 0.078 2200 0.002 0.012 0.59 0.110 <0.001 < 0.007 0.82 2.0

Dry season 14 0.014 0.015 2330 0.043 0.018 0.49 0.017 <0.001 < 0.007 0.68 1.8

E-23 Rainy

season 13 0.015 0.028 2150 0.002 0.017 0.40 0.013 <0.001 < 0.007 0.72 1.8

Dry season 14 0.013 0.032 2330 0.046 0.019 0.54 0.02 <0.001 < 0.007 0.61 1.7

E-24 Rainy

season 13 0.014 0.047 2333 0.004 0.021 0.61 0.008 <0.001 < 0.007 0.68 1.7

Dry season 13 0.017 0.096 2210 0.032 0.017 0.49 0.036 <0.001 < 0.007 0.82 2.0

K-1 Rainy

season 5.4 0.009 0.120 - 0.006 0.025 0.73 <0.007 <0.001 < 0.007 0.85 -

Dry season 11 0.0095 0.028 2120 0.026 0.013 0.48 0.03 <0.001 < 0.007 1.04 2.3

K-2 Rainy

season <5 0.010 0.030 - 0.006 0.026 0.64 <0.007 <0.001 < 0.007 1.40 -

Dry season 11 0.01 0.024 2320 0.022 0.01 0.51 0.017 <0.001 < 0.007 0.65 1.8

K-3 Rainy

season <5 0.015 <0.004 - 0.007 0.030 0.51 <0.007 <0.001 < 0.007 1.40 -

Dry season 12 0.019 0.026 2340 0.068 0.039 0.68 0.022 <0.001 < 0.007 0.69 1.9

K-4 Rainy

season <5 0.007 <0.004 - 0.58 0.35 1.2 <0.007 <0.001 < 0.007 0.85 -

QCVN 10:2008 - - 0.5 - - - - - - - - -




Table 2.11 Analytical results of heavy metals in sea water in the dry season (February 2009) and the rainy season (August 2008 and June 2009) samplings

Sample Cu

(mg/l)

Pb

(mg/l)

Zn

(mg/l)

Cd

(mg/l)

Cr

(mg/l)

Fe

(mg/l)

Hg

(mg/l)

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E-1

Rainy season

<0.005 <0,001 - 0,003 0,008 <0,005 < 0,02 < 0,08 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08-0,19 < 0,001 E-2

Rainy season

<0.005 <0,001 - 0,003 0,013 <0,005 < 0,02 < 0,08 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08-0,10 < 0,001 E-3

Rainy season

<0.005 <0,001 0,011 <0,005 < 0,02 < 0,02 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08-0,62 < 0,001 E-4

Rainy season

<0.005 <0,001 - 0,003 0,023 <0,005 < 0,02 0,15 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E-5

Rainy season

<0.005 <0,001 - 0,002 0,009 <0,005 < 0,02 < 0,02 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E-6

Rainy season

<0.005 0,004 <0,005 – 0,007 <0,005 < 0,02 < 0,02 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E-7

Rainy season

<0.005 <0,001 – 0,008 <0,005 <0,005 < 0,02 < 0,08 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E-8

Rainy season

<0.005 0,004 0,022 <0,005 < 0,02 < 0,08 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E-9

Rainy season

<0.005 0,001 0,029 <0,005 < 0,02 < 0,08 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E-10

Rainy season

<0.005 <0,001 - 0,008 0,009 <0,005 < 0,02 < 0,08 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 0,132 < 0,001 E–11

Rainy season

<0.005 <0,001 0,008 <0,005 < 0,02 < 0,08 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E–12

Rainy season

<0.005 0,002 0,007 <0,005 < 0,02 < 0,08 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E-13

Rainy season

<0.005 <0,001 0,010 <0,005 < 0,02 0,13 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E-14

Rainy season

<0.005 <0,001 0,008 <0,005 < 0,02 < 0,08 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08 < 0,001 E-15

Rainy season

<0.005 <0,001 <0,005 <0,005 < 0,02 < 0,08 < 0,001

Dry season

<0,005 <0,001 <0,005 <0,005 < 0,02 <0,08-0,37 < 0,001 E-16

Rainy <0.005 0.003 0.006 <0.005 < 0.02 < 0.08 < 0.001



Sample Cu

(mg/l)

Pb

(mg/l)

Zn

(mg/l)

Cd

(mg/l)

Cr

(mg/l)

Fe

(mg/l)

Hg

(mg/l)

season

Dry season

<0.005 <0.001 <0.005 <0.005 < 0.02 <0.08 < 0.001 E-17

Rainy season

<0.005 0.001 <0.005 - 0.008 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 <0.001 <0.005 <0.005 < 0.02 <0.08 < 0.001 E-18

Rainy season

<0.005 0.003 0.008 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 <0.001 <0.005 <0.005 < 0.02 0.09 < 0.001 E-19

Rainy season

<0.005 <0.001 0.010 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 <0.001 <0.005 <0.005 < 0.02 0.15 < 0.001 E-20

Rainy season

<0.005 0.003 0.008 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 <0.001 <0.005 <0.005 < 0.02 0.18 < 0.001 E-21

Rainy season

<0.005 <0.001 0.007 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 <0.001 <0.005 <0.005 < 0.02 <0.08 < 0.001 E-22

Rainy season

<0.005 <0.001 0.011 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 <0.001 <0.005 <0.005 < 0.02 0.17 < 0.001 E-23

Rainy season

<0.005 <0.001 0.015 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 <0.001 <0.005 <0.005 < 0.02 0.27 < 0.001 E-24

Rainy season

<0.005 <0.001 0.009 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 0.006 0.050 <0.005 < 0.02 0.087 < 0.001 K-1

Rainy season

<0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 0.002 0.011 <0.005 < 0.02 0.086 < 0.001 K-2

Rainy season

<0.005 0.002 0.013 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 <0.001 <0.005 -0.014 <0.005 < 0.02 <0.08 < 0.001 K-3

Rainy season

<0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 < 0.001

Dry season

<0.005 <0.001 <0.005 <0.005 < 0.02 <0.08-0.30 < 0.001 K-4

Rainy season

<0.005 0.004 0.005 <0.005 < 0.02 < 0.08 < 0.001

QCVN10:2008 1 0.1 2 0.005 0.05 0.3 0.005

Source: CPSE, March 2010 Based on analytical results presented in Table 2.9, 2.10 and 2.11, some conclusions of sea water quality in project area may be summarised as follows:

In general, almost parameters of sea water quality analysed in project area meet QCVN10:2008/BTNMT. Temperature and salinity parameters of sea water vary in very narrow range. BOD and COD contents are

relative statble between sampling stations in both seasons. pH values are in range of 7.3 - 7.9 in both of rainy and dry seasons. DO values at offshore sampling stations in both seasons are in the range from 5.4 to 6.1mg/l and meet QCVN

10:2008 (>5mg/l).



Total suspended solid (TSS) at almost sampling stations varies in a narrow range from 11 to 16 mg/L in both seasons, except stations from K1 to K4 there is different TSS contents between two sampling seasons.

The total oil content in water at offshore sampling stations is quite homogeneous and not much different

between two surveyed seasons. The highest total oil content is recorded at station K-4 (Mieng island) in the dry season.

At almost offshore stations, CN- contents are lower than detection limit of analytical method in both of two

seasons.

NH4+ content at all sampling stations are much lower than QCVN 10:2008/BTNMT (0.5mg/l).

NO2-, NO3- contents as well as total N content at almost of sampling stations are very low and vary in a narrow range. However, the contents of three above-mentioned parameters increase about 6 – 7 times higher at station K-4, Mieng island, in the rainy season.

Total phosphorus content at most of offshore sampling stations is lower than detection limit of analytical method. At stations E21 and E22, total phosphorus content increase significantly in the rainy season.

Among seven analyzed trace heavy metals, four metals are below the detection limit of analytical method AAS

(Cu, Cd, Cr and Hg). Other metals are also found in very low content in comparison with QCVN 10:2008 at offshore sampling stations in both of rainy and dry seasons.

2. Seabed sediment quality Grain size distribution Analytical results of grain size distribution in seabed sediment in the project area are summarized in Table 2.12. Description of physical appearance of sediments and sampling schedule are given in Appendix III – Item A – Sampling Diary.

Table 2.12 Summary of analytical results of gain size distribution in dry season (February 2009) and rainy season (August 2008 and June 2009) samplings

Station Mean Phi Standard Deviation

Skew-ness

Kurtosis % Coarse % Fine

Sorting index

Sediment type

Dry season

0.44 1.92 1.07 5.26 39.92 3.34 Average Coarse sand K-1

Rainy season

-0.05 2.34 2.35 7.98 45.82 8.57 Bad Coarse sand

Dry season

0.15 1.91 1.30 5.66 48.07 3.07 Average Coarse sand K-2

Rainy season

2.38 2.41 1.05 3.92 6.64 18.07 Bad Fine sand

Dry season

3.07 3.50 -0.24 1.65 9.94 38.38 Very Bad Very fine sand K-3

Rainy season

2.17 2.90 0.77 2.86 16.65 21.86 Very Bad Fine sand

Dry season

3.14 2.67 -0.38 2.25 1.64 65.73 Very Bad Very fine sand K-4

Rainy season

2.38 3.77 0.49 1.63 24.95 38.32 Extremely Bad Fine sand




Skew-ness


Sorting index

Sediment type

Dry season

3.21 1.40 -0.17 8.91 2.49 6.75 Good Very fine sand E-1

Rainy season

3.54 1.69 0.33 6.48 2.61 16.07 Average Very fine sand

Dry season

4.15 2.72 -0.24 2.77 7.59 46.65 Very Bad Coarse silt E-2

Rainy season

4.64 2.25 -0.11 3.37 2.33 53.84 Bad Coarse silt

Dry season

3.37 2.99 -0.05 2.27 14.63 39.05 Very Bad Very fine sand E-3

Rainy season

3.92 2.63 -0.09 2.84 7.36 41.35 Very Bad Very fine sand

Dry season

3.15 3.05 0.06 2.19 16.44 35.16 Extremely Bad Very fine sand E-4

Rainy season

3.35 2.92 0.11 2.34 11.47 36.70 Very Bad Very fine sand

Dry season

2.67 2.71 0.60 2.82 10.01 24.82 Very Bad Fine sand E-5

Rainy season

2.75 2.74 0.60 2.74 8.26 26.03 Very Bad Fine sand

Dry season

2.57 2.98 0.51 2.42 15.03 27.39 Very Bad Fine sand E-6

Rainy season

4.90 2.68 -0.24 2.18 1.82 60.59 Very Bad Coarse silt

Dry season

0.40 1.48 1.29 8.43 23.27 1.95 Good Coarse sand E-7

Rainy season

1.45 2.73 1.06 3.49 21.05 15.42 Very Bad Medium sand

Dry season

3.36 2.72 0.44 2.39 3.49 33.17 Very Bad Very fine sand E-8

Rainy season

3.43 3.50 0.01 1.71 16.67 45.00 Extremely Bad Very fine sand

Dry season

0.74 1.47 0.91 7.47 17.73 1.94 Good Coarse sand E-9

Rainy season


Dry season


Rainy season

4.57 2.72 0.08 1.96 1.01 51.10 Very Bad Coarse silt

Dry season


Rainy season

2.64 2.23 1.33 4.12 1.75 19.94 Bad Fine sand

Dry season

2.90 2.16 0.92 4.36 4.11 17.93 Bad Fine sand E-12

Rainy season


Dry season

2.63 3.38 0.35 1.87 22.52 35.60 Extremely Bad Fine sand E-13

Rainy season


Dry season


Rainy season

5.29 2.65 -0.42 2.37 1.55 66.69 Very Bad Medium Silt

Dry season


Rainy season


Dry season


Rainy season


Dry season

4.19 2.74 0.15 2.02 2.54 46.87 Very Bad Coarse silt E-17

Rainy 4.32 3.03 -0.09 2.01 5.82 50.85 Extremely Bad Coarse silt




Skew-ness


Sorting index

Sediment type

season

Dry season

3.74 0.95 3.28 15.69 0.00 10.62 Very Good Very fine sand E-18

Rainy season

4.06 1.30 2.33 7.82 0.00 21.28 Good Coarse silt

Dry season


Rainy season

2.93 3.01 0.24 2.21 12.07 29.73 Extremely Bad Fine sand

Dry season


Rainy season

3.81 2.69 0.19 2.46 4.95 38.62 Very Bad Very fine sand

Dry season

1.77 3.43 0.71 2.13 36.07 27.89 Extremely Bad Medium sand E-21

Rainy season

3.88 3.52 -0.18 1.66 13.97 53.59 Extremely Bad Very fine sand

Dry season

2.93 3.28 0.27 1.83 15.72 38.43 Extremely Bad Fine sand E-22

Rainy season


Dry season

6.06 1.96 -0.49 3.25 0.32 83.26 Average Find silt E-23

Rainy season


Dry season

0.84 2.43 1.30 4.70 33.57 9.03 Bad Coarse sand E-24

Rainy season


Source: CPSE, March 2010 Analytical results in Table 2.12, it may withdraw some comments as follows:

Sediments at sampling stations are quite different due to specific geology and topography. The seabed sediments at all sampling stations are classified from medium silt to coarse sand. Mean diameter varies in a wide range (from -0.05 to 5.29 in the rainy season and from 0.15 to 6.06 in the dry season).

Sediments at surveyed area have tendency to be coarser, especially the sediment at stations K1 and E24

which are located close to Hon Me island. Sediment in these stations containing a lot of hard rock and are classified as coarse sand and medium sand.

At stations K1 to K4, E6, E7, E9, E12, E14 and E23, mean phi and fine content values are significantly

different between the rainy and the dry season. It may be due to geological characteristic at Nghi Son gulf are not homogeneous.

Hydrocarbons in sediment Analytical results of hydrocarbons in sediment in project area are presented in Table 2.13.



Table 2.13 Analytical results of hydrocarbons in sediment in the dry season (February 2009) and the rainy season (August 2008 and June 2009) samplings

UCM ∑n-C13-35 CPI Pr/Ph UCM /∑n-C13-35 THC

Station Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season

K-1 0.9 2 0.2 0.3 2 1.8 1.3 1.2 5 6 1 3

K-2 1.4 2 0.3 0.4 2 1.6 0.6 0.5 5 5 2 3

K-3 2.8 2 1.1 0.3 5 3.0 1.6 1.4 3 5 5 3

K-4 2.7 3 0.8 0.5 4 4.1 1.5 2.1 3 6 5 5

E-1 1 2 0.3 0.4 1.6 3 0.6 2.1 6 5 2 3

E-2 3 3 0.8 0.6 3.7 5 1.2 2.3 4 5 4 5

E-3 3 2 0.8 0.4 2.4 4 0.9 2.1 3 4 6 3

E-4 3 1 0.8 0.4 3.5 4 1.4 1.8 3 3 4 2

E-5 2 1 0.4 0.3 2.7 3 0.6 1.8 5 5 3 2

E-6 1 2 0.4 0.4 4.1 3 2.6 1.0 4 4 2 3

E-7 1 1 0.2 0.4 1.4 4 1.0 1.8 8 3 1 2

E-8 1 2 0.3 0.4 2.2 3 1.0 2.1 3 4 2 3

E-9 0 1 0.2 0.3 1.1 3 1.1 1.6 3 3 1 2

E-10 1 2 0.3 0.4 2.5 3 1.0 1.5 4 4 2 2

E-11 1 1 0.4 0.1 3.0 1 1.1 0.9 3 9 2 2

E-12 1 9 0.3 0.6 2.2 1 1.1 0.1 4 16 2 13

E-13 1 2 0.4 0.4 3.9 3 1.6 1.7 3 4 2 3

E-14 1 2 0.3 0.5 1.9 3 0.6 1.0 4 5 2 5

E-15 1 2 0.3 0.4 2.4 3 0.8 10.4 4 5 2 4

E-16 2 2 0.4 0.3 2.3 2 0.7 1.0 4 5 2 3

E-17 2 3 0.7 0.5 4.1 3 1.5 0.6 3 6 3 5

E-18 1 2 0.3 0.4 1.5 1 1.1 0.6 5 6 2 3

E-19 2 2 0.5 0.5 3.1 3 1.4 0.5 3 5 2 4

E-20 2 2 0.5 0.5 2.9 3 1.0 0.7 3 4 2 3

E-21 2 3 0.5 0.7 3.5 3 1.3 0.7 3 4 3 4

E-22 3 2 0.6 0.4 2.8 3 1.3 1.6 5 6 4 4

E-23 3 3 0.8 0.4 3.1 3 1.6 1.8 4 7 5 4

E-24 1 2 0.3 0.4 1.9 4 0.7 1.1 4 5 2 3

Source: CPSE, March 2010 Analytical results in Table 2.13 show that:

Hydrocarbons (HC) and other organic materials exist in sediments in motive balance condition including 02 contrary chemical and physical processes: (i) accumulation of hydrocarbons deposited from water and/or HC in earth’s womb to sediments, (ii) biodegradation and/or dispersion of HC from sediments to water. These processes are much influenced by environmental conditions (temperature, current, sediment characteristics…) as well as human activities (drilling, disposal…). Therefore, HCs content in sediments may be changed by time.



THC values at offshore sampling stations vary in a narrow range in both of rainy and dry seasons (from 1 to 6 µg/g in the dry season and from 2 to 13 µg/g in the rainy season).

All CPI values (Carbon Preference Index) are higher than 1 in both of rainy and dry seasons. This means the odd n-alkane chain is more predominant than even n-alkane one. By this distribution, hydrocarbon found usually originates from biologic compounds. It shows that Non-petrogenic hydrocarbons contribute a given proportion in the total hydrocarbon compositions.

Heavy metals in sediment Analytical results of heavy metals in sediments are presented in Table 2.14.

Table 2.14 Analytical results of heavy metals in sediments in the dry season (February 2009) and the rainy season (August 2008 and June 2009) samplings

Station Cu (µg/g) Pb (µg/g) Zn (µg/g) Cd (µg/g) Cr (µg/g) V (µg/g) Hg (µg/g)

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

K-1 7.4 11 24 25 38 52 < 1 < 1 10 27 < 63 < 63 0.047 0.072

K-2 14 20 20 28 41 57 < 1 < 1 13 46 < 63 < 63 0.037 0.061

K-3 30 30 17 46 83 66 < 1 < 1 60 66 < 63 < 63 0.063 0.069

K-4 34 35 22 39 88 71 < 1 < 1 59 73 < 63 < 63 0.056 0.076

E-1 10 9.3 <6 14 52 58 < 1 < 1 38 40 < 63 < 63 <0.02 0.076

E-2 22 21 9.1 24 62 73 < 1 < 1 44 50 < 63 < 63 0.048 0.071

E-3 30 21 31 20 83 73 < 1 < 1 50 49 < 63 < 63 0.10 0.093

E-4 25 21 25 21 80 70 < 1 < 1 48 47 < 63 < 63 0.08 0.077

E-5 16 18 23 23 72 71 < 1 < 1 39 48 < 63 < 63 0.038 0.056

E-6 20 27 27 33 73 88 < 1 < 1 46 54 < 63 < 63 0.059 0.048

E-7 8.3 18 15 29 42 69 < 1 < 1 16 47 < 63 < 63 0.072 0.061

E-8 21 31 22 32 78 95 < 1 < 1 50 58 < 63 < 63 0.16 0.075

E-9 7.4 27 18 31 41 85 < 1 < 1 16 48 < 63 < 63 0.18 0.094

E-10 21 24 23 31 76 80 < 1 < 1 47 50 < 63 < 63 0.12 0.070

E-11 27 11 30 35 90 51 < 1 < 1 49 23 < 63 < 63 0.13 0.048

E-12 20 29 30 31 71 88 < 1 < 1 39 48 < 63 < 63 0.17 0.072

E-13 30 26 34 30 90 85 < 1 < 1 53 49 < 63 < 63 0.15 0.085

E-14 24 26 24 34 85 84 < 1 < 1 51 49 < 63 < 63 0.13 0.061

E-15 24 24 23 35 82 92 < 1 < 1 58 60 < 63 < 63 0.13 0.066

E-16 26 22 28 32 85 82 < 1 < 1 58 56 < 63 < 63 0.15 0.077

E-17 33 30 37 35 91 99 < 1 < 1 56 63 < 63 < 63 0.15 0.116

E-18 10 8.9 17 17 60 51 < 1 < 1 42 33 < 63 < 63 0.17 0.027

E-19 22 19 23 26 68 71 < 1 < 1 48 46 < 63 < 63 0.16 0.067

E-20 24 30 26 36 70 89 < 1 < 1 49 48 < 63 < 63 0.15 0.063

E-21 33 33 42 40 89 101 < 1 < 1 56 54 < 63 < 63 0.13 0.087

E-22 33 26 40 33 90 77 < 1 < 1 59 43 < 63 < 63 0.13 0.080

E-23 37 25 36 35 92 78 < 1 < 1 60 44 < 63 < 63 0.21 0.093

E-24 7.8 27 14 35 41 79 < 1 < 1 11 45 <63 < 63 0.13 0.086




Analytical results in Table 2.14 show that:

Cd and V contents are lower than the limit detection of the analytical analysis by AAS.

At stations of E7, E9 and E24, contents of Cu, Pb, Zn, Cr and Hg vary rather large between the rainy and the dry season, except Hg content at station E7. At remained stations, there is small diferent contents between two seasons.

Biological environment

Phytoplankton Summary results of phytoplankton community at offshore stations in August 2008, February 2009 and June 2009 samplings are presented in Table 2.15. Detail analytical results will be given in Appendix III.

Table 2.15 Analytical results of phytoplankton community in the dry season (February 2009) and the rainy season (August 2008 and June 2009) samplings

Taxon quantity (taxon/0.05m3) Density (x103 ind/ m3) H(s) J C Station Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season

K1 13 10 1516515 35 0.03 2.44 0.01 0.73 0.99 0.28

K2 13 16 1792835 62 0.04 3.20 0.01 0.80 0.99 0.18

K3 11 13 238420 37 0.17 2.84 0.05 0.77 0.96 0.22

K4 15 13 1770505 29 0.04 2.65 0.01 0.72 0.99 0.28

E2 14 23 1005095 4192 0.09 2.74 0.02 0.61 0.98 0.21

E3 13 21 3178830 8888 0.10 1.98 0.03 0.45 0.98 0.39

E4 11 21 2928150 2724 0.05 3.13 0.01 0.71 0.99 0.16

E5 16 4 1027830 56 0.02 1.79 0.01 0.89 1.00 0.32

E6 12 11 1143990 128 0.10 2.86 0.03 0.83 0.98 0.19

E7 11 3 987120 84 0.04 1.02 0.01 0.65 0.99 0.61

E8 18 6 1072800 120 0.08 2.44 0.02 0.94 0.99 0.20

E9 16 5 254220 56 0.10 1.75 0.03 0.76 0.98 0.39

E10 15 8 1929460 108 0.03 2.44 0.01 0.81 0.99 0.23

E11 14 4 4335 144 3.20 1.29 0.84 0.64 0.15 0.53

E12 17 3 378350 52 0.48 0.99 0.12 0.63 0.89 0.62

E13 14 10 3732755 76 0.03 2.82 0.01 0.85 1.00 0.19

E14 16 15 738720 176 0.05 3.28 0.01 0.84 0.99 0.14

E15 15 8 775260 148 0.02 2.32 0.01 0.77 1.00 0.26

E16 14 5 967950 260 0.06 0.99 0.02 0.43 0.99 0.66

E17 11 4 729840 2172 0.13 0.30 0.04 0.15 0.97 0.92

E19 13 19 2599640 1368 0.02 3.60 0.01 0.85 1.00 0.10

E20 17 15 1877995 768 0.03 2.98 0.01 0.76 0.99 0.17

E21 16 8 738010 60 0.05 2.84 0.01 0.95 0.99 0.17

E22 12 7 1621275 1880 0.06 0.20 0.02 0.07 0.99 0.96



Taxon quantity (taxon/0.05m3) Density (x103 ind/ m3) H(s) J C Station Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season

E23 8 4 59990 44 0.09 1.87 0.03 0.93 0.98 0.29

E24 12 4 221130 44 0.26 1.82 0.07 0.91 0.94 0.31

Mean 14 10 1280424 912 0.21 2.18 0.05 0.71 0.95 0.34

Max 18 23 3732755 8888 3.20 3.60 0.84 0.95 1.00 0.96

Min 8 3 4335 29 0.02 0.20 0.01 0.07 0.15 0.10


Although recorded taxon quantity in the dry season is higher than the ones in the rainy season, but in the dry season, phytoplankton community in offshore surveyed area is not diversity and homogenous. The reason is due to algae blooming phenomenon during survey time (strong blooming phenomenon of marine algae).

Taxon composition and distribution: It is easy to recognize that on the dry season, the number of taxon among

stations is rather eveness while these taxons are strongly changed among stations in the rainy season. Taxon quantity is too low at stations of E5, E7, E11, E12, E17, E23, E24 and rather high at stations E2, E3, E4, E19.

Concerning to taxon composition, in the dry season, there are four phyla identified in which each phylum of

Dianophyta and Bacillariophyta occupies about 50%. The portions of the others are too small. In the rainy season, there are 05 phyla identified in which Bacillariophyta is the most diversity; following ones are Dianophyta, Cyanophyta, Chlorophyta and Euglenophyta in descending order.

Density composition and distribution: the remarkable note that the phytoplankton density in the dry season is

thousands times higher than that in the rainy season. This phenomenon is probably related to nutrient contents of water in the dry season. In some cases, the increament of Nitrate content will form a suitable ratio between nutrient substances which pushs up the developemnt of algae blooming. The sharply increasing density among studied stations E2, E3, E4 made density variation between stations in the rainy season is higher than that ones in the dry season. Structural densities are much different between stations named E17, E22 and E16 in the rainy season with the dominant of green algae (Cyanophyta). This means there is in fluctuating between density and taxon quantity in the water environment of the studied area.

To density composition, although there are 04 phyla of phytoplankton presented, the Bacillariophyta takes

nearly 100% of density; portions of the others are very small. In the rainy season, Bacillariophyta also takes the largest one, however, portions of Cyanophyta, Dianophyata and Chlorophyta are also remarkable.

Concerning to community indices: in the dry season, like a consequence of the blooming of one species

algae, all community indices are almost in bad levels. Diversity index (H(s)) and Evenness index (J) are low while predominant index (C) is high at almost stations. At station E14, this phenomenon is not recorded. On a contrary, all community indices are almost in normal levels in the rainy season.

The zooplanktonic community Analytical results of zooplankton community at offshore sampling station are summarized in Table 2.16. Detailed results are presented in Appendix III – Item B.



Table 2.16 Analytical results of zooplankton community in the dry season (February 2009) and the rainy season (August 2008 and June 2009) samplings

Taxon quantity (/station) Density (ind/m3)

H(s) J C Station

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

K1 34.0 32.0 201.2 953.7 4.08 3.64 0.80 0.73 0.09 0.12

K2 37.0 24.0 499.9 209.1 3.75 3,82 0,72 0,83 0,12 0,10

K3 35.0 25.0 483.1 365.4 3.20 3.84 0.62 0.83 0.23 0.10

K4 38.0 35.0 706.1 3,799.1 3.31 3.97 0.63 0.77 0.24 0.09

E2 23.0 33.0 2,254.8 784.9 3.54 4.07 0.78 0.81 0.09 0.09

E3 30.0 40.0 1,487.1 485.3 4.08 4.04 0.83 0.76 0.09 0.13

E4 28.0 40.0 3,716.7 919.9 4.08 4.44 0.85 0.84 0.11 0.07

E5 31.0 35.0 260.1 273.0 2.97 3.95 0.60 0.77 0.12 0.09

E6 33.0 32.0 421.5 1,149.0 4.48 3.72 0.89 0.74 0.14 0.12

E7 35.0 27.0 656.5 357.9 4.28 2.60 0.83 0.55 0.09 0.35

E8 34.0 35.0 526.5 598.0 4.22 3.50 0.83 0.68 0.14 0.18

E9 38.0 35.0 1,468.0 773.8 4.04 4.29 0.77 0.84 0.06 0.07

E10 28.0 30.0 737.3 601.1 3.26 3.05 0.68 0.62 0.27 0.18

E11 28.0 35.0 266.7 138.5 3.36 4.06 0.70 0.79 0.07 0.09

E12 28.0 36.0 2,567.7 603.4 3.51 4.03 0.73 0.78 0.17 0.09

E13 40.0 35.0 387.1 1,014.1 4.19 4.13 0.79 0.81 0.07 0.09

E14 32.0 30.0 1,112.8 356.0 4.00 3.82 0.80 0.78 0.16 0.11

E15 22.0 33.0 1,104.8 936.9 3.62 3.54 0.81 0.70 0.27 0.14

E16 28.0 33.0 1,117.9 401.1 3.73 3.98 0.77 0.79 0.35 0.10

E17 40.0 38.0 30,840.0 1,816.8 3.44 3.80 0.65 0.72 0.08 0.12

E19 20.0 34.0 4,895.0 1,239.4 3.19 3.72 0.74 0.73 0.13 0.15

E20 34.0 27.0 796.6 9,541.7 4.38 3.89 0.86 0.82 0.08 0.09

E21 31.0 36.0 738.7 252.4 3.01 4.20 0.61 0.81 0.09 0.09

E22 31.0 41.0 8,280.0 538.3 4.31 4.38 0.87 0.82 0.15 0.07

E23 35.0 35.0 335.4 1,717.2 3.63 4.02 0.71 0.78 0.09 0.09

E24 33.0 39.0 506.7 2,005.8 4.27 3.95 0.85 0.75 0.10 0.10

Mean 31.8 33.7 2,552.6 1,224.3 3.77 3.86 0.76 0.76 0.14 0.12

Max 40.0 41.0 30,840.0 9,541.7 4.48 4.44 0.89 0.84 0.35 0.35

Min 20.0 24.0 201.2 138.5 2.97 2.60 0.60 0.55 0.06 0.07


Difference from phytoplankton community, the number of zooplankton taxon is relatively high and evenness among stations as well as between two seasons. Concerning to taxon composition, Copepoda is the most diversity group in zooplankton community on both of dry and rainy seasons. It takes 75% of total taxon quantity. The second belongs to Chaetognata group. The other groups took smaller portions and different between two seasons.



Similar to taxon quantity, density of zooplankton community is rather evenness. Exception for the strong increasing of density causing by strong development of Copepoda and Ostracoda groups record at station E17 in the dry season; and the increasing in density at station E20 on rainy season causing by the strong development of Larva, Chaetognata and Ostracoda groups. At other stations, the variation of density between two seasons as well as among stations is not big different.

To density composition, Copepoda is also the most dominant in both of rainy and dry season; the following ones are Larvae and Cladocera. The others are changed a lot between two seasons.

In both of rainy and dry seasons, all community indices are at relatively good levels.

Macrobenthic community Analytical results of macrobenthic community at offshore sampling station are summarized in Table 2.17.

Table 2.17 Analytical results of macrobenthic community

in the dry season (February 2009) and the rainy season (August 2008 and June 2009) samplings

Taxon quantity (taxon/0.3m2)

Density (ind./m2)

Biomass (g/m2)

H(s) J C Station

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

K1 28 43 493 600 4.77 11.69 2.50 3.98 0.52 0.73 0.42 0.15

K2 44 56 650 530 8.59 5.74 2.88 5.31 0.53 0.92 0.39 0.04

K3 54 60 403 557 14.02 8.75 5.18 5.26 0.90 0.89 0.05 0.04

K4 42 59 247 727 26.55 12.43 5.04 5.26 0.94 0.89 0.04 0.04

E2 46 63 1,197 1,663 74.48 78.57 3.12 4.78 0.56 0.80 0.29 0.07

E3 61 59 1,087 957 31.53 49.47 4.66 4.83 0.79 0.82 0.07 0.06

E4 75 63 1,187 777 35.00 30.60 4.61 5.27 0.74 0.88 0.09 0.04

E5 70 56 727 460 20.04 30.34 5.23 5.35 0.85 0.92 0.05 0.03

E6 68 33 597 360 29.70 9.15 5.33 3.95 0.88 0.78 0.05 0.13

E7 28 55 300 347 4.09 16.34 4.12 5.47 0.86 0.95 0.08 0.03

E8 29 18 153 93 1.48 2.39 4.54 4.04 0.94 0.97 0.06 0.07

E9 46 36 370 287 7.06 6.85 5.13 4.80 0.93 0.93 0.04 0.05

E10 23 41 137 227 1.49 8.43 4.23 4.96 0.93 0.93 0.07 0.05

E11 35 56 197 537 4.75 16.95 4.88 5.02 0.95 0.86 0.04 0.05

E12 71 45 920 373 33.27 8.34 4.97 4.99 0.81 0.91 0.06 0.04

E13 49 27 337 120 21.37 4.88 5.18 4.61 0.92 0.97 0.04 0.05

E14 25 31 90 157 11.93 7.29 4.61 4.72 0.99 0.95 0.04 0.05

E15 27 33 117 190 7.27 2.17 4.63 4.71 0.97 0.93 0.04 0.05

E16 25 30 107 130 1.54 3.19 4.54 4.80 0.98 0.98 0.05 0.04

E17 49 37 273 210 18.79 6.21 5.42 4.81 0.96 0.92 0.03 0.05

E19 57 61 447 1353 7.27 48.93 5.04 4.07 0.86 0.69 0.05 0.16

E20 66 49 637 757 25.55 33.91 5.35 4.72 0.89 0.84 0.04 0.06

E21 61 66 360 573 9.92 17.14 5.64 5.68 0.95 0.94 0.02 0.05

E22 64 67 573 587 34.32 27.48 5.29 5.67 0.88 0.94 0.05 0.03



Taxon quantity (taxon/0.3m2)

Density (ind./m2)

Biomass (g/m2)

H(s) J C Station

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

E23 37 61 333 417 5.76 9.42 3.89 5.55 0.75 0.94 0.18 0.03

E24 42 57 543 340 7.38 9.21 2.95 5.63 0.55 0.97 0.38 0.02

Mean 47 49 480 513 17.23 17.92 4.58 4.93 0.84 0.89 0.10 0.06

Max 75 67 1,197 1,663 74.48 78.57 5.64 5.68 0.99 0.98 0.42 0.16

Min 23 18 90 93 1.48 2.17 2.50 3.95 0.52 0.69 0.02 0.02


Some community parameters such as density, biomass also fluctuates strongly among stations as well as between two seasons. Almost remained parameters (except biomass and density) are similar between two seasons and their values are in good level. At stations E2, E3 and E4 density and biomass strongly increase due to the strong development of Mollusca and Echinodermata groups.

Regarding to the composition, there are 04 groups including Polychaeta, Crustacean, Mollusca and Echinodermata in which, Polychaeta took the largest portion of taxon quantity, following ones are Crustacean, Mollusca and Echinodermata. Composition of density as well as biomass is much different among stations. This shows the non-symetric in structure of density and biomass of the Macrobenthic community and distributes the different of living conditions in seabed sediment between these stations.

2.1.1.5 Marine Resources Thanh Hoa shoreline has a bow-shaped with 102 km long and it is limited from Day estuary (Ninh Binh) to Dong Hoi belonging to Ha Hai commune, Tinh Gia district (Nghe An province borders). The territorial waters area is 1.7 thousand km2. This area is influenced by the hot-cold sea current and it creates the fishing ground with large reserves particularly Hon Me islands, Tinh Gia district. Hon Me Island area exploits important seafood in Northern Bay and it is not only living place of resident community for Tinh Gia district Thanh Hoa province but also its vicinity as well as commercial enterprises. The sea area, there is the aquatic products with high economic value such as fish, shrimp and squid sources. 1. Fish [4] Hon Me Island (Tinh Gia district) is important sea product exploitation in Northern Bay. The sea area has a large number of seafood species having high economic value such as pagrus (Pagrus major- cá nho), commom pony fish (Leiognathus spp-cá liet), Sepia (Sepia lycidas- muc nang mat cao), chirocentrus (Chirocentrus dorab – Cá Ria), Plotosus anguilaris (cá ngát), Indo-Pacific mackerel (Scomberomorus guttatus- cá thu cham), commersonis anchovy (Stolephorus commersoni- cá com), marine tilapia (Pomacentridae- cá rô bien), Holocentridae (cá son đá). Previously fishing grounds are located in the east and southeast of Hon Me islands at the depth of 30-40m (Figure 2.7 and 2.8). Up to now, commercial fishes were reduced, trash fish increased. However, distribution area is quite stable.

The fishing grounds at the East of Hon Me island, in Northeast monsoon season, Pagrus major (cá Nho) has the highest yield rate (17.52%), Leiognathus spp (cá liet) (12.34%), Sepia lycidas (10.96%), others species are below 10%. Otherwise in South-West monsoon season, in the fishing grounds at the East of Hon Me island there is the predominating species such as Evynnis cardinalis (cá mien sành hai gai) (71.99%) and Leiognathus (cá liet) (8.89%).



Figure 2.7 Distribution of pelagic fishery in Southern crop

Figure 2.8 Distribution of pelagic fishery Ground in Northern crop



Table 2.18 Fluctuation of fisheries yield at the East of Hon Me Island

No Scientific name English name Northeast monsoon

season (%)

Southwest monsoon season

(%) 1 Pagrus major - 17.52 2 Leiognathus spp. Pony fish 12.34 8.89 4 Saurida elongata Lizard fish 9.25 1.79 5 Nemipterus japonicus Japan bream 8.51 - 6 Scolopsis taeniopterus - 6.92 - 7 Saurida undosquamis True lizard fish 6.17 - 8 Scomberomorus guttatus Indo-Pacific mackerel 5.73 - 10 Pennahia macrocephalus Croaker 3.00 11 Evynnis cardinalis - - 71.99 12 Trichiurus haumela Hairtail - 2.12 13 Upeneus sulphureus - - 2.12 Source: [4] In the fishing grounds at Southeast of Hon Me island, in Northeast monsoon season there are Chirocentrus dorab

(cá rua) (24.26%), Plotosus anguilaris (cá ngát) (21.28 %), Scomberomorus guttatus (cá thu cham) (16.60%), Stolephorus commersoni (cá com thuong) (10.06 %), other species (10%). In the Southwest monsoon season there is Evynnis cardinalis (cá mien sành hai gai) (58.42%), Indian anchovy (cá com An Đo) (9.56%) and other species with low yield.

Table 2.19 Fluctuation of fisheries yield at South of Hon Me Island

No Scientific name English name Northeast monsoon

season (%)

Southwest monsoon season

(%) 1 Chirocentrus dorab - 24.26 - 2 Plotosus anguilaris - 21.28 - 3 Scomberomorus guttatus Mackerel 16.60 - 4 Stolephorus commersoni Anchovy 10.06 - 5 Leiognathus sp. Pony fish 6.22 - 6 Nemipterus japonicus Bream 2.92 - 7 Stolephorus indicus Indian anchovy 2.92 9.56 9 Evynnis cardinalis - - 58.42 12 Priacanthus tayenus Purple-spotted bigeye - 2.65

13 Scomberomorus commerson Narrow-barred king

mackerel - 2.18

14 Saurida tumbil Lizard fish.

- 2.12

Source: [Ref 4] In general, territorial waters regions of Thanh Hoa province are about 1.7 thousand km2. Stock/biomass of the seafood sources estimated about 10 thousand to 12 thousand tons in which: Pelagic fishery is about 5 to 6 thousand tons such as Decapterus maruadsi (cá nuc), Rainbow sardine (cá lam),

Auxis (cá ngu) (50%), Scomberomorus guttatus (cá thu), Pomfret fish (cá chim), Sardinella fish (cá trích) (20%). Up



to now, fish species yield such as Sardinella fish (cá trích), Stolephorus indicus are significantly changed due to excessive catch by the explosive.

The fish species have high economic value such as Lutjanus. sp (cá hong), Muraenesox cinereus (cá dua), Pseudupeneus luteus (cá phèn), Nemipterus japonicus (cá luong) ...The possibility of exploitation every year is 1.5 - 2.0 thousand tons. The tendency development exploitation of fish in the sea bottom is essential.

2. Shrimp [4] According to the survey results on marine shrimp in the Vietnam sea show that there are 225 species, 69 varieties of 24 families. Of which there were 96 species with economic and export value as Table 2.20.

Table 2.20 List of marine shrimp species with economic and export value

Scientific name English name Penaeus merguiensis Australian banana prawn P. indicus Indian prawn P. chinensis (P. orientalis) Penaeus orientalis P. marginatus (P. teraoi) Prawn P. semisulcatus Prawn P. japonicus Kuruma prawn P. monodon Giant tiger prawn P. latisulcatus - P. longistylus - Funchalia woodwardi - Metapenaeus ensis Greasy back shrimp M. affinis Pink prawn M. joyneri Yellow prawn M. intermedius - M. tenuipes King prawn M. spinulatus prawn M. brevicornis prawn M. moyebi (M. burkenroadi) - Parapenaeopsis hardwickii Cat prawn P. sculptilus Cat prawn P. hungerfordi Cat prawn P. gracillima - Aristaeidae - Aristaeomorpha foliacea - Aristeus virilis - Plesiopenaeus edwardsianus - Solenoceridae - Solenocera crassicornis - S. chopraj - S. melantho - Nephropidae (Homaridae) Lobster S. chopraj - S. melantho -



Scientific name English name Nephropidae (Homaridae) Lobster Metanephrops andamanicus - M. thompsoni - M. sinensis - Palinuridae Lobster Panulirus longipes - P. homarus - P. penicillatus - P. polyphagus - P. versicolor - P. stimpsoni - P. ornatus Ringsping lobster Linuparus trigonus - Puerulus angulatus - Scyllaridae Lobster Scyllarides squammosus - Ibacus ciliatus Slipper lobster Thenus orientalis -

Source: Natural condition and biological resources at Hon Me island - Thanh Hoa province- Tendency of social-economic Development [4]

Most of the main shrimp species exists at the Hon Me sea. The shrimp grounds in the south season tend to be distributed at greater depth (Figure 2.9). Estimated reserves are about 1,700 - 2,000 tons, mainly in two shrimp grounds such as Hon Ne and Hon Me. Annual exploitation is about 1,000-1,300 tons. The main components were M. affinis (pink prawn) and Cat prawn (Tôm s�t).

Figure 2.9 Distribution of shrimp ground in Hon Me sea area



3. Squid [4] It is identified 53 squid species at Hon Me waters in which one species belongs to Nautiloidea subclass and 52 species belong to Coleoidea subclass (12 varieties, 6 families, 3 orders). 12 species with high economic value found in Nghi Son waters are Sepioteuthis lessoniana, Loligo chinensis, Loligo duvauceli, Loligo edulis, Loligo singhalensis, Sepia latimanus, Sepia pharaonis, Sepia aculeata, Sepia lycidas, Sepia esculenta, Symplectoteuthis oualaniensis and Octopus vulgaris. There are two main squid grounds (Figure 2.10):

Squid ground 1: Distribution in the coastal strip from Bien Son to Lach Ghep (around Hon Me island)

Squid ground 2: Offshore Hon Me island (east and southeast of Hon Me island) Estimated reserves is about 6,000 tons of squid (ability to exploitation of 3,000 tons) and 3,000 tons of Cuttle fish (ability to exploit of 1,500 tons).

Figure 2.10 Distribution of Cephalopoda ground at Hon Me Sea area



4. Coral Reefs [5] According to surveyed results of NSRP at 15 coral reefs locations around Hon Me archipelogoes, a total of 31 coral species in three orders (hard, soft, black coral order) were found. Among them, 22 hard coral species, 8 soft coral species and only 1 black coral were found (Table 2.21). When comparing with other coral community, obviously coral in Hon Me is one of the less abundant although environment, clear water, hard bottom, good water circulation, is quite suitable for coral growth. According to Yet et al. (1997), there were 56 coral species belong to 30 genera, 14 families in Hon Me Archipelagoes. The comparison between two surveyed in 1997 and 2009 shows that this survey reveal a reduction of 45% in number of species, 40% in number of genus and 29% in family (Figure 2.11). Number of black and soft coral species was quite stable but the number of hard coral is reduced dramatically, some families like Agariciidae, Mussidae, Pectiniidae, Siderastreidae are not anymore present at the transect sites.

Table 2.21 Structure of Coral Class in Hon Me Archipelago (2009)

Taxon 1997 2009

Order Family number

Genus number

Species number

Family number

Genus number

Species number

Hard coral (Scleractinia) 10 26 49 4 11 22 Soft coral (Alcyonacea) 3 5 6 5 6 8 Black coral (Antiphatharia) 1 1 1 1 1 1 Total 14 30 56 10 18 31 Source: Report on Investigation and assessment of Coral Reefs of NSRP [.5]

0 10 20 30 40 50 60

Family

Genus

Species

Family

Genus

Species

1997

2009

Black coral (Antiphatharia)

Soft coral (Alcyonacea)

Hard coral (Scleractinia)

Figure 2.11 Comparison of coral structure between 1997 & 2009



5. Aquatic species having extinct danger at Thanh Hoa Waters According to the decision of the Agriculture and Rural Development Ministry No 82/2008/QD9-BNN in July 17th, 2008 given list of extintc danger aquatic species in Vietnam should be protected, recovered and developed. Based on this decision, some aquatic species having extinct danger of Thanh Hoa sea are presented in Table 2.22.

Table 2.22 Aquatic species having extinct danger of Thanh Hoa Sea

No Enghlish name Latin Name Natural Distribution Area

I ANIMAL 1. Whale Neophocaena

phocaenoides Around Me island

II REPTILE 2. Tortoise Dermochelys coriacea From Thanh Hoa to Binh Thuan and Truong Sa III FISH 3. Ca Bong bop Bostrichthys sinensis From Quang Ninh – Thanh Hoa – Ha Tinh 4. Blotched snakehead Channa maculata The province of the North to Thanh Hoa 5. Ca Chia voi Trachryrhamphus serratus From Quang Ninh to Kien Giang 6. Greasy grouper Epinephelus tauvina From Quang Ninh to Kien Giang IV CRUTACEAN 7. Scalloped spiny

lobster Panulirus homarus Vietnam sea, mainly central sea.

8. Ornate spiny lobster Panulirus ornatus Vietnam sea, mainly central sea. V FLORA 9. Macro-Algae Hypnea japonica Thanh Hoa (Quang Xuong), Nghe An, Ha Tinh,

Quang Binh, Quang Tri, Thua Thien Hue, Da Nang and Quang Nam.

Source: Natural condition and biological resources at Hon Me island - Thanh Hoa province- Tendency of social-economic Development [4] 2.1.2 ONSHORE ENVIRONMENTAL BASELINE 2.1.2.1 Topographic, geological and seismic conditions 1. Topography

Nghi Son area possesses a multiple-type topography, divided into the following main types:

Mountains and hills at the West and Southwest of the Project area have average elevation varying from 100 m to 560 m, formed by Cretaceous ferruginous sediment rock. This relief covers an area of 5,100 ha in the mountains of Chuot Chu and Xuoc, of which bare hills and mountains make up 2,225 ha, projected forestations land accounting for 2,548 ha and thinly scattered and low vegetation for 327 ha.

Coastal delta with 2 to 6 m sand dunes consists of 1,278 ha of cultivated land, 180 ha of Natural land and 800 ha of residential land. Generally, the land is flat. The possibility of being flooded is limited.

The Delta of Lach Bang is flat terrain, slopping gradually to the sea. The rivers of Lang Bach and Ha Nam are regularly submerged by seawater. Aquaculture area along these rivers



occupies approximately 94 ha. These lands belong to Hai Binh, Hai Thuong and Hai Ha communes.

The area of Nghi Son Island has shallow waters and nearshore islands. Nghi Son Island is 4.5 km length, extended in South - North direction. The topography of the Island is mainly hilly.

Hon Me Archipelagos are located some 10 km from the coast. The topography of these islands is rather hilly with shallow sea water.

2. Geology Based on the literature review and the latest survey results, the following geological formation of Nghi Son area are identified:

Cam Thuy formation is located on the eastern part of Hon Me Island. This formation is composed of alteration basalt, limestone lenses, effusive agglomerates of late age with thickness of about 300 to 400 m.

Dong Trau formation is distributed on the western part of the National Road 1A. Its composition consists of sandstone and siltstone-claystone in the inferior part, and thick bedded limestone and marine-limestone in the superior part. The thickness of this stratum is about 1,000 – 1,500 m.

Dong Do formation is distributed on the eastern part of the National Road 1A. Its includes the Xuoc, Coc and Bien Son mountains. The major composition comprises brownish grey sandstone, interceded siltstone-clay stone and conglomerate. The strata structure is inclined by oblique bedding of 80°– 90° < 30°– 60°. The upper part of the rock surface is completely weathered to become centimetre- to-meter thick residual soil.

Quaternary Period – Origin of marine sedimentation (mQ): This geological formation is mainly

distributed along seaside and low valleys around the mountains of Xuoc and Chuot Chu and along valleys of the communes of Tinh Hai, Hai Yen which makes up approx 80% of their total area. It is discordantly covered on the Dong Do formation. The composition is interceded by sand, sandy clay and silty clay. Based on geotechnical properties, from the surface downwards, the soil is divided into the following layers:

Layer 1: backfill and cultivated land;

Layer 2: fine sand from marine deposit;

Layer 3: soft clay – sandy clay;

Layer 4: clay – silty clay;

Layer 5: sand;

Layer 6: sandy clay;

Layer 7: residual and collusion soil;

Bed-rock, weathered rock layer.



Soil layers in surveyed area are summarized in Table 2.23.

Table 2.23 Summary of soil conditions

Stratum thickness (m) Reduced level (m ND) Stratum Code

Stratum Name General or Predominant Description Max Min Mean Max Min Mean

A RECENT FILL

Generally stiff red brown but locally pinkish white sandy gravelly CLAY with some cobbles and boulders

(At time of investigation. Final thickness will be up to 5m)

3.0 0.4 1.3

B MAKE GROUND, TOPSOIL AND SUBSOIL

Silty clay with some gravel, organic matter, locally a sand 2.0 0.3 0.8

12.5

13.9

0.4

0.8

5.7

4.9

C

C1

C2

PROBABLY MARINE DEPOSITS

Granular– Loose to medium dense fine SAND locally dense, slightly clayey

Cohesive – Soft locally firm CLAY occasionally with shells. Upper layers can be stiff, desiccated crust?

Base level of Marine Deposits 5.9 -13.2 -7.1 D

D1

D2

PROBABLY DELTAIC DEPOSITS Cohesive – Firm to stiff becoming very stiff vartbly coloured CLAY locally sandy and/or with sand bands Granular – Medium dense to very dense locally loose fine to medium silty locally clayey SAND

54.9

20.5

1.5

0.1

18.1

3.9

Level of Top of Completely Weathered Bedrock/Residual Soil

9.3 -70.6 -27.0 E COMPLETELY WEATHERED BEDROCK/RESIDUAL

SOIL

Dense to very dense SAND or very stiff to hard often gravelly CLAY 20.0 0.0 4.8

Rockhead Level 9.3 -83.9 -31.0 18.2 1.1 6.6

F BEDROCK

Interbedded weak to moderately strong red brown SANDSTONE, SILTSTONE and/or MUDSTONE locally strong and very strong locally with layers weathered to a clay/sand

Depth Penetrated

Source: NSRP-LLC, June 2010 3. Seismic Seismological characteristics The Nghi Son site is located in the north east part of the region with the age of continent crust dating back to early Carboniferous- Truong Son Hercynides. Adjacent to it in the north east there is the North West tectonic region where the continental crust was formed in early Paleozoic, separated from the Truong Son Hercynides zone by the Ma river deep-seated fault, 12 km apart from the plant to the north east. In the late Paleozoic and during the Mesozoic the continental crust was destroyed again in most of the north west area of Vietnam and a new crust was formed at the end of the late Triassic (the Da river intercontinental rift). This intensive tectogenesis process has greatly influenced the tectonics of the



project site. The north east part of the Hong river fault zone was developed into the Hanoi Cenozoic superimposed depression. The formation and development of the Hanoi depression have closely been related to the tectonic activities of the Hong river, Chay river and Lo river fault zones in the Cenozoic. The Truong Son Hercynides covers a quite large area, limited by the Ma river deep-seated fault to the north east and by Ta Khet Zone to the south and southwest.

Tectonic fault characteristics of the project site: seismological activities are closely related to tectonic fault characteristics at project site and the vicinity. Main faults

The fault of Ma river: This is one of the deep- seated faults. It plays an important role in two tectonic regions with the age of continental crust formation dating to the Paleozoic (in the northeast) and early Carboniferous (in the Southwest). The Fault has an extension of over 400km in the north west – south east direction from the land to Tinh Gia. The current activity of the fault is demonstrated by earthquake activities. It can be said that this is one of the faults in Vietnam with the strongest seismic activities. The current activity of the fault is also demonstrated by remote sensing, landslide, land-cracking and the occurrence of thermal and mineral spings. This is a large fault with high activity, located very close to the Nghi Son refinery and petrochemical complex (the nearest point at a distance of 12 km), and thus can directly influence structures.

The fault of Fumay Tun (Ma river 2): This is a II order fault separating the facio-structural zones

within the continental crust region at the beginning of Early Carboniferous, almost parallel with the Song Ma fault. It begins from Dien Bien and runs along the SW slope of the Fumay Tun mountain range, passing the NW of Pa Hoc village, then joins the Song Ma fault NW of Lang Chanh with a length of 250km. At present this zone is in relatively high activity with strong and deep centered earthquakes on the Vietnam- Laos border and south west of Lang Chanh. Since this fault is about 125 km away from the project site, the possibility that it could influence the project site is small.

The fault of Son La: This is a deep-seated fault which extends long (500km) and sinuously starting

at Sing Ho. The fault zone extends in a sub-meridian direction to the NW of Tuan Giao, Moc Chau; then in the NW-SE direction it reaches the sea in the area of Nga Son.

The current activity of the Son La fault zone is expressed clearly through earthquake activities. Its activity is also expressed by the land cracking and landslides in Lai Chau province, Son La town (in 1990) and the occurrence of thermal and mineral water springs.

This is one of the strong earthquake-generating fault zones, located not far from the study area (about 70km to the NE), and may cause earthquake danger to structures.

The fault of Da river: This is a II order fault, located relatively far away from the Project area and its

earthquake generation capacity is not high and thus there is a small possibility that it poses earthquake danger to structures.

The fault of Hong river: This is a deep-seated fault zone of global scale, extending near 1,000 km

from Tibet, running in NW-SE direction along the valley of the Red river through Yen Bai to Son Tay



and further buried under the Quaternary sediments of the Red river delta. Recent research results show that in the Neotectonic stage, two opposite strike-slip phases happened. This is cause of seismic activities in the Hanoi low land areas and other areas along the fault.

The fault of Chay river, located far away from the Project area and thus there is a small possibility

that it poses earthquake danger to structures. The fault of Ca river:The Song Ca fault in the south west of Nghi Son has a fairly great penetration

depth with geotectonic activities expressed by a variety of evidence:

- Distinct lineaments shown in the remote sensing images - Destruction of the Paleozoic, Mesozoic, including Neogene formations - Many earthquakes happened along it during the last century.

Main tectonic faults of the project site and the vicinity are given in Figure 2-12.



Figure 2-12.



Table 2.24 Basic features of fault zones in Nghi Son area

No

Fault name

Extending direction

Order and

number

Length

(km)

Penetration depth (km)

Dipping direction and angle

Displacement mechanism in N-Q

Nearest distance to

project (km)

1

Ma river

NW-SE

1- 4

400

60

NE/60-80

Right-slip reverses to normal right-slip in

SE extreme section.

11,.3

2 Son La NW-SE 1- 3 500 60 NE/60-70 As above 67

3 Hong river NW-SE 1- 2 >1,000 35-40 NE/65-70 As above 90

4 Chay river NW-SE 1-1 450 35-40 NE/80 As above 134

5 Fumay y Tun (Ma river 2) NW-SE 2- 5 250 25-30 NE/60-65 As above 115

6 Da river NW-SE 2- 6 350 25-30 NE/60-80 As above 76

7 Ca river NW-SE 2- 2 > 230 25-30 NE/60-80 Right-slip to normal

right-slip in SE extreme section

84

8 Ca river NW-SE 2- 3 > 150 35-40 NE/65-80 As above 55

9 Rao Nay NW-SE 2-1 230 35-40 NE/65-80 As above 96.5 Source: NSRP-LLC, June 2010 Recent seismic in project area Project area has high density of seismic centers. One of the most powerful seismic at magnitude of 6.7 has been recorded in project area. Seismic at M>4.5 with center vibration level of 6-7 occur quite frequent. Depths of seismic focuses are in range of 10-30km. 2.1.2.2 Meteorological conditions Thanh Hoa province has a transitional climate between the Northern and Central Regions of Vietnam with tropical monsoon type. The climatic characteristics during the winter are the same than for the Northern Region with hot (from May to September) and cold (from December to next year April). The rainy season and the storm season arrive later than in the Northern Region. Predominant wind direction of the province is East and Southeast. Annually, about 30 days have also West wind called Laos wind. 1. Temperature [6] Project area is located in the tropical monsoon area, besides it is affected by the Laotian wind (hot-dry in the summer) that often causes unfavorable for production and life of people. Monthly average temperature in Tinh Gia district in the period of 2004-2008 are presented in Table 2.25.



Table 2.25 Monthly Average Meteorological Data at Tinh Gia Station from 2004 to 2008

Month Temperature

(0C) Rainfall

(mm) Radiation

(hour) Wind velocity

(m/s) January 17.1 24.2 60.0 1.0 February 18.0 3.2 55.0 1.2

March 20.1 15.6 59.0 1.0 April 24.1 4.3 121.0 1.2 May 27.3 24.5 184.0 1.4 June 29.8 18.3 192.0 1.6 July 29.5 69.5 192.0 1.4

August 28.6 127.9 152.0 1.0 September 27.3 90.6 140.0 1.4

October 25.4 105.1 116.0 1.6 November 22.5 56.5 136.0 1.8 December 18.9 4.9 71.0 1.6 Average 24.1 544.6 1,477 1.32

Source: Southern Region Hydro Meteorogical Center. 2008 Based on monthly average temperature data at Tinh Gia station during 2004-2008 show that:

Average temperature in the project area is 24.1oC The lowest temperature is about 17oC (January) and the highest one 29.8oC (June)

According to statistical data of absolute maximum and minimum temperature at Tinh Gia stations during 1951 – 2008 [6] show that:

Absolute lowest temperature was recorded of 4.6oC in January (20th January 1954) Absolute highest temperature was recorded of 41.2oC in May (3rd May 1994)

During first six months of 2010, Tinh Gia is one area getting highest temperature of the Northern provinces. Air temperature recorded at Tinh Gia area in June 2010 reaches to 39oC – 41oC. 2. Rainfall [6] Monthly average rainfall (mm) at Tinh Gia station in the period of 2004-2008 is presented in Table 2.25. The rainfall results in this period show that:

Annual rainfall focus on May to October. The maximum rainfall occurs from August to October with a maximum rainfall reaching 4127.9mm in August. Dry season lasts from November to April. Even during the dry season, rainfall still occurs at a lower rate.

Total annual rainfall shows that there is no stability on the rainfall regime from year to year. The rainfall variability is very strong through the years and it depends on the unusual fluctuation of storms and tropical low pressure. Yearly rainfalls can vary in range of 1,506.2 – 2,397.5mm. Annual average rainfall (period 2004-2008) was 544.6mm.



3. Radiation [6] Compared to Thanh Hoa province, annual average sunshine hours in Tinh Gia district are higher. Total annual average hours at Tinh Gia district during 2004 – 2008 are 1,477 hours. The highest and lowest sunshine hours are 190.0 (in June and July) and 55.0 hours (in February).

4. Wind [6] Annual average wind speed recorded at Tinh Gia Station in period of 2004-2008 is 1.32m/s. Annual maximum wind speed is 1.8m/s (November) and minimum value is 1.0m/s (January, March and August). Besides, according to statistical data of highest wind speed (Table 2.26) and wind roses (Figure 2.13) in period of 1951 – 2008 recorded at Tinh Gia Station show that:

From October to February, prevalent wind direction is North, Northeast and Northwest. Wind direction is relatively stable with appearance frequency in January with directions of 37.3%, 19% and 15.7%, respectively. Average wind velocity is about 3.3 to 3.5 m/s and maximum wind velocity reaches 31 m/s. Maximum wind velocity frequency (< 5 m/s) reaches 70.8% in December and 78.3% in February. Frequency of maximum wind velocity (> 10m/s) reaches 6.0% in December and 1.1% in February.

March to May is a transitional period. The wind directions are not stable and the main wind directions are North (23.4%), Northeast (15%) and Southeast (7.6%). Average wind velocity is 3.2 to 3.4 m/s and the maximum wind velocity is 24 m/s. In this period, wind frequency of <5 m/s is about 85.4% (April). Wind frequency of above 10 m/s occurs rarely during this period with a frequency of about 0.4% (in April).

From May to August, the prevalent wind direction is Southwest (31%), South (20,9%) and Southeast (17%) (July). Along with the change of wind direction, average wind velocity varies about 3.6 to 4 m/s, the maximum wind velocity is quite strong with 35 m/s. Frequency of weak wind velocity varies from 18.2% (June) to 73.9% (August).

September to November is the transition period with variation of wind velocity and direction. The frequencies of North, Northeast of and Northwest directions are 35%, 19.8%, 16.2% respectively. Average velocity varies about 3.6 to 4.0 m/s and the maximum wind velocity reaches 46 m/s. Frequency of wind velocity (< 5 m/s) accounts for 80.3% (September) and 70.0% (December). Frequency of wind velocity (>10 m/s) appears mostly in October (5.9%).



Table 2.26 Annual Maximum Wind Velocity at Tinh Gia Station (m/s)

Year Vmax Direction Month Year Vmax Direction Month

1951 29 E 3/IX 1980 38 SE 16/IX

1952 27 ENE 28/VIII 1981 15 NNE 9/XI

1953 26 SW 14/VIII 1982 20 NW 18/X

1954 14 SW 12/XII 1983 12 SSW, SE VII

1955 10 NE 2/II 1984 10 N 22/X

1956 16 NE 1/IX 1985 24 N 22/X

1957 12 ENE 13/III 1986 20 NW 10/VIII

1958 12 NNE 6/VI 1987 27 E 23/VIII

1959 8 SW 3/VI 1988 15 SW 3/VII

1960 9 NW 13/X 1989 40 W 24/VII

1961 8 SSW 12/VI 1990 16 NNW 20/IX

1962 10 NE 17/IX 1991 10 ENE 17/VIII

1963 20 N 9/IX 1992 9 NE XII

1964 17 NW 8/X 1993 34 SE 12/VII

1965 8 NE 2/IX 1994 18 S 31/VII

1966 10 NE 14/XI 1995 15 SW V

1967 12 NW 7/IX 1996 25 S 23/VIII

1968 10 W 13/VIII 1997 18 NNW 22/IV

1969 9 SW 5/VI 1998 14 NNW 5/X

1970 >20 NNW 29/IX 1999 10 SW, N 19/III, 19/X

1971 17 SE 18/VII 2000 18 N 10/V

1972 12 E 6/IX 2001 15 NE 15/VIII

1973 20 N 8/VII 2002 10 N 06/X

1974 8 NE 6/XII 2003 18 SW 22/VII

1975 24 WWNN 20/IX 2004 14 SSE 20/IX

1976 16 N VII 2005 33 SSE IX

1977 18 SE 5/IX 2006 29 SSW VII

1978 18 NNE 12/VIII 2007 16 NE X

1979 12 NNW, NE 8,9/IX 2008 10 NE,NNW 22/III, 30/IX Source: Southern Region hydro Meteorogical Center, 2009 Below wind rose figures show prevail wind direction and velocity for each month in Tinh Gia station during 1951-2000.



JANUARY FEBRUARY MARCH

APRIL MAY JUNE

JULY AUGUST SEPTEMBER

OCTOBER NOVEMBER DECEMBER

Figure 2.13 Monthly wind roses in period of 1951-2000

at Tinh Gia station

0

5

10

15N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

2

4

6

8

10

12N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

2

4

6

8

10

12N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

2

4

6

8

10

12N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

2

4

6

8

10

12N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

2

4

6

8

10

12N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

2

4

6

8

10N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

2

4

6

8

10

12N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

2

4

6

8

10

12

14N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

5

10

15

20N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

5

10

15N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

0

5

10

15

20N

NNE

NE

ENE

E

ESE

SE

SSE

S

SSW

SW

WSW

W

WNW

NW

NNW

Chú thích

0.1 - 3.9 (m/s)

4 - 8.9 (m/s)

9 - 14.9 (m/s)

> 15 (m/s)

LEGEND



5. Extreme climatic phenomena [6] According to meteorological statistic data from 1951 to 2008, there were approximately 43 storms landed or impacted directly on Thanh Hoa province. Table 2.27 shows the time, direction and moving velocity of the major storms from 1951 to 2007.

Table 2.27 Major Storms in Thanh Hoa Province in period of 1951 - 2007

No. Name of storm Time Location Direction Velocity (m/s)

1 NORA 3/9/1951 Thanh Hoa W 22

2 LOIS 28/8/1951 Thanh Hoa WNW 25

3 OPHELIA 14/8/1953 Thanh Hoa NW 21

4 NONAME 29/8/1958 Thanh Hoa – Nghe An WNW 18

5 AGNES 18/8/1960 Thanh Hoa WNW 17

6 CHARLOTTE 22/9/1962 Ninh Binh WNW 27

7 PAYE 9/9/1963 Thanh Hoa SSW 13

8 ROSE 6/9/1965 Ninh Binh WSW 30

9 PHYLLIS 2/8/1966 Ninh Binh NW 15

10 PATSY 7/9/1967 Nghe An W 21

11 ROSE 13/8/1968 Ninh Binh W 22

12 HARRIET 7/7/1971 Thanh Hoa NW 10

13 TEAN 18/7/1971 Thanh Hoa WNW 25

14 MARGE 15/9/1973 Thanh Hoa WNW 18

15 10 DELLA 27/10/74 Thanh Hoa W 13

16 8 MICE 20/9/1975 Thanh Hoa W 30

17 RUTH 16/9/1980 Thanh Hoa WSW 19

18 KELLY 4/7/1981 Thanh Hoa – Nghe An WNW 14

19 CECIL 16/10/1985 Quang Tri – Ha Tinh –

Thanh Hoa WNW 20

20 DOT 22/10/1985 Ha Tinh– Thanh Hoa WNW 18

21 IR VING 24/7/1989 Thanh Hoa NW 19

22 7 BRIAN 3/10/1989 Nghe An – Thanh Hoa WNW 25

23 2 LEWIS 12/7/1993 Nghe An –Thanh Hoa –

Quang Ninh WNW 10

24 AMY 31/7/1994 Thanh Hoa WSW 17

25 LUKE 14/9/1994 Thanh Hoa W 20

26 LOIS 28/8/1995 Thanh Hoa WNW 13

27 TED 11/10/1995 Thanh Hoa N 10

28 WILLIE 22/9/1996 Nghe An – Ha Tinh

WSW 12

29 WUKONG 10/9/2000 Ha Tinh WSW 19



No. Name of storm Time Location Direction Velocity (m/s)

30 Tropical low pressure 27/9/2000 Thanh Hoa WNW 10

31 USAGI 11/8/2001 Nghe An-Ha Tinh WNW 15

32 ATNĐ 10/9/2001 Thanh Hoa-Nghe An WNW 15

33 3 KONI 22/7/2003 Thanh Hoa NW 25

34 Tropical low pressure 9/9/2003 Nghe An-Ha Tinh NW 20

35 Storm No 2 31/7/2005 Nam Dinh WNW 15

36 Storm No 3 12/8/2005 Thanh Hoa WNW 15

37 Storm No 5 31/8/2005 Nghe An WNW 15

38 DAMREY 27/9/2005 Thanh Hoa WNW 20

39 ATNĐ 3/7/2006 Thanh Hoa NW 15

40 Storm No 5 25/9/2006 Ha Tinh-Quang Binh WNW 15

41 Storm No 2 7/8/2007 Thanh Hoa-Nghe An NW 10

42 Storm No 4 25/9/2007 Thai Binh WNW 15

43 Storm No 5 3/10/2007 Quang Binh-Ha Tinh WNW 15 Source: Southern Region hydro Meteorogical Center, 2009 Statistical data for 56 years (1951-2007) show that Nghi Son Gulf is more influenced by storms and tropical low pressure than other area in Vietnam. There were more than 50 storms and cyclones landed to this area. But almost these storms created height waves, especially Kelly and Nancy storms. The maximum sea level risen by storms in Nghi Son Gulf is over 2.5m. Besides, two these storms had caused damages and impacted to houses, fishing boats and trees of local residents. But damage level is not serious. 2.1.2.3 Water Resources 1. Surface water There are Lach Bang, Thi Long and Yen Hoa rivers in the project area. However, discharges of these rivers are small and their waters are salinity intrusion. Besides, in project area and its vicinity, there are some reservoirs and lakes, such as Dong Chua, Que Son, Kim Giao, Muc and Yen My. Characteristics of these lakes/reservoirs are presented in Table 2.28.

Table 2.28 Characteristics of reservoirs

Lake name Area (km2)

Serviceable Volume (million m3)

Flood protective volume (million m3)

Dong Chua 9.2 1.26 0.64 Que Son 3.1 0.44 0.194 Kim Giao - 2.28 - Song Muc 236.0 187.0 - Yen My 137.0 80.63 58.8

Source: Overall Plan of NSEZ in Period of 2006-2025



2. Ground water Based on surveyed results of ground water level in the project area, especially in Mai Lam commune undertaken in FS stage show that ground water was found in layer (1) and fine sand layer (2). The surveyed results of ground water in Mai Lam commune are presented in Table 2.29.

Table 2.29 Ground water level in boreholes at Mai Lam commune

Borehole name

Water depth (m)

Ground elevation

(m)

Water level (m)

Borehole name

Water depth (m)

Ground elevation

(m)

Water level (m)

K-3 0.51 0.56 0.05 K-37 0.4 2.4 2.0

K-5 0.90 0.94 0.04 K-39 1.7 3.7 2.0

K-7 1.68 2.3 0.6 K-41 0.4 1.4 1.0

K-9 0.50 2.6 2.0 K-43 1.6 3.0 1.4

K-16 2.1 6.2 4.1 K-55 0.5 2.7 2.2

K-18 - 2.7 - K-57 1.2 2.3 1.1

K-20 0.55 1.1 0.6 K-59 1.0 1.9 0.8

K-22 - 0.7 - K-61 0.8 1.2 0.3

K-24 - 1.5 - K-63 1.2 2.0 0.8

K-1 4.0 2.58 -1.42 K-34 3.1 4.24 +1.14

K-2 2.5 2.23 -0.27 K-36 1.22 2.73 +1.51

K-4 1.0 1.25 +0.25 K-38 1.1 2.47 1.37

K-6 1.6 1.31 -0.29 K-40 - 1.94 -

K-10 1.25 1.65 +0.4 K-42 1.1 1.63 0.53

K-11 1.5 1.03 -0.47 K-44 3.4 2.51 -0.89

K-12 0.8 1.56 +0.76 K-45 3.4 2.28 -1.12

K-13 1.0 1.06 +0.06 K-46 1.46 2.44 0.98

K-14 1.8 1.65 -0.15 K-47 1.42 2.14 +0.72

K-15 1.8 1.06 -0.74 K-48 1.1 2.43 +1.33

K-17 1.8 5.48 +3.68 K-49 1.8 2.49 +0.69

K-19 2.3 2.86 +0.56 K-50 0.8 1.1 +0.3

K-21 1.05 0.72 -0.33 K-51 1.5 1.20 -0.3

K-23 1.6 1.24 -0.36 K-52 1.1 1.33 +0.23

K-25 3.3 4.71 +1.41 K- 53 1.0 1.43 +0.43

K-26 3.6 2.83 -0.77 K-54 3.5 2.94 -0.46

K-27 1.22 2.80 +1.58 K-56 1.4 2.27 +0.87

K-28 1.15 2.71 +1.56 K-58 - 2.54 -

K-29 1.72 1.34 -0.38 K-60 0.9 1.47 0.57



Borehole name

Water depth (m)

Ground elevation

(m)

Water level (m)

Borehole name

Water depth (m)

Ground elevation

(m)

Water level (m)

K-30 1.4 1.66 0.26 K-62 0.9 1.28 +0.38

K-31 1.52 1.73 +0.21 K-64 1.3 2.80 1.5

K-32 0.9 1.97 +1.07 K-65 1.8 1.73 -0.

K-33 1.0 1.20 +0.2 K-66 1.2 1.27 +0.07

Source: NSRP-LLC, June 2010 Monitoring results of ground water show that total discharge in 08 boreholes may be up to 13.306 m3/day. Water quality in project area is not equal (ground water quality at some boreholes are good, but water at some boreholes are salinity intrusion and acid sulphate soil), reserve is not much and unstable. 2.1.2.4 River system and flooding situation in project area Project area locates near Lach Bang river. This river connects to Hoang Mau and Yen Hoa rivers by Nha Le channel before flowing to Nghi Son Gulf. Lach Bang river is 34.5km in length and 246.5km2 in area. Total discharge of this river is about 800 million m3. There is flood control dike 3m in height with frequence of 10% built along Lach Bang riverside. Hydrological regime of Lach Bang river is influenced by tidal regime of Nghi Son Gulf. Amplitude of tide in Lach Bang river is about 2.0m. Project area locates near Lach Bang river and is influenced by tidal regime of Nghi Son Gulf. Lach Bang river flows to Nghi Son Gulf, so maximum water level in Lach Bang river may up to 2.5 m in case of typhoons. However, foundation of project area is +3m in height, it is hardly to be flooded in this area . Moreover, lower section of Lach Bang river is flat and even, sloping gently to the sea, so drainage ability of this area is very well and foundation of the Plant is +6m after clearance. Therefore, it is unable to occur flood in Project area. 2.1.2.5 Existing Environmental Conditions of Onshore and Coastal Area To assess environmental quality in the project area, CPSE has conducted survey sampling in two seasons: rainy season (August 2008 and June 2009) and dry season (February 2009) and analyzing of surface water, sediment and biology samples at onshore of the project area and its vicinity. The sampling locations are showed in Figure 2.5. 2.1.2.5.1 Air quality There are total 08 air sampling stations in project area, harbour, pipeline and its vicinity. Coordinates of these sampling stations are presented in Table 2.30.



Table 2.30 Coordinates of onshore air sampling stations

Coordinates Station Location

Y (m) X (m)

A-1 Residential area near Lach Bang river 581809 2145674 A-2 Residential area near Hai Yen commune 581262 2142614 A-3 581571 2140920 A-4

Project area 579741 2139607

A-5 School in Mai Lam commune 582102 2141271 A-6 Along export pipeline 583085 2139745 A-7 Export berth 586207 2135224 A-8 Fishing village in Nghi Son 586274 2138406

Grid: UTM; Datum: VN2000 1. Ambient hourly air quality Analytical results of air quality measured hourly are presented in Table 2.31.

Table 2.31 Analytical results of hourly air quality in onshore area

in dry season (February 2009) and rainy season (August 2008 and June 2009) samplings

NO2 CO SO2 H2S TSP Benzene Xylene PM10 THC Station

mg/Nm3 Dry season 0.014 3.2 0.012 <0.001 0.19 KPH KPH 0.03 1.6

A1 Rainy season 0.010 3.3 0.011 <0.001 0.23 KPH KPH 0.03 10 Dry season 0.011 3.4 0.010 <0.001 0.21 KPH KPH 0.03 2.5

A2 Rainy season 0.004 4.1 0.007 <0.001 0.17 KPH KPH 0.02 7.6 Dry season 0.013 3.3 0.012 <0.001 0.20 KPH KPH 0.03 2.2





A7 Rainy season 0.008 3.4 0.007 <0.001 0.20 KPH KPH 0.02 7.5 Dry season 0.009 3.2 0.008 <0.001 0.22 KPH KPH(1) 0.04 3.6

A8 Rainy season 0.009 2.6 0.010 <0.001 0.23 KPH KPH(1) 0.02 10

QCVN 05:2009 (1) 0.2 30 0.35 - 0.30 - - - - QCVN 06:2009 (2) - - - 0.042 - 0.022 1 - -

Source: CPSE, March 2010 The analytical results of air quality in Table 2.31 show that: Carbon monoxide (CO)

CO is one of important parameters used for emission research. This is a toxic gas formed from uncompleted oxidation process. Final products of engines are mainly CO2 and water, so increase of CO content in emission is caused by operation of flares.



Average value of CO contents at sampling stations range in a narrow range in both seasons. Compare to the results in the rainy season, CO in dry season is a slightly higher but these values are significantly lower than the allowable limit of 30mg/m3 of QCVN 05:2009/BTNMT and the allowable limit of 40mg/m3 of Equator principles.

Total hydrocarbon content (THC)

There is noticeable changing of THC content among sampling times in day. Average value of

THC content recorded in dry season is much lower than that in rainy season at all of sampling stations.

Gas chromatography shows that THC is mainly CH4 formed from anaerobic decomposition of

organic substances. In the rainy season, CH4 increase highly since strong operation of microorganisms in humid condition. CH4 tends to fly and disperse into atmosphere due to its light molecular weight. At sampling time, since temperature is low and dispersion process decreases, CH4 is easily captured.

Sulfur dioxide (SO2)

SO2 contents at all sampling stations are significantly lower than allowable limit of QCVN 05:2009/BTNMT(0.35mg/m3).

Hydrogen Sulfide (H2S)

All H2S values recorded in two seasons are lower than detection limit method and

significantly lower than allowable limit of QCVN 05:2009/BTNMT (0.042 mg/m3). Nitrogen dioxide (NO2)

In both sampling seasons, NO2 content at all stations is lower than allowable limit of 0.2

mg/m3 (QCVN 05:2009/BTNMT). Total Suspended Particulate Matter (SPM)

Average content of SPM is exceeded allowable limit (0.3mg/m3 – QCVN 05:2009) at stations A4 and A6 in the rainy season. This may be due to the fact that SPM is not only originated from transportation activity but also from other activities such as movement of some trucks bulldozers, digging, etc.

PM10

In generally, Particulate Matter (PM10) at all sampling stations in the dry season are higher than the ones in the rainy season.

Benzene and Xylen

In both of rainy and dry seasons, benzene and xylen contents at all sampling stations are lower than detection limit of analytical methods (GC-MS method).



2. Ambient air quality in 24 hours Parameters of CO, SO2 and SPM are measured continuously 24 hours in one day at 3 stations (A1, A2 and A5) in the rainy season June 2009. Analytical results of these parameters were presented in Table 2.32.

Table 2.32 Analytical results of ambient air quality in 24 hours

Station CO mg/m3

SO2 mg/m3

SPM mg/m3

A1 3.3 0.024 0.15 A2 4.4 0.037 0.14 A5 1.8 0.035 0.21

QCVN 05:2009 (1) 5.0 0.125 0.20 Source: CPSE, March 2010 (1) QCVN 05:2009/BTNMT: Air quality – Ambient air quality standards, 24 hourly average SPM parameter at station A5 is a little higher than allowable limit stipulated in QCVN 05:2009/BTNMT, but all other parameters are much lower than allowable limit of QCVN 05:2009/BTNMT. Noise and vibration quality

To assess noise and vibration quality in the project area, CPSE has measured noise and vibration nearby residential areas and in the plant’s boundary (Figure 2.14).

N01N02

N03N05N04

N06

N07

N08

N09 N10N11 N12

N13

N16N14

N15

Figure 2.14 Stations for Site Measurement of Noise and Vibration at the Boundary of Plant Area



Measure results of vibration and noise are shown in Table 2.33 and 2.34.

Table 2.33 Measure results of vibration and noise at residential site (hourly average)

Noise Vibration

Dry season Rainy season Dry season Rainy season Station

6am-6pm 6pm-10pm 10pm-6am

6am-6pm 6pm-10pm

10pm-6am

7am-7pm 7pm-7am 7am-7pm 7pm-7am

A6 73.6 66.7 55.0 56.9 57.2 56.6 56.8 54.4 57.7 51.9

A7 59.1 55.3 50.3 45.0 45.5 45.8 53.7 50.5 52.7 51.5

A8 49.7 48.1 47.0 43.6 43.9 43.7 47.9 47.1 49.7 47.9

N17 43.9 48.2 39.8 51.7 51.7 52.2 44.2 44.9 45.7 45.8

N18 43.6 58.3 39.9 46.5 47.0 47.2 43.7 54.8 44.9 57.2

N21 58.7 51.5 39.4 48.4 44.9 49.0 50.5 46.5 51.5 50.6

TCVN (1) 70 70 50 70 70 50 75 65 75 65 Source: CPSE, March 2010 Note: (1) Noise standard of the Project for residential area

Table 2.34 Measurement results of vibration and noise at Plant site (hourly average)

Noise Vibration

Dry season Rainy season Dry season Rainy season Station

6am-6pm 6pm-10pm

10pm-6am

6am-6pm 6pm-10pm

10pm-6am

7am-7pm

7pm-7am

7am-7pm 7pm-7am

N2 74.9 75.5 48.6 54.9 54.6 54.8 64.1 61.5 64.9 63.2

N5 71.9 76.6 49.7 58.3 57.2 55.0 61.7 60.3 63.9 60.8

N6 68.3 64.1 48.3 52.0 50.7 49.0 60.5 55.2 62.5 60.9

N7 52.3 55.3 56.6 55.0 55.2 55.1 48.8 53.8 49.4 50.2

N9 61.4 55.7 55.5 54.3 53.8 53.6 50.7 52.7 48.7 51.3

N10 50.0 49.4 49.8 50.0 50.0 50.0 48.5 49.2 48.6 51.1

N13 50.6 46.5 46.3 53.0 51.5 51.2 48.7 46.8 49.0 45.3

N14 55.2 49.1 47.2 52.7 52.5 51.3 48.4 47.9 47.1 46.7

N15 52.7 51.5 50.8 51.2 51.9 50.9 49.1 49.9 47.2 48.8

N16 71.1 72.3 48.3 55.7 56.4 55.7 60.0 56.7 59.9 57.2

A3 49.6 49.4 47.9 49.2 49.4 48.8 47.9 47.2 47.2 45.9

A4 55.1 49.3 51.4 53.1 52.8 52.8 47.8 47.6 47.8 45.8

TCVN (1) 70 70 70 70 70 70 75 65 75 65 Source: CPSE, March 2010 Note: (1) Noise standard of the Project for residential area Results in Table 2.33 and 2.34 show that: At residential area

In general, noise values at residential area in dry and rainy season (except station A6) are lower than limit level of Project Noise Standards. Noise values of station A6 in shift 1 (6am-



6pm) and shift 3 (10pm-6am) are higher than limit level due to this station is located near the road with a lot of traffic.

The values of vibration at residential area are lower than limit level stipulated in Vietnamese standard (TCVN 6962:2001).

There is no different of noise and vibration between rainy and dry season.

At Plant area

Noise values at station N2, N5 and N16 in the dry season are higher than Project noise standards (70dB) from 6am to 10pm. The reason is due to these stations are sited along the dense traffic road. Beside that, stations N5 and N16 are also located at high noise area

All vibration values at plant area are lower than limit level stipulated in Vietnamese standard (TCVN 6962:2001). At all station, there are no different of vibration values at dry and rainy season.

2.1.2.5.2. Water quality Assessment of water quality in onshore area is based on analytical results and comparison with QCVN 08:2008/BTNMT. Location of surface water, sediments and biology sampling stations in onshore area (B1 and B2 stations) and coastal area (B3 to B11 station) are presented in Table 2.35.

Table 2.35 Location of surface water, sediments and biology sampling stations in onshore and coastal areas

Coordinate

Station Sampling Location Y (m) X (m)

B-1 Lach Bang estuary 582403 2145255

B-2 Lach Bang river 580628 2145943

B-3 Organic soil disposal site of the Project 580881 2142931

B-4 Planned outfall point 583207 2141610

B-5 Planned cooling water intake point 583467 2140543

B-6 Planned cooling water discharge point 583630 2139896

B-7 585726 2136850

B-8 585882 2135532

B-9

Vicinity of product export berth (old export port alternatives)

586049 2134913

B-10 Area between B1 and B4 station 582736.2 2143735.6

B-11 Near Nghi Son fishing village 586893.4 2138191.2 Grid: UTM; Datum: VN2000

1. Onshore area Analytical results of onshore surface water quality and its vicinity are presented in Table 2.36, 2.37 and 2.38.



Table 2.36 Physical analysis results of onshore surface water quality (August 2008 and February 2009)

On field parameters Station

pH Salinity ‰ Temperature oC Dry season 7.5 31 23

B - 2 Rainy season 7.5 32 28 Dry season 7.2 32 22

B - 3 Rainy season 7.3 31 27

QCVN 08: 2008/BTNMT 5.5 – 9 - - Source: CPSE, March 2010

Table 2.37 Chemical analysis results of onshore surface water quality (August 2008 and February 2009)

Parameter (mg/L)

Station TSS Oil NH4+ Total N Total P Phenol TOC Benzene CN- BOD

Coliform (MPN/ 100ml)

Dry season 30 0.011 0.046 0.84 0.023 <0.001 1.2 < 0.001 < 0.007 0.57 19

B - 2 Rainy

season 5.8 0.011 <0.004 0.70 <0.007 <0.001 1.1 < 0.001 < 0.007 0.79 105

Dry season 17 0.012 <0.004 1.03 0.015 <0.001 2.8 < 0.001 < 0.007 0.66 22

B - 3 Rainy

season 26 0.012 0.060 1.03 <0.007 <0.001 3.35 < 0.001 < 0.007 2.61 11

QCVN 08 : 2008/BTNM 100 0.3 1 - - 0.02 - - 0.02 25 10,000


Table 2.38 Metal analysis results of onshore surface water (August 2008 and February 2009)

Station Cu (mg/l)

Pb (mg/l)

Zn (mg/l)

Cd (mg/l)

Cr (mg/l)

Fe (mg/l)

Hg (mg/l)

Dry season <0.005 0.004 <0.005 <0.005 < 0.02 0.33 < 0,001

B - 2 Rainy season <0.005

<0.001-0.002

<0.005-0.006 <0.005 < 0.02 <0.08-0.12 < 0,001

Dry season

<0.005 0.003 <0.005 <0.005 < 0.02 0.24 < 0,001 B - 3

Rainy season <0.005 0.004 0.015 <0.005 < 0.02 0.61 < 0,001

QCVN 08 : 2008/BTNMT 1 0.05 2 0.01 0.05 2 0.002 Source: CPSE, March 2010 Note: QCVN 08:2008/BTNMT, Column B2: National technical regulation on surface water quality From results of above tables, it may withdraw some conclusions as followings:

Surface water quality (B2 and B3 station) in both of two seasons are quite good and lower than allowable limits stipulated in QCVN 08:2008/BTNMT;

Phenol, benzene, CN- and some heavy metal contents are lower than the detection limit of analytical methods;

TSS, NH4+ and total P contents at station B2 in dry season is much higher than the ones in the rainy season.

Metal contents are lower than allowable limits stipulated in QCVN 08:2008/BTNMT.



2. Coastal area Analytical results of surface water in coastal area and its vicinity are presented in Table 2.39, Table 2.40 and Table 2.41.

Table 2.39 Physiochemical analysis results of coastal surface water quality

(August 2008 and February 2009)

Parameter Station

pH DO (mg/l) Salinity (‰) Temperature (oC) Dry season 7.5 5.5 32.9 24.1

K - 7 Rainy season 7.6 5.4 29 27 Dry season 7.8 5.5 32.5 24.4





K - 12 Rainy season 7.5 5.6 31 27 Dry season 7.7 5.7 33 25

E - 1 Rainy season 7.6 5.6 30 27 Dry season 7.6 5.6 33

E - 18 Rainy season 7.5 5.6 30 26 Dry season 7.8 - 31 23

B - 1 Rainy season 7.7 - 32.0 27.7 Dry season 7.8 - 32 22







B - 10 Rainy season 7.7 - 29 25 Dry season 7.8 - 32 24

B - 11 Rainy season 7.7 - 28 26

QCVN 10 : 2008 6.5 – 8.5 - - - Source: CPSE, March 2010



Table 2.40 Chemical analysis results of coastal surface water quality (August 2008 and February 2009)

Parameter (mg/L) Station Season

TSS THC(*) NH4+ SO42- NO2- NO3- Total N Total P Phenol TOC Benzene CN- BOD COD Coliform (MPN/100ml)

Dry season 18 0.013 0.059 2310 - - 0.93 0.019 <0.001 1.3 < 0.001 <0.007 0.7 1.9 48 B - 1 Rainy season 5.1 0.013 <0.004 - - - 0.23 <0.007 <0.001 1.2 < 0.001 < 0.007 0.80 - 140 Dry season 16 0.022 0.051 2360 - - 0.60 0.018 <0.001 1.2 < 0.001 < 0.007 0.89 2.1 160 B - 4 Rainy season 5.8 0.022 0.022 - - - 0.54 <0.007 <0.001 1.1 < 0.001 < 0.007 0.71 - 25 Dry season 14 0.011 0.06 2320 - - 0.74 0.034 <0.001 1.1 <0.001 < 0.007 0.67 1.8 80 B - 5 Rainy season 5.4 0.011 0.023 - - - 0.63 <0.007 <0.001 0.935 < 0.001 < 0.007 0.67 - 25 Dry season 15 0.0091 0.049 2310 - - 0.57 0.013 <0.001 1.0 < 0.001 <0.007 0.69 1.9 14 B - 6 Rainy season 6.0 0.009 0.023 - - - 0.65 <0.007 <0.001 0.94 < 0.001 < 0.007 0.80 - 28 Dry season 17 0.0085 0.18 2250 - - 0.96 0.055 <0.001 1.9 < 0.001 < 0.007 0.65 1.8 22 B - 7 Rainy season 7.3 0.009 0.50 - - - 1.5 <0.007 <0.001 2.1 < 0.001 < 0.007 4.81 - 125 Dry season 15 0.013 0.079 2440 - - 0.57 0.013 <0.001 1.3 < 0.001 < 0.007 0.73 1.9 10 B - 8 Rainy season 10.5 0.013 <0.004 - - - 0.50 <0.007 <0.001 1.1 < 0.001 < 0.007 0.81 - 355 Dry season 14 0.0096 0.028 2420 - - 0.68 0.007 <0.001 1.1 < 0.001 < 0.007 0.69 1.9 11 B - 9 Rainy season 9.5 0.010 0.024 - - - 0.46 <0.007 <0.001 1.0 < 0.001 < 0.007 0.73 - 125 Dry season 16 0.009 0.026 2340 - - 0.65 0.017 <0.001 1.3 < 0.001 < 0.007 0.77 0.92 10 B - 10 Rainy season 8.3 0.016 0.046 2215 - - 0.88 0.012 <0.001 1.4 < 0.001 < 0.007 0.64 - <2 Dry season 15 0.011 0.10 2320 - - 0.58 0.028 <0.001 1.2 < 0.001 < 0.007 0.75 1.1 10 B - 11 Rainy season 9.4 0.017 0.053 2060 - - 0.72 0.009 <0.001 1.3 < 0.001 < 0.007 0.78 - <2 Dry season 11 0.011 <0.004 2170 0.019 0.089 0.58 0.032 <0.001 <0.001 <0.001 <0.007 0.69 1.9 - K - 7 Rainy season 11 0.012 0.13 2150 0.048 0.012 0.62 0.012 <0.001 0.032 < 0.001 <0.007 0.69 1.9 - Dry season 14 0.01 0.0093 2370 0.037 0.014 0.81 0.034 <0.001 0.034 <0.001 <0.007 0.68 1.8 - K - 8 Rainy season 13 0.012 0.097 2340 0.004 0.005 0.70 0.023 <0.001 0.034 < 0.001 <0.007 0.68 1.8 - Dry season 14 0.011 0.014 2375 0.014 0.021 0.57 0.021 <0.001 0.01 <0.001 <0.007 0.71 1.9 - K - 9 Rainy season 14 0.017 0.014 2245 0.007 0.015 0.60 0.012 <0.001 0.01 < 0.001 <0.007 0.71 1.9 - Dry season 19 0.015 0.0086 2390 0.027 0.009 0.56 0.018 <0.001 0.018 <0.001 <0.007 0.66 1.8 - K - 10 Rainy season 15 0.017 0.022 2130 0.005 0.016 0.58 0.013 <0.001 0.018 < 0.001 <0.007 0.66 1.8 - Dry season 18 0.015 0.0085 2420 0.021 0.029 0.46 0.013 <0.001 0.013 <0.001 <0.007 0.68 1.8 - K - 11 Rainy season 16 0.015 0.05 2150 0.018 0.012 0.55 0.011 <0.001 0.013 < 0.001 <0.007 0.68 1.8 - Dry season 19 0.014 0.0081 2415 0.025 0.032 0.55 0.012 <0.001 0.012 <0.001 <0.007 0.66 1.8 - K - 12 Rainy season 15 0.015 0.063 2225 0.006 0.009 0.94 0.089 <0.001 0.012 < 0.001 <0.007 0.66 1.8 - Dry season 13 0.012 0.026 2390 0.016 0.0.12 0.41 0.012 <0.001 0.012 <0.001 < 0.007 0.75 1.9 - E - 1 Rainy season 14 0.013 0.034 2150 0.001 0.016 0.49 <0.007 <0.001 <0.007 < 0.001 < 0.007 0.63 1.9 - Dry season 15 0.013 0.0391 2370 0.017 0.011 0.64 0.011 <0.001 0.035 <0.001 < 0.007 0.8 2.0 - E - 18 Rainy season 11 0.018 0.051 2150 0.005 0.026 0.58 0.029 <0.001 0.029 < 0.001 <0.007 0.61 1.8 -

QCVN 10 : 2008/BTNMT - 0.2 0.5 - - - - - 0.002 - - 0.01 - - 1000 Source: CPSE, March 2010



Table 2.41 Metal analysis results of onshore surface water (August 2008 and February 2009)

Parameter (mg/L) Station

Cu Pb Zn Cd Cr Fe Hg

Dry season <0.005 0.008 0.032 <0.005 < 0.02 0.319 < 0.001 B - 1

Rainy season <0.005 0.002 <0.005 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 <0.001-0.016 0.050 <0.005 < 0.02 0.167 < 0.001 B - 4

Rainy season <0.005 0.003 <0.005 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 0.006 0.009 <0.005 < 0.02 0.290 < 0.001 B - 5

Rainy season <0.005 <0.001-0.004 <0.005 <0.005 < 0.02 <0.08-0.14 < 0.001

Dry season <0.005 0.004 <0.005-0.007 <0.005 < 0.02 0.364 < 0.001 B - 6

Rainy season <0.005 <0.001 <0.005-0.008 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 0.004 <0.005 <0.005 < 0.02 0.182 < 0.001 B - 7

Rainy season <0.005 <0.001 <0.005-0.012 <0.005 < 0.02 <0.08-0.08 < 0.001

Dry season <0.005 0.004 0.010 <0.005 < 0.02 0.260 < 0.001 B - 8

Rainy season <0.005 0.004 0.010 <0.005 < 0.02 0.26 < 0.001

Dry season <0.005 0.006 0.009 <0.005 < 0.02 0.238 < 0.001 B-9

Rainy season <0.005 <0.001-0.003 <0.005-0.007 <0.005 < 0.02 0.14 < 0.001

Dry season <0.005 0.002 0.030 <0.005 < 0.02 < 0.08 < 0.001 B-10

Rainy season <0.005 0.002 0.030 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 0.001 0.014 <0.005 < 0.02 < 0.08 < 0.001 B-11

Rainy season <0.005 0.001 0.014 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 <0.001 0.005 <0.005 < 0.02 < 0.08 < 0.001 K-7

Rainy season <0.005 <0.001 0.005 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 – 0.77 < 0.001 K-8

Rainy season <0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 – 0.77 < 0.001

Dry season <0.005 <0.001 0.005 <0.005 < 0.02 < 0.08 < 0.001 K-9

Rainy season <0.005 <0.001 0.005 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 < 0.001 K-10

Rainy season <0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 <0.001 0.006 <0.005 < 0.02 < 0.08 < 0.001 K - 11

Rainy season <0.005 <0.001 0.006 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 < 0.001 K - 12

Rainy season <0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 <0.001 <0.005 <0.005 < 0.02 <0.08 < 0.001 E - 1

Rainy season <0.005 <0.001 -

0.003 0.008 <0.005 < 0.02 < 0.08 < 0.001

Dry season <0.005 <0.001 <0.005 <0.005 < 0.02 <0.08 < 0.001 E - 18

Rainy season <0.005 0.003 0.008 <0.005 < 0.02 < 0.08 < 0.001




Above results show that:

In general, most of analytical results of coastal surface water are rather good and lower than allowable limits stipulated in QCVN 10:2008/BTNMT.

Phenol, Benzene, CN- and some heavy metal contents (Cd, Cu, Cr and Hg) are lower than the detection limit of analytical methods.

The parameters of pH, Temperature, Salinity, Dissolved Oxygen are stable between stations and between two sampling seasons. At some stations locating very close to onshore, especially station B7, there are existing a lot of algae in the rainy season, so the concentration of BOD, NH4+, Total N and TOC increase slightly.

2.1.2.5.3 Groundwater quality Assessment of water quality in onshore area is based on analytical results and comparison with QCVN 09:2008/BTNMT. Locations of sampling stations are presented in Figure 2.5 and coordinates of them are shown in Table 2.42.

Table 2.42 Coordinates of ground water sampling stations - NSRP

Coordinate

Station Location Y (m) X (m)

G-1 579714 2139604

G-2 Plant site

581571 2140920

G-3 Along onshore pipeline route 583088 2139762

G-4 Product export berth 586212 2135223

G-5 Nghi Son fishing village 586042 2138253

G-6 The East of the Refinery Plant close to shoreline 582102.0 2141271.0

G-7 Refinery area 581014.7 2141872.5 Grid: UTM; Datum: VN2000 The water depths of sampling wells are as follows: 6-7m at G1 well; 9-10m at G2 well; 10m at G4 well; 14m at G6 well. Wells G3, G5 and G7 are pumping wells. Analytical results of ground water in Project area are presented in Table 2.43 and Table 2.44.



Table 2.43 Analytical results of ground water quality in Project area (August 2008 and February 2009)

Parameter (mg/l)

Station pH

Colour (Co/Pt) Oil NH4+ SO42- NO3- Phenol Cl- Benzene CN- TDS

Hardness (mgCaCO3/L)

COD (mg/l)

Coliform (MPN/ 100ml)

Dry season 6.3 225 0.014 0.066 30 1.39 <0.001 43 < 0.001 < 0.007 295 95 5.0 34 G - 1 Rainy

season 6.1 221 0.024 0.037 11 0.19 <0.001 50 < 0.001 < 0.007 - 40 11 3,400

Dry season 6.7 22 0.013 0.016 34 1.99 <0.001 53 < 0.001 < 0.007 295 90 3.4 49 G - 2 Rainy

season 7.1 34 0.012 0.12 26 0.21 <0.001 106 < 0.001 < 0.007 - 160 3.5 140

Dry season 7.0 <5 0.011 <0.004 30 1.52 <0.001 39 < 0.001 < 0.007 390 195 1.7 33 G - 3 Rainy

season 6.6 3.9 0.011 0.011 21 1.7 <0.001 71 < 0.001 < 0.007 - 370 7.1 700

Dry season 5.1 <5 0.014 0.0048 25 1.82 <0.001 58 < 0.001 < 0.007 245 65 2.5 350 G - 4 Rainy

season 4.4 1.8 0.014 0.066 41 1.4 <0.001 355 < 0.001 < 0.007 - 320 4.7 49


season 7.0 1.8 0.006 <0.004 6.7 0.20 <0.001 28 < 0.001 < 0.007 - 180 4.7 23


season 7.8 <5 0.024 0.037 11 0.19 <0.001 50 < 0.001 < 0.007 - 40 11 3,400

Dry season 6.7 <5 0.012 0.017 29 0.98 <0.001 78 < 0.001 < 0.007 600 250 5.6 790 G - 7 Rainy

season 7.3 <5 0.013 0.020 25 1.5 <0.001 91 < 0.001 < 0.007 660 250 5.1 1,720

QCVN 09 : 2008/BTNMT 5,5–8,5 - - 0.1 400 15 0.001 250 - 0.01 - 500 4 3




Table 2.44 Metal analysis results of ground water in Project area (August 2008 and February 2009)

Station Cu (mg/l) Pb (mg/l)

Zn (mg/l) Cd (mg/l)

Cr (mg/l)

Fe (mg/l) Hg (mg/l)

Mn (mg/l)

Dry season

<0.005 0.007 0.017 <0.005 < 0.02 0.19 < 0.001 0.03 G - 1

Rainy season

0.029 0.008 0.030 <0.005 0.28 < 0.08 < 0.001 0.12

Dry season <0.005 0.002 0.008 <0.005 < 0.02 0.10 < 0.001 < 0.03

G - 2 Rainy

season <0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 < 0.001 0.03

Dry season <0.005 0.002 <0.005 <0.005 < 0.02 0.18 < 0.001 0.68

G - 3 Rainy

season 0.005 0.003 0.013 <0.005 0.25 < 0.08 < 0.001 1.40

Dry season

<0.005 0.004 0.014 <0.005 < 0.02 0.29 < 0.001 < 0.03 G - 4

Rainy season

<0.005 0.01 0.15 <0.005 < 0.02 < 0.08 < 0.001 0.31

Dry season <0.005 0.002 0.042 <0.005 < 0.02 0.11 < 0.001 <0.03

G - 5 Rainy

season <0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 < 0.001 0.03

Dry season <0.005 <0.001 <0.005 <0.005 < 0.02 0.09 < 0.001 <0.03

G - 6 Rainy

season 0.029 0.008 0.030 <0.005 0.28 < 0.08 < 0.001 0.12

Dry season

<0.005 0.004 0.023 <0.005 < 0.02 < 0.08 < 0.001 0.04 G - 7

Rainy season

<0.005 <0.001 <0.005 <0.005 < 0.02 < 0.08 < 0.001 <0.03

QCVN 09 : 2008/BTNMT 1 0.01 3 0.005 0.05 5 0.001 0.5

Source: CPSE, March 2010 Analytical results in Table 2.43 and Table 2.44 show that:

In both seasons, except G1 (shallow well, high turbidity and yellow color), water of remained wells are clear and colorless.

In rainy season as well as in dry season, most of analytical results of ground water are quite good and lower than allowable limit of QCVN 09:2008/BTNMT, except coliform (at all of stations) and Mn (at station G-3) which is exceeded the allowable limit.

Phenol, CN-, and almost metal contents are lower than detection limit of analytical methods.



2.1.2.5.4 Sediment Quality

1. Grain size distribution in onshore sediment

Analytical results of grain size distribution are summarized in Table 2.45, 2.46 and 2.47.

Table 2.45 Analytical results of grain size distribution in onshore sediment (August 2008 and February 2009)

Station Mean of diameter

Standard deviation (diameter)

Unsymmetry Sharpness %

coarse %

fine Classification

index Type of

sediment

Dry season 3.52 1.73 0.96 4.92 0.89 19.66 Average Very fine sand

B-2 Rainy season 1.55 1.31 1.65 11.16 3.20 3.00 Good

Average sand

Dry season 3.16 1.44 1.84 8.53 0.64 10.25 Good Very fine sand

B-3 Rainy season 3.80 1.86 1.38 4.20 0.00 23.79 Average

Very fine sand


Table 2.46 HC analysis results of onshore sediment (August 2008 and February 2009)

Station UCM ∑n-C13-35 CPI Pr./Ph. UCM /∑n-C13-35 THC

Dry season 14 2.2 4 0.7 6 19 B-2

Rainy season 2 0.3 2.2 0.9 7 2

Dry season 2 1.8 4 3.8 1 5 B-3

Rainy season 2 1.8 3.9 2.9 1 4


Table 2.47 Metal analysis results of onshore sediment (August 2008 and February 2009)

Station Cu (µg/g)

Pb (µg/g)

Zn (µg/g)

Cd (µg/g)

Cr (µg/g)

Fe (%)

Hg (µg/g)

Dry season 26 34 65 < 1 43 3.1 0.27 B-2

Rainy season 7 20 31 < 1 3,0 19 0.038

Dry season 8.4 17 46 < 1 27 1.5 0.052 B-3

Rainy season 13 18 46 < 1 3.1 63 0.030 Source: CPSE, March 2010 Results in above tables show that:

Sediment at station B2 in rainy season is coarser than the ones in dry season. By visual observation, environment at station B2 is contaminated by many waste sources in the dry season.

Similar to variation of grain size, total hydrocarbon content in sediment at station B2 in the dry season (19µg/g) is much higher than that in rainy season (2µg/g) due to the difference of sediment characteristis between two seasons.



At all onshore stations, metal contents in sediment samples are at normal level in both of two seasons. Cd contents are lower than the detection limit (1µg/g). Fe content in sediment as well as soil recorded in rainy season is much higher than that in dry season.

2. Grain size distribution in coastal sediment Analytical results of grain size distribution in coastal sediment and vicinity are presented in Table 2.48, Table 2.49 and Table 2.50.

Table 2.48 Analytical results of grain size distribution in coastal sediment

August 2008 and February 2009

Station Mean of diamete

r


Unsymmetry

Sharpness %

coarse %

fine Classify index

Type of sediment

Dry season 5.11 1.89 0.59 2.49 0.00 57.63 Average Moderate sludge

K-7 Rainy

season 5.66 2.08 -0.27 3.01 0.66 75.50 Poor Moderate sludge

Dry season 2.43 2.28 0.79 4.04 5.60 11.56 Poor Fine sand K-8 Rainy

season 3.42 1.48 1.79 7.39 0.34 15.11 Good Very fine sand

Dry season 4.78 1.87 0.91 2.68 0.00 41.94 Average Coarse sludge

K-9 Rainy

season 4.93 2.16 0.41 2.10 0.00 53.68 Poor Coarse sludge

Dry season 3.86 1.42 1.50 7.91 0.69 17.69 Good Very fine sand K-10 Rainy

season 3.71 2.16 0.57 3.71 2.61 29.45 Poor Very fine sand


K-11 Rainy

season 6.12 1.77 0.03 2.31 0.00 85.37 Average Fine sludge


K-12 Rainy

season 6.40 1.69 -0.04 2.48 0.00 92.51 Average Fine sludge

Dry season 3.21 1.40 -0.17 8.91 2.49 6.75 Good Very fine sand E-1 Rainy

season 3.54 1.69 0.33 6.48 2.61 16.07 Average Very fine sand

Dry season 3.74 0.95 3.28 15.69 0.00 10.62 Very good Very fine sand E-18 Rainy

season 4.06 1.30 2.33 7.82 0.00 21.28 Good

Coarse sludge

Dry season 3.51 0.53 4.87 46.10 0.00 2.55 Very good Very fine sand B-1 Rainy

season 0.95 1.16 1.17 8.74 4.31 1.03 Good Coarse sand

Dry season 3.74 1.15 1.76 14.21 0.84 9.68 Good Very fine sand B-4 Rainy

season 3.25 0.82 2.58 18.96 0.00 3.25 Very good Very fine sand



B-6 Dry season 3.48 0.73 -2.22 38.94 1.23 2.42 Very good Very fine sand



Station Mean of diamete

r


Unsymmetry

Sharpness %

coarse %

fine Classify index

Type of sediment

Rainy season

2.82 0.72 1.78 22.21 0.38 1.81 Very good Fine sand

Dry season 2.06 2.30 0.43 3.17 13.26 12.81 Poor Fine sand B-7 Rainy

season 3.41 2.73 0.23 2.58 7.89 31.39 Very poor Very fine sand

Dry season 4.44 1.85 1.12 3.32 0.03 33.32 Average Coarse sludge

B-8 Rainy

season 2.96 1.23 2.59 11.72 0.16 8.31 Good Fine sand

Dry season 6.39 1.61 -0.27 3.30 0.00 93.62 Average Fine sludge B-9 Rainy

season 2.87 1.22 2.94 13.70 0.20 8.13 Good Fine sand



Dry season 2.15 3.09 0.55 2.26 20.23 23.74 Extremely poor Fine sand B-11 Rainy

season 2.15 3.09 0.55 2.26 20.23 23.74 Extremely poor Fine sand

Source: CPSE, March 2010 Sediments at coastal sampling stations are classified as fine silt to coarse silt in the rainy season

and from fine silt to fine sand in the dry season. It is noted that, the dredging activity at areas of shipping channel is observed in dry survey, so sediment at stations B8 and B9 seems to be finer than that of the rainy survey.

It also records that sediment at station B1 significantly changed between two sampling seasons. It may be due to stations B1 locates at the estuary of Lach Bang River, where is noticeably effected by current, weather from season to season.

Table 2.49 Analysis results of Hydrocarbon in coastal sediment


Station UCM ∑n-C13-35 CPI Pr/Ph UCM /∑n-C13-35 THC

Dry season 10 1.2 4 1.5 8 13 K-7

Rainy season 18 1.7 4.2 2.2 11 22 Dry season 1.4 0.3 1 0.7 5 2

K-8 Rainy season 5 0.6 2.3 1.7 9 7 Dry season 13 1.1 3 1.1 11 16

K-9 Rainy season 29 1.1 2.8 1.4 26 32 Dry season 5.8 0.9 3 2.3 7 9



K-12 Rainy season 6 1.4 4.1 3.0 4 9 Dry season 2 0.4 3 2.1 5 3

E-1 Rainy season 1 0.3 1.6 0.6 6 2

E-18 Dry season 2 0.4 1 0.6 6 3



Station UCM ∑n-C13-35 CPI Pr/Ph UCM /∑n-C13-35 THC

Rainy season 1 0.3 1.5 1.1 5 2 Dry season 2 0.3 1 0.8 9 3

B-1 Rainy season 2 0.2 1.0 0.9 10 2 Dry season 2 0.4 1 1.2 5 2







B-10 Rainy season 2 0.2 2 0.6 10 3 Dry season 4 0.9 2 0.8 4 6

B-11 Rainy season 4 0.9 2 0.8 4 6

Source: CPSE, March 2010 Hydrocarbons analysis results of coastal sediment at the project and its vicinity are presented in Table 2.49 showing that:

THC values at coastal sampling stations vary in a wide range in both of rainy and dry seasons (from 2 to 23 µg/g in the dry season and from 2 to 32 µg/g in the rainy season).

THC contents at stations B8, B9 and K9 vary greatly from rainy season to dry season.

All CPI values (Carbon Preference Index) are higher than 1 in both of rainy and dry seasons.

Table 2.50 Metal analysis results of coastal sediment


Station Cu (µg/g) Pb (µg/g) Zn (µg/g) Cd (µg/g) Cr (µg/g) V (µg/g) Fe (%) Hg (µg/g)

Dry season 30 32 77 < 1 54 < 63 - 0.106 K-7 Rainy

season 40 36 73 < 1 98 < 63

- 0.092


season 16 21 55 < 1 56 < 63 -

0.044


season 27 26 53 < 1 65 < 63 -

0.053

Dry season 12 8,5 55 < 1 33 < 63 - 0.031 K-10 Rainy

season 14 15 39 < 1 49 < 63

- 0.022

K-11 Dry season 27 16 73 < 1 53 < 63 - 0.024



Station Cu (µg/g) Pb (µg/g) Zn (µg/g) Cd (µg/g) Cr (µg/g) V (µg/g) Fe (%) Hg (µg/g)

Rainy season

32 33 59 < 1 72 < 63 -

0.055


season 31 33 58 < 1 70 < 63 -

0.053

Dry season 10 <6 52 < 1 38 < 63 - <0.02 E-1 Rainy

season 9,3 14 58 < 1 40 < 63 -

0.076

Dry season 10 17 60 < 1 42 < 63 - 0.17 E-18 Rainy

season 8,9 17 51 < 1 33 < 63

- 0.027

Dry season 8 20 58 < 1 41 - 2.7 0.074 B-1 Rainy

season 5 27 22 < 1 2,2 - 2.2

0.051

Dry season 8 21 48 < 1 1,9 - 32 0.046 B-4 Rainy

season 11 16 49 < 1 3,0 - 3.0 0.030


season 11 15 49 < 1 3,6 - 3.6 0.024


season 11 24 58 < 1 4,4 - 4.4 0.031


season 15 24 37 < 1 1,9 - 1.9 0.045


season 12 20 43 < 1 3,1 - 3.1 0.041


season 14 26 38 < 1 2,7 - 2.7 0.050


season 15 21 46 < 1 28 - 2.3 0.062


season 7,7 18 51 < 1 24 - 2.3 0.033

Source: CPSE, March 2010 Metal analysis results of coastal sediment in Table 2.50 show that:

Among selected metals, Cd and V are found lower than detection limit of AAS method.

Contents of metals are not much changed from season to season at most of coastal sampling stations accept at stations B8, B9 where observed the dredging activity in dry survey.



2.1.2.4.5 Soil quality Soil sampling locations are shown in Figure 2.4 and coordinates of them are presented in Table 2.51.

Table 2.51 Soil sampling coordinates in Project area

Coordinate Station Location

Y (m) X (m)

D-1 Disposal site of the Project 580881 2142931 D-2 Open site 579697 2140014 D-3 579714 2139604 D-4 581571 2140920 D-5

Project site 581919 2140049

D-6 Along pipeline 583088 2139762 D-7 Product export pipeline 586212 2135223 D-8 Nghi Son fishing village 586042 2138253 D-9 Refinery site 581014.7 2141872.5

Source: CPSE, March 2010 Grid: UTM; Datum: VN2000 Table 2.52 HC analysis results of soil in Project area


Station UCM ∑n-C13-35 CPI Pr./Ph. UCM /∑n-C13-35 THC % TOM

Dry season 2 2.0 3.5 0.9 1 6 1.9 D-1

Rainy season 0 1.0 3.8 0.6 0 2 0 Dry season 1 0.4 2.1 0.8 3 3 0.5

D-2 Rainy season 0 0.4 1.9 1.0 1 1 0 Dry season 18 3.3 1.6 0.7 5.4 28 4.4

D-3 Rainy season 2 0.9 3.8 0.3 2 5 2 Dry season 2 0.7 3.9 0.7 2 4 0.9




D-7 Rainy season 205 KPH KPH KPH KPH 219 205 Dry season 7 0.6 1.6 0.9 11 16 1.6


D-9 Rainy season 4 2.2 5 0.4 2 8 2.1




Table 2.53 Metal analysis results of soil in Project area August 2008 and February 2009

Station Cu (µg/g) Pb (µg/g) Zn (µg/g) Cd (µg/g) Cr (µg/g) Fe (%) Hg (µg/g)

Dry season 8.3 19 32 < 1 28 1.6 0.12 D-1

Rainy season 14 22 42 < 1 2.1 38 0.048 Dry season 9.6 6.9 8.9 < 1 11 0.81 0.069

D-2 Rainy season 14 14 24 < 1 1.5 22 0.040 Dry season 17 17 45 < 1 13 1.0 0.074

D-3 Rainy season 17 15 32 < 1 0.87 14 <0.02 Dry season 5.5 17 29 < 1 17 1.3 0.087


D-5 Rainy season 12 27 64 < 1 3.4 41 0.050 Dry season 7.4 27 68 < 1 38 2.4 0.11




D-9 Rainy season 8.2 22 79 < 1 15 1.2 0.066

QCVN 03:2008/BTNMT(*) 100 300 300 10 - - - Source: CPSE, March 2010 From above results, some conclusions may be withdrawn as followings:

Total hydrocarbon contents of soil at sampling stations vary in wide range (from 3 to 84µg/g in the dry season and from 1 to 219µg/g in the rainy season). The highest value of THC is found at station D7 located at Nghi Son fishing village in both of two seasons;

At all onshore stations, metal contents in soil samples are lower than QCVN 03:2008/BTNMT;

Cd contents at all stations are lower than detective threshold of analytical method (1<µg/g). Recorded Fe contents in sediment samples in rainy season are higher than they are in dry season.

2.1.2.5.6 Biological Ecosystem 1. Terrestrial Ecosystem Flora [7] Based on survey result in the radius 7.5 km, the flora ecosystem types in the Project study area have been defined as follows:



Secondary broad-leaf, restored tropical forests ecosystem

This ecosystem mainly exists on Hon Me Island. The whole island is covered by small and medium green broadleaf trees and bushes with some main species including Schaeffer octophylla of Araliaceae family, Sapium discolor of Euphorbiaceae family, Sterculia lanceolata of Sterculiaceae family, etc.

Plantation forest ecosystem

Plantation forest ecosystem is located in many areas of the Project Study Area. The main plantations are located on the Do (Hai Thanh commune), Chuot Chu, Cam mountains and some hills of Hai Yen, Hai Thuong and Mai Lam communes. Plantation forests here occupied diverse areas and have different species and plant ages. Most species in plantation forest are Eucalyptus (Bach đan) with age of 7-10 years, Pinus merkusiana (cây thông) with age of 15-20 years, Eucalyptus exserta (bach đan lieu) with age 1-5 years, Acacia auriculaeformis (Keo la tram), Albizia corniculata (muong) and the top layer of Pinus (thong). There are few Acacia magnum (Keo tai tuong).

Shrub - ecosystem

This is the most common ecosystem in the project area, appearing in hilly and mountainous areas. Shrub ecosystem is the consequence of human effects on the model of broad-leaf restored tropical forest. However, even on Hon Me Island, where tree cutting activities have not been done by residents during the past decades, shrub ecosystem still exists because poor soil or thin soil layer cannot support development of trees. Shrub ecosystem structure only includes 2 layers: shrub ecosystem at the maximum height of 8m and bush layer at the maximum height of 3m. However, the diversification is decided by the high quantity of species per area unit. Furthermore, advantageous number of bush species usually changes in a relatively small area, for example, Rhodomyrtus tomentosa can dominate in one area and Melastoma candidum can be abundant just several meters beside. This is different from pure forest or advantageous plants forest, like - Dipterocarpaceae forest.

Grass ecosystem, coastal sand-bank

Grass and coastal sand bank ecosystem is counted to have 106 species which ranks 4th in term or species quantity among 8 ecosystems of the projected area. The common species are Imperata cylindrica (cỏ tranh), Ischaemum indicum (cỏ trấu), Ischaemum indicum (cỏ lông sương), Microstegium vagans (cỏ lá tre), Miscanthus nepalensis (lách), M. floridulus (chè vè), Saccharum spontaneum (lau), Thysanolaena latifolia (đót).

Standstill water ecosystem

Project area has some standstill water as lakes, bogs, ponds where shrimps are bred. It has a small quantity of botany species with 12 species, ranking 7th among 8 ecosystems of the area. All the botanies in this ecosystem are herbaceous plants in which Pteridophyta has 2 species Equisetum diffusum, Acrostichum aureum. Angiospermae has 3 species Enhydra fluctuans, Homonoia riparia, Ipomoea aquatica belonging to Dicotyledones. Monocotyledones has 7 species: Sagittaria sagittaefolia, Acorus calamus, A. gramineus, Pistia stratiotes, Eleocharis palustris, Cyperus elatus, Eichornia crassipes.



Agricultural ecosystem

Agricultural ecosystem includes food plants, mainly short-term plants planted on the agricultural land in the project area. This ecosystem has 79 species, ranking 5th in term of species quantity among 8 ecosystems.

Population ecosystem

Floral species composition in this ecosystem is relatively diversified, including not only wild plants but also different useful plants used to produce handicraft, constructional material, beverage, to chew, fruit tree, plant for packing, drug plants, used as spices, vegetable, pot plant, shade tree... It has 127 species, ranking 3rd just after shrub ecosystem and secondary broad-leaf restored tropical forest ecosystem.

Most of families raise such fruit trees as coconut, guava, starfruit, banana, averrhoa, papaya, longan, leeches…and do the same with such greens and plants of the spices as thi la (Anethum graveolens), rau mui (Coriandrum sativum), mui tau (Eryngium foetidum), rau hung lang (Mentha aquatica), kinh gioi (Elsholtzia ciliata), hung chanh (Coleus amboinicus )… Other plants can be named are cruciferae like cai xanh (Brassica juncea), su hào (B. caulorapa), bap cai (B. oleracea)…

Mangrove forest ecosystem

Mangrove system mainly located in Lach Bang, Thanh Binh Hamlet, Hai Thanh and Hai Binh Communes and Yen Hoa river belonging to Hai Ha and Hai Thuong communes. The mangrove forest ecosystem has 10 species such as Đuoc Voi (Rhizophora stylosa), Vet Du (Bruguiera gymnorhiza), Mam Bien (Avicennia marina) and Ban Chua (Sonneratia caseolaris).

Distribution Map of Flora ecosystem is shown in Figure 2-15.



Figure 2-15



Regional Threats to Flora Diversity Flora diversity in the Project Study Area has not yet been affected by regional threats except the invasive introduced species that not only affect directly to the environment but also cause damage for preservation as well as community’s health and living. According to “Harmful exotic plants” published by IUCN and The Institute of Ecology and Biological Resources in 2003, the project area has these following invasive introduced species:

1. Mimosa pigra L. (common English name for all) 2. Lantana camara L. 3. Imperata cylindrica ( L.) P.Beauv. 4. Eupatorium odoratum L. 5. Leucaena leucocephala ( Lamk.) de Wit. 6. Eichhornia crassipes ( Mares ) Solms.

The lesson of Mai Duong (Mimosa pigra) plant in Tram Chim National Garden is the warning for un-extended growth and persistent of invasive introduced species because it springs up well in any type of soils, sprouts even in stumps, breed and flourish strongly after burned, its seeds can scatter far following streams…In the Project Study Area, Mimosa pigra makes its appearance in many places with few individuals. For instances, this exotic plant can be found along the road, on the ponds of Mai Lam Commune.

Vegetation and Flora Assemblages in the Project Area The project affects some different areas such as Plant site area (328ha), Nghi Son Refinery Project Management Board, Equipment storage area and other area for constructor (101 ha), Borrow pit - Chuot Chu Mountain (136 ha), Disposal area (40 ha), Access road (8 ha), Pipeline (30ha) and Port and Jetty (36 ha). According to collection data during field survey, vegetation and flora assemblages in specific project area are shown as following: Plant site area

Vegetation in the project area mainly plant short-term food product such as rice, sweet potatoes, corn and peanut. In addition, in residential areas plant fruit trees as pineapple, guavab, banana, pepper, papaya and vegetables.

Borrow pit – Chuot Chu Mountain

The vegetation on Chuot Chu Mountain is mainly covered by Eucalyptus (Bach đan) (7-10 year), Pinus merkusiana (cay thong) (15-20 year), Acacia auriculaeformis (keo la tram), Acacia magnum (keo tai tuong). Under



the wood layer is shrub layer, liana and grass. Eucalyptus with shrub layer is scattered such as Rhodomyrtus tomentosa (cây sim), Melastoma candidum (mua), Saccharum spontaneum (Lau), Miscanthus japonicus (chít), M. Floridulus (chè vè), Dicranopteris linearis (gu�t), Bidens pilosa (đ�n bu�t), Eupatorium odoratum (c� lào), Ischaemum indicum (c� lông s��ng), Imperata cylindrica (c� tranh).

Disposal area and Access road

The Disposal area and access road was previous used for aquaculture along Lach Bang river. Vegetation at this area includes c� tranh (Imperata cylindrica), c� tr�u (Apluda mutica), c� lông s��ng (Ischaemum indicum ), c� lá tre (Microstegium vagans), lách (Miscanthus nepalensis), chè vè (M. floridulus), lau (Saccharum spontaneum) and đót (Thysanolaena latifolia).

Pipeline and Port and Jetty

The vegetation along Pipeline and Port and Jetty is mainly Population and Grass and coastal sand bank Ecosystem.

Terrestrial Fauna [8] The existing fauna in the Project Study Area has been described through specific field survey, data, sample collection and analysis in laboratory conducted by CPSE from August 16th to September 3rd 2008. Mammal Through field survey, interviews of local communities and reference document related to the Project Study Area, 24 species, 15 families, 9 orders of mammal have been identified. Mammal species composition and distribution in the project area and its vicinity are presented in Table 2.54.

Table 2.54 Mammal Species Composition and Distribution

Ecosystem

No Scientific name English name (1) (2) (3) (4) (5) (6)

I. SCANDENTIA TREE-SHREWS 1. Tupaidae Tree-Shrews 1 Tupaia belangeri Common Tree-Shrew x x II. PRIMATES PRIMATES 2. Cercopithecidae Old-World Monkeys 2 Macaca assamensis Assamese Macaque x x 3 Macaca fascicularis Crab-Eating Macaque x III. SORICOMOPHA INSECTIVORES 3. Soricidae Shrews 4 Crocidura attennata Grey Shrew x x 5 Suncus murinus House Shrew x x IV. CHIROPTERA BATS 4. Hipposideridae Trident Bats 6 Asellicus stoliczkanus Stoliczka’s Trident Bat x x 5. Pteropodidae Fruit Bats



Ecosystem No Scientific name English name

(1) (2) (3) (4) (5) (6) 7 Macroglossus minimus Common Long-Tongued Fruit bat x x V. PHOLIDOTA PANGOLINS 6. Manidae Pangolins 8 Manis pentadactyla Chinese Pangolin x VI. CARNIVORA CARNIVORES 7. Viverridae Civets, Viverrids 9 Viverra zibetha Large Indian Civet x x 10 Viverricola indica Small Indian Civet x x x 8. Herpestidae Mongooses

11 Herpestes javanicus Small Asian Mongoose x x 12 Herpestes urva Crab-Eating Mongoose x x VII. ARTIODACTYLA EVEN-TOED UNGULATED 9. Suidae Pigs

13 Sus Serofa Wild Boar x 10. Cervidae Deer

14 Muntiacus muntjak Common Barking Deer x VIII. RODENTIA VIII. RODENTS 11. Sciuridae Non-Flying Squirrels

15 Callosciurus erythraeus Palla’s Squirrel x x 16 Callosciurus inornatus Irrawaddy Squirrel x 17 Tamiop macclellandii Himalayan Striped Squirrel x x x 12. Spalacidae Bamboo Rats

18 Rhizomys pruinosus Hoary Bamboo Rat x x 13. Muridae Rats

19 Mus caroli Ryukyu Mouse x x x 20 Mus musculus House Mouse x x 21 Rattus losea Lesser Rice-Field Rat x x 22 Rattus tanezumi House Rat x x 14. Hystricidae Old-World Porcupines

23 Hystrix brachyura Malayan Porcupine x TOTAL 7 0 6 4 10 16

Source: Assessment of existing biodiversity of terrestrial fauna (mammals, birds, reptiles and amphibians) in the Nghi Son Petrochemical Project, Tinh Gia district, Thanh Hoa province by Prof. Dr. Dang Huy Huynh, M.Sc. Ngo Xuan Tuong and Coworkers, 2008 Avifauna Through field survey, interviews of local communities and reference document related to the Project Study Area; 73 species, 26 families, 7 orders of avifauna have been identified. Avifauna species composition and distribution in the Project Study Area are presented in Table 2.55.



Table 2.55 Avifauna species composition and distribution

Threatened species No Scientific name English name

SĐVN, 2007 NĐ32 /2006 I. GALLIFORMES 1. Phasianidae 1 Francotinus pincadeanus Chinese Francolin 2 Gallus gallus Red Junglefowl II. CORACIIFORMES 2. Alcedinidae 3 Alcedo atthis Common Kingfisher 3. Halcyonidae 4 Halcyon smyrnensis White-throated Kingfisher 5 Halcyon pileata Black-capped Kingfisher III. CUCULIFORMES 4. Centropodidae 6 Centropus sinensis Greater Coucal 7 Centropus bengalensis Lesser Coucal IV. APODIFORMES 5. Apodidae 8 Collocalia fuciphaga Edible-nest Swiftlet 9 Apus pacificus Fork-tailed Swift V. COLUMBIFORMES 6. Columbidae

10 Streptopelia tranquebarica Red Collared Dove 11 Streptopelia chinensis Spotted Dove 12 Treron curvirostra Thick-billed Green Pigeon VI. CICONIIFORMES 7. Scolopacidae

13 Tringa nebularia Common Greenshank 14 Actitis hypoleucos Common Sandpiper 8. Charadriidae

15 Himantopus himantopus Black-winged Stilt 16 Charadrius dubius Little Ringed Plover 17 Charadrius alexandrinus Kentish Plover 18 Charadrius mongolus Lesser Sand Plover 9. Laridae

19 Sterna sp. Tern 10. Accipitridae

20 Milvus migrans Black Kite 21 Spilornis cheela Crested Serpent Eagle IIB 11. Falconidae

22 Falco severus Oriental Hobby 12. Podicipedidae

23 Tachybaptus ruficollis Little Grebe 13. Ardeidae

24 Egretta garzetta Little Egret




SĐVN, 2007 NĐ32 /2006 25 Casmerodius alba Great Egret 26 Bubulcus ibis Cattle Egret 27 Ardeola bacchus Chinese Pond Heron 28 Butorides striatus Little Heron 29 Nycticorax nycticorax Black-crowned Night Heron 14. Pelecanidae

30 Pelecanas philippensis Spot-billed Pelican EN VII. PASSERIFORMES 15. Laniidae

31 Lanius collurioides Burmese Shrike 32 Lanius schach Long-tailed Shrike 16. Corvidae

33 Corvus macrorhynchos Large-billed Crow 34 Artamus fuscus Ashy Woodswallow 35 Rhipidura albicollis White-throated Fantail 36 Hypothymis azurea Black-naped Monarch 37 Dicrurus macrocercus Black Drongo 38 Dicrurus leucophaeus Ashy Drongo 39 Oriolus chinensis Black-naped Oriole 17. Muscicapidae

40 Monticola solitarius Blue Rockthrush 41 Culicicapa ceylonensis Grey-headed Canary flycatcher 42 Copsychus saularis Oriental Magpie Robin 18. Sturnidae

43 Sturnus nigricollis Black-collared Starling 44 Acridotheres tristis Common Myna 45 Acridotheres grandis White-vented Myna 46 Acridotheres cristatellus Crested Myna 19. Paridae

47 Parus major Great Tit 20. Hirundinidae

48 Hirundo rustica Barn Swallow 49 Hirundo daurica Red-rumped Swallow 21. Pycnonotidae

50 Pycnonotus jocosus Red-whiskered Bulbul 51 Pycnonotus sinensis Light-vented Bulbul 52 Pycnonotus cafer Red-vented Bulbul 53 Pycnonotus aurigaster Sooty-headed Bulbul 54 Pycnonotus finlaysoni Stripe-throated Bulbul 55 Alophoixus pallidus Puff-throated Bulbul 22. Cisticolidae

56 Cisticola juncidis Zitting Cisticola 57 Prinia subflava Plain Prinia 23. Zosteropidae

58 Zosterops japonicus Japanese White-eye




SĐVN, 2007 NĐ32 /2006 24. Sylviidae

59 Orthotomus sutorius Common Tailorbird 60 Orthotomus atrogularis Dack-necked Tailorbird 61 Macronous gularis Striped Tit Babbler 62 Garrulax chinensis Black-throated Laughingthrush 63 Garrulax canorus Hwamei 64 Stachyris nigriceps Grey-throated Babbler 65 Yuhina zantholeuca White-bellied Yuhina 25. Nectariniidae

66 Dicaeum concolor Plain Flowerpecker 67 Dicaeum cruentatum Scarlet-backed Flowerpecker 68 Nectarinia jugularis Olive-backed Sunbird 69 Aethopiga siparaja Crimson Sunbird 70 Arachrothera longirostra Little Spiderhunter 26. Passeridae

71 Passer montanus Eurasian Tree Sparrow 72 Anthus richardi Richard's Pipit 73 Lonchura punctulata Scaly-breasted Munia

Source: Assessment of existing biodiversity of terrestrial fauna (mammals, birds, reptiles and amphibians) in the Nghi Son Petrochemical Project, Tinh Gia district, Thanh Hoa province by Prof. Dr. Dang Huy Huynh, M.Sc. Ngo Xuan Tuong and Coworkers, 2008

Notes: - SĐVN (2007): Red Data Book of Vietnam 2007: EN: Endangered. - NĐ32/2006: The Governmental Decree No 32/2006/NĐ-CP: IIB: Limit of exploitation and use.

Reptiles Through field survey, interviews of local communities and reference document related to the Project Study Area; 22 species, 7 families, 1 orders of reptiles have been identified. Composition and distribution of Reptile in the Project Study Area are presented in Table 2.56.

Table 2.56 Reptiles species composition and distribution

Ecosystem

No Scientific name English name (1) (2) (3) (4) (5) (6)

I. SQUAMATA 1. Geckonidae 1 Gecko gecko Tockay, Gecko x x x 2 Hemydaclylus frenatus Spiny-tailed House Gecko x x 2. Agamidae 3 Acanthosuura lepidogaster Scale-bellied Tree Lizard x x x x 4 Calotex versicolor Garden fence lizard x x x x 5 Physignathus cocincinus Indochineses water dragon x x x x 6 Leiolepis guttata Gutta butterfly lizard x 3. Seincidae 7 Lygosoma quadrupes Short-limbed supple skink x 8 Mabuya longicaudata Long-tailed Skink x x x




(1) (2) (3) (4) (5) (6) 4. Varanidae 9 Varanus salvalor Water monitor x x 5. Boidae

10 Python molurus Burmese python, Asiatic rock python x 6. Colubridae

11 Ahaetulba prasina Oriental Whip Snake x x 12 Amphiesma stolata Buff-striped Keelback x x 13 Boiga multomculata Multitemporaled Cat Snake x x 14 Elaphe radiata Copperhead racer, Radiated rat

snake x x x x

15 Pareas hamptoni Hampton’s slug snake x x 16 Ptyas korros Indochineses rat snake x x 17 Ptyas mucosus Common rat snake, Oriental rat

snake x x x

18 Xemochrophis piscata Checkered keelback x 7. Elapidae

19 Bungarus fasciatus Banded krait x 20 Bungarus multicinctus Many-banded krait x 21 Naja atra Chinese Cobra x x 22 Trimeresurus albolabrix White-lipped pitviper, Bamboo snake x x

Total 6 1 10 2 13 17


Amphibian Through field survey, interviews of local communities and reference document related to the Project Study Area, 11 species, 4 families, 1 orders of amphibian have been identified. Amphibian species composition and distribution in the Project Study Area are presented in Table 2.57.

Table 2.57 Distribution of amphibians species in the Project area


(1) (2) (3) (4) (5) (6) I. ANURA 1. Bufonidae 1 Bufo galeatus Gamboja toad x x x 2 Bufo melanosticus Asian common toad, Common sunda toad,

Black spined toad x x x x

2. Ranidae 3 Huia sp. frog x 4 Hoplobatrachus rugulosus Common lowland frog, Chinese bullfrog,

Taiwanese frog x x

5 Limnoneates limnocharis Grass frog, Paddy frog, Rice frog, Asian pool frog x x x x 6 Rana guentheri Gunther’s amoy frog, Gunther’s frog x x x 7 Rana johnsi Johnsi frog x x




(1) (2) (3) (4) (5) (6) 8 Rana nigrovittata (*) Black-striped frog x 3. Rhacophoridae 9 Polypedates leucomystax Four-lined Treefrog x x x x 4. Michrohylidae

10 Kaloula pulchra Guangdong Rice Frog x 11 Michrohyla ornata Ornate Pigmy Frog x x

Total 2 0 5 6 8 6


Diversity of invertebrate fauna based on habitat types in the project area is presented in Table 2.58.

Table 2.58 Diversity of vertebrate fauna based on habitat types in the project area

Species quantity No Class animal Hon Me Island Tidal mud

flat Residential

area Agricultural area Shrub area Plantation forest and

hilly forest 1 Mammal 8 0 6 4 10 16 2 Bird 47 26 50 36 42 50 3 Reptile 6 1 10 2 13 17 4 Amphibians 2 0 5 6 8 6

Total 63 27 71 48 73 89


Table 2.58 shows that the vertebrate fauna is not diverse. It is noted that the range of animals is overlaped in different habitat types and also depends on the seasons. In migration season, many water birds are found in the lakes and estuary, where they can find the food during migration time. Sensitive and Protected Species Based on the Vietnam Red Book (2007) and Decree 32/2006/ND-CP of the Government, the threatened species located in the Project Study Area are presented in Table 2.59.

Table 2.59 Threatened species in the Project Study Area

No Scientific name English name SĐVN 2007 NĐ32 /2006

MAMMALIA MAMMAL Four species Five species 1 Macaca assamensis Assamese Macaque VU IIB 2 Macaca fascicularis Crab-Eating Macaque LR IIB 3 Manis pentadactyla Chinese Pangolin EN IIB 4 Viverra zibetha Large Indian Civet IIB 5 Viverricola indica Small Indian Civet IIB 6 Hystrix brachyura Malayan Porcupine VU AVES BIRD One species One species



No Scientific name English name SĐVN 2007 NĐ32 /2006

7 Spilornis cheela Crested Serpent Eagle IIB 8 Pelecanas philippensis Spot-billed Pelican EN REPTILIA REPTILE Eight species Six species 9 Leiolepis guttala Gutta butterfly lizard VU 10 Varanus salvalor Water monitor EN IIB 11 Python molurus Burmese python, Asiatic rock python CR IIB 12 Elaphe radiata Copperhead racer, Radiated rat snake VU IIB 13 Ptyas korros Indochineses rat snake EN 14 Ptyas mucosus Common rat snake, Oriental rat snake EN IIB 15 Bungarus fasciatus Banded krait EN IIB 16 Bungarus multicinctus Many-banded krait IIB 17 Naja atra Chinese Cobra EN

AMPHIBIA AMPHIBIANS One species 18 Bufo galeatus Gamboja toad VU

Source: Assessment of existing biodiversity of terrestrial fauna (mammals, birds, reptiles and amphibians) in the Nghi Son Petrochemical Project, Tinh Gia district, Thanh Hoa province by Prof. Dr. Dang Huy Huynh, M.Sc. Ngo Xuan Tuong and Coworkers

Notes: - SĐVN (2007): Red Data Book of Vietnam 2007: CR: Critically Endangered; EN: Endangered; VU: Vulnerable. - NĐ32/2006: The Governmental Decree No 32/2006/NĐ-CP: IIB: Limit of exploitation and use.

Threatened species are listed in the Vietnam Red Data Book (2007) and the Government Decree No 32/2006/NĐ-CP including six species of mammals, two species of birds, nine species of reptiles, and one species of amphibians. However, these species are distributed in the mountains and forests which are quite far from the construction site and the future Refinery and Petrochemical Complex Plant. The remaining (unthreatened) species are distributed widely in Tinh Gia District (Thanh Hoa) in particular and Vietnam general. Location, coordinates and distribution map of threatened species (animals, birds, reptiles, amphibians) are presented as follows:

Assamese Macaque Macaca assamensis (Assamese Macaque) Location: Hon Me Archipelago. Coordinate: 19o21’07.3”N-105o54’54.4”E.

Crab-Eating Macaque Macaca fascicularis (Crab-Eating Macaque) Location: Hon Me archipelago. Coordinate: 19o21’07.3”N-105o54’54.4”E.

Chinese Pangolin Manis pentadactyla (Chinese Pangolin) Locations: Xuoc mountain, Rang Cua mountain.

Large Indian Civet Viverra zibetha (Large Indian Civet) Location: Xuoc mountain.

Small Indian Civet Viverricola indica (Small Indian Civet) Locations: Cam mountain, Rang Cua mountain. Coordinate: 19o20’21.7”N-105o45’54.4”E.

Malayan Porcupine Hystrix brachyura (Malayan Porcupine) Locations: Chuot Chu mountain, Cam mountain. Coordinates: 19o20’47.2”N-105o46’50.8”E; 19o20’21.7”N-105o45’54.4”E.



Crested Serpent Eagle Spilornis cheela (Crested Serpent Eagle) Locations: Hon Me Archipelago, Chuot Chu mountain, Cam mountain, Xuoc mountain, Rang Cua mountain. Coordinates: 19o21’07.3”N-105o54’54.4”E; 19o20’47.2”N-105o46’50.8”E; 19o20’21.7”N-105o45’54.4”E.

Spot-billed Pelican Pelecanas philippensis (Spot-billed Pelican) Location: Gieng Ngoc area (Nghi Son commune). Coordinate: 19o19’37.5”N-105o48’58.0”E.

Gutta butterfly lizard Leiolepis guttala (Gutta butterfly lizard) Locations: Along seaside of communes: Hai Hoa, Hai Thuong, Hai Yen, Nghi Son…

Water monitor Varanus salvalor (Water monitor) Locations: Hon Me archipelago, Xuoc mountain. Coordinate: 19o21’07.3”N-105o54’54.4”E.

Burmese python, Asiatic rock python Python molurus (Burmese python, Asiatic rock python) Locations: Chuot Chu mountain, Xuoc mountain, Rang Cua mountain. Coordinate: 19o20’47.2”N-105o46’50.8”E.

Copperhead racer, Radiated rat snake Elaphe radiata (Copperhead racer, Radiated rat snake) Location: Hon Me Archipelago. Coordinate: 19o21’07.3”N-105o54’54.4”E.

Indochineses rat snake Ptyas korros (Indochineses rat snake) Locations: Hon Me archipelago, Chuot Chu mountain, Cam mountain. Coordinates: 19o21’07.3”N-105o54’54.4”E; 19o20’47.2”N-105o46’50.8”E; 19o20’21.7”N-105o45’54.4”E.

Common rat snake, Oriental rat snake Ptyas mucosus (Burmese python, Asiatic rock python) Locations: Hon Me archipelago, Rang Cua mountain. Coordinate: 19o21’07.3”N-105o54’54.4”E.

Banded krait Bungarus fasciatus (Banded krait) Location: Hon Me archipelago. Coordinate: 19o21’07.3”N-105o54’54.4”E.



Figure 2-16



2. Aquatic ecosystem To assess aquatic ecosystem (plankton and benthos) at the coastal and onshore areas nearby the project area; CPSE carried out the sampling in dry and rainy seasons (2008-2009). Biological sampling locations will be illustrated in Figure 2-5. Onshore area Phytoplankton Analytical results of phytoplankton community at two onshore stations are presented in Table 2.60 and detailed results will be attached in Appendix III.

Table 2.60 Analytical results of phytoplankton community in onshore area August 2008 and February 2009

Number of taxon (taxon/0.05m3)

Density (103.inds/m3) H(s) J C

Station Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season

B2 19 19 5,670 318 2.85 3.27 0.67 0.77 0.26 0.14

B3 15 14 15,939 175 2.61 2.07 0.67 0.54 0.20 0.41

Average 17 17 10,805 247 2.73 2.67 0.67 0.66 0.23 0.27

Diversity of phytoplankton community is rather difference between two studied stations. At station B2, both of taxon quantity and diversity index are higher than that at station B3. The changing of other parameters of phytoplankton is in normal range between two stations as well as two seasons. Concerning taxon composition, on both of two seasons, there are 03 phyla presented including Bacillariophyta, Dinophyta and Cyanophyta. The Bacillariophyta is the most diversity one. It takes 73% and 58% of taxon total on dry and rainy seasons. The following ones are Dianophyta and Cyanophyta. Concerning to density composition, Bacillariophyta also takes the largest portion, on dry season; following ones are Cyanophyta and then Dianophyata. However, on rainy season, the highest portion belongs to Cyanophyta phylum. The portions of the others are nearly equal



Zooplankton Analytical results of zooplankton at two onshore stations are presented in Table 2.61.

Table 2.61 Analytical results of zooplankton in onshore area


Source: CPSE, March 2010 Parameters of zooplankton community are much difference depending on location and season. Except density, all other indices are in relatively low level; especially at B2 where just one taxon presents in the rainy season. At both stations, density on the dry season is much higher than that one in the rainy season. Concerning to taxon composition, there are four groups presented including Copepoda, Ostracoda, Chaetognata and Larva. The taxon of larva group is not defined. Copepoda predominantly presents on both seasons as well as two stations. Ostracoda just presents on dry season while Chaetognata just presents on rainy season. Concerning to density composition, Copepoda also takes the largest portion on dry season and takes the second portion on rainy season. Not be counted on taxon composition but larva group takes the important portion in density on both seasons. Benthos Analytical results of benthos community at two onshore stations are presented in Table 2.62. Detailed results are given in Environmental baseline report of NSRP as Appendix III.

Table 2.62 Analytical results of benthos community in onshore area



Density (ind/m2)

Mass (g/m2) H(s) J C

Station Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season Dry

season Rainy

season

B2 2 14 23 770.00 0.34 191.23 0.59 1.08 0.59 0.28 0.73 0.72

B3 12 10 83 86.67 4.61 0.19 3.04 2.80 0.85 0.84 0.18 0.19

Average 7.0 12 53.3 428.3 2.48 95.71 1.82 1.94 0.72 0.56 0.46 0.46

Source: CPSE, March 2010 It is said that the macrobenthos community is much different in number of taxon, density as well as biomass. They are high or low depend on the sampling location as well as the sampling season

Number of taxon Density (ind/m3)

H(s) J C Station

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

B2 5.0 1.0 1,960 300 2.05 0.00 0.88 - 0.12 1.00

B3 4.0 4.0 1,040 360 1.69 1.97 0.85 0.99 0.08 0.26

Average 4.5 2.5 1,500 330 1.87 0.99 0.86 0.99 0.10 0.63



The community indices are also much different between stations. However, it was similar between two seasons. They are rather good at station B3 but bad at station B2. There are 04 benthic groups identified including Polychaeta, Crustacea, Mollusca and Echinodermata. Polychaeta takes the largest portion of taxon quantity; following ones are Crustacea or Mollusca and Echinodermata. In density, Mollusca group takes the largest portion; the second large portion belongs to Polychaeta then Crustacea. Biomass is too different between two seasons as well as two sampling stations; on the rainy season, biomass value is too high due to increasing biomass of Mollusca. Therefore, biomass portion is the highest in this season. However, in the dry season, the largest portion belongs to Crustacea. Coastal area Phytoplankton Analytical results of phytoplankton community at coastal stations are presented in Table 2.63.

Table 2.63 Analytical results of phytoplankton community at coastal stations



Density (103.ind/m3) H(s) J C Station

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

B1 14 17 1,289,520 193 0.053 2.25 0.01 0.55 0.99 0.37

B4 16 14 2,464,575 310 0.026 2.16 0.01 0.57 1.00 0.34

B5 17 24 96,210 320 0.318 2.96 0.08 0.65 0.93 0.23

B6 19 18 256,585 284 0.308 2.44 0.07 0.58 0.94 0.29

B7 12 9 512,575 12,064 0.039 0.11 0.01 0.04 0.99 0.98

B8 12 25 681,333 121 0.103 3.66 0.03 0.79 0.98 0.11

B9 14 23 1,200,792 107 0.041 3.81 0.01 0.84 0.99 0.10

B10 18 12 4,312,960 1,684 0.037 2.40 0.01 0.67 0.99 0.25

B11 15 5 219,545 52 0.416 1.99 0.11 0.86 0.91 0.30

K7 17 10 122,725 1,491 0.23 0.89 0.06 0.27 0.96 0.72

K8 15 18 154,880 55 0.36 3.25 0.09 0.78 0.92 0.18

K9 22 23 73,560 246 1.10 3.44 0.25 0.76 0.70 0.14

K10 12 20 1,884,135 97 0.02 3.45 0.01 0.80 1.00 0.13

K11 14 21 420,060 125 0.06 2.71 0.02 0.62 0.99 0.30

K12 12 18 817,080 54 0.05 3.46 0.01 0.83 0.99 0.12

E1 14 19 4,132,700 3,096 0.03 2.97 0.01 0.70 1.00 0.18




Density (103.ind/m3) H(s) J C Station

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

E18 19 17 1,651,160 3,636 0.03 2.87 0.01 0.70 1.00 0.19

Average 15 17 1,193,553 1,408 0.19 2.64 0.05 0.65 0.96 0.29

Max 22 25 4,312,960 12,064 1.10 3.81 0.25 0.86 1.00 0.98

Min 12 5 73,560 52 0.02 0.11 0.01 0.04 0.70 0.10

Source: CPSE, March 2010 Variation of taxon quantity is rather great, especially on rainy season. The number of taxon is also different among studied stations; on rainy season, taxon number of two stations (B11 and B7) strongly reduces; and the taxon quantity increases in stations B5, B8. Density recorded in the dry season is about a thousand times higher that that on rainy season. Extremely high of density of phytoplankton in the dry season with the average value is about billion cells/m3 causing by strong development of algae species named Pseudonitzschia sp. (Bacillariophyta) leads the high density in this area. As this result, the Bacillariophyta group occupied almost density at all stations. Dinophyta takes a very small portion in density. The density portion of the others is not worth at all sampling stations.

As a consequence of the abnormal developing of one alga species, in the dry season the predominant index so high while the evenness index and diversity index is too low. This phenomenon is not recorded on the rainy season. This phenomenon could be related to the eutrophication due to the increase of concentration of Nitrogen and Phosphorus in sea water as given in these above sections.

Zooplankton Analytical results of zooplankton at coastal stations are presented in Table 2.64.

Table 2.64 Analytical results of zooplankton at coastal stations


Species Density (Cell/m3) H(s) J C Station

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

B1 28,0 7,0 8075,0 21,1 3,45 2,10 0,72 0,75 0,20 0,32

B4 32,0 8,0 2189,3 27,9 4,19 2,70 0,84 0,90 0,08 0,18

B5 25,0 11,0 2393,3 57,2 3,80 2,45 0,82 0,71 0,29 0,28

B6 36,0 18,0 2496,9 33,5 3,88 2,10 0,75 0,50 0,06 0,45

B7 18,0 7,0 13880,0 4700,0 3,90 1,80 0,94 0,64 0,07 0,42

B8 34,0 11,0 659,5 243,1 3,88 2,44 0,76 0,73 0,09 0,26

B9 13,0 16,0 341,1 143,6 3,13 3,23 0,85 0,81 0,09 0,15



Species Density (Cell/m3) H(s) J C Station

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

B10 21.0 33.0 1077.5 280.5 3.73 3.65 0.85 0.72 0.21 0.14

B11 34.0 32.0 2177.2 232.9 3.99 4.24 0.78 0.85 0.18 0.07

K7 26.0 7.0 521.2 67.1 3.78 2.45 0.80 0.87 0.10 0.21

K8 29.0 5.0 2368.9 26.1 4.01 1.54 0.83 0.66 0.08 0.48

K9 36.0 16.0 833.5 381.1 4.02 3.20 0.78 0.80 0.10 0.15

K10 28.0 20.0 1732.6 314.7 3.65 3.74 0.76 0.87 0.11 0.09

K11 36.0 26.0 947.3 5788.2 4.07 3.84 0.79 0.82 0.09 0.09

K12 39.0 22.0 855.0 449.1 3.94 3.51 0.75 0.79 0.10 0.12

E1 29.0 33.0 22749.7 1164.0 3.13 4.09 0.64 0.81 0.16 0.08

E18 30.0 33.0 2727.6 224.8 3.94 3.73 0.80 0.74 0.09 0.14

Mean 29.1 17.9 3883.9 832.6 3.79 2.99 0.79 0.76 0.12 0.21

Max 39.0 33.0 22749.7 5788.2 4.19 4.24 0.94 0.90 0.29 0.48

Min 13.0 5.0 341.1 21.1 3.13 1.54 0.64 0.50 0.06 0.07

Source: CPSE, March 2010 Parameters of zooplankton community change a lot among the sampling stations as well as between two seasons. Generally, the zooplankton community was relatively diversity and evenness especially on the dry season. The number of taxon, density as well as H(s) recorded on the dry season is higher than that ones in the rainy season at almost stations. Taxon distribution and composition: total of 10 groups are classified, in which Copepoda took over 75% on both seasons however its portion also strongly changes among stations. Cladocera is quite common and evenness among studied stations on dry season but it is not common on the rainy season. On the contrary, Chaetognata is more common in the dry season but it just present at several stations in the dry season. The portion of other groups changes a lot between two seasons. Density distribution composition: total density as well as density of each group strongly changed among stations, especially on rainy season, Copepoda takes almost density on dry season, took a small portion at several stations on rainy season. Larva group, although not be counted on taxon quantity, also takes large portion at almost stations. Benthos Analytical results of benthos community at coastal sampling stations are presented in Table 2.65.



Table 2.65 Analytical results of benthos community at coastal sampling stations August 2008 and February 2009


Density (ind/m2)

Mass balance (g/m2)

H(s) J C Station

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

Dry season

Rainy season

B1 28 15 367 193 8.40 26.20 3.17 3.04 0.66 0.78 0.26 0.19

B4 41 31 1,567 580 125.22 21.40 1.94 3.64 0.36 0.73 0.55 0.14

B5 44 21 3,080 807 286.04 17.07 0.97 1.22 0.18 0.28 0.81 0.72

B6 24 21 10,527 6,090 607.05 305.71 0.20 0.31 0.04 0.07 0.97 0.94

B7 3 7 117 340 47.10 6.67 0.37 0.99 0.24 0.35 0.05 0.68

B8 25 16 220 163 3.90 0.75 4.31 3.15 0.93 0.79 0.06 0.17

B9 4 17 17 253 0.53 1.09 1.92 3.35 0.96 0.82 0.28 0.14

B10 23 20 4,953 1,073 299.95 71.46 0.45 2.62 0.10 0.61 0.91 0.25

B11 65 37 1,023 1,473 42.29 21.76 5.06 2.91 0.84 0.56 0.05 0.24

K7 54 30 597 520 4.83 17.60 4.96 3.36 0.86 0.69 0.06 0.17

K8 34 61 277 1,400 11.10 13.69 4.36 4.33 0.86 0.73 0.09 0.13

K9 7 8 23 83 8.99 1.27 2.81 1.92 1.00 0.64 0.14 0.43

K10 15 22 207 237 11.29 4.75 2.71 3.76 0.69 0.84 0.24 0.11

K11 41 32 490 217 4.17 6.92 4.30 4.59 0.80 0.92 0.10 0.05

K12 26 38 130 710 0.18 32.90 4.53 3.75 0.96 0.71 0.05 0.15

E1 39 54 480 1,970 11.97 96.63 4.36 3.70 0.83 0.64 0.09 0.17

E18 25 42 553 880 7.88 44.96 3.40 3.06 0.73 0.57 0.16 0.33

Average 29 28 1,449 999 87.11 40.64 2.93 2.92 0.65 0.63 0.29 0.29

Max 65 61 10,527 6,090 607.05 305.71 5.06 4.59 1.00 0.92 0.97 0.94

Min 3 7 17 83 0.18 0.75 0.20 0.31 0.04 0.07 0.05 0.05

From above results, some conclusions are drawn as follows:

Parameters of benthos community at coastal stations are also different among stations as well as between two seasons. On average, however, almost parameters (except biomass and density) are similar between two seasons.

At some stations such as B5, B6, B7, B10.., the community parameters are in bad level. However, at some other stations such as K8, K11, K12… the parameters were in good levels. Density and biomass are two items got the largest changing among sampling stations as well as between two seasons.

At stations B10, B5, B4 and especially at B6, density and biomass strongly increase basing on the strong development one mollusk species.

Regarding to the composition, there are 04 groups including Polychaeta, Crustacean, Mollusca and Echinodermata in which, Polychaeta took the largest portion of taxon quantity, following ones are Crustacean, Mollusca and Echinodermata; the Mollusca group takes the largest portion of density as well as biomass, the order of other groups was similar to that in taxon quantity.



2.1.3 PRELIMINARY ASSESSMENT ON ENVIRONMENTAL LOADING CAPACITY 2.1.3.1 Assessment on Environmental Sensitivity of the Project Area Refer environmental sensitivity map at Nghi Son-Thanh Hoa and its vicinity established by CPSE in 2009, Environmental sensitivity index (ESI) is defined basing on ecological characteristic and social-economic factors. Resource sensitivity index at the study area is classified to riverside, coastal and nearshore area units depending on their sensitivity level to oil pollution. ESI map of the project area and its vicinity in Figure 2-17 shows that:

Main site of the Complex has moderate ESI since this area is mainly agricultural land and forestry area;

Around Me island, ESI is high since there are fish, shrimp, cuttle ground and coral reefs;

Coastal area from Nghi Son port to Lach Bang fishing port has high ESI because there are many natural oyster grounds and fish cages concentrated in this area;

Along Lach Bang river, there are mangrove forest and aquacultural activities. Therefore, ESI of this area is assessed as high;

The rest area belonging to Project area and its vicinity has ESI at low to moderate level.



Figure 2 - 17



2.1.3.2 Preliminary Assessment on Environmental Loading Capacity NSRP Project is sited within NSEZ where other industrial activities are planned as:

1. Integrated Nghi Son Port and Vinashin Shipyard is under site leveling. Nghi Son Port is located at about 7 km south of the Project site. The existing Integrated Nghi Son harbour is mainly used to import and export of constructional materials and domestic goods.

2. Opposite with integrated port is Nghi Son Power plant 600 megawatts which are about 6 km from NSRP plant site. The Project will use 14 tons/hour of coal mined in Hon Gai, Quang Ninh Province. The coal will be shipped from the mine to the power plant jetty, and then transported to the coal storage yard by conveyor belt.

3. Nghi Son Cement plant operating is about 5 km from the project site. The plant is along Provincial Road 513, but the jetty is stretching from the plant to Nghi Son Bay. This jetty is next to NSRP harbour.

4. In the future, a new NSEZ port will be built next to NSRP harbor. This new NSEZ port may cause some problem of accident since it will be very close to the NSRP harbour.

However, up to now, most of industrial factories of Thanh Hoa province are located at Tinh Gia town and coastal communes such as Nghi Son, Hai Chau, Hai Ha, Hai Binh and Hai Thuong that far away from project area. NSRP plant is located at pure agricultural area where air quality is still good. Marine facilities such as habour are located along the coastal communes where salt and seafood production has not been existed.

Basing on the results of baseline survey carried out by CPSE in the rainy season (from 8/8/2008 to 15/8/2008) and dry season (from 20/2/2009 to 1/3/2009 and from 18/3/2009 to 26/3/2009), some conclusions on existing environment and estimated environmental loading capacity are as below:

In onshore areas

All parameters of air, water, sediment, soil and groundwater are still much lower than the allowable Vietnamese standards. So, this proves that the existing environment is still good and not much polluted and NSRP activities will not increase much environment loading capacity because all wastes will be treated and managed strictly as mentioned in following sections (mitigation measures, environmental management plan,…).

In coastal and offshore areas

In generally, most of analytical results of surface water are quite good and lower than allowable limits stipulated in QCVN 10:2008/BTNMT. So, the environment loading capacity in coastal and sea area nearby the project is rather good. In particular, coral around Me islands has declined so much because of explosive catching from fishermen. However, NSRP LLC considered this sensitivity ecosystem and carried out the survey on existing coral distribution to change the pipeline route to SPM to avoid the impact on coral as much as possible. During the operation phase, the NSRP LLC will also treat the temperature of cooling water effluent to minimize the impact on sea water quality as well as aquatic species in the area.



2.2 EXISTING SOCIAL CONDITIONS [9] 2.2.1 Economic Condition 2.2.1.1 Agriculture Tinh Gia district plans to transfer economic structure from rural agricultural economy to agriculture – industry – service oriented intensive cultivation, lower prices, increase income per area unit and connecting raw material areas with product area. The status of agriculture of communes in the project area is presented in Table 2.66.

Table 2.66 Agriculture Status of Communes Belong to Project Area

Parameter Tinh Hai Hai Yen Mai Lam

Area of cultivation (ha) 255.8 151.5 891.0 - Rice (ha) 103.2 50.8 431 - Corn (ha) - - 61 - Peanut (ha) 50.3 55.0 175 - Sesame (ha) 43.2 30.2 135.0 - Sweet potato (ha) 59.1 4 78.5 - Vegetation (ha) - 11.5 10.5

Breed (animal) 22,840 17,307 38,307 - Cattle 150 135 1,214 - Pig 2,910 172 3,243 - Poultry 19,780 17,000 33,850

Source: report “Economic-Social situation of commune”, 2009 2.2.1.2 Industry Most of industry factories are located at Tinh Gia town and coastal communes such as Nghi Son, Hai Chau, Hai Ha, Hai Binh and Hai Thuong. Mechanical engineering, manufacturing, construction materials are mainly located at centre of district; agriculture production is mainly located at Son Lam, Truc Lam, Mai Lam, Phuong Cat,… Salt and seafood production are located at coastal villages as Hai Chau, Hai Ha, Hai Binh, Hai Thuong and Hai Thanh. Currently, at the new Nghi Son economic zone there is only Nghi Son cement plant operating. This will be industrial centre of Nam Thanh – Bac Nghe region.

Table 2.67 Total industrial production of Tinh Gia district Unit: Million VND

Year

2005 2006 2007 2008 2009

Total production value 65 75.95 95.69 119.25 151.35 Source: Statistics Department of Tinh Gia district, 2009

In general, the industrial factories are small and mainly satisfy the local demand except Nghi Son cement plant and some products like fish sauce, seafood and fired-brick.



Tinh Gia district concentrates on future industrial development as follows:

Refinery and Petrochemical industry

Presently, NSRP-LLC has completed FEED stage for NSRP. Total capacity of NSRP is about 200,000 thousand barels/year.

Steel industry and mechanical industry

Nghi Son economic zone have attracted investment to build steel sheet factory, shape-steel, high-grade steel to satisfy the demand of economic zone, especially for build and repair ship. This is plan development Nghi Son shipyard with capability to build 50,000 DWT for new ship and repair 100,000DWT ship.

Construction materials industry

Nghi Son cement plant has capacity of 2.15 million tons per year and has been upgraded capacity of plant to 4.3 million tons per year. In addition, Cong Thanh cement plant has capacity of 2.8 million tons per year. In year 2020, Truong Lam brick factory has improved capacity to 55 millions bricks per year.

Electrical industry

The Nghi Son economic zone will build the thermal power plant with capacity of 1,800MW at Nghi Son. Currently, the thermal power plant has been deployed to build the first phase with capacity of 600MW.

Processing industry of agricultural-forestry products

The factory of seafood export and processing has capacity of 2,500 to 3,000 tons per year, the salt factory at Hai Chau has capacity about 15,000 tons per year. Currently, district is investing and building pet-food factory, canned-food processing factory and soft-drink factory,…

Consumer product industry

Developing industrial products for consumer as textile, leather footwear, electronic, high-level refrigeration… to serve for province, Nam Thanh – Bac Nghe region, Central area and export..

In addition, there are light industrial activities in Tinh Gia district as follows:

- Dong Chem industrial group at Nguyen Binh commune are mainly consumer woodwork, garment and mechanical service.

- Industries located at Hai Binh commune are to serve logistic for fishery and seafood processing.

- Industries located at Tan Truong – Truong Lam commune are to produce construction materials and mining.

- Industries at Tan Dan commune are to product stone for exporting, consumer woodwork and electronic repair.

- Cho Kho industries belong to Hai Ninh commune which main branches are mechanical, electronic repair, refrigeration and electronic.

- Restore and develop tradition trade villages at fish sauce production (Hai Thanh, Hai Chau communes), salt production (Hai Chau, Hai Ha, Hai Binh and Hai Thuong communes), handicraft (communes belong to Nghi Son peninsula).



Untill year of 2010, NSEZ has 16 deploying projects, in which:

Projects such as NSRP, Nghi Son Thermal Electricity Plant, Shipyard, expanded Nghi Son Cement Factory, Cong Thanh Cement Factory and Tinh Hai Resettlement are on site clearance and construction process;

Other projects such as Nghi Son port, island ecotourist area and industrial parks 1, 2 and 3 are going to site levelling.

Projects will have been deployed in NSEZ up to 2010 are shown in Figure 2-18. 2.2.1.3 Forestry

The area of forest land in the project area is presented in Table 2.68.

Table 2.68 Protective Forest Area of Commune belong to Project Area

Type of Forest Tinh Hai Hai Yen Mai Lam

Planting Forest (ha) 106.78 100.2 - Protective forest (ha) 31.8 92.8 369.46

Mangrove swamp (ha) - - - Source: Report “Economic-Social situation of commune”, 2009 In general, the forest area in area of Mai Lam, Hai Yen and Tinh Hai communes is mainly planting forest on hills and mountains and protective forest at coastal area. Mangrove in the radius of 10km of the project site is distributed along lach Bang river banks which belong to area of Thanh Binh ward of Hai Thanh and Hai Binh commune, Yen Hoa ward of Hai Ha and Hai Thuong commune. Based on result of vegetation cover survey undertaken by CPSE in August 2008 and February 2009, Mangrove ecosystem along Lach Bang and Yen Hoa river banks is very thin and short (maximum height in the range of 50-60cm), dead mangrove trees appear at some areas and poor in species. The maximum width of mangrove is about 50-70m. Preliminary estimation of managrove area is about 1.59 ha along Lach Bang river banks and about 7.2 ha along Yen Hoa riber banks. However, the project area is without mangrove. The shortest distance from complex site to Lach Bang river is about 1km and the longest distance is about 3km toward to the North.



Figure 2-18



2.2.1.4 Aquaculture and Fisheries Mai Lam commune

- Total output of exploitation and aquaculture of commune is 7 tons in 2009. The aquaculture area of commune is 152.24 ha and mostly at Kim Tuyen, Truong Thanh, Hai Lam hamlets. The culture objects are mostly white shrimp, sugpo prawn, crayfish and freshwater fish.

Hai Yen commune

- The aquaculture area of commune is 1.8 ha. Currently, 12 households are feeding at small ponds, lakes. Aquaculture production is small.

- Total boats of commune are 6 ones with capacity of about 6 HP/unit and mostly catch fish, squid, oyster and arca. Total production of fish, squid is about 27 tons per year, oyster and arca is 110 tons per year. There are 256 households (391 persons) participating in catching fish, belong to Dong Yen, Trung Hau and Bac Yen hamlets.

Tinh Hai commune

- The aquaculture area of commune is 53.5 hectares. The aquaculture area of the commune mainly concentrated along Lach Bang river.

- Total boats in the commune are about 44 with capacity of 12HP/unit. Beach of the commune is smooth so there are about 80-100 households catching at coastal and they have been catching all kinds of aquatic products such as Acetes, squill-fish. In 2008, Acetes output was about 37 tons.

Hai Thuong commune

- Total output of exploitation and aquaculture of commune is 332.5 tons in 2008. The aquaculture area of commune is 3-4 ha along to Yen Hoa river mouth and mainly extensive culture and raising objects are mostly white shrimp, sugpo prawn and crab.

- Total boats of commune are 52 with capacity of about 12HP and 6HP. The boat is primarily catching fish at nearshore and Silago sihama (ca đuc), Leiognathus berbis (ca liet) (120 to 130 tons per year), shrimp (5-6 tons per year), cuttlefish (5-6 tons per year).

Hai Ha commune

- The existing of aquaculture area was 60ha concentrated along Yen Hoa river with low output. - Total boats in the commune are about 189 with a capacity of about 40-90HP/unit. The boat is mainly coastal

catching with aquatic products such as shrimp, Acetes, squid and crabs. In addition, some boats catch away from shore. Total output of exploitation in 2008 was 1,047.9 tons.

In general, the communes at the project area having aquaculture area are not so much and there are many small aquacultural ponds along the Lach Bang and Yen Hoa rivers. Especially, at Nghi Son Gulf (near export berth of Nghi Son Cement Factory), there are about over 479 fish-cages to feed fish such as Lutjanus.sp (Ca Hong), Cephalopholis nigripinnis (ca Mu), Rachycentron canadum (ca Gio) and Lutjanidae erythropterus (ca Hanh).



2.2.1.5 Salt industry Salt production activity in the Project area and its vicinity in NSEZ mainly concentrates along Yen Hoa river and is bounded by Nghi Son peninsula which is belong to Hai Thuong and Hai Ha communes with area of 66.05ha and along Lach Bang river (near Lach Bang fishing port), Hai Binh commune with area of 45.2ha. Communes locate in Project area (Mai Lam, Hai Yen and Tinh Hai communes) are without salt production activity. 2.2.1.6 Tourist Tinh Gia district has some famous tourist areas as: Nghi Son island and Hai Thuong commune. With terrain full of obstacle and difficult of access, this place was used

as military base of feudal dynasties and was especially under the Tay Son – Nguyen Hue dynasty.

Hai Hoa seashore belongs to Dong Hai hamlet and Giang Son hamlet, Hai Hoa commune; with distance of 2km to the East from centre of Tinh Gia district. Hai Hoa seashore has 3 to 4 km length and 200 to 300m width.

Ngoc Hoang cavern belongs to Truong lam commune through Mu Cua mountain chain with 500m length. In addition, there are Tien cavern and Ngoc Nu cavern.

Lach Bang river landscape tourism, this river is bending along Non Tien mountain before going to the sea. 2.2.2 Social Condition 2.2.2.1 Population The Project belongs to Tinh Gia district, Thanh Hoa province and this project will affect 3 communes as Mai Lam Commune, Hai Yen and Hai Tinh. Population of the communes located in the project is presented in Table 2.69.

Table 2.69 Existing population of the affected communes

Tinh Hai Hai Yen Mai Lam

2006 Household 1,220 937 1,315 Population 5,831 3,603 6,917

2007 Household 1,432 1,216 1,352 Population 6,476 4,311 7,510

2008 Household 1,394 1,216 1,325 Population 8,261 4,399 7,509

Source: “Socio-economic situation report of commune”, 2008 Affected households (HHs) in Mai Lam, Hai Yen and Tinh Hai communes are presented in Table 2.70.



Table 2.70 Affected households

Commune Tinh Hai Hai Yen Mai Lam

Total

Number of households 600 1482 525 2,607 Source: Due Dilligence Report – NSRP, February 2010

In which:

1. Plant site (Area B): 1907 Households, including: - Mai Lam commune: 525 Households - Tinh Hai commune: 600 Households - Hai Yen commune: 782 Households

2. Harbour and onshore pipeline area (Areas E and J): 700 Households

- Hai Yen commune: 700 Households 2.2.2.2 Transportation and Infrastructure Road way Existing road way infrastructure of NSEZ in general and Project area in particular includes main routes as follows: Provincial Road 513 is the main way connecting National Road 1A to NSEZ and Nghi Son Port. Provincial Road

513 is 12.38km in length, 12m in width and made of asphalt. This road is being used for goods transport from Nghi Son Port to National Road 1A;

Expansion road 513 to 34m in width for the section from Ho bridge to Nghi Sơn Power Plant

Nghi Son – Bai Chanh route is a part of road connecting Nghi Son town to Ho Chi Minh Highway with total length of 56 km; This route is under construction and the section crossing to Tinh Gia district is about 22km.

Road 2B is 27km in length and 5-6m in width. This road connects communes in Nghi Son area;

Route from National Road 1A to Lach Bang fishing port is 6km in length, 3.5m in width and asphalted. There are 12 small concreted bridges, 01 concreted bridge and 01 combined bridge in whole route;

Earth route from Hai Nhan to Mine D69 Truong Lam is 24km in length with 04 small bridges and 06 temporary bridges;

Apart from above routes, there are some civil earth roads with width of 2-4m. According to master plan of NSEZ up to year of 2015, works constructed and upgraded are as follows: Provincial Road and inter-commune roads;

- Upgrade route connecting Nghi Son to Ho Chi Minh Highway with total length of 56 km; - Construct road connecting Provincial Road 513 to Quynh Luu District, Nghe An Province; - Upgrade roads between communes.

Urban traffic system

Traffic system of economic fuction area is set up based on connection roads between areas:



- Main road in North – South axis connecting new urban to tax free area and Southern port; - Main roads in East – West axis (connecting North – South highway and Western industrial park to the

Refinery, duty-free and port areas); - National Road 1A plays role as urban traffic and divides NSEZ into two areas.

Eastern area of NSEZ:

- Construct main road running through Northern urban centre; - There are some main routes connecting National 1A to the Refinery, duty-free and port area in the West to the

East; - Connecting Eastern areas is a road in North – South direction linking three areas of new northern urban center

- National 1A – Nghi Son integrated port. Western area

- Western areas connecting route will run parallel to National 1A and North – South railway route. Western and Eastern areas connected by East-West roads:

- Road connecting Nghi Son port to Cong Thanh Cement Factory; - Road connecting port area to Western industrial park; - Road connecting Northern urban to North-South highway; - Construct more route connecting directly Nghi Son port to Noth-South highway with tunnel 3.4km in length

running through Xuoc mountain. Railway The Bac Nam railway through Tinh Gia district is about 25km length. There is a train station here which is an advantage in transportation goods from North to South. Khoa Truong railway station will be upgraded in 2015, proving a new station 1,200 metres long, by 100 metres wide equipped with four tracks. Airway Currently, the nearest airport is Vinh airport of Nghe An province. A Grade 3 airport will be built in Quang Loi community, Tinh Gia district. The airport is about 80 km from site and about 23 km south from Thanh Hoa city. It will comprise a single runway between 1,400 and 2,000 metres in length and 40 -50 metres wide, capable of carrying between 200,000 and 400,000 passengers per year. Marine transportation The deep water port system of Nghi Son located in key economic zone of the Northern central area. The port plays particularly important role in promoting for Nam Thanh – Bac Nghe economic region. International maritime channel of Nghi Son port has the advantage of the Vietnam port system. Nghi Son port is

quite close to Asia – Europe – North America International navigation system. Especially in the North East Asia area, Nghi Son port has the large advantages about connecting way in large ports such as Hong Kong, Cao Hung (Taiwan) compared to other ports of Central and South area (Figure 2-19).

National maritime channel of Nghi Son port is the gateway to Central and North areas. Besides, it is important role

in connection the national waterway North-South system.



Figure 2-19



Harbour Existing harbour system of NSEZ consists of PTSC Port and specific port of Nghi Son Cement Factory:

PTSC Port (previously named Nghi Son Integrated Port) is Type 1 port located in Nghi Son area, Tinh Gia district, Thanh Hoa province (19o18’20”N, 105o49’00”E). It includes 02 berths. This port may serve 10,000DWT ships in berth 1 and 30,000DWT ones in berth 2. Most of transported products in this port are cement, iron, steel, rice, manure… Exported goods from year 2005 to 2008 are 903,000; 985,000; 1,388,000 and 15,000,000 tons respectively.

Specific port of Nghi Son Cement Factory in Hai Thuong commune, Tinh Gia district, Thanh Hoa province (20o20’42”N, 105o49’12”E) include 01 berth. Capacity of this port is 2,000,000 tons/year and may serve 30,000DWT ships. Transported products are cement and materials used for cement production, such as coal, gypsum and other additives… Exported goods from year 2005 to 2008 are 1,100,000; 1,112,000; 1,362,000; and 15,852,000 tons respectively.

Up to year 2020, NSEZ will plan a harbour system including:

Upgrade PTSC Port to 05 berths and may receive 30,000 DWT ships.

Exported port of NSRP may receive 30.000DWT ships and SPM is able to receive 300.000DWTvessels.

Harbour of Nghi Son thermal electricity plant may receive 5 million tons coal equaling to plant capacity of 3,000 MW and 01 million tons (600 MW).

Waterway In the North of NSEZ, there is Lach Bang river running in East-West direction. At present, this river is not used for transport due to its narrow width of 10m, depth of 0.5m, curve radius of 100 m. there is a bridge named Do Dua put acrossing the river with traffic width of 10m, space height is lower than 2.5m and only small boats with capacity of 10tons can run through by high tide period. 2.2.2.3 Power system The existing of power system at Nghi Son economic zone includes:

National Grid 110-220KV belongs to North Central area which is power source for Nghi Son transformation stations 220/110 KV – 125mVA. The two transformation 110KV stations in project area are as follows:

- 110KV station at Tinh Gia

- 110KV station at Nghi Son cement Factory

The 220KV grid at Thanh Hoa – Nghi Son is directly supplied power to 220KV Nghi Son transformation station. This power grid linked to the power supply points and the Nghi Son economic zone.

2.2.2.4 Telecommunications The telecommunication system of district consists of 36 post-offices and 10 public phones using card. There are 2.4 land-line phones per 100 people and 0.5 cell phone per 100 people. There are seven internet access points for the whole district. In general, the telecommunication of Tinh Gia district has not yet been much developed.



2.2.2.5 Land use status in NSEZ

Land use status in NSEZ area is presented in Table 2.71 and and Figure 2.20.

Table 2.71 Land use status in NSEZ

No. Type of land Total area (ha) Rate %

1 Residential land 984.6 5.3

2 Land for office, public constructions 23.3 0.1

3 Land for non – agricultural production 352.8 1.9

4 Land for public purpose 1,410.3 7.6 5 Land for sercurity 613.4 3.3 6 Land for religion, cultural/historical relics 2.7 0.0

7 Land for agriculture 10,092.0 54.2

- Agricultural production land 3,804.4 - Forestry land 5,533.7 8 Graveyard 170.4 0.9 9 Rivers/streams and specific surface water 897.3 4.8 10 Spare land 4,065.0 21.8

Source: NSEZ Management Board, 2009 NSRP is constructed in an even and flat area with a large proportion of agricultural land. The most notice is Coc Mountain and Chuot Chu Mountain locating in the Southwest of Project area. These mountains are covered with forest. Table 2.72 shows that lands in Project area as well as Tinh Hai, Mai Lam and Hai Yen communes are mainly used for agricultural production.

Table 2.72 Land use status in Project area

Affected communes Tinh Hai Mai Lam Hai Yen

Type of land

ha % ha % ha % Total area 674.9 100.0 1,792.8 100.0 662.9 100.0 1 Production land 492.8 73.0 1,175.0 65.5 440.4 66.4

1.1 Agricultural land 322.0 47.7 548.5 30.6 235.0 35.4 1.2 Forestry land 116.6 17.3 475.6 26.5 205.4 31.0 1.3 Aquacultural land 54.1 8.0 150.8 8.4 0.0 0.0

2 Non-productive land 177.1 26.2 306.8 17.1 153.0 23.1 2.1 Residential land 71.9 10.6 32.0 1.8 42.7 6.4 2.2 Used for special purposes1 58.1 8.6 214.4 12.0 94.6 14.3 2.3 Others 47.2 7.0 60.4 3.4 15.8 2.4

3 Spare land2 5.0 0.7 311.1 17.4 69.5 10.5 Source: Due Dilligence Report – NSRP, February 2010

1 Land used for special purposes include constructions used for office, business service, production; lands used for sercurity, national defence; land not used for agricultural production; land used for public purpose (drainage system, pavement, harbour, ferry, parking, train station, irrigation, dike, damp, electric supply system, communication, gas/oil/fuel pipeline, hospital, market, orphanage, stadium, cultural constructions). 2 Spare land consists of: a) Unused delta land; b) Unused hilly land; c) rock mountains is not covered with forest.



Figure 2.20



2.2.2.6 Affected area

According to investigation and assessment results of site clearance and compensation phase (2008-2009) [16], affected area is about 394ha and presented in Table 2.73.

Table 2.73 Area affected by the Project

Affected commune (ha) Site Mai Lam Tinh Hai Hai Yen

Total affected area (ha)

B. Plant site 63 117 148 328 E. Pipeline 0 0 30 30 J. Harbour 0 0 36 36

Total 63 117 214 394 Source: Socio-Economic Survey, 2008 2.2.2.7 Affected graves

In construction phase, there will be 1,915 graves affected by the project implementation. These graves will be moved to cummunial graveyard presented in Table 2.74.

Table 2.74 Graves affected by the Project

Commune Tinh Hai Hai Yen Mai Lam

Total

Number of grave 832 433 1,083 2,348 Source: Socio-Economic Survey, 2008-2009 2.2.2.8 Existing Potable Water Drainage and System The existing potable water system Currently residents in Nghi Son economy zone and its vicinity use raining water and drilling well for domestic use. Only one cleaning water treatment station with capacity of 3,000 m3 per day is located at Tan Truong commune, but it only supplies for Nghi Son cement plant. Regarding the water supply, most of the Households (88%) use water from deep wells, shallow wells (55.1%) and rainy water (33.9%) for their daily activities.

Table 2.75 Source of Drinking and Cooking water

Rain water Shallow well Deep well Purchased

water Public tap

Piped water

Surveyed

HH HH % HH % HH % HH % HH % HH %

Total 443 150 33.9 244 55.1 390 88.0 0 0 0 0 0 0 Source: Socio-economic Survey (2008-2009) According to NSEZ master plan up to 2015, total required supply water taken from surface water of lake Yen My and lake Muc river is 80,000 m3/day. Main works of NSEZ water supply system up to 2015 include: Con Cat water pump station:



Natural water pump station located at lake Con Cat has capacity of 25,000 m3/day so that it will pump water in this lake to lake Yen My through plastic pipeline route with diameter of 600 and length of 4,000 m.

Yen My water pump station: Existing water pump station at lake Yen My will be upgraded from 30,000 m3/day to 80,000m3/day. Then, water will be routed to lake Dong Chua by plastic pipeline with diameter of 600 and length of 26,800 m.

Pump station - Level 1: Existing level 1 pump station at lake Dong Chua will be upgraded from 20,000m3/day to 80,000m3/day.

Water plant: Existing water plant at lake Dong Chua will be upgraded from 20,000m3/day to 80,000m3/day.

Water supply system: Design as circle network type. Pipeline diameters vary from 100 to 800.

Water supply system master plan of NSEZ up to year of 2020 will be presented in Figure 2.21.



Figure 2.21



2.2.2.9 Drainage system and waste water treatment plant in NSEZ Existing system At present, NSEZ in general and Project area in particular, neither drainage system nor domestic wastewater plant have not been constructed yet. Total domestic wastewater is discharged directly into channels and Nghi Son Gulf. Planning NSEZ drainage system will be designed to discharge separately (for rain water drainage system and collection and treatment system of industrial – municipal wastewater).

Drainage system include self-flow sewer with diameter of 300 – 800 mm, buried depth of 4m. Areas having buried depth more than 4m will be installed transition pump stations. Locations of these stations are as follows:

Drainage basin 1 (residential area in the North-West of Lach Bang river): effluents are treated at wastewater plant ־ with capacity of 15,000 m3/day.

Drainage basin 2 (residential area in the South of Lach Bang river): effluents are treated at wastewater plant with ־ capacity of 6,500 m3/day.

Drainage basin 3 (residential area in the West of Tan Truong commune): effluents are treated at wastewater plant ־ with capacity of 2,500 m3/day.

Drainage basin 4 (residential area in Truong Lam Commune): effluents are treated at waste water plant with ־ capacity of 1,500 m3/day.

Drainage basin 5 (Industrial park in the East of National 1A, duty-free and Refinery areas): effluents are treated at ־ wastewater plant with capacity of 30,000 m3/day.

Drainage basin 6 (Industrial park in the West of National 1A): effluents are treated at waste water plant with ־ capacity of 25,000 m3/day.

Drainage basin 7 (Nghi Son port, Nghi Son Cement Factory, thermo-electric plant…): effluents are treated at ־ wastewater plant with capacity of 25,000 m3/day.

Drainage basin 8 (eco-residential area and golf court): use dispersed drainage system. Waste water is treated ־ locally for each residential area by septic sludge or small scale wastewater treatment plant. Planned output is about 2,000 m3/day.

Drainage system and waste water plant master plan diagram of NSEZ up to 2020 will be shown in Figure 2.22.



Figure 2.22



2.2.2.10 Solid waste collection and treatment system in NSEZ Existing situation Solid waste collection and treatment system in NSEZ has not been established yet. Most of solid wastes will be littered to surrounding area. Industrial and domestic solid wastes generated from factories will be collected and treated by sanitary contractor. Planning Domestic solid wastes will be collected by manual method combined with mechanics. Solid wastes will be

separated after collection into organic and inorganic waste before treatment process. Inorganic waste will be transported to landfill. Organic waste will be processed by waste treatment plant to organic fertilizer.

Industrial solid wastes are classified into recycleable and unrecycleable solid wastes. Recycleable waste is collected separately and processed onsite or transported to other recycle units. Unrecycleable waste will be collected and transported to solid waste treatment plant served for NSEZ. Hazardous waste is collected and treated properly in accordance with environmental requirement.

Solid waste treatment area:

- Domestic solid waste will be transported to solid waste treatment area in Tinh Gia District (in the North of NSEZ), planned area is about 10ha.

- Industrial solid waste will be transported to solid waste treatment area in Truong Lam District. In treatment area, a security landfill will be constructed for hazardous waste treatment purpose. Total area of this plant is about 40ha.

2.2.2.11 Culture, Health and Education There is health care station at each commune to meet the basic needs to examine and treat medically, emergency and regular childbirth. Professional quality of doctors in the healthcare station has also been improved. Statistical data of healthcare station in the communes are presented in Table 2.76.

Table 2.76 Statistics of Medical Station in the Project Area

Parameter Hai Yen Tinh Hai Mai Lam

Healthcare station 1 1 1 Doctor - 1 1 Nurse 8 5 4

Physician 4 3 4 Pharmacist 1 1 1

Source: “Socio-economic situation report of commune”, 2009

Tinh Gia district has 33 communes and one town with 106 schools in which 34 kindergarten, 37 primary schools, 35 secondary schools and 01 continuing education center. In 2007-2008, the district has about 49,527 students and 2,490 teachers in kindergarten, primary school, secondary school and continuing education center. The education quality, number of excellent student and teacher of the district



have been improved. Each year, there were over 95% of students graduated. The district has 19 schools that meet national standards (including kindergarten: 03 schools, primary school: 15 schools; secondary school: 01 school). Education and training network of the communes of the project area has stable developed and widely distributed and meet learning needs of people. Statistical data of school of the communes in the project area are presented in Table 2.77.

Table 2.77 Educational condition of the communes in the project area

Parameter Hai Yen Tinh Hai Mai Lam

Kindergarten School 1 1 1 Classes - 9 -

Pupil 120 205 380 Teacher 9 14 16

Primary school School 1 1 1 Classes - 13 -

Pupil 320 401 595 Teacher 18 20 27

Secondary school School 1 1 1 Classes 21 12 -

Pupil 280 455 689 Teacher 16 28 45

High school School 1 - - Classes 45 - -

Pupil 3,000 - - Teacher - - -

Source: “Socio-economic situation report of commune”, 2009 2.2.2.12 Cultural Resources and Archaeology In Tinh Gia district, there are no archeological relics, only historical heritages, charm landscapes are as below:

Tinh Hai fortress and Ninh citadel were built on Bien Son’s island in Nguyen’s dynasty. In addition, on island there is Ngoc’s well mentioned in My Chau – Trong Thuy’s legend;

Tho Son citadel is located at Nguyen Binh commune. This citadel was built under the reign of Minh Mang;

Group of historical heritage and landscape at Lach Bang includes Quang Trung temple, Cue Latch temple (worship Hong Nuong general), Dot Tien pagoda. This group is ranking certificated by Ministry of Culture;

Ba Lang church was built in 1893, this is called Gia To cultural art;

The temple of Bui Thi Xuan of Bui family is located at Hai Thanh commune;

Architectural stone monument worships Le Dinh Chau Prince.



Section 3.

ENVIRONMENTAL IMPACT ASSESSMENT The pre-construction, construction and operation of the Nghi Son Refinery and Petrochemical Complex are likely to cause significant direct and indirect, positive and negative impacts on the receiving environment. Many of the negative impacts can be avoided or reduced to acceptable levels, while benefits derived from the project can be enhanced by adopting good engineering practices and appropriate mitigation measures during the design, construction and operation periods. As comment in Section 0 about Scope of the Project, Tinh Gia District PC, NSEZ Management Board and NSPM are responsible for implementation of activities in pre-construction phase (including site clearance, compensation and resettlement, capital dredging…). In this phase, the material exploitation activities for first stage of site leveling and stage II of leveling from +3.5m to +6m before constructing the Complex’s infrastructure were approved by NSEZ Management Board, in which there are 01 Environmental Impact Assessment (EIA) report for material exploitation activity and 01 Commitment of Environment Protection (COEP) report for site leveling activity. Although the pre-construction phase is out of scope of this EIA report, but according to Safety, Health and Environment (SHE) requirements of International Finance Corporation (IFC), NSRP LCC has carried out an investigation survey and prepared a separate Resettlement Due Diligence report for the Project. Moreover, relocation and resettlement activities will cause long-term effects on the society. Hence, effects on local community in compensation, relocation and resettlement period are also mentioned and assessed in detail in this report. Therefore, this chapter aims to find and assess the direct and indirect impacts that are likely to occur as a result of construction and operation phases of the Nghi Son Refinery and Petrochemical Complex. The significance of impact also depends on whether the affected environmental components have already undergone modifications. Impact significance has been established by using the following criteria: The component is recognised by a law, policy, regulation, or official decision (e.g. a park,

ecological reserve, rare or endangered species, habitat for fauna or flora, archaeological site, or historical site);

The risks to the health, security, and well-being of the population; Intensity of the impacts (i.e. degree of perturbation of the environment affected and degree of

sensitivity or vulnerability of the component); Magnitude of the impact (i.e., spatial dimension such length or area); Duration of the impact (i.e., temporal aspect and reversibility); Frequency of the impact (e.g., intermittent occurrence); Probability of the impact; Indirect effect on other components (i.e., interaction between the affected component and other

components); Sensitivity or vulnerability of the component;



Uniqueness or rareness of the component; Durability of the component and the ecosystems; Value of the component to the population.

This methodology considers the intensity of the impact which is an integration of the component’s environmental value with its degree of disturbance used for determining the intensity and significance of impacts are as follows: The degree of disturbance for a component defines the scope of the changes that affect the component. The environmental value of a component is the synthesis of its ecosystem-based value and its social value. The approach used to assess environmental impacts of the project determines the intensity, extent, and duration of the anticipated positive or negative impact. The main impact levels used in this report include:

1. Severe environmental effect: Change in ecosystem or activity leading to long term damage (i.e. lasting for 10 years and over) with poor potential for recovery to a normal state. Likely effect on human health; long term loss or change to users or public finance.

2. Major environmental effect: Change in ecosystem or activity over a wide area leading to medium term damage (lasting for over 2 years) but with the likelihood of recovery within 10 years. Likely effect on human health; financial loss to users or public.

3. Moderate environmental effect: Change in ecosystem or activity in a localized area for a short time, with good recovery potential. Similar scale of effect to existing variability but may have cumulative implications; Potential effect on health but unlikely; may cause a nuisance to some users.

4. Minor environmental effect: Change, which is within scope of existing variability but can be monitored and/or noticed; may affect behavior but not a nuisance to users or public.

Areas affected directly by the Project will be limited by (a) the scope of effect of the Project stationary constructions; (b) the scope of effect of the temporary works used in construction phase (transportation road, camps, water supply system, waste water treatment system, pipeline, dredging and disposal area, the harbour); Offsite areas are affected directly by emission of gas, noise, deposition of silt, fire & explosion, waste water discharge or the traffic occurs beyond the Project area. 3.1 SOURCE OF IMPACT TO THE ENVIRONMENT Based on project activities, the main sources of impact are defined by 2 phases of the Project as follows:

Construction/installation phase Operation phase

3.1.1 Impact Source Relating to Wastes 3.1.1.1 In construction phase The source of impact during construction phase depends upon the type of construction activities, the construction methods, construction equipment used, plant equipment fabricated onsite, chemicals / materials used, source / amount of utilities and duration of work. The impacts in construction phase are generated from following areas:



Refinery and Petrochemical complex and supported utilities; Harbor facility; Onshore product pipeline system; Seawater intake and outfall facilities including pipelines; SPM and offshore crude oil pipeline to the Refinery from SPM location.

The quantities/composition of various waste streams such as air emissions, wastewater and solid wastes will be mentioned in assessment. Therefore, Table 3-1 only identifies the sources, waste types, and type of impact. In subsequent sections, the emissions with regards to air, wastewater, solid waste, hazardous wastes, noise and accidental releases have been qualified.

Table 3.1 Impact source related to wastes in construction phase

Generated wastes

No. Source of impact Emission Wastewater Solid waste

Other impacts

Onshore constructions

1 Activities of construction equipments and engines

Dust, CO, NOx, SOx, VOC, CH4, HC

- Residue oil Noise, vibration, light,

public health

2 Operation of Constructional equipment and truck transportion


- Residue oil Noise, vibration, traffic safety, public health

3 Complex installation activities

Dust

-

Empty drums, papers, wood scraps, plastic containers, oily

& chemical wipers

Noise, vibration, public health, occupational health and safety

4 Tank installation Dust, VOC Used materials Occupational health and safety

5 Washing facilities surface before painting (depend on used methods)

Dust (metal dust) Wastewater Fe2O3, SiO2,

K2O, CaO

Noise, public health, occupational health and safety

6 Painting activities Dust, VOC

- Used paints,

brushes, wipers

Occupational health and safety

7 Welding and cutting activities

Dust, heat - Welding rods

Noise, heat, occupational health and safety

8 Pipeline trenching and installation Dust - Spoil materials Ecology / Flora and

fauna

9 Non-destructive testing (NDT)

Radioactive ray - Occupational health and safety

10 Onshore cleaning and hydrotesting (Pipeline & tank system)

- Wastewater - Marine environment, Fisheries

11 Workforce -

Domestic wastewater

Domestic waste

Social disruption, employment, quality of life, HIV/AIDS, public health

12 Fuel spills HC Wastewater Oily wastes Occupational health



Generated wastes No. Source of impact

Emission Wastewater Solid waste Other impacts

and safety Offshore constructions

1 Construction equipments and engines


- - Noise, Vibration

2 Pilling and construction activities


Wastewater - Marine environment, Fisheries

3 Dredging activities at intake channel and breakwater

- -

Dredged materials

Coastal water environment

4 Ship/barge operation for SPM and crude pipeline trenching and installation


Wastewater Marine environment, Fisheries

5 Pipeline Cleaning and Hydrotesting - Wastewater - Marine environment,

fisheries,

6 Workforce - Domestic

wastewater Domestic

waste

Social disruption, employment, quality of life, public health

Exhaust gases

In construction phase, exhaust gases are generated from diesel generators, engine-driven machinery used for site work, welders/cutters and surface coating during equipment fabrication, transport vehicles, fuel oil storage tanks, transporting truck, excavation, trenching and earthworks. Waste water

The effluents usually create from vehicle washing, hydrotest water and sewage. In the rainy season, a significant volume of storm water runoff also generates. In addition, used oil, paints, cleaning solvents, etc., also form hazardous effluent during construction phase. The effluent from equipment/vehicle washings contains mainly TSS and oil. Typically, these will be discharged to the land with preliminary treatment for removing oil and grease. The effluents from equipment/vehicle washings contain mainly TSS and oil. Typically, these effluents generated during construction and commissioning phase will be treated and disposed in correct way by EPC Contractor to ensure that final discharge of effluents is in compliance with Project Discharge Standards. The cleaning and hydrotesting effluent generated from pipeline and tank-farm cleaning and hydrotesting process is assumed the biggest volume in construction phase. Depending on cleaning and hydrotesting alternative (use chemicals or not), estimation of this effluent is assumed based on the volume of biggest tank and onshore pipeline system. Estimation of domestic wastewater in the construction phase is based on average manpower of 21,862 (22,000 in round) persons and peak manpower requirements of 32,795 (33,000 in round) persons. Anticipated construction period to mechanical completion is 36 months which equate to approximately 930 working days, based on a 6-day working week. Estimation of effluent in the construction phase is given in Table 3.2.



Table 3.2 Estimation of Effluent in Construction Phase

No. Source Volume (m3) 1 Raw water for concrete 278,250 2 Cleaning and hydrotesting water for tank testing 500,000 3 Cleaning and hydrotesting water for pipeline routes 187,500 4 Raw water for flushing 375,600 5 Domestic wastewater

Average (22,000 pers x 0.2m3/day x 930days) 4,092,000 Peak (33,000 pers x 0.2m3/day x 930days) 6,138,000 Source: Technical Doc. 3550-8710-PR-0003, REV A1 provided by FWL in April 2009 The sewage generated from site offices and constructional sites and camps will contain both total suspended solids (TSS) and biochemical oxygen demand (BOD). Solid Waste

Solid wastes usually generate from construction debris, excavated soil, packaging materials, scrap metals from construction and equipment fabrication, vehicle/equipment maintenance waste, etc. The excavated soil from onshore pipeline route can be used for pipeline backfilled; the others are often segregated and stored in roll-off containers at waste yards managed by the EPC contractor. Besides, there is a volume of domestic waste generated by 33,000 workers. The estimation of these wastes is given in Table 3.3.

Table 3.3 Non-hazardous wastes in construction phase

No. Waste type Generation rate (Ton/year) 1 Sand/Soil from excavation soil 6,141 2 Packing waste – card board 50 3 Packaging waste wood 300 4 Packaging waste-thermocol 20 5 Drums/container (uncontaminated) 4 6 Glass 40 7 Used PPE (uncontaminated) 50 8 Paper waste 150 9 Office furniture 5 10 Office electronic wastes 5 11 Compostable food and canteen waste >10,000 12 Domestic sewage ≈70 m3/day* Total 16,835

Source: Technical Doc. 3550-8150-PH-0002, REV D1 provided by NSRP LLC in December 18, 2009

Domestic solid waste especially from the camps are collected and stored in waste skips and disposed to local landfill. Hazardous waste

Solid and liquid hazardous wastes will be generated from equipment maintenance and lubrication, surface coating, on-site fabrication, empty containers of paints/solvents/oils and accidental spills. These wastes typically include used lube oil, batteries, empty drums of paint/solvent/additives, floor sweepings from material storage yard, oily sludge, contaminated soils from spills, off-specification materials, electrical and mechanical components, etc. Most of these cannot be recycled or disposed off -site. Estimation of hazardous wastes in construction phase is listed in Table 3.4.



Table 3.4 Hazardous wastes in construction phase

No. Waste type Description Quantity (Ton/year)

1 Oily waste Engine, transformer oil, waste fuel, waste lube oil, cooking oil 21

2 Oily container/drum

Oil filters, empty chemical drums, maintenance waste-gease, oil, cotton waste, rags, etc

9

3 Used batteries/ cartridges

Dry batteries, Li, Cd, batteries, Lead acid batteries/acid, toner, used photocopy cartridges, used fluorescent tubes, aerosol containers/cans, used smoke ionic detectors, refrigerant Residues, Pigging residues,

12

4 Contaminated materials

Solvents/ paints/ thinners residue, sealants/mastic, spill absorbents, contaminated soil, contaminated insulation, mineral wool material, used PPE

33

5 Lab and medical wastes

Medical /clinical/first aid waste, laboratory waste e.g. expired chemicals

3

6 Radioactive waste Radioactive waste <1 Source: Technical Doc. 3550-8150-PH-0002, REV D1 provided by NSRP LLC in December, 2009 These wastes will be handled safely and stored in skips, drums and containers at the waste yard. They are then transferred to the authorized treatment contractor by EPC Contractor in accordance with Decision No.155/1999/QĐ-TTg dated 16th July 1999 issued by the Government on hazardous waste management regulation. Sources of accident In construction phase, accidental impact sources at construction sites result mainly from oil spills during routine loading/unloading, transportation and use of hazardous materials. The cleanup of such spills generates oil-contaminated sands, floor sweepings and general debris. For instance, where compressed gas cylinders or welding gases are used, there is a likelihood of such impact sources during storage and transport activities. 3.1.1.2 Source of impact in operation phase

The sources of impact related to wastes in operation phase include air emissions, liquid effluents, solid wastes and hazardous wastes generated from the process units along with the utilities, tank farm system and marine facilities. 3.1.1.2.1 Emission gas Flue gas from stacks During the operation phase, air emissions of the Nghi Son Refinery and Petrochemical Complex are emitted through point source stacks of process units and utilities. There are totally 19 stacks from various process units and utilities. Based on FEED document [Ref 10], the assumptions and estimated emission rate from refinery stacks (process headers) are in compliance IFC HSE Guidelines for the “Petroleum refining”, emission from stacks located in the aromatic section and naphtha and aromatic complex are compliance with IFC HSE Guidelines for “Large volume petroleum based organic chemicals manufacturing” and boiler and gas turbine stack emission are compliance with IFC HSE Guidelines for “Thermal power plants”. In the normal operation, emissions rates of NOx, SO2, CO and PM from point source stacks are given in Table 3-5.



Table 3.5 Emission concentration of pollutants at the point source stacks in the operation phase - NSRP

SOx (mg/Nm3)

NOx (mg/Nm3)

CO (mg/Nm3)

PM10 (mg/Nm3)

No. Source name Fuel type % S Flue gas

flow (Nm3/s) Project standard

(1)

Concentration of SOx at

point source stack

Project standard

(1)

Concentration of NOx at

point source stack

Project standard

(1)

Concentration of CO at point source stack

Project standard

(1)

Concentration of PM10 at

point source

1 SRU Stack Fuel gas 0.0058 32.57 150 120 450 167 800 150 50 50

2 FGD Stack HSFO 0.909 262 400 65 400 50 800 150 50 50

3 RFCC-Co Boiler Stack HSFO 0.909 133 400 400 400 300 800 800 50 50

4 GT HRSG Stack 1 Diezel+LPG 0.04 193 400 20 152 152 800 150 50 50

5 GT HRSG Stack 2 Diezel+LPG 0.04 193 400 20 152 152 800 150 50 50

6 HMU Reformer Stack Fuel gas 0.0058 69.18 400 20 450 60 800 150 50 50

7 CDU Stack Fuel Oil 0.24 22.28 400 400 450 450 800 150 50 50

8 ETP-Incinerator Fuel gas 0.0058 0.83 400 20 450 167 800 150 50 50

9 RHDS Stack 1 Fuel gas 0.0058 5.07 400 20 450 167 800 150 50 50

10 RHDS Stack 2 Fuel gas 0.0058 5.07 400 20 450 167 800 150 50 50

11 NAC-1-42 H101 Fuel gas 0.0058 39.14 100 20 300 124 800 150 20 20

12 NAC-2-49 H101 Fuel gas 0.0058 12.54 100 20 300 171 800 150 20 20

13 NAC-3-44 H201 Fuel gas 0.0058 49.53 100 20 300 171 800 150 20 20

14 NAC-4-47 H101 Fuel gas 0.0058 5.1 100 20 300 124 800 150 20 20

15 NAC-5-46 H101 Fuel gas 0.0058 7.14 100 20 300 124 800 150 20 20

16 NAC-6-40 H101 Fuel gas 0.0058 4.3 100 20 300 171 800 150 20 20

17 KHDS1 Fuel gas 0.0058 1.43 400 20 450 167 800 150 50 50

18 KHDS2 Fuel gas 0.0058 1.82 400 20 450 167 800 150 50 50

19 GOHDS Fuel gas 0.0058 4.11 400 20 450 167 800 150 50 50

Source: Technical Document provided by FWEL, June 2010 Note: (1) Project standards are taken from Section 0 - Table 0.2, this standard is considered and selected strictly between Vietnamese Standard and IFC EHS guideline



The values from Table 3.5 show that all concentrations of pollutants (SOx, NOx, CO and PM10) at the point source stacks of the NSRP are within project standards which are considered as more stringent than the Vietnamese standards and IFC EHS guidelines. Emission gas from flare system In the case of general power failure, discharges from all relief valves (except acid gas service) are routed to the HC flare system. Flaring gas will be routed to the HC purge flare / HC flare by maintaining the different head in the HC purge flare seal drum and HC flare seal drum. Emission rate from HC flare /HC purge flare system are given in Table 3-6.

Table 3-6 Emission rate from flare in normal and emergency cases

Emission concentration (mg/Nm3)

Flare Name Case NOx SO2 CO PM

GPF of Island 1 323 - 1,758 44 HC FLARE ESD GPF of Island 2 98 - 531 28 GPF of Island 1 214 89,236 1,166 50 GPF of Island 2 97 10,568 528 29

ESD

Max H2S release (SRU 3-down) 84 315,076 457 50

HC PURGE FLARE

Normal operation 58 - 316 - Project standards 450 400 800 50

Source: FWEL, October 2009 In normal operation, there is no emission of SOx and PM10 at HC purge flare. The emission concentrations of NOx and CO are within the project standards. In emergency cases, the emission concentrations of NOx and PM10 at both HC flare and HC purge flare are still within project standards. However, the emission concentrations of SOx and CO exceed project standards, especially in the case of maximum H2S release of SRU 3-down. VOC from storage tank system

The fugitive emissions from NSRP are mainly from the storage tanks. The storage tanks include the crude oil, intermediate, final product fuel oil and plant inventory storage tanks. The emissions from these tanks mainly contain VOC and their emission rates are given in Table 3-7.

Table 3-7 Emission rate of VOC from storage tank system

Source Description Number of

tanks VOC emission rate

(kg/tank/year) Refinery FO tank 1 455 Utility fuel oil tank 3 15 Ship loading fuel oil tank 1 15 GO HDS feed tank 4 2,846 RHDS diesel tank 2 4,144 GO premium tank 3 5,723

Vertical fixed roof tank

GO (Ind) tank 2 9,048 FRN tank - CFRT 2 2,846 Desulphurised heavy naphtha 1 1,937

Internal floating roof tank

Reformate tank 1 2,379



Source Description Number of

tanks VOC emission rate

(kg/tank/year) Light reformate tank 1 1,603 Heavy reformate tank 1 520 Heavy aromatics tank 1 1,192 RC/ DSRC tank 6 192 Crude tanks 8 2,376 Alkylate tank 2 2,057 Heavy FCC naphtha tank 2 394 Gasoline 92 tank 2 8,812 Gasoline 95 tank 2 8,812 SR slop tank 2 4,482

External floating roof tank

Cracked slop tank 1 2,018 Jet tank 3 111 Ventilated internal

floating roof Kerosene tank 1 111 Total 52 140,511

Source: FWEL, October 2009 3.1.1.2.2 Wastewater In the operation phase, the process effluents comprise spent caustic, benzene contaminated wastewater, water from sour water stripper and various overhead receivers, boiler blow down and backwash from process units, which is collected through the drain system. The continuous oil contaminated wastewater is collected from oily water equalization tank, equipment areas and tanker loading areas and is routed to the drain system. The cleaning wastewater comes from various process and utility areas. Accidentally oil-contaminated surface water (AOC) including surface run-offs (rain water, wash down) are collected from project areas with a risk of contamination. Therefore, Specific wastewater streams are collected in dedicated systems before passing to the effluent treatment plant (ETP), including:

Dedicated collection of benzene contaminated water (BCW) in a closed system to prevent atmospheric emission of benzene

Dedicated collection of spent caustic effluent for flow balancing and prevention of atmospheric H2S emissions

Water from crude oil tank bottom will be routed to a dedicated API separator to remove gross oil content.

The sanitary effluent generated from administrative building and offices is collected separately, pre-treated and routed into the biotreatment stage of the ETP. Total amount of sanitary water is about 14m3/h from refinery and 0.7m3/h from Jetty area. So, total amount of sanitary water in operation phase is about 14.7m3/h. The total quantity of process wastewater from various process units including utilities and sanitary is about 600 m3/hour. The ETP consists of a two stage oil/water separation unit along with third stage biological treatment. Cooling water will be seawater taken from Nghi Son bay at the coastal. After cooling circulation, about 5-20% of cooling water will be routed to FGD for desulphurisation purpose. The neutralized effluent from the desalination plant is estimated of 564 m3/hour which will also be potentially discharged to the sea through the outfall facilities.



Estimation volume of effluents generated from refinery complex is summarized in Table 3-8.

Table 3-8 Quantity of NSRP effluents in operation phase

No. Source Flow rate (m3/h)

1 Sea water intake 128,200

Total effluent outlet 129,364

- Peak ETP outlet (including industrial effluent and domestic effluent) 600

- Peak RO/IX Reject/Regent 564

- Power FGD outlet 23,000

2

- Cooling water 105,200

Source: Technical Document provided by FWEL, October 2009 3.1.1.2.3 Solid waste Non-hazardous solid waste Solid wastes during the operational phase include hazardous and non-hazardous wastes. Non-hazardous solid wastes include packing materials, used electrical fittings, domestic waste from residential camp, canteen waste, STP sludge, waste paper, printer cartridges, metal scrap, used spare parts and cans, drums and containers of non-hazardous materials. These wastes are stored at designated waste storage areas at the facility and finally disposed off at approved dumpsites or sold to potential authorized buyers for recycling (e.g. waste paper, packing materials, metal scrap and printer cartridges). A suitable waste management facility for storage of solid wastes will be located at the plant boundary. Hazardous solid waste When the project comes into operation phase, hazardous wastes from various process units are mainly spent catalysts, spent absorbents, spent de-sorbents, replacement of inert materials, oily sludge, waste chemicals, containers of hazardous materials, incineration ash, etc. Liquid hazardous wastes include spent caustic waste oil / paints / solvents and chemicals. The estimated quantities of significant hazardous wastes are given in Table 3-9.

Table 3-9 Quantity of hazardous wastes in operation phase

No. Source Unit Quantity Notes 1 Spent catalyst MT 1,110.8 Once in 04-05 years 2 Spent hydrotreater catalyst MT 153.2 Once in 04 years 3 Spent solid phosphoric acid catalyst MT 224.6 Once in 02 years 4 Spent catalyst (CR3S) sulphur recovery unit MT 140 Once in 05 years 5 Spent catalyst (TG 107) from SCOT section MT 70 Once in 05 years 6 Spent adsorbents MT 17.323 Once in 04 years 7 Spent catalyst replacement Ton/year 1,760 Annual



No. Source Unit Quantity Notes 8 Replacement of inert material Ton/year 52 Annual 9 Spent adsorbents Ton 603 Once in 04 years 10 Spent adsorbents Ton 1.3 Annual 11 Spent desorbents Ton 1116 Once in 20 years 12 Spent desorbents Ton 2.63 Annual 13 Spent caustic m3/year 1,632 Weekly (34m3) 14 Catalyst grading materials (from HDS reactors) Ton 49 Once in 04years 15 Teal oil liquid waste m3/year 280 Regular 16 Hydrocarbon drains m3/year 146 Regular 17 Spent selective hydrogenation catalyst Ton 10 Once in 04 years 18 Clay treater sludge Ton 154 Every 06 months 19 Clay treater sludge (from BT clay treater) Ton 103.6 Every 02 years 20 ETP sludge Ton/year 5,204 Regular 21 Incineration ash from ETP Ton/year 2,100 Regular

Source: Technical Doc.3550-8150-PH-0002 – REV D1 provided by NSRP LLC - December, 2009 Total amount of sludge is about 25,080kg/day in normal case and 57,360kg/day in peak case. These wastes will be stored in designated and protected hazardous waste storage area of the Refinery. The hazardous waste storage area will be typically part of the waste management facility, which will be planned and located at the site for storage of non-hazardous and hazardous wastes. 3.1.1.2.4 Accidental impact sources Accidental impact sources from the refinery include gaseous and liquid sources. The gaseous impact sources include fuel gas/LPG leakage from the supply/process pipelines and LPG leak from the storage tanks due to corrosion or external damage. The liquid impact sources include spills or leakages from crude oil/intermediates/final products/fuel oil storage tanks, product export pipelines, oil spills from SPM, crude pipeline and shipping collision. The significance of the above leaks depends on the quantities (inventory) of material contained, type of leak (small / medium leak or rupture) and the location of leak (onsite /offsite). The hazard identification (HAZID) or hazard and operability (HAZOP) studies have been undertaken by FEED consultant for this project. The quantitative risk assessment (QRA) of potential hazards and consequences of accidental impact sources is carried out by FEED Contractor. 3.1.2 Impact source not related to wastes Non-waste impact sources in construction phase are mainly generated by:

Complex construction and installation of equipments; Tankfarm construction and installation; Harbor construction (including hard jetty, product jetties, breakwater, turning basin and access

channel through sea route); Offshore and onshore pipeline construction;



Unload and transport materials and super size & super weight equipments; Breakwater construction; Pilling and construction activities harbor; SPM and Crude pipeline trenching and installation; Anchoring activities of laying barge and supply vessel.

In the operation phase, main impact sources not related to wastes are generated from following activities:

Operation of the complex; Product distribution road; Crude and product storage area; Offshore pipeline maintenance; Offloading crude at SPM; Loading products at harbour Shipping activities.

The impact sources not related to wastes from project phases are given in Table 3.10.

Table 3.10 Impact sources not related to wastes from construction and operation phases

Impact sources not related to waste

Refinery Marine facilities Impact

CONSTRUCTION PHASE

- Foundation treatment and installation of equipments

- Foundation treatment and tankfarm installation

- Welding and cutting activities - Onshore pipeline installation - Intake and outfall construction

- Breakwater construction - Pilling and harbor construction activities - SPM and crude pipeline trenching and

installation - Anchoring activities of laying barge and

supply vessel

- Social issues - Noise & vibration - Seawater environment - Biological environment

OPERATION PHASE

- Product distribution road - Onshore pipeline maintenance - Crude and product storage area

- Pipeline maintenance - Offloading crude at SPM - Loading products at jetties - Shipping activities

- Noise & vibration - Seawater environment - Shoreline erosion

The above-mentioned activities will cause impacts to society, noise & vibration, sea water, biology and shoreline erosion in project phases.



3.2 IMPACTED OBJECTS 3.2.1 CONSTRUCTION, INSTALLATION AND COMMISSIONING PHASE In order to ensure the efficiency of cost and environmental sustainable development, NSRP LLC has considered safety and environmental standards since the FEED preparation phase. All design options strictly comply with standards of Vietnam and World Bank. According to site philosophy for main project components, process units will be arranged in an optimum way to reduce used natural resource. From environmental point of view, it shows that:

Arrangement of high heat and pressure process units at the centre of the Plant will mitigate negative impacts on surrounding residential area;

Crude oil tankfarm, product tankfarm and pipeline joint areas will be located in the Northeast of the Complex. Product tank and sphere tank area will be in the Eastern fence of the Plant to reduce the length of product pipeline to the harbor;

Wastewater treatment area is sired between product tank area and process units in order to collect and treat effluents easily;

Intermediate tank, waste storage, crane and administrative areas are located nearby the West fence of the Complex and Coc mountain;

The control house is sited close the administrative area and near the process units;

The flare will be put in the Southeast corner of the Complex;

The arrangement of SPM at 33.5 km far from the shore does not need to dredge maintenancely. Crude oil tanker will approach SPM easier and may go in and out from any directions and especially reduce environmental impacts on marine resource (coral reef) around Me island;

Crude oil pipeline is installed in the North of Me island and far from coral reef area to mitigate impact during construction phase and potential risk of oil spillage;

Product berth construction is considered to the stability of the seashore and near the Complex to reduce product pipeline length and potential risk of marine transport activities;

For Thanh Hoa Province, product berth construction in the East of the Complex will be an advantage for broaden Nghi Son harbor system in the future. This is safe and easy for management and operation of the Nghi Son harbor. Especially, the operation of the harbor will not cause any disturbance to the traffic of local people living in Nghi Son island;

Breakwater construction in the North harbor will reduce effect of sea wave, current and sedimentation loading in the initial phase of the construction, especially heavy modules transport.

3.2.1.1 ENVIRONMENTAL IMPACTS FOR CONSTRUCTION OF ONSHORE FACILITIES

(REFINERY AND SUPPORTED FACILITIES) The environmental components affected by the onshore implementation of Nghi Son Refinery and Petrochemical Complex concern mainly air quality, noise and vibration, water resources, soil quality, flora and vegetation, fauna and wildlife, aquatic habitat, cultural resources, land and natural resources, livelihood activities, population, health and safety, etc. In addition, the project impacts on global environmental issues like greenhouse gases and biodiversity are also considered.



The works assessed in this part include:

The complex site (area B); Onshore pipeline system (area E) including crude, product, cooling intake, outfall pipelines.

3.2.1.1.1 Air quality Project activities During the construction phase, dust will be generated due to earthwork activities and exhaust gases from constructional equipment and truck movement at site. Potential impacts Dust The potential impacts on air quality during construction phase of the refinery are the generation of dust from earthwork activities, transportation, site movement of vehicles on unpaved surfaces and the engine exhaust from construction equipment, vehicles at the construction sites and labor camps. Dust is considered as major adverse impact due mainly to earthworks for site improvement, site excavation for foundation and surface polishing of tank system. The movement of 586 equipment (dump trucks, excavators, bulldozer, roller/compactor, grader, piling, etc.) will create a lot of dusts in the dry season (December to May) and cause dust pollution to Project area and the vicinity as similar as mentioned in pre-construction phase. Moreover, people living along provincial road 513 will be also affected by dust. The steel welding and cutting activities, polishing tank surface and spraying paint on tank and pipeline system will generate a great quantity of dust, VOC and oxide metals (Fe2O3, SiO2, K2O). These substances will directly affect on health of on-site workers and local effects to air quality at working site. In general, dust generated from construction activities of the Complex and supported utilities will directly impact on on-site workers at the Project area. The Project is located in NSEZ but it is too near residential area. Therefore, in construction phase, dusts do not only affect on the project area but also affect on residential area and nearby communes. Impact level is assessed as moderate for 03 years of construction and installation. Emission gas The major exhaust gases consist of PM, NOx, SOx, CO and VOC. Based on number of constructional equipment, volume of used fuels and constructing time, estimation of exhaust gases are given in table 3.11.



Table 3.11 Estimate exhaust gases from construction equipment in construction phase

Exhaust gases (Ton) Equipment

Number of equipment

(pc)

Used fuel (Ton) TSPb COc SO2a NOXd VOCe

Cranes 40 3,152 13.6 44.1 0.019 220.6 12.7 Mass transportation buses (60 seats)

122 4,340

18.7

60.8

0.026

303.8

17.4

Heavy equipment 40 2,846 12.2 39.8 0.017 199.2 11.4 Earthmoving equipment 284 17,178 73.9 240.4 0.101 1,202 68.7 Other cars & trucks 100 1,581 6.80 22.1 0.009 110.7 6.3 Total 586 29,096 125.1 407.4 0.175 2,037 116.4 Notes: Used fuel is assumed for 515 working days Specific weight of Diesel is 0.85 ton/m3 a: S content is taken of 0,3%W. b,c,d,e: 4.3; 20S; 70; 14 and 4 for TSP, SO2; NOx; CO and VOC respectively. Fugitive emissions from earthmoving equipment, crane and heavy machines will release combustion gases like TSP, NOx, SO2, CO and VOC which will impact local ambient air quality. Based on estimation exhaust gases from 586 construction equipments and vehicles, the total exhaust gases is estimated to be 2,037tons of NOx, 407tons of CO, 125tons of TSP, 116tons of VOC and 0.175tons of SO2. All these gases created from movement sources will be easily dispersed in an open and flat terrain. Therefore, the impact of exhaust gases is considered as minor for three construction years. The painting activity is potential source of VOC release into environment, especially under sunshine in the dry season. In practice, the painting activity is carried out in different locations of the Complex, so the VOC will easily disperse into the air with very low concentration and affect insignificantly on the environment. Moreover, NSRP LLC will suggest the EPC Contractor apply international painting standards to ensure that VOC concentration comply with Vietnamese and International requirements. Hence, impact level of painting activity is assessed as minor. Noise and vibration Project activities Noise generated on construction site will come from sources which vary in nature and intensity. The most significant noises are produced by heavy equipment operating on the site, such as compressors, pneumatic and hydraulic tools, excavators, loaders, graders, bulldozers, shovels, and hammers. Other noise sources can include trucks traveling to and from the site, the loading and unloading of materials, and sirens and backup warning signals. There is also noise produced by engines (i.e., valves, air cooling and exhaust systems), as well as vibrations generated by tools. Moreover, poor equipment maintenance (e.g., loose parts and poor lubrication) can create vibrations and, consequently, increase the noise level. The use of dynamite is also a significant noise source on construction sites. Primary receptors for construction-related noise and vibrations include site employees and residents and structures in the communes near to the construction site. Potential Impacts

Noise is a concern for project workers and local communities, especially in the early morning and nighttime site work activities. The typical noise levels expected from the various construction machines are presented in Table 3.12.



Table 3.12 Noise level in construction phase

Noise source Number of equipment1 Expected noise level2 (dBA) Heavy cranes 40 115 Mass transportation 122 75 Heavy equipment 40 125 Earthmoving equipment 284 115 Others 100 72-74

Total 586 Source: 1: FWL, April 2009 2: Refer to Vietnam construction standards The heavy equipments used in construction and installation works, diesel generators, pilling machines, roller/compactors, etc. and the road transportation will cause noise impact on the workplace as well as the vicinity and access roads. It is likely that at certain locations close to the noise sources within the work site, the noise levels will be in excess of 85dB(A) which is required the personnel on-site to wear ear protection devices. The construction activities on-site are likely to affect the ambient noise levels, especially near residential areas. For construction equipment with a typical level of 85 dBA at 15 m, the expected noise level is approximately 49 dBA at 1 km distance from the source and 43 dBA at 2 km distance. Simultaneous operation of multiple pieces of heavy equipment can increase noise level by up to 10 dBA. The noise from a construction work site may have a significant impact on residence located within 1 km of construction activity and could exceed IFC noise guidelines. Noise levels for a typical haul truck are 85 dBA at 15 m with the average velocity of 80km/h, the forecasted equivalent noise level is LAeq 1h: 50 dBA at a distance of 400 m from the road, in compliance with IFC residential daytime noise guidelines but exceeding residential nighttime guidelines. Noise from transport vehicles will be only transient for a given location and can be considered as a nuisance during daytime and night-time along the transportation access. During the night-time when the ambient noise levels are low, the level of perception to noise is more sensitive and impact more significant. Moreover, the direct driving a great quantity of concrete piles for foundation consolidating will generate noise but also cause strong vibrating within the project area. It is noted that the noise and vibration caused by pilling drivers are most long lasting, stretching and make uncomfortable (reverberation effect) to local communities within first year of construction period, especially at night-time. Thus, noise generated from construction equipment will directly affect to health of construction workers and nearby communities. Impacts level is assessed as moderate and uninterrupted during working process.



3.2.1.1.2 Surface water Impact by construction/installation of intake water and outfall effluent system

Project activities The water intake from the sea is installed at the seashore and located on the north of export jetty. Related to intake installation, some works, such as installation of crest breakwater, intake channel, will be implemented. The outlet location will be 6 km from shoreline. The outlet system consists of main pipeline and diffuser pipes which have some number of ports. Whole outlet system will be buried under seabed with ports which are 1 m higher than the surface of seabed. Potential impacts Intake channel with 350m in width and 70m in length will be dredged to designed depth in order to ensure supplying enough sea water for cooling purpose. The dredging activities will impact to 24,500m2 seabed and generate a significant quantity of dredged materials. Wastes from dredging activity and above-mentioned earthwork will be discharged at approved site by the authority or at disposal site of capital dredging materials in the construction phase. Turbidity will be increased during intake installation near shore. The construction of outlet system will strongly cause the seabed disturbance and increasing turbidity of coastal water. However, construction activities are done in a short time, therefore adverse impact level is considered as short-term and moderate. Potential water pollution due to onshore cleaning and hydrotesting activities Project activities Cleaning and hydrotesting activities will be undertaken after completing installation tank system and in plant pipeline system. It is planned to use freshwater and some chemicals as oxygen scavenger, corrosion inhibitor, biocide and dye. Preliminary estimate shown that hydrotest volume is about 500,000m3 which will be retained in settling pond to remove particulates and recycle for one by one tank testing. At last, cleaned and hydrotested wastewater will be treated through on-site effluent treatment facilities before discharging into the environment. Potential impact The discharge of treated cleaning and hydrotest water into coastal water might cause oxygen depletion and high turbidity around the outfall area. In practice, the hydrotest water will be diluted quickly by effects of sea waves and tide. Therefore, the impact level is assessed as minor within 1-2 weeks. Effect of sanitary wastewater discharge Project activities During the construction phase, a large number of employees are mobilized to the site. The average number is about 22,000 persons and the peak period will be 1.5 times higher (33,000 persons).



Approximately 6,600 m3 of domestic wastewater per day will be generated during the peak period of construction activity (Table 3.2). This sewage will be treated in a dedicated effluent treatment system and discharged subject to the storm water channel to the sea. Potential impact The potential impacts which may be associated with the sanitary effluent discharge are to reduce water quality in receiving waters due to high BOD and COD and dissolved oxygen (DO) depletion around outfalls due to bacterial digestion. This might also cause eutrophication due to increased organic loading (algal blooms) and resultant localized anoxia. NSRP LLC will ensure that effluent treatment design standards are set in the environmental design basis, so that the treated effluent from the construction camps will not be discharged into a highly sensitive as Lach Bang watershed. On this basis, the discharge of sanitary effluent from the camps will cause a moderate adverse environmental impact. Impacts will last throughout the construction phase (3 years), but its magnitude will be most significant during peak construction operations. Any adverse impacts to local water quality as a result of the discharge may also be offset by the cessation of raw sewage disposal into water environment following relocation of discharge site. Effect of storm water discharge Project activities Large volumes of turbid storm water will be generated at the worksite, particularly following excavation work, pipeline trenching and backfilling. Potential impact At the end of site leveling period, Dap Ngoai canal will be tiredly backfilled. In order to drainage water for the area from Chuot Chu mountain foot to the road 513, NSEZ management board had constructed a drainage creek along road 513 to Lach Bang river. According to calculation, maximum volume of runoff storm water at the Plant site is about 143,514 m3/h. In order to prevent inundation to nearby community, the Project has designed a drainage channel in the North of the plant to drain off all volume of runoff storm water in the surface of the Plant. Runoff storm water in the South will be drained through a drainage system constructed by NSEZ Management Board along Road 513. Therefore, all of water run off in the project site as well as rain water around Chuot Chu mountain foot area will be totally drainaged out and do not cause effect to nearby populated area. Impact level of runoff storm water is assessed as minor. 3.2.1.1.3 Groundwater Project activities The water requirement during the construction phase is taken from Nghi Son water supply plant. Preliminary quantity of water needed for domestic demand of 33,000 workers in the construction phase is approximately 6,600 m3/day in average and 9,900m3/day in peak daily demand. Total average demand over construction phase (930days) is about 6,138,000 m3.



In addition, raw water for mixing concrete, flushing and tank cleaning and hydrotesting are estimated of 1,153,850m3. Water used for these activities will be supplied by NSEZ. If wastewaters generated in the construction phase are not treated properly, it will be a potential risk of causing groundwater pollution. Potential impacts Pipeline trenching, site upgradation and consolidation activities might impact to groundwater regime of surface layer from Chuot Chu mountain to Lach Bang river. Impact level is assessed as minor due to trenching depth is in the range of 1m in minimum and 4m in maximum. The discharge treated hydrotest water to the coastal water is assessed as minor after controlling content of contaminated substances. The significant potential impact to groundwater contamination in this phase is from sanitary wastewater due to having peak number of workers. As planned, the EPC contractor will provide toilets at the site and camps to collect and treat domestic wastewater on site. Therefore, the impact level to groundwater quality is assessed as small in a short period. 3.2.1.1.4 Soil environment Project activities The EPC contractor will implement construction activities such as establishing infrastructure, transport, temporary storage and installing machines, equipments, works, process units. The contractor will use many materials and chemicals in construction and pre-commissioning phase. Besides, in the peak of construction phase, the Project may mobilize maximum workers up to 33,000 persons. The EPC contractor may need more land to set up camps for workers, assemble and temporarily store a great number of equipments, materials… Potential impacts Soil disturbance Total area for onshore constructions is 394 ha. Most of land acquired for the Project (65%) is low production agricultural land (1 paddy crop and 1 onland product crop). The Project area is only about 2.2% of total NSEZ area (18,612 ha). However, foundation treatment activities, building infrastructure and installing units will cause strong disturbance to soil structure from agricultural to industrial land. Impact level is assessed as moderate in construction phase. Potential soil pollution caused by wastes Estimated generation rate of non-hazardous solid wastes in construction and installation phase is about 16,835 tons/year (Table 3.3), in which 59.5% is compostable food and canteen waste (10,000 tons/year), 36.6% is sand/soil waste from site preparation (6,141 tons/year) and 3.9% is others such as packing waste, glass, furniture, domestic waste… Estimation of domestic sludge generated from construction site and camps is about 70 m3/day. This is potential source of soil pollution if there is not suitable or enough collection and treatment equipments. Therefore, if mitigation measures for soil environment are applied strictly, impact level is assessed as minor in 3 construction years.



Hazardous wastes generated in construction phase are mainly contaminated materials, oily waste and used batteries… Estimated generation rate of hazardous waste is about 79 tons/year (Table 3.4), in which 41.8% is contaminated waste (33 tons/year), 38% is oily waste (30 tons/year), 15.2% is used batteries (12 tons/year), 3.8% is laboratory waste, and less than 1.2% is radioactive waste (less than 1 ton/year). All these wastes will be classified on-site and stored in safe containers. Besides, process of cleaning steel plate surface for tank system installation will create a number of metal slags. Estimated generation rate is about 100 tons/year. Since high pressure cleaning process is often carried out outdoor, slag will be dispersed on the ground and hardly to be collected absolutely. Especially in rainy season, these slags will infiltrate into ground to make the soil contamination. Impact level is assessed as moderate during tanks and pipeline system installation. 3.2.1.1.5 Biological environment Flora Project activities The site clearance, trenching and pipeline installation activities will occupy 30 ha residential, agriculture land and coastal protective forest. This area will be used for onshore pipelines system including: two 48” crude pipelines, 13 product pipelines, one intake cooling pipeline and one outfall pipeline and other supported pipelines connecting from Harbor to tank area. EPC contractor may need more land for their accommodation camps, site gathering, assembling and temporary storage a large quantity of equipment, materials, etc., so more number ha of vegetation and flora will be affected. Potential impact Based on “Biodiversity assessment report for the project area and the vicinity” [7] of national biological specialists, August 2008, approx. 70% of pipeline route area (area E) is residential land with fruit trees and 30% remained area is protective forestry which is typical by Casuarinas equisetifolia with the age of 5-10 year old. Estimation of affected coastal protective forest is about 35,000 m2 (3.5ha) and quantity of cut down trees is approx. 2,916 trees. The onshore pipeline construction will required permanent vegetation clearance on 30 ha residential area, product land (peanut, sesame) and coastal protective forest (3.5 ha). In practice, at onshore pipeline area, there is not any rare species and vegetable cover is mainly fruit trees and crops. Affected protective forest is limited in a small area (350m in length and 100m in width), the significance of this impact is assessed as minor. Fauna and wildlife Project activities The site clearance, trenching and pipeline installation activities will occupy 30 ha of residential, agricultural land and coastal protective forest.



Potential impact Based on field survey to project site in February 2009, some distributed birds as white herons were observed in Area N and sub-soil disposed area. The biological survey results for area E and its vicinity (October 2009) shown that these areas are mainly considered as residential and agricultural ecosystem. These ecosystems are not supported any threatened species. The presence of 33,000 workers may affect threatened fauna species through local market food supplies or restaurant. However, since full accommodation will be provided for most of these workers and then reduce the potential impact on the threatened fauna species. The significance of this adverse impact is assessed as minor and short-term. 3.2.1.2 Offshore Construction (Harbor, Breakwater, Pipeline and SPM) 3.2.1.2.1 Air environment Project activities

It is assumed that the number of equipment mobilized for construction marine facilities will be about 10% of quantity of equipment and trucks estimated for the plant site.

Typical equipment for onshore construction consist of excavator, rock hammer/breaker, bulldozers, wheel loader, trucks for backfill materials (rock and sand) transport, survey equipment, anchors, winch or sheaves etc. During offshore construction/installation of crude pipeline and SPM, approximately 42 vessels or equipment packages with capacity of 100 to 200 tones and 37 vessels or equipment with capacity over 200 tones will be required.

Offshore construction activities should be completed within a period of 36 months. Potential Impacts Site preparation harbor, breakwater, access routes and material transportation activities will cause negative environmental impacts on air quality, including dust arising from site preparation, construction activities, transportation and exhaust emission from the operation of diesel generators, construction equipment and heavy trucks. 1. Dust Earthworks associated with breakwater and harbor construction will require large quantity of material including sand. Furthermore, the construction of the harbor and breakwater will be affected by sea winds, so the activities of site leveling and truck movement for loading spoil sand, stones and construction materials will generate a significant quantity of dust that will impact on labors working at the project site and local people living along Tinh Hai and Hai Yen beach. The fine particulate might affect the respiratory system of Contractor employees at the project site and can cause asthma, pneumonia and bronchitis. These activities will have a significant direct impact on project labor and local people living in the vicinity.



In summary, dust generated from constructional activities will cause significant direct impacts on labours working in the project sites and to local residents living in the vicinity. These impacts will last for duration of the construction works (36 months). The significance of this impact is considered to be major during the first two years and will gradually be reduced to minor effect in the third year of the construction and installation phases. 2. Emission exhaust The onshore based construction of harbor, breakwater, crude pipeline and SPM system will use typical construction equipment including excavator, rock hammer/breaker, bulldozers, wheel loader, trucks for backfill materials transport, survey equipment, anchors, winch or sheaves etc. The operation of these machines/equipment will emit to the environment significant quantities of exhaust gases. Based on total number of construction equipment for the whole project and the scope of marine construction activities, it is assumed that the equipment used for marine construction is about 10% of the ones used for plant construction. Estimated volume of emission gas generated from equipments used in harbor and breakwater construction phase is presented in Table 3.13.

Table 3.13 Estimated volume of emission gas generated from equipments used in harbor and breakwater construction phase

Emission gas (ton)

Equipment Quantity Used fuel

(ton) TSPb COc SO2a NOXd VOCe Crane 4 315 1.35 4.41 0.02 22.05 1.26 Truck 12 434 1.87 6.08 0.03 30.38 1.736 Heavy equipment 4 285 1.23 3.99 0.02 19.95 1.14 Soil/stone transport device 28 1,718 7.39 24.05 0.10 120.26 6.872 Others 10 158 0.68 2.21 0.01 11.06 0.632

Total 58 2,910 12.51 40.74 0.17 203.7 11.64 Notes: Used fuel is assumed for 515 working days Specific weight of Diesel is 0.85 ton/m3 a: S content is taken of 0,3%W.

b,c,d,e: 4.3; 20S; 70; 14 and 4 for TSP, SO2; NOx; CO and VOC respectively.

Exhaust gases emitted in construction/installation and pre-commissioning phase of the offshore pipeline includes emission gas of ship engines, generator, welding machine, crane and other equipments on the pipeline installation ship, pulling ship, pipe carrier and supply boats. Components of exhaust consist of CO, CO2, NOx, SOx, dust and unburnt HC. These exhausts may increase concentration of pollutants in the air. As planned, there will be 42 ships/devices with capacity of 100 – 200 tons and 37 ships/devices with capacity of 200 tons. Ships taking part in installation of crude oil pipeline within 12 months include laying barges, pipe carrier and service vessels. Estimated amount of DO used for laying barge and equipments is about 18 tons/day; pulling ship is 0.85 ton/day; pipe carrier is 0.85 ton/day and supply boats is 0.17 ton/day. Fuel used for ships includes fuel used for ship engines and fuel used for onboard devices. According to calculation method of United Kingdom Offshore Operators Association (UKOOA) [17], estimated exhaust from the operation of installation ships is presented in Table 3.14.



Table 3.14 Estimated exhaust gases generated from constructional ships/barges

Amount of exhaust (ton) Vessel

Used fuel (ton) CO2b

COc

NOxd

SO2a

CH4e

VOCg

Laying barge 5,616 17.971 0.0590 0.223 0.010 0.001 0.007 Pulling ship 265 0.849 0.0028 0.0105 0.0005 0.00003 0.0003 Supply boats 53 0.170 0.0006 0.0021 0.0001 0.00001 0.0001 Pipe carrier 265 0.849 0.0028 0.0105 0.0005 0.0000 0.0003

Total 6,199 19.838 0.065 0.246 0.011 0.001 0.008 Note: Used fuel is assumed for 312 working days (26 day/month x 12 months) a: S content is taken of 0,3% W.

b, c, d, e,g: 3.2 for CO2; 0.0105 for CO; 0.0397 for NOx; 0.6 for SO2; 0.00011 for CH4 and 0.0013 for VOC Above results show that: Exhausts from harbor and breakwater installation equipments are mainly NOx (203.7 tons), CO

(40.7 tons), TSP (12.5 tons), VOC (11.6 tons) and SOx (0.02 ton) for 3 construction years. These pollutants will disperse quickly at construction sites and do not cause any significant impact on the air environment.

Amount of exhaust gases from offshore pipeline installation process are small and mainly from

laying barge. This emission may cause some temporary impacts on coastal activities. However, since due to the natural dispersion on the sea condition, the impact level in offshore pipeline installation/construction is expected to be a minor.

3. Noise Project activities As mentioned in this report, quantity of construction equipments used for marine harbour and breakwater is about 58 including cranes, heavy equipments, transport trucks, etc. The piling of large numbers of steel and concrete piles by pile hammers and the activities of excavators, vibro-rollers, vibro-tampers, concrete mixer, and welding machines will generate noise and vibration during the construction period. Transportation of material, sands, cement, stones for construction or rehabilitation of road access, construction of breakwater, jetty and harbor will involve heavy machinery that will impact the population living near the project area but also the transportation routes. Potential Impacts Operation of above machines will cause noise and vibration at harbor area, especially the pile driver. Excessive noise will cause nuisance, interfere with hearing/ conversation, cause fatigue, increase heart rate and reduce sleep quality. The direct piling of steel and concrete piles to the seabed will disturb to local people in the vicinity.



Excessive noise will affect on hearing and nervous system. Noise generated from construction equipments in radius of 15 m [18] is estimated as follows:

- Bulldozer: 93dB - Diesel compressor: 80dB - 1.5-ton pile driver: 75dB - Concrete mixer: 75dB

If distance from the hearer to the machine increases/decreases twice times, noise level will increase/decrease 6 dB. Moreover, at spacious area, the noise will increase due to reflex sound from vicinity works. Effect levels of noise are presented in Table 3.15.

Table 3.15 Effect levels of noise

Noise Effect 45dB on night and 60dB on day Not affected

70 – 80dB Tired 95 – 110dB Harmful 120 – 140dB Potentially causing injury

Source: [18] Among harbor and breakwater construction equipments, the noise of pile driver lasts longest and is the most disturbance to local community. That driving concreted piles directly into seabed not only make noise but also strong vibration at harbor area. Affected area will be defined in radius of 200m around harbor location. According to [19], the noise from construction activities will cause negative impacts on the workers if:

Continuous noise (more than 1 hour) is 10dB higher than allowable standard for area and time in day.

Sudden noise is 15dB higher than allowable standard for area and time in day within less than 1 minute compared with impact threshold.

So, the noise generated from harbor and breakwater construction equipments and varying in range of 75 – 93 dB will cause direct effect on health of labour force working for the Project and local community in radius of 200m, especially at night. The impact level of noise is assessed as moderate during construction phase. For activities of offshore pipeline and SPM installation, construction machines and engines, operations of welding, ship engine and crane will make noise and disturb the atmosphere on the ship installing crude oil pipeline and SPM. Total noise of these equipments in a defined space onboard will directly affect on workers, cause nervous and tired. 3.2.1.2.2 Surface water The construction of marine facilities including harbor, breakwater, crude pipelines and the dredging activities will have significant impacts on the environment and social aspects. The presence of this oil and gas production and transport facilities on the coast in a relative non-industrial area may be source of important impacts.



Installation of SPM and crude pipelines Project activities Single point mooring (SPM) construction activities include setting up a pipeline end manifold (PLEM) system on the seabed below the SPM, inter-connecting hoses and two 48" sub-sea crude pipelines connecting PLEM with the crude oil tank farm. Potential impacts The installation of the PLEM system and anchor buoy leg mooring on the seabed will also cause moderate local disturbance of the sediments as well as obliteration of small areas where the PLEM system and leg mooring sit on the seabed. The presence of the PLEM and leg mooring will result in sediment disturbance and redistribution around the facilities. These impacts are expected to reduce significantly after installation of SPM and pipelines are completed. During subsea pipeline construction activities, the barge is moored using eight anchors. Each anchor cable typically consists of wire rope over one kilometer long carried on eight single drum winches. The pipeline needs to be protected against mechanical damage and for stability reasons. Therefore, the pipeline shall be buried within a pre-excavated trench. This will ensure that the pipeline will not become exposed due to erosion, be stable in the surf zone and be protected from fishing vessel or tourist boats. Two 48" sub-sea crude pipelines run parallel for 33.5km from SPM to landfall point with the interval of 43m. For safety purpose, onshore and coastal pipeline will be buried at least 1m underground. Supposing that trenching and pipeline installation process will disturb the interval between 2 pipelines (43m) and their moving toward two sides (25m) and on each 1 km, laying barge must anchor 2 times with 8 anchors/time and each anchor will create a 3 m2 hole on the surface of the seabed. Therefore, total seabed area affected directly by pipeline installation is estimated as about 2,279,608 m2. As above-mentioned, the seabed topography of the project area is relatively flat and its gradually sloping toward to offshore in which there are some little rough areas. The seabed sediment is mainly sandy clay. Therefore anchoring of laying barge, pipeline trenching and burring activities will cause strong disturbance to the seabed and organic matters, make temporary un-stability of bottom sedimentation loading, and increase considerably of the suspended solid and pollutants within some kilometers from construction site by sloughing seabed sediment along the pipeline route. Especially for the shallow water which is considered to be higher sensitive coastline than the offshore. The impact level is considered as major in the nearshore and moderate in the offshore during construction period. It is important to note that fishing activities are taken place in Nghi Son bay. The SPM area and pipeline route beyond the Eastern of Hon Me Island should be an exclusion zone for fishing activities. However, illegally used explosives in the fishery may form hazards to the pipelines and SPM. Also, mooring activities of local fishermen may be high potential risk for the SPM. Therefore, the interactions between fishing and protection activities of marine facilities can be raised due to the need for fishermen to understand and avoid pipelines in terms of damage liability. Because the potential for gear to become damaged or miss harped when crossing the pipeline as well as the potential for heavy fishing gears to damage the weight coat of the pipeline.



Harbor construction Project activities It is assumed that about 1,400 piles will be piled. Harbor construction will be carried out from the shore, progressing seaward to the various berths in order to take advantage of land bases access and support. Based on the scale of the harbor, a large quantity of steel and reinforced concrete piles (1,400 piles) will be piled into the seabed to the required depth on the parent stone (25 to 35.5m). All piles are locked together to prevent soil erosion behind the harbor and suffered jetties. Concrete piles are installed by temporary bracing system just after finishing the piling work in order to fix the piles and hold up concrete casing system. Estimation of seabed area directly affected by piling in front of the harbor is about 41,060 m2. Potential impacts Impact caused by sand deposition at harbor area In order to assess deposition at harbor and access channel areas, NSRP LLC has used sedimentation model of the marine consultant, Royal Haskoning [20], based on reference to mass of deposited silt, change of depth and silt depositing velocity at access channel area of Nghi Son cement port in the period 2000 – 2008. Mean water depths of the approach channel to the cement port show that:

2000: 13 m 2006: 11 m 2008: 10 m

According to these figures, the annual siltation rate varies between 0.3 and 0.5 m/year. With an estimated area of the cement port approach channel of 1 Mm2, the annual siltation volume would vary between 0.3 and 0.5 Mm3. According to above data, following estimates of dredging quantities related to the Nghi Son Port (south of the peninsula) is as follows:

2002: 2,0 million m3 2006: 0,6 million m3 2008: 2,0 million m3 (including a deepening of the approach channel to allow for 30,000 DWT

vessels) According to these figures 600,000 m3 of sediment has accumulated in four years in this approach channel, thus on average 150,000 m3 per year. With an estimated area of 300,000 m2, the annual siltation rate amounts to 0.5 m per year. If stable factor is 2.05 and annual volume of deposit is about 100,000 m3/year, estimated volume of deposit at access channel of NSRP will be about 205,000 m3/year (Table 3.16).



Table 3.16 Quantity and deposition rate at NSRP access channel

Run ID

Sedimentation of cement port approach channel

[m3/yr]

Sedimentation of NSRP approach channel and harbour basin [m3/yr]

Ratio of NSRP and cement port approach channel sedimentation

[%] 1 48,000 99,000 206% 2 69,000 141,000 204% 3 50,000 100,000 200%

4 50,000 97,000 195% 5 68,000 138,000 203%


The simulation modeling of deposition at harbour and access channel is carried out with the expansion basin the harbour in the future. This basin is longer than one in construction phase but the width is the same.

The presence of breakwater will create a barrier that waves cannot pass and current velocity will decrease significantly. As the result of this, deposition at harbour basin is nearly equal to zero.

Therefore, some conclusions regarding the sedimentation and erosion pattern can be made (Figure 3.1) as follows:

- The majority of the sandy infill of the NSRP approach channel takes place in the shoreward half of it. - The maximum siltation rate in the approach channel is about 0.2 m/yr, occurring in the bend. - The siltation of the harbour basin is limited to the southern part at a rate of 0.1m/yr. - After one year, the ratio of sandy siltation of the NSRP and cement port approach channels is more or less

independent of the parameters settings, viz. varying between 194 and 206%. - During the year, however, this ratio varies considerably. - Given a fixed ratio of 205% and an ‘observed’ annual infill of the cement port approach channel of 100,000

m3/yr, the annual sandy siltation of the NSRP approach channel amounts to 205,000 m3. - A scour hole develops over a relatively large area (approximately 1×1 km2) due to contraction of the current

around the tip of the breakwater. The depth of the scour hole remains restricted to a few decimeters only.

Figure 3.1 Sedimentation (red) and erosion (blue) pattern after one year morphological simulation time



Impacts caused by clay deposition at dredging area

Besides sand/silt deposition, annual deposition of fine particulates is about 0.2 m/year.

A distinction is made between the initial operational phase and a future extension phase. The main difference between the two is the area of the harbour basin. The harbour basin at the start of operation has an area of approximately 0.7 million m2 whereas in the future extension phase it will have an approximate area of 1.7 million m2 (Table 3.17).

Table 3.17 Volume of the annual infill with fines

Phases Area of the

harbor basin [million m2]

Area approach channel

[million m2]

Area subject to fine infill

[million m2]

Siltation rate

[m/year]

Annual siltation volume [m3/year]

Initial operational phase 0.7 1.2 1.3 0.2 260,000 Future extension 1.7 1.2 2.3 0.2 460,000

Source: [20] With a further extension in the form of the construction of a breakwater south of the NSRP approach channel extending towards the cement port approach channel the infill with fines will be reduced but will not become zero. Tidal filling of the port basin will bring considerable amounts of fine suspended material into the harbour basin which will partly settle around slack water. It is therefore advised to account in that phase of the project for an infill with fine sediment similar to the infill in the initial operational phase (140,000 m3/yr – harbour basin only). Note that this volumetric infill is spread over a much larger area than in the initial operational phase thus resulting in a smaller siltation rate of about 0.1 m. The infill of the NSRP dredged areas with fine sediment in the initial operation phase is estimated at 260,000 m3/year. In a future extension phase the harbour basin is enlarged thereby increasing the annual infill with fines to 460,000 m3. These volumetric infill volumes are based on a siltation rate of 0.2 m/year. In summary, activities of pile driving, harbor construction, harbor and access channel dredging will take away sea bed sediment layer and make a strong disturbance to water environment at harbor area. According to research and assessment of sand/silt deposition, it shows that activities of harbor construction and dredging will make changes of deposition at harbor area and access channel. The impact level is assessed as major and short-term. Impacts of breakwater construction Project activities Two breakwaters will be built at NSRP harbor, low-crested breakwater and harbor breakwater. The function of the harbor breakwater is to reduce the downtime for small vessels under operational conditions. The low-crested breakwater is to create a settlements basin before the water intake structure and to prevent sediments to enter the intake structure. The construction of the harbor breakwater will be carried out at the north of the harbor and will have a total length of 1,800 m. The low crested breakwater for the intake structure will be constructed likewise the northern breakwater. The seabed levels range approximately from CD -5.5m to CD +1.0m at the foreshore. The upper elevation of the breakwater structure is +9m height and construction will comprise



of a rock core with a protective rock or concrete layer. The total volume of materials used for construction of the breakwater is 300,000 m3. Breakwater construction is required soil excavation for toe stability down to -5.5m under the seabed with area of 110 m in width and 1,800 m in length. Total seabed area affected by breakwater construction is about 198,000 m2. Potential impacts Impact of breakwater on current regime In order to assess impact of breakwater of the harbor on current regime, NSRP LLC has used FINEL2D model to calculate and simulate current regime at harbor area and its vicinity. This model runs based on wave equations and average depth of Tokin Gulf and specifically calculates for shallow water area at Nghi Son Gulf (Figure 3.2). This model is very suitable for modeling current at estuaries, sea and coastal areas. Besides, FINEL2D model also calculates sediment loading and predict movement of sand, silt or combined model and changes of sea/river bed.

Figure 3.2 FINEL2D model for Tokin Gulf

The computational grid consists of nearly 70,000 elements varying in grid size from 5 km to 500 m. Model set-up standards are referred from Svasek standard values as follows:

Mesh size: 5 km2 to 100m2 Uniform Chezy friction factor: 90 m½/s Eddy viscosity: *Not used * Density of sea water: 1,030 kg/m3 Gravitational acceleration: 9,81 m/s2 Corriolis effect: not applied Wind force: not applied

Calculations are modeled for a tidal period from spring tide (Figure 3.3) to neap tide (Figure 3.4).



Figure 3.3 Current at spring tide – NSRP harbor area

H. A1-1 Current on spring tide - 6 hours before high water H. A1-2 Current on spring tide -3 hours before high water

H. A1-3 Current on spring tide - high water H. A1-4 Current on spring tide -03hours after high water



Spring tide

Spring tide - 6 hours before high water (H.A1-1 – Figure 3.3): The tide is generally moving in a north-south direction. There is evidence that the approach channel is causing some refraction to the currents, but this is not a strong effect.

Inside the harbour the currents are very weak, with a large almost stagnant area stretching from the root of the main breakwater to the roundhead. South of the quayside there is a slow moving anticlockwise eddy. North of the main breakwater, the breakwater gives rise to another slowly moving anticlockwise circulation, which due to the geometry of the main breakwater. At the intake channel the current vectors show that the movement of water is into the intake with a velocity of approximately 0.1m/s. Across the sea area the velocity of the tidal currents ranges from 0.03m/s to 0.3m/s.

Spring tide – 3 hours before high water (H.A1-2 – Figure 3.3): current speed is about 0.0 – 0.2m/s. At this stage in the tide cycle the tide is at or around slack water. The currents across the area have generally lessened, although there is localized acceleration of flow mid-point and roundhead of the main breakwater.

The anticlockwise circulation to the south of the harbour is weakening as is the water circulation to the north of the main breakwater. Water circulation in the harbour is very slow and the current vectors show no clear directionality.

At high water (H.A1-3 – Figure 3.3): the direction of the currents has changed from north to south indicating that the tide has switched from flood to ebb flow. Within the harbour, just off the roundhead there is a noticeable clockwise eddy moving at approximately 0.15m/s.

To the north of the main breakwater the currents follow the coastline moving at between 0.1m/s to 0.12m/s. The breakwater alignment causes an acceleration of the currents along its seaward face with velocities reaching 0.36m/s at the roundhead.

The currents across the area are generally between 0.0m/s and 0.33m/s, with some currents in the south east corner reaching 0.42m/s. These do not affect the harbour or operation of the intake.

Spring tide – 03 hours after high water (H.A1-4 – Figure 3.3): modeling strong movement toward the South of tidal currents. The ebb tide is fully developed, and along the northern face of the main breakwater the currents are accelerated to between 0.24m/s and 0.33m/s.

The slowly moving/stagnant water in the harbour reduced in size as a result of an increase in the size of the clockwise circulation to the south of the breakwater roundhead. Across the area the tidal currents range between 0.0m/s to 0.42m/s.

Spring tide – 06 hours after high water: To the north of the main breakwater and intake channel, the

tidal flow has slowed considerably, with only a weak southerly movement along the coastline illustrated.

Directly in the lee of the main breakwater there is growing area of very slowly moving water with no clear directionality indicated. The size of the clockwise circulation has also increased. It is also noted that the harbour approach channel does not appear to affect the currents as they move across it. Tidal currents do not exceed 0.24m/s.



Figure 3.4 Current at neap tide – NSRP harbor area

H. A1-5 Current on neap tide – 06 hours before high water H. A1-6 Current on neap tide –03 hours before high water

H. A1-7 Current on neap tide – High water H. A1-8 Current on neap tide –03 hours after high water



Neap tide:

Neap tide – 06 hours before high water (H.A1-5 – Figure 3.4): The tide is moving in a northerly direction and so is on a rising or flood tide. In contrast to the anticlockwise circulations, the Northern eddy is located away from the coastline and above the outer half of the main breakwater arm. The eddy moves faster on its seaward (northward moving) edge, where velocities are approaching 0.1m/s, whereas the inner (southward moving) edge moves at approximately 0.05m/s. This is because the breakwater exerts a greater influence over the tidal currents on the neap tide than on the spring tide. The southerly anticlockwise circulation is of a similar size and form to that of the spring tide, although the velocities are approximately 50% of those noticed on the spring tide. In the harbour the current vectors are indistinct, but the general perception is one of a very slowly moving anticlockwise rotation of the water body. The approach channel to the harbour does not appear to attract flow, hence the flood tide continues uninterrupted in a northerly direction.

Movement into the intake channel is at a rate of 0.05m/s to 0.1m/s, which is at the lower end of the design range 0.1m/s – 0.5m/s.

Neap tide –3 hours before high water (H.A1-6 – Figure 3.4): There is a small anticlockwise circulation approximately 2 km east south-east of the breakwater round head.

The flow patterns inside the harbour are not well defined and appear to ‘meander’ north, which is consistent with this stage of the tide being at or around slack water.

To the north of the main breakwater the anticlockwise rotation has widened. The velocities are generally less than 0.05m/s. Flow through the intake channel is around 0.06m/s to 0.08m/s.

To the north and south of the main breakwater there are large areas of very slow water movement that are hugging the coastline. This condition does not last for long as the tidal currents pick up again towards high water. The lower current velocities on the neap tide are as a result of the smaller neap tidal range.

Neap tide - At high water (H.A1-7 – Figure 3.4): Across the area the current velocities are between 0.01m/s and 0.5m/s. north of the main breakwater the anticlockwise circulation is weakening and the direction of the current vectors indicates that the tide is changing from flood to ebb.

South of the breakwater the current vectors show a clear change from food to ebb. Velocities in the intake channel are 0.05m/s to 0.08m/s.

Neap tide – 03 hours after high water: The ebb flow is now well established. Where the currents flow around the breakwater roundhead, the currents are accelerated to approximately 0.12m/s.

In the lee of the breakwater the flow is weak and towards the root of the breakwater, before being directed south by the alignment of the quay wall (H.A1-8 – Figure 3.4): velocities in the intake channel are 0.06m/s to 0.1m/s.

Neap tide – 06 hours after high water: The tidal flow is still strongly moving south, with localized

acceleration of currents around the breakwater roundhead. A small, weak, clockwise eddy is also present immediately off the roundhead.



From the South of the harbor, there is a large slowly moving body of water hugging the coastline with velocities no higher than 0.01m/s.

In addition, dredging activity for beakwater construction will generate a significant quantity of dredged materials. Quantity of dredged materials and diging activities will be determined in detailed basis design stage. Dredged materials and spoil materials will be discharged at designated site approved by the authority or at dumping site of capital dredged materials in preconstruction phase. In general, constructing breakwater will destroy structure of the shoreline and change wave and current regime at harbor area. Impact level is assessed as moderate and long-term. Impact of hydrotest water Project activities After the pipeline and the installations of all tie-ins completed, the crude pipeline will be cleaned and hydrotested. Following activities carried out during testing and pre-commissioning:

Flooding and gausing for metering internal pipeline diameter; Pipeline cleaning and hydrotesting; Dewatering Drying and cleaning pipeline.

Sea water will be used for crude pipeline cleaning and hydrotesting. Estimation of cleaning and hydrotesting volume is about 187,500 m3. It is planned to use some chemicals for sea water treatment with the adequate measured amounts related to the volume of water being pumped by dosing pumps. The flow rates and volumes pumped for each chemical are measured and recorded.

Oxygen scavenger, to remove dissolved oxygen from the seawater so as to prevent corrosion inside the pipeline;

Biocide, to prevent the growth of organisms and bacteria;

Corrosion inhibitor(s), to prevent or reduce attack by chlorides and other potentially harmful components of seawater related to the metallurgy of the pipe (or its lining);

Dye, colored and normally fluorescent under ultra-violet light (such as "fluorescence") which aids divers in tracing the location of any leaks.

Potential impacts It assumed that cleaning and hydrotesting water will be treated and then discharged at SPM location about 33.5 km offshore. The water depth of this site is about -27 m and bottom sediment is sandy clay. The use oxygen scavenger (as ammonium bisulphate) for cleaning and hydrotesting process will cause local oxygen depletion phenomenon around discharge site due to the oxidization of sulfite ion (SO32-) into sulfate ion (SO4-2). The generation of sulfate ion does not affect to marine environment because it is available in high content in sea water. During testing, part of biocide and inhibitor will remain inside the pipe thus amount of chemical discharged following the hydrotest water will be reduced.



The discharge of cleaned and hydrotested water containing seawater and small amount of chemicals into the marine environment may increase pH value, suspended solid in the water column and disturb of water surface layer. Considering high dilution ability, the environmental impact is assessed as minor in the vicinity of the discharge point. In practice, hydrotest water will be discharged into moving sea water environment and strong mixing under continuously wave and tidal effects. That means at pipeline outlet, hydrotest water will be immediately diluted with seawater. So, the hydrotest discharge will cause temporary and local oxygen reduction at the area surrounding discharge site and the effect level is assessed as small and locally during the discharge period (about one week). Domestic Wastes from Barges/Vessels Project activities During crude pipeline construction, it assumes that at least one constructional barge with full equipment for installing pipeline will be used, one barge for supplying pipes and two supply boats for supporting fuels, foods and others for pipeline construction barge. Potential impacts The solid wastes generated from the offshore pipeline construction activities and redundant materials such as metals, welding rods, paper, plastic boxes, oily cloths, etc., with small quantity will be collected separately and transported by support vessels to the shore for further treatment. Moreover, the manual procedures during installation and transportation will be done in accordance with technical standards proposed in order to minimize the potential material strewing. The impact related to solid waste coming from construction activities will be negligible. All domestic waste from kitchen (such as food, fruit peel) will be collected and discharged directly to the sea. Indecomposable waste will be collected in separate drums and transported by support vessel to the shore and disposed at the stipulated disposal site. The significance of domestic waste considering the technical standards on water quality is assessed as negligible. The sanitary generation on board is estimated as small and will be collected to septic tank system for treatment before discharging to the sea. The impact level is assessed as minor to sea water. 3.2.1.2.3 Land and Terrestrial Ecology Flora Project activities Site clearance for onshore harbor will be done on about 36 ha coastal protective forest. Potential impacts Predominant tree in the coastal protective forest is Casuarina equisetifolia in the age of 5-10 year old with diameters in the range of 10-25 cm. The density of the coastal protective forest is about 50trees/100m2. The number of Casuarina equisetifolia is estimated at approximately 150,000 trees. The



impact level is considered as moderate since this forest was used for protection and is also a source of material for Hai Yen Commune. The construction crude pipeline will be carried out at the distance of 6.7 km far from Hon Me Island and will not cause any impact to onshore flora on Hon Me island. Fauna Project activities Using 36 ha coastal protective forest may be the source of impacts on coastal fauna ecosystem. Potential impacts Based on assessment report of existing biodiversity of terrestrial fauna project area [8], there is absence of rare and endangered species living in the project area (coastal protective forest). The species composition of the vertebrate fauna in the project area is relatively poor and most of species found are common ones (birds, etc.). The construction of the harbor will affect 36 ha of potential fauna habitat of common species living in coastal forest and sandy beach. These species might migrate to coastal forest stretching along the coast. Therefore, the significance of this impact is assessed as minor. The taking materials from borrow pits and quarry sites for the construction of breakwater, jetty and harbor platform may affect potential habitat used by rare or endangered species. These species will move away from the excavation sites to search new habitats nearby. The significance of this impact is assessed as moderate and permanent. 3.2.1.2.4 Marine ecosystem Project activities Activities that will have impacts on the marine environment are the construction of crude pipeline (33.5 km), SPM, breakwater and harbor. Potential impacts The trenching, installation and backfilling activities for 33.5km pipelines and SPM will cause disturbance of 2,279,608 m2 of seabed area. These activities will scratch the seabed surface and rouse available pollutants in bottom sediment, change the distribution of the sediment grain size causing the local disturbance to benthic community. The soil excavation for breakwater toe stability will take out all seabeds benthic in the area of 198,000m2 and pilling activities for harbor construction will cause strong seabed disturbance in the area of 41,060 m2. These activities will burry and smother the benthic organisms, even though destroy bivalve species living in harbor area.



3.2.2 OPERATION PHASE 3.2.2.1 Operation of Onshore Facilities (the Plant and support facilities) 3.2.2.1.1 Air environment 1. Emission from stacks and flares Project activities Air quality is affected by various sources of emission such as stacks, incinerator, flare, tanks, etc. Potential impacts The emissions from these sources are considered by conducting dispersion modeling for prediction of impacts on air quality. The following are the sources considered for dispersion modeling:

Process heaters (CDU, HMU, RFCC, GOHDS, KHDS, N&AC, SRU); RFCC Boilers; Boiler emission gas treatment system; Gas turbines; ETP Incinerator; Flares.

To satisfy national standards and IFC requirements for stationary point source, FEED consultant has considered optimum stack height, flare height and emission rate of each pollutant as follows:

Optimum stack height was determined using GIIP, HMIP D1 Method and BREEZE AIR SCREEN3 developed by the United States Environmental Protection Agency (USEPA). The stack height selected is in compliance with the ambient air quality standard in isolation from other emission sources in the area.

Air emissions from refinery stacks (Process heaters) are in compliance with Vietnamese standards and IFC EHS Guidelines for "Petroleum Refining". Air emissions from the stacks located in the Aromatic section of Naphtha and Aromatic Complex are compliance with Vietnamese standards and IFC EHS Guidelines for "Large Volume Petroleum Based Organic Chemicals Manufacturing". Boiler and GT stack emissions are in compliance with to Vietnamese standards and IFC EHS Guidelines for "Thermal Power Plants".

In order to meet projects point source emission limits, all gases from RFCC boiler and emission gas treatment system are routed to DeSOx and DeNOx system before discharged into the atmosphere. Low and ultra-low NOx burners are recommended for heaters of process units, utilities and waste incinerator. Therefore, input data of emission rate used for dispersion model are accounted for applying mitigation measures.

At “in start-up and shut-down” periods, emission from stack does not meet the project standard, however it happens in short time so the effect on ambient air quality is negligible. Therefore, “in start-up and shut-down” case is not put into consideration of air emission modeling.



To assess air quality, the Atmospheric Dispersion Modeling System (ADMS) from CERC (Cambridge Environmental Research Consultants) with the United Kingdom Meteorological Office, National Power plc and University of Surrey is used. The first version of ADMS was released in 1993 and the current model is ADMS version 4. Principle of ADMS may be summarized as follows: The air dispersion modeling was carried out using ADMS 4, a “new generation” Gaussian plume air

dispersion model capable of modeling dispersion in the atmosphere of passive, buoyant or slightly dense, continuous or finite duration releases from single or multiple sources.

ADMS uses the atmospheric boundary layer and the reciprocal of the Monin-Obukhov length to

characterise the atmosphere. The boundary layer is defined by measurable physical parameters obtained from meteorological data, which allows for a more realistic representation of the changing characteristics of dispersion with height and time. This results in a more soundly based prediction of the concentration of pollutants than previous generation dispersion models.

The model takes into account emissions from the source, location of nearby buildings, topography

and meteorological data for the local area. The model will then provide a predicted concentration of the substance of interest at a specified point. The process is re-iterated for a large number of meteorological conditions and at a large number of receptor points to build up a prediction of the long-term mean and short-term peak concentrations over the area of interest.

ADMS 4 is a new version of Gauss atmospheric dispersion model with two parameters used to

define characteristic of atmospheric boundary layer as follows:

- The boundary layer depth, and - The Monin-Obukhov length.

Rather than in terms of the single parameter Pasquill-Gifford class. Dispersion under convective meteorological conditions uses a skewed Gaussian concentration distribution (shown by validation studies to be a better representation than a symmetrical Gaussian expression). The ADMS4 is used in many countries in European, Asia, Australia, North America and the Middle East. For the NSRP, ADMS is computed for the maximum ground level concentrations of NOx, SO2, CO and PM10. These emission results will be added with baseline data of each pollutant before assessing the compliance to project standards. To verify the compliance with the ambient air quality standards from stacks and flares, a full-scale air dispersion modeling is studied as follows:

Emission from 19 stacks and combined case for all stacks are considered in the operation case; and 1 HC flare in normal operation;

Emission from HC flare and HC purge flare in the emergency case;



The emission from each source and combined sources are modeled and the concentrations from combined sources at specific distances are added together to topography and contour maps to obtain the overall ground level concentrations. The ADMS Model requires hourly meteorological data for calculating the ground level concentration of pollutants. The hourly meteorological input data within three years (2005-2007) from Tinh Gia Meteorological Station is used for the modeling. This is a National Meteorological Station located at 19.5oN; 105.8oE which is about 15.65km far from the Nghi Son Refinery Plant toward to North and Northeast direction. The complex elevation and impact of all mountains terrain in the radius of 7.5 km for air dispersion is considered and applied by the Grid dimension 500m x500m as Figure 3.5. All topography data for computed area with the 7.5km radius are made as input file of the ADMS model.

Figure 3-5 Terrain condition of NSRP in ADMS model Summary of emission input and output results for point sources system are given in Table 3.18 and Table 3.19.



Table 3.18 Input data of ADMS model in normal operation case For NSRP Stack # 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20

Stack name

SRU Common

stack

FGD Stacks for

Boiler

RFCC Co Boiler

Gas Turbine HRSG-1

Gas Turbine HRSG-2 HMU CDU Stack ETP

Incinerator RHDS-1 RHDS-2 NAC-1 Common NAC-2 NAC-3 NAC-4 NAC-5 NAC-6 KHDS-1 KHDS-2 GOHDS HC Purge

Flare DESCRIPTION OF POINT SOURCE

Ref. # X 601 DeNox 50 H-101 110 A-001 110 A-002 010-SK-001 190-A-215 20-H-101 20-H-201 42-H-101-4 49H101 44H-201A/B 47H101 46H-101 40-H-101 H-001 H-002 H-01

East 580180 580082 580459 580045 580045 580358 580604 580930 580052 580110 581035 580770 581058 580784 580819 580967 580544 580523 580554 581729 Coordinates of point source as VN2000 North 2141315 2140371 2140822 2140610 2140625 2140782 2141323 2141050 2141142 2141154 2140748 2140822 2140630 2140775 2140580 2140846 2141116 2141112 2141222 2140824

Fuel used Title/type Fuel gas HSFO HSFO Diesel/LPG Diesel/LPG Fuel Gas Fuel Oil Fuel Gas Fuel Gas Fuel Gas Fuel Gas Fuel Gas Fuel Gas Fuel Gas Fuel Gas Fuel Gas Fuel Gas Fuel Gas Fuel Gas

Sulphur in % 0,0058 0,909 0,909 0,04 0,04 0,0058 0,24 0,0058 0,0058 0,0058 0,0058 0,0058 0,0058 0,0058 0,0058 0,0058 0,0058 0,0058 0,0058

Quantity in Kg/Sec 0,635 18,145 1,061 0,533+0,

08 0,533+0,08 5,689 1,881 0,07 0,417 0,417 3,219 1,059 4,073 0,419 0,587 0,354 0,118 0,15 0,338

HHV Mj/Kg 44,12 39,571 39,571 43 /

46,28 43 / 46,28 44,12 43,053 44,12 44,12 44,12 44,12 44,12 44,12 44,12 44,12 44,12 44,12 44,12 44,12

Fuel Details

Heat input in MW 28 718 42 155 155 251 81 3 18,4 18,4 142 45,6 179,7 18,5 25,9 15,6 5,2 6,6 14,9 Dry standard

flow NM3/sec 32,57 262,00 133,00 193,00 193,00 69,18 22,28 0,83 5,07 5,07 39,14 12,54 49,53 5,10 7,14 4,30 1,43 1,82 4,11 Actual flow m3/sec 73,00 329,00 176,00 339,00 339,00 125,00 38,00 2,00 11,00 11,00 74,00 22,00 90,00 10,00 13,00 8,00 3,00 4,00 9,00

Exit Vel. m/sec 7 15 7 15 15 7 7 7 7 7 7 7 7 7 7 7 7 7 7 12,7 Temp. in 'K 571 343 338 460 460 423 423 530 500 500 440 440 423 440 440 440 500 500 500 322

Flue gas Details

Oxygen in % 3 3 3 15 15 3 3 3 3 3 3 3 3 3 3 3 3 3 3 Diameter in m. 3,6 5,3 5,7 5,4 5,4 4,8 2,6 0,6 1,4 1,4 3,7 2,0 4,0 1,3 1,5 1,2 0,7 0,9 1,3 0,58 Stack

details Recomm. Height

in m. 50,00 100,00 100,00 65,00 65,00 45,00 50,00 30,00 50,00 50,00 50,00 50,00 50,00 30,00 30,00 30,00 30,00 30,00 30,00 180 mg/NM3 50,00 50,00 50,00 50,00 50,00 50,00 50,00 50,00 50,00 50,00 20,00 20,00 20,00 20,00 20,00 20,00 50,00 50,00 50,00 PM gm/ sec 1,629 13,100 6,650 9,650 9,650 3,459 1,114 0,041 0,254 0,254 0,783 0,251 0,991 0,102 0,143 0,086 0,072 0,091 0,205 1,00 mg/NM3 120,00 65,00 400,00 20,00 20,00 20,00 400,00 20,00 20,00 20,00 20,00 20,00 20,00 20,00 20,00 20,00 20,00 20,00 20,00 SO2 gm/ sec 3,908 17,030 53,200 3,860 3,860 1,384 8,910 0,017 0,101 0,101 0,783 0,251 0,991 0,102 0,143 0,086 0,029 0,036 0,082 0 mg/NM3 167,00 50,00 300,00 152,00 152,00 60,00 450,00 167,00 167,00 167,00 124,00 171,00 171,00 124,00 124,00 171,00 167,00 167,00 167,00 NOx gm/ sec 5,439 13,100 40 29,336 29,336 4,151 10,024 0,138 0,847 0,847 4,853 2,144 8,469 0,632 0,885 0,735 0,239 0,304 0,686 3,00 mg/NM3 150,00 150,00 800,00 150,00 150,00 150,00 150,00 150,00 150,00 150,00 150,00 150,00 150,00 150,00 150,00 150,00 150,00 150,00 150,00

Emission Data

Co gm/ sec 4,886 39,300 106,400 28,950 28,950 10,377 3,341 0,124 0,761 0,761 5,871 1,881 7,430 0,765 1,071 0,645 0,215 0,273 0,616 14,000

Emissions Control Measures

[1] Low Nox Burners [2] Stack height = 50m

[1] FGD System [2]DeNOx System [3] Stack height = 100m

[1] FGD and DeNOx [2] Stack height = 100m


[1] Ultra -Low Nox Burners [2] Stack height = 45m














[1] Stack height = 180m

Source: Document provided by FWL, June 2010.



The stack height stated above are based on emission levels estimated and modeled during the FEED stage of the Refinery Project. These values shall be re-assessed with the emission information from the Vendor and the revised height shall ensure the compliance to the Vietnamese and IFC Guideline requirements. Final stacks height will be determined using updated input data during EPC phase.

Table 3.19 Emission input data of flare system in emergency case

Location (VN2000)

Emission rate

Source name

Northing Easting Case

Total flue gas flow rate

(Nm3/s)

Velocity (m/s)

Exit Temp. (oK)

Heat Releases (BTU/hr) SO2

g/s NOx g/s

CO g/s

PM10

g/s

GPF OF ISLAND 1 1,064 79 575 44,865,206,523 - 344 1,871 47 HC

FLARE 2140834 581727 GPF OF ISLAND

2 3,774 178 377 47,324,135,403 - 368 2,005 104

GPF OF ISLAND 1 231 154 520 5,780,168,548 20,624 50 269 12

GPF OF ISLAND 2 397 154 377 4,497,203,156 4,196 39 210 12

HC PURGE FLARE

2140824 581729

MAX H2S Release 56.84 38 333 566,919,714 18,225 4.85 26.41 2.78

Source: FWL, November 2009 Impacts from point source emission in normal operation Emission results of NOx, SO2, CO and PM from individual stack and combined all stacks in the case of normal operation are given in Table 3-20.



Table 3-20 Maximum ground level concentrations of air pollutants from point sources in normal operation

Emission Results of SO2

1 hour Maximum Ground Level


Annual Maximum Ground Level

Point source Source ID Conc.

(µg/m3)

Conc.+ baseline (µg/m3)

Distance (m)

Conc. (µg/m3)


Distance (m)

Conc. (µg/m3)


Distance (m)

SRU S1 8.66 15.66 697 2.32 9.32 664 0.17 7.17 640 FGD S2 16.88 23.88 1,945 3.60 10.6 2,640 0.26 7.26 2,110

RFCC S3 86.32 93.32 1,309 23.95 30.95 1,512 1.73 8.73 1,010 GT1 S4 2.07 9.07 915 0.38 7.38 1,592 0.03 7.03 4,089 GT2 S5 2.08 9.08 930 0.38 7.38 1,605 0.03 7.03 3,709 HMU S6 3.33 10.33 515 1.04 8.04 482 0.06 7.06 512 CDU S7 55.14 62.14 590 10.81 17.81 389 1.16 8.16 465 ETP S8 0.83 7.83 446 0.17 7.17 446 0.02 7.02 563

RHDS1 S9 1.22 8.22 545 0.35 7.35 328 0.03 7.03 473 RHDS2 S10 1.25 8.25 499 0.31 7.31 272 0.02 7.02 479

NAC-1 42-H-101 S11 2.35 9.35 683 0.66 7.66 654 0.05 7.05 686 NAC-2 49-H-101 S12 2.03 9.03 217 0.45 7.45 331 0.05 7.05 391 NAC-3 44-H-201 S13 2.28 9.28 116 0.84 7.84 541 0.06 7.06 573 NAC-4 47-H-101 S14 2.09 9.09 458 0.62 7.62 387 0.06 7.06 477 NAC-5 46-H-101 S15 2.37 9.37 434 0.82 7.82 352 0.07 7.07 453 NAC-6 40-H-101 S16 2.15 9.15 387 0.60 7.6 387 0.06 7.06 535

KHDS1 S17 1.20 8.2 460 0.27 7.27 460 0.03 7.03 467 KHDS2 S18 1.16 8.16 477 0.25 7.25 477 0.03 7.03 320 GOHDS S19 1.45 8.45 404 0.37 7.37 404 0.04 7.04 392 HC Flare F1 0.00 7 - 0.00 7 - 0.00 7 -

Combined source (*) All 118.41 125.41 7,264 34.21 41.21 1648 2.76 9.76 908 Project Standard 350 125 50

Notes: - Baseline of SO2: 7µg/m3 - (*) combined source is the highest concentration in year of 2005, 2006 and 2007.



Emission Results of NOx



Annual Maximum Ground Level


(µg/m3)


Distance (m)

Conc. (µg/m3)


Distance (m)

Conc. (µg/m3)


Distance (m)

SRU S1 12.05 21.05 697 3.22 12.22 664 0.23 9.23 641 FGD S2 12.99 21.99 1,945 2.77 11.77 2,641 0.20 9.2 2,111

RFCC S3 64.90 73.9 1,309 18.01 27.01 1,512 1.30 10.3 1,010 GT1 S4 15.72 24.72 915 2.89 11.89 1,592 0.21 9.21 4,088 GT2 S5 15.83 24.83 930 2.88 11.88 1,605 0.20 9.2 3,709 HMU S6 10.00 19 515 3.12 12.12 482 0.18 9.18 512 CDU S7 62.03 71.03 590 12.16 21.16 389 1.30 10.3 465 ETP S8 6.77 15.77 446 1.38 10.38 266 0.62 9.62 563

RHDS1 S9 10.26 19.26 545 2.90 11.9 328 0.21 9.21 473 RHDS2 S10 10.48 19.48 499 2.58 11.58 272 0.21 9.21 479

NAC-1 42-H-101 S11 14.56 23.56 683 4.11 13.11 654 0.32 9.32 686 NAC-2 49-H-101 S12 17.34 26.34 217 3.88 12.88 331 0.40 9.4 391 NAC-3 44-H-201 S13 24.16 33.16 116 7.14 16.14 541 0.50 9.5 573 NAC-4 47-H-101 S14 12.92 21.92 458 3.82 12.82 387 0.40 9.4 474 NAC-5 46-H-101 S15 14.69 23.69 434 5.06 14.06 352 0.46 9.46 453 NAC-6 40-H-101 S16 18.35 27.35 387 5.12 14.12 387 0.52 9.52 535

KHDS1 S17 9.89 18.89 460 2.23 11.23 460 0.25 9.25 467 KHDS2 S18 9.80 18.8 477 2.13 11.13 477 0.23 9.23 320 GOHDS S19 12.17 21.17 404 3.11 12.11 404 0.37 9.37 392 HC Flare F1 17.39 26.39 1541 4.79 13.79 398 0.25 9.25 1,691

Combined source (*) All 175.11 184.11 7264 41.32 50.32 1415 4.55 13.55 931 Project Standard 200 100 40

Notes: - Baseline of NO2: 9µg/m3 - (*) combined source is the highest concentration in year of 2005, 2006 and 2007



Emission Results of CO





(µg/m3)


Distance (m)

Conc. (µg/m3)


Distance (m)

Conc. (µg/m3)


Distance (m)

SRU S1 10.82 3,010.82 697 7.91 3,007.91 635 2.89 3,002.89 664 FGD S2 38.96 3,038.96 1,945 22.84 3,022.84 2,619 8.30 3,008.3 2,641

RFCC S3 172.63 3,172.63 1,309 120.72 3,120.72 789 47.90 3,047.90 1,512 GT1 S4 15.52 3,015.52 915 8.16 3,008.16 2,902 2.85 3,002.85 1,592 GT2 S5 15.62 3,015.62 930 8.17 3,008.17 2,917 2.84 3,002.84 1,605 HMU S6 25.00 3,025 515 18.21 3,018.21 84 7.80 3,007.8 423 CDU S7 20.68 3,020.68 590 13.05 3,013.05 138 4.05 3,004.05 389 ETP S8 6.08 3,006.08 446 4.27 3,004.27 423 1.24 3,001.24 266

RHDS1 S9 9.22 3,009.22 545 6.75 3,006.75 376 2.61 3,002.61 328 RHDS2 S10 9.41 3,009.41 499 6.99 3,006.99 343 2.32 3,002.32 272

NAC-1 42-H-101 S11 17.62 3,017.62 683 13.34 3,013.34 98 4.97 3,004.97 654 NAC-2 49-H-101 S12 15.22 3,015.22 217 11.48 3,011.48 217 3.40 3,003.4 331 NAC-3 44-H-201 S13 21.20 3,021.2 116 15.34 3,015.34 169 6.27 3,006.27 541 NAC-4 47-H-101 S14 15.64 3,015.64 458 11.75 3,011.75 458 4.62 3,004.62 387 NAC-5 46-H-101 S15 17.78 3,017.78 434 15.25 3,015.25 434 6.12 3,006.12 352 NAC-6 40-H-101 S16 16.10 3,016.1 387 11.75 3,011.75 387 4.49 3,004.49 387

KHDS1 S17 8.90 3,008.9 460 6.25 3,006.25 460 2.01 3,002.01 460 KHDS2 S18 8.80 3,008.8 477 6.14 3,006.14 217 1.91 3,001.91 477 GOHDS S19 10.93 3,010.93 404 8.62 3,008.62 222 2.79 3,002.79 404 HC Flare F1 81.15 3,081.15 1,541 52.85 3,052.85 1,147 22.35 3,022.35 398

Combined source (*) All 295.28 3,295.28 7,264 182.81 3,182.81 1,102 73.68 3,073.68 1,648 Project Standard 30,000 10,000 5,000

Notes: - Baseline of CO: 3,000 µg/m3 - (*) combined source is the highest concentration in year of 2005, 2006 and 2007.



Emission Results of PM10


Annual Maximum Ground Level Point source Source ID

Conc. (µg/m3)


Distance (m)

Conc. (µg/m3)


Distance (m)

SRU S1 0.97 23.97 664 0.07 23.07 641 FGD S2 2.77 25.77 2,641 0.20 23.2 2,111

RFCC S3 2.99 25.99 1,512 0.22 23.22 1,010 GT1 S4 0.95 23.95 1,592 0.07 23.07 4,088 GT2 S5 0.95 23.95 1,605 0.07 23.07 3,709 HMU S6 2.60 25.6 482 0.15 23.15 512 CDU S7 1.35 24.35 389 0.14 23.14 465 ETP S8 0.41 23.41 266 0.05 23.05 563

RHDS1 S9 0.87 23.87 328 0.06 23.06 473 RHDS2 S10 0.77 23.77 272 0.06 23.06 479

NAC-1 42-H-101 S11 0.66 23.66 654 0.05 23.05 686 NAC-2 49-H-101 S12 0.45 23.45 331 0.05 23.05 391 NAC-3 44-H-201 S13 0.84 23.84 541 0.06 23.06 573 NAC-4 47-H-101 S14 0.62 23.62 387 0.06 23.06 474 NAC-5 46-H-101 S15 0.82 23.82 352 0.07 23.07 453 NAC-6 40-H-101 S16 0.60 23.6 387 0.06 23.06 535

KHDS1 S17 0.67 23.67 460 0.08 23.08 467 KHDS2 S18 0.64 23.64 467 0.07 23.07 320 GOHDS S19 0.93 23.93 404 0.11 23.11 392

HC Purge Flare F1 1.60 24.60 398 0.08 23.08 1,691 Combined source (*) All 9.68 32.68 1,898 0.98 23.98 2,334

Project Standard 150 50 Notes: - Baseline of PM10: 23 µg/m3 - (*) combined source is the highest concentration in year of 2005, 2006 and 2007.



The results in Table 3.20 show that:

The higher concentrations from the above modeling calculation are combined with the baseline concentrations of these pollutants (7µg/m3 of SOx; 9µg/m3 of NOx; 3,000µg/m3 of CO and 23 µg/m3 of PM) to estimate the maximum ground level concentration of the pollutants.

With having FGD and Desulphurisation system, the SOx emission results in 01-hour, 24-hour

and annual of individual stacks are much lower than project standards (PS) of 350 µg/m3 in 1-hour, 125 µg/m3 in 24-hour and 50 µg/m3 in annual from 4 to 45 times. In combined case, SOx emission is 3 - 5 times lower than project standards in both 1-hour, 24-hour and annual. The maximum ground concentration of Sox is in the range of 908 - 7,264 m (Appendix IV, Figure IV.1 to Figure IV.6). In normal operation, there is no emission of SO2 through HC purge flare.

With having Low and ultra-low NOx burners, NOx emission results in 1-hour, 24-hour and

annual of all individual stacks are lower than Project Standards from 2.7 to 12.7 times. NOx generated for 1-hour, 24-hour and year of HC flare are lower than Project Standards from 4.3 to 7.6 times. In combined case of 19 stacks and 1 HC Flare, NOx emission results in 1-hour, 24-hour and annual are lower than Project standards from 1.1 to 3 times. Maximum ground concentration of NOx in 1-hour (184.11ug/m3) is not much lower than allowable limit (200ug/m3). Maximum ground concentration point of NOx locates in range of 931 – 7,264m from the stack base (Appendix IV, Figure IV.7 to IV.12)

CO emission results in 1-hour, 8-hour and 24-hour of individual stacks are lower than Project

Standard from 1.6 to 10 times. CO emission in combined all stacks and HC purge flare are well within project standards and lower than the project standards from 1.6 to 9 times. The maximum ground concentration of CO is in the range of 1,102 - 7,264m (Appendix IV, Figure IV.13 to IV.18).

PM10 emission results in 24-hour and annual of individual stacks in normal operation are lower

than Project Standard from 2.2 to 6.4 times. In combined case for all stacks and HC flare, the maximum ground concentration of PM10 is lower than the project standards from 1.5 t0 4.6 times. The maximum ground contents are in the range of 1,898 - 2,334m (Appendix IV, Figure IV.19 to IV.22).

In briefly, the maximum ground concentrations of SO2, NOx, CO and PM10 accounted for

individual stack and 1 flare as well as combined case of all stacks and flare are very low and well within the applicable of National Technical Regulation QCVN 05:2009 and World Bank/IFC standards. In normal operation, HC purge flare is working for maintaining purpose. Therefore, there is no emission of SO2 and emission results of NOx, CO and PM are negligible.

Generally, the maximum ground concentrations from individual stacks SRU, CDU, ETP,

RHDS1, RHDS2, NACs, KHDS1, KHDS2 and GOHDS are within plant boundary in the range of 84 - 680 m from the stack basement. The maximum ground concentrations of FGD, RFCC, GT1, GT2 stacks and HC purge flare stacks are in the range of 900 to 4,088m in the downwind



direction of the stacks site. The sites having maximum ground concentrations are fell mostly within the confine of the refinery site of Coc Mountain and some mountain nearby as Chuot Chu, Tran and Xuoc Mountain which are away from the residential areas. Therefore, impact level from point sources in the normal operation is assessed as minor to air quality.

The emission concentrations results stated above are based on primary stack height, emission

levels estimated and modeled during the FEED stage of the Project. These values shall be reassessed with the emission information from the Vendor and the revised height shall ensure the compliance to the Vietnamese and IFC Guideline requirements.

Impacts from point source emission in emergency case

Table 3-21 Maximum ground concentrations of air pollutants

from flares in emergency case

Case

1 hour - SOx Maximum Ground

Level (ppm)

1 hour - NOx Maximum Ground

Level (ppm)

1 hour - CO Maximum Ground

Level (ppm)

HC Purge gas flare GPF island 1 14.28 0.035 0.186 HC flare GPF island 1 0 0.074 0.405 HC Purge gas flare GPF island 2 2.91 0.027 0.145 HC Purge gas flare max H2S 29.03 0.008 0.042

ERPG (1,2,3)* 0.3 3 15 1 15 30 200 350 500 Note: ERPG (1,2,3)*: ERPG1, ERPG2, ERPG3 The modeling results from Table 3-21 show that:

In emergency cases, the maximum ground concentrations of 1-hour NOx and 1-hour CO are much lower than the Emergency Response Planning Guideline 1 (ERPG1) value (Appendix IV, Figure IV-23 & Figure IV-30). It means that no adverse health effects to individuals.

Under emergency conditions, SOx emission is only occurred at HC Flare. The maximum

ground concentrations of SOx from GPF of island 1 is within the Emergency Response Planning Guideline 3 (ERPG3) values (15ppm) and maximum ground level concentrations of SOx from GPF of island 2 is within the ERPG2 (3ppm). But emission results of SOx in the Max H2S case are unaccepted with two times higher than ERPG3 (Appendix IV, Figure IV-31 & Figure IV-32).

In emergency cases, radiation intensity at sterile radius: 6.31 kw/m2 (API recommendation). A

minimum sterile radius of at least 60 m shall be required to avoid injury to personnel due to the possible emission of burning liquid droplets. Radiation intensity at property boundary 3.18 kW/m2.

In practice, the maximum flaring time in the case of max H2S is happened in very short time. But health effects might occur to project employees and communities nearby.



Impacts of VOC from tank system Fugitive emissions of volatile organic compounds (VOC) from the Complex have been estimated from hydrocarbon loss. The estimated quantities of fugitive emissions are based on storage volumes from tank system.

VOC emissions from tank farms are controlled due to inherent design features, e.g., installing floating roof tanks, vapor recovery systems, nitrogen blanketing, etc. Considering all the above measures, the facility wide VOC emissions are very small. Total VOC loss is approximately 141 tons/year (see Table 3.7), compared with 9,6 million tons of crude oil/year. The ratio of VOC tons and crude oil million tons is 14.69 compared with the Benchmark of IFC Guideline on Petroleum refinery from 120 to 300. The VOC emission will be well within acceptable limits. And therefore, the impacts level is considered as minor. Impacts of green house gas (GHG) The Complex is designed to use energy efficiently by using energy saving technology such as energy optimum method in CDU, energy recovery in preliminary heaters to reuse heat from emission gas, saving energy between units and using energy saving devices. A heat exchange network is designed to optimize recovered heat, reduce operation cost and increase operational ability of process units. Input temperature of the CDU heater is at maximum value due to taking advantage of heat from stacks and it achieves target of heat sources efficient using. The operation of process units will generate a significant amount of CO2 into the environment that will contribute green house effects.

Total volume of CO2 generated from the Complex operation is about 5.9 million tons/year. However, in comparison with statistical data of green house gas in the United States (1990-2007), total CO2 generated from burning of fossil fuels in 2007 was about 5.7x1012 tons, so CO2 emission level of the Project is insignificant in comparison of the ones of the global. 2. Noise and vibration Project activities Process equipment such as compressors, pumps, heaters, blowers, flare, boilers, turbines, etc. will be major noise sources during the operation phase. The truck loading will also be a generation of noise at plant site as well as along their route to the Complex. Potential impacts As mentioned in Section 1, project noise level standards are based on the most stringent limits from local Vietnamese and IFC guidelines. So the noise generated by the equipment shall not exceed the noise limits for any of the conditions of operation, including turndown, start-up, shut-down and commissioning of the equipment. The equipment must comply with the most restrictive of the specified work area or sound power level criteria. Sound pressure level limits apply at 1m from the process equipment surface and at 3m from vent or on nearest platform (Table 3.22).



Table 3.22 Noise Level in the Operation Phase

Noise Source Work Area Code Noise Limit dB(A) Centrifugal compressors G1 85 Centrifugal and axial R1 95 Fired heaters and boilers G1 85 Gas turbines G1 85 Air cooled exchangers G1 85 Cooling tower G1 85 Pumps, gears, G2 82 Blowers, agitators/mixers G1 85 Equipment fitted with acoustic enclosure R2 110 Operating vents G1 85 Emergency vents R2 110 Valves and piping components G2 82 Other noise sources located outdoors G2 82 Noise sources located inside process G3 79

Flare G1 85 Source: FWL, October 2009 Based on Table 3.22, the noise generated equipments at the Refinery will be kept at value of 85 dB(A). Equipment fitted with Acoustic Enclosure and Emergency Vents will be at 110 dB(A). The flare will be at 85 dB(A) during emergency operations, but start up noise will be less than 85 dB(A). Therefore, the noise generating from machines, equipment and process units will be limited inside the plant boundary and cause directly to project workers only. The impact level is considered as minor and long term. NSRP LLC is defined the design Noise level standard for construction to meet relevant standards during operation. Detail assessment will be carried out during detail design phase. However, during detail engineering, EPC Contractor will carry out the assessment to make sure that noise levels meet Project Standard. 3.2.2.1.2 Water Quality Impact of continuous water intake Project activities The Refinery and Petrochemical Complex will require continuous supply of large volume of sea water (Max 42.8 m3/s) for cooling purpose. Potential impact The automatic filters between 2 and 3 times per day will generate high suspended materials in the released water. In the case of discharging water from the backwash cycle into the outfall sump, it will cause the exceeding (>30mg/l as PS) of suspended solid content at the outfall site. The maintenance dredging of the intake channel may affect to coastal water quality within the four week plant maintenance cycle. However, this activity is small in comparison with the dredging activities for harbor area and the impact level is minor and limited locally in intake channel only.



Optimum effluent outfall and thermal impacts Project activities Project operation will need to discharge a maximum condition at 154,000m3/h to Nghi Son coastal water including cooling water, treated industrial and sanitary effluent, FGD effluent and RO effluent with and maximum temperature of 40oC. Potential impacts In order to estimate the thermal impact caused by effluent discharge, NSRP LLC has used the CORMIX model to predict dilution and thermal dispersion abilities of cooling water [11]. Summary of principle of the CORMIX model is as follows:

CORMIX is a USEPA-supported mixing zone model and decision support system for environmental impact assessment of regulatory mixing zones resulting from continuous point source discharges. The system emphasizes the role of boundary interaction to predict steady-state mixing behavior and plume geometry.

The CORMIX methodology contains systems to model single-port, multiport diffuser discharges

and surface discharge sources. Effluents considered may be conservative, non-conservative, heated, brine discharges or contain suspended sediments.

CORMIX can predict mixing behavior from diverse discharge types ranging from power plant

cooling waters, desalinization facility or drilling rig brines, municipal wastewater, or thermal atmospheric plumes. CORMIX can also be applied across a broad range of ambient conditions ranging from estuaries, deep oceans, swift shallow rivers, to density stratified reservoirs and lakes.

Some special hydrodynamic features of CORMIX include:

Makes complete near-field and far-field plume trajectory, shape, concentration, and dilution predictions and visualizations.

Includes plume boundary interactions, including dynamic near-field attachments.

Models conservative, non-conservative, and heated pollutant types.

Alerts user when plume encounters regulatory mixing zone constraints, including Toxic Dilution Zone CMC and CCC values.

Application to steady, unsteady ambient currents/tides, or stagnant ambient conditions. In order to select optimum effluent outfall location and assess thermal effects to Nghi Son Bay seawater, US Environment Protection Agency’s CORMIX model has been used by NSRP LLC to determine near-field initial dilution and the number and spacing of the discharge ports. It also describes the modeling of the thermal plume in the far-field zone to determine the outfall length required to meet the environmental and process criteria. Input data for thermal modeling are given in Table 3.23.

http://www.epa.gov/�

http://www.cormix.info/integral.php�

http://www.cormix.info/picgal/rmixingz.php#rmz�

http://www.cormix.info/picgal/tbjet.php�

http://www.cormix.info/picgal/tbjet.php�

http://www.cormix.info/picgal/boundary.php�

http://www.cormix.info/picgal/ccsystem.php�

http://www.cormix.info/methodology.php�

http://www.cormix.info/CORMIX1.php�



http://www.cormix.info/cormix-gts.php�

http://www.cormix.info/picgal/coolingwaters.php�

http://www.cormix.info/picgal/brine.php�

http://www.cormix.info/picgal/mwastew.php�

http://www.cormix.info/picgal/atmospheric.php�

http://www.cormix.info/picgal/estuaries.php�

http://www.cormix.info/picgal/oceans.php�

http://www.cormix.info/picgal/rivers.php�

http://www.cormix.info/ambdensityprofiles.php�

http://www.cormix.info/picgal/lakes.php�

http://www.cormix.info/picgal/nearfield.php�

http://www.cormix.info/picgal/farfield.php�

http://www.cormix.info/picgal/documentation.php#pr�

http://www.cormix.info/picgal/visualizations.php�

http://www.cormix.info/picgal/boundary.php�

http://www.cormix.info/picgal/nearfield.php�

http://www.cormix.info/picgal/attachments.php�

http://www.cormix.info/glossary.php#C�

http://www.cormix.info/glossary.php#N�

http://www.cormix.info/picgal/coolingwaters.php�

http://www.cormix.info/picgal/rmixingz.php#rmz�

http://www.cormix.info/picgal/rmixingz.php#tdz�

http://www.cormix.info/picgal/rmixingz.php#tdz�

http://www.cormix.info/picgal/rmixingz.php#cmcccc�

http://www.cormix.info/picgal/rmixingz.php#cmcccc�

http://www.cormix.info/picgal/steady.php�

http://www.cormix.info/picgal/unsteady.php�



Table 3.23 Input data for thermal modeling

Condition Value Rate of discharge to receiving waters 154,000 m3/h or 42.78 m3/s Distance of riser ports above seabed 1.0 m Orientation of discharge ports Horizontal Temperature of discharge water 40oC Salinity of discharge water 31 ppt Density of discharge water 1,015.02 kg/m3 Ambient current velocity 0.02 m/s Wind speed at sea surface 2.0 m/s Ambient water temperature 31oC Ambient water salinity 31 ppt Ambient water density 1,018.39 kg/m3

Source: FEED Document No. 9T7151/R082 provided by FWL, October 2009 Near-field modeling is used to obtain an estimate of the dilution of the effluent within the near-field mixing zone. The discharge layout combinations are considered for 9 cases (L1 – L9), number of pipes, number of risers, number of ports, velocity of nozzle at different water depth in the range of 4 - 6m (Table 3.24). The results of COMIX modeling are given in Table 3.25.

Table 3.24 Discharge layout combinations

Discharge layout

Number of pipes

Number of risers

Number of port (nozzles) on each riser

Interval between

risers

Velocity at nozzle (m/s)

L1 5 25 2 10 2.42 L2 5 25 2 20 2.42 L3 5 12 4 10 2.52 L4 5 12 4 20 2.52 L5 5 12 4 40 2.52 L6 3 25 2 10 4.04 L7 3 25 2 20 4.04 L8 3 12 4 40 4.20 L9 4 12 4 20 3.15

Source: FEED document No. 9T7151/R082 provided by FWL, October 2009



Table 3.25 Results of CORMIX Model Runs

Test Cases Initial local

Dilution

Initial local temperature excess (ºC)

Dilution at 100m

distance

Temperature excess at

100m distance (ºC)

“Overlapped” temperature

excess at 100m distance (ºC)

L 1 + AC 1 6.3 1.43 6.35 1.42 6.10 L 1 + AC 4 9.5 0.95 9.53 0.94 4.72 L 2 + AC 2 13.0 0.69 13.06 0.69 3.44 L 2 + AC 3 14.3 0.63 14.40 0.63 3.15 L 2 + AC 4 15.6 0.58 15.70 0.57 2.85 L 3 + AC 1 3.7 2.46 3.72 2.45 12.25 L 4 + AC 1 5.9 1.52 5.95 1.51 6.55 L 5 + AC 2 12.2 0.74 12.26 0.73 3.65 L 5 + AC 3 13.4 0.67 13.49 0.67 3.35 L 6 + AC 1 4.4 2.04 4.40 2.04 6.12 L 6 + AC 4 6.6 1.36 6.62 1.36 4.07 L 7 + AC 2 9.0 1.00 9.02 1.00 2.99 L 7 + AC 3 9.9 0.91 9.92 0.91 2.73 L 7 + AC 4 10.8 0.84 10.83 0.83 2.50 L 8 + AC 2 8.4 1.07 8.43 1.07 3.20 L 8 + AC 3 9.3 0.97 9.32 0.97 2.90 L 9 + AC 5 15.2 0.59 15.36 0.59 2.35

Source: FEED document provided by FW in October, 2009 Notes: AC1 to AC4: water depth at 4m; 5; 5.5m and 6m

L1 to L9: discharge layout with different pipe number, riser number, port number and different velocity at nozzle The results show that at water depth of 4m none of the 8 discharge layouts comply with the World Bank guidelines due to “Overlapped” temperature excess at 100m distance (ºC) is higher than 3oC. At a water depth of 5m, only layout 7 complies with the guideline. At water depth of 5.5m, both layouts 7 and 8 comply with the guideline and at a water depth of 6m Layout 9 complies with the guideline. The initial local dilution of layout 7, 8 and 9 at water depth more than 5m is rather good. Dilution of these layouts is in the range of 9.92 – 10.83 times at the distance of 100m. Therefore the following recommendations may be made:

The outfall should have a minimum of 3 diffuser pipes Each diffuser section should be 440m long with12 risers or 480m long for 25 risers The diffuser sections should be located in a minimum water depth of 5.5m

In order to assess the thermal plume caused by effluent discharge, CORMIX model for far-field effect is undertaken for satisfying two following criteria:

1. The temperature of the water at the edge of a scientifically defined mixing zone shall not exceed 3oC above the temperature of the ambient water; and

2. The temperature of the water at the intake shall be no more than 0.5oC above the ambient water temperature for 100% of the time.



The first criteria is required in order that the benthic flora and fauna are not adversely affected, whilst the second is a process requirement dictated by NSRP Consultant (Foster Wheeler Energy Ltd.) and effectively means that there shall be no recirculation of the warmer discharge water into the intake. The model is run for five outfall length scenarios (Table 3.26).

Table 3.26 Modeling Scenarios

VN-2000 Coordinates Model

scenario Outfall length

(km) Easting Northing Discharge flow (m3/s)

Temperature of discharge

(oC) 1 2.5 584778.958 2142821.628 42.8 40 2 3 585271.010 2142860.380 42.8 40 3 3 585271.010 2142860.380 42.8 37 4 4.5 586766.958 2143248.525 42.8 40 5 6 588608.056 2143631.635 42.8 40

From the discussion of the plume movement across a spring and neap tide, it is possible to see a pattern emerging. On spring tides the currents disperse the excess heat more effectively. On neap tides, due to the limited tidal range and therefore lower current velocities, there is a gradual build-up of excess heat in the sea water. This is then flushed, to a degree, by the spring tides that follow on. Figure 3.7 shows a graph of the time series of excess temperature against time. The scenarios examined are clearly identified. For the 2.5km (pink line) and 3km (green line) outfalls the pattern of peaks and troughs is similar. The peaks represent the neap tides where the excess temperatures are highest. The troughs represent the spring tides when the currents are fastest and the advection and dispersion is at its most effective. By inspection it can be seen that the peaks i.e. the excess temperatures on neap tides, are increasing over the first three cycles. This process also applies to the spring tides i.e. the troughs. This suggests that whilst the receiving waters are efficient at dispersing heat from the discharged cooling water for a short while after discharging starts, there is a gradual build-up of residual heat in the water. The same pattern is seen when the time series of the 4.5km (blue line) and 6km (orange line) outfalls are plotted. For the 6km option the thermal plume model has been run for approximately 2½ months model time. The increase in residual heat in the water is more gradual, but after 2½ months the curve is beginning to move down again. The more gradual shape of the excess temperature time series curve for the 6km outfall is believed to be as a result its location and distance offshore. Thus, whilst the depth of water and the distance play a part the degree of ‘flushing’ inshore induced by a flood spring tide is much weaker. A similar pattern is shown for the 4.5km outfall option; although it is evident that whilst the operational criteria is met for much of the time, excess temperature does eventually exceed the 0.5oC limit.



Figure 3.7 Time series plot of excess temperature at intake channel On the basis of the two months simulated data for the 6km outfall (without eddy diffusivity) a continuous distribution function (cdf) has been plotted. This shows that even against the relaxed process criteria, the excess temperature is at or below 0.1oC for approximately 33% of the time. Including eddy diffusivity for the 2.5km and 3km outfalls would not induce sufficient mixing to be of benefit. It is also unlikely that it would lower the residual build-up sufficiently to make a 4.5km outfall viable in terms of the process criteria. At 6km the model results show that the process criteria can be met, but that it is possible that a residual build-up of excess heat could occur. The recommendation therefore is that the discharge outfall should be further optimised to between 4.5km and 6km. In summary, some conclusions of the modeled results are as follows:

An outfall discharging 2.5km offshore does not meet either the environmental criteria or the process criteria, as the temperature of the receiving waters at the intake channel is in excess of the 3oC limit imposed by the World Bank IFC guidelines.

An outfall discharging 3km and 4.5km offshore meets the World Bank IFC guidelines, but does not meet the process requirements.

An outfall discharging 6km offshore meets both World Bank IFC guidelines and operational criteria. Notwithstanding this an examination of the temperature excess time series at the intake suggests that there is the potential for a long term build-up of residual heat in the sea water.

Therefore, on the basis of the model simulations, the 6km outfall is adopted for NSRP.

For the outfall discharging 6km offshore, the thermal dispersion result are summarized in Figure 3.8 and Figure 3.9 including:



At 6 hours before the spring tide high water, the plume traveling north but with the tail of the plume spread out to encompass the coral beds and sensitive fishing grounds at the Hon Me Archipelago. The temperature around the archipelago is between 0.2oC and 0.4oC above the ambient temperature (E1–Figure 3.8).

At 3 hours before high water the plume has moved further north and has almost cleared the Hon Me Archipelago (E3–Figure 3.8). At high water the tide is turning and the plume is shown moving south again on an ebb tide. The outer edge of the plume is skirting the edges of the archipelago, but the temperature excess is well within the allowable range of 3oC. The temperature at the intake channel is at or below the operational requirement.

At 3 hours after high water (E4–Figure 3.8) the ebb flow is well developed. The western edge of the plume is shown approaching the main breakwater roundhead but is not affected by it. At 6 hours after high water the plume passes between the Hon Me Archipelago and Nghi Son Island (E5–Figure 3.8). It does not reach the main breakwater.

On the flood cycle of the neap tide, the plume extends north and makes contact with the coastline and also extends south to surround the Hon Me Archipelago at the coastline. At the site of the discharge the excess temperatures rise as a result of the much lower tidal currents and weaker advection and dispersion. Where the plume makes contact with the coastline and the archipelago the temperature is well within the environmental requirements (E6-Figure 3.9).

As the tide moves towards the neap high water the shape of the plume changes but the excess temperatures around the islands and at the coastline to the north does not increase (E6 to E10 – Figure 3.9). Indeed through out the neap tidal cycle there is little movement at the edges of the plume; the main activity being near to the discharge where excess temperatures above 8oC are predicted. The different sea water temperature at the area around Hon me island is in the range of 0.6 – 0.8oC only, within allowable environmental limit of the IFC.

Briefly, the modeling of the thermal plume is undertaken for a worst case condition of 154,000 m3/h of cooling water discharge, 40oC of cooling water temperature at the outfall and 31oC of receiving temperature (sea water). The worst case conditions have been considered and conditions on site would likely be better than predicted. In practice, the discharged cooling water volume is less than the modeled value (68.3%) and it will be mixed together with 18.7% of other treated effluents before routing to the outfall. By above the serious consideration of dynamic current, outfall layout, outfall length scenarios and thermal plume effect, the thermal impact level of effluent discharge is considered as minor and long term.



Figure 3.8 Thermal Plume Plots Outfall 6km, Discharge 40°C – Spring Tide



Figure 3.9 Thermal plume plots outfall 6km, discharge 40°C – Neap tide



Impacts of continuous effluent discharge Project activities When project comes into operation phase, following effluents need to be discharged to the sea:

Treated ETP effluent for industrial and sanitary wastewater Treated FGD effluent for desulphurisation (De-SOx) Cooling sea water RO reject effluent

In the operation phase, drainage systems are built to collect separately different effluents generating from site-wide and process units including clean process water (CPW), clean storm water (CSW), accidentally oil contaminated wastewater (AOC), continually oil contaminated wastewater (COC) and sanitary wastewater. In addition, specific wastewater streams are collected in dedicated systems before passing to the ETP, including:

Dedicated collection of Benzene Contaminated Water (BCW) in a closed system to prevent atmospheric emission of benzene.

Dedicated collection of Spent Caustic Effluent for flow balancing and prevention of atmospheric H2S emissions.

Potential impact All above-mentioned wastewater drainage systems other than the CSW system and PCW system are routed to appropriate effluent treatment Plant (ETP). Clean storm water (CSW) shall be assumed to comply with the necessary standard for direct discharge to the sea via the North Trapezoidal Channel. The reject and regeneration streams from Demineralised water plant, after pH neutralisation, are considered clean for direct discharge via the seawater return line. Quality of the treated water will strictly comply with the Project standards presented in Introduction Section - Item 0.2.2.3. These project standards are considered based on Vietnamese standards and IFC EHS guideline values for petroleum refining facilities, large scale organic chemical manufacturing and petroleum based polymer manufacturing. The project standards are more stringent than the national technical regulation on industrial wastewater (QCVN 24:2009/BTNMT) for discharge of treated effluents to coastal water. After treated, effluent is routed to treat waste water storage basin. At here, waste water will be tested before blended with sea water to discharge. If not meeting the Standards, effluent will be routed back to storage tank and treated at oily waste water treatment system. The storage tank may contain maximum volume of fire water during 6 hours or waste water for 24 hours. As estimation, volume of this storage tank is 17,220m3. In the ETP, industrial and sanitary effluents will be pre-treated separately before routing to integrated treatment tank for further treatment (detail ETP will be mentioned in mitigation measures). In order to assess how effluents impact to receiving resource - seawater, the summary of water intake and outlet are presented in Table 3.27.



Table 3.27 Maximum water intake and outlet of NSRP in the operation phase

Parameters Peak ETP outlet

Peak RO/IX Reject/

Regent #

FGD outlet (max.

assumed)

Cooling water

Sea water intake

Water outlet

Minimum dilution at

outfall zone

(assuming 8 times)

Costal water

Standard QCVN10:

2008/BTNMT

Amount (m3/h) 600 564 23,000 105,200 128,200 129,364 -

Temp (deg.C) 40 Ambient

<40 40 40 30 40.00 31 30

pH 6 to 9 6 to 9 6 6.74 6.74 6.5 to 8.5

BOD 25 0 1 0.735 0.735 - -

COD 72 0 10 1.917 1.917 3.67 2 4

TSS 30 30 30 30 10.5 30.00 13 50

Cadmium 0.009 0 0.005 0.005 0.005 0.005 0.005 0.005

Hydrocarbon 4.5 0.5 0.0139 0.0139 0.0139 0.04 0.016 0.1 Chromium (total) 0.5 0.25 0.25 0.02 0.02 0.06 0.0249 -

Chromium (III) - 0 - - - - 0.1

Chromium (VI) 0.05 0 0.05 - - - 0.05

Copper 0.5 0.5 0.005 0.005 0.005 0.01 0.0055 0.5

Zinc 2 2 0.0136 0.0136 0.0136 0.03 0.0156 1

Iron 3 2.5 0.188 0.188 0.188 0.211 0.1906 0.1 Cyanide Total (Free) 0.1 0.1 - - - - -

Cyanide CN- 0.09 0.09 0.007 0.007 0.007 0.008 0.0071 0.005

Lead 0.1 0.05 0.0043 0.0043 0.0043 0.00 0.0044 0.02

Nickel 0.45 0.45 - - - - -

Mercury 0.009 0.005 0.001 0.001 0.001 0.00 0.0010 0.002

Vanadium 1 1 1 1 1 1.00 1.0000 -

Phenol 0.2 0 0.001 0.001 0.00100 0.002 0.0011 0.001

Benzene 0.05 0 0.001 0.001 0.001 0.00 0.0010 -

Benzopyrene 0.05 0 - - - - -

Vinyl chloride 0.05 0 - - - - -

Di chloroethane 1 0 - - - - -

AOH 0.3 0 - - - - -

Sulphide (S2-) 0.45 0.25 - - - - 0.01

T-Nitrogen 10 10 0.62 0.62 0.62 0.704 0.6294 -

NH4 9 9 0.038 0.038 0.038 0.119 0.0470 0.5

T-Phosphorus 2 2 0.0143 0.0143 0.0143 0.032 0.0163 -

Coliform 4,500 4,500 55 55 55 95 59 1000

DO - - 5.84 5.84 5.84 - >=4

F- 9 9 - - - - 1.5

As 0.09 0.09 - - - - 0.04

Mn 0.9 0.9 - - - - 0.1 AOH: Adsorbable Organic Halogens calculate "< values" as minimum analysis limit values Offshore (K number points) DO data is applied for Sea water DO '# Assuming peak flow - Normal flow shall be 313 m3/hr.



The results in Table 3.27 show that each waste water treatment properties (ETP and FGD) are satisfied with Industrial waste water discharge limit. The combined discharge mode has much advantage for both economic and environmental point of view. The most contribution is cooling water (81.32%) while ETP treated effluent is a minor (0.46%) which is diluted about 215 times before discharging at the outfall. For FGD treated effluent, its contribution is about 16.78% and be diluted about 5.62 times at the outfall. Consider COD loading from treated effluent (ETP and FGD) of NSRP (Table 3.28), total loading is rather small of 273.2 kg/h.

Table 3.28 Estimate COD loading from NSRP in operation phase

Effluent stream Flow rate

m3/h % Flow

COD level mg/l

COD loading kg/h

Maximum treated effluent from ETP 600 0.46 72 43.2 Maximum RO effluent 564 0.44 0 0 Maximum treated effluent from FGD 23,000 16.78 10 230 Cooling water 105,200 81.32 1.92 201,6

Total Treated effluent discharge 129,364 100 2 474.8

According to the document of FEED, most effluents of the Complex are treated at ETP and meet industrial waste water standard of the Project. Effluent from demineralization unit and desulphurization system are separately treated and meet industrial waste standard of the Project. Cooling water is considered as clean effluent and without treatment. Domestic wastewater at harbour area is treated to meet project standards for domestic wastewater. Then, these effluents are blended and discharged into the sea. This blending action make effluents from the Refinery have the same properties with receiving water source (the sea water). As mentioned in the report, effluent is discharged via several smaller diffuser pipes branching off the main discharge line above 1m on the seabed that point towards the surface. The diffuser pipes enhance the dispersion plume and outfall location is 6km far from the shoreline. Based on CORMIX Model Runs [Ref.11] effluent will be diluted at least 8 times at the 100m distance outfall zone. The calculation shows that almost pollutants (COD, TSS, Cd, Zn, Hg, NH4+, As, Coliform, etc.) from treated effluent meet coastal water standard QCVN 10:2008/BTNMT. Some pollutants as Oil, Iron, Cyanide and Phenol are slightly higher than the costal water standards (QCVN10:2008). The main reason is that their baseline concentrations of Nghi Son bay are really higher than the ones in the allowable limits of QCVN 10:2008/BTNMT. On the other hand, the above estimation is based on maximum discharging of ETP while normal operation of ETP is 350m3/h only. Therefore, the impact level of effluent discharge will not cause significant impact to coastal sea water quality. 3.2.2.1.3 Groundwater environment Project activities During the operation phase, water supplied for the Complex will routed from Nghi Son water supply plant, so the groundwater will not be affected. A significant amount of hazardous waste managed, stored and disposed or leaked will cause a potential risk of groundwater contamination.



Potential impact All hazardous materials, chemicals and waste materials will be contained in proper vessels /storage facilities with adequately designed containments to prevent any impact sources or spills on the land and subsequently to groundwater. Appropriate methods of handling and transportation will be established for hazardous materials and wastes. There will be no underground storage tanks at the facility and the material loading and unloading areas will be designed with proper enclosures on paved surfaces. In addition, the process effluents and sewage will be treated onsite at adequately designed ETP facilities to meet the regulatory requirements for recycling and disposal standards. Therefore, the potential for groundwater contamination is insignificant. The potential causes for groundwater contamination are the disposal of solid and hazardous wastes on land and accidental spillages of hazardous materials (oils, chemicals, paints, cleaning solvents, etc.). All solid and hazardous wastes will be properly collected, segregated and stored in appropriate storage areas. Recyclable wastes such as metal and wood scrap will be sold to scrap buyers, as feasible. Other non-hazardous wastes will be disposed off to approve landfill sites. Therefore, potential impacts due to discharge of handling of solid / hazardous wastes will be minimized by implementation of measures as above. 3.2.2.1.4 Soil environment The normal operation of NSRP complex will not cause any additional impact to soil environment due to modern technology and cemented plant surface. However, potential impacts may be created from hazardous materials, hazardous wastes storage and handling and accidental releases only. Effect of leakage from storage tanks Project activities The handling and storage a significant hazardous wastes inside boundary might be a potential risk of soil contamination. The estimated type and amount of the waste are show in Table 3.9. Potential impacts The potential leakage might occur at pipe joints, valves, loading arms, etc. The leakages are usually small and only limited at working area. In practice, Crude oil and products are stored and handled in closed systems and involve the use of insulated storage tanks and lagged and trace-heated transfer lines. Exposure to fuel oil is therefore limited, except on tank filling and during maintenance operations. In addition, each tank is surrounded by bund system; any crude/product release will be kept inside the bunds. Commercial caustic flakes/ beads are received in 25 kg bags by road trucks in the refinery complex. The bags are unloaded and stored in the Refinery warehouse or in dry enclosed space. Solid caustic feeding package is provided for automatic handling, opening and unloading the caustic bags into the concentrated caustic preparation tank. Caustic flakes are safely unloaded into the tank using a solid caustic feeding package. Therefore, the potential risk of caustic leakage is small and impact level is assessed as minor to soil environment.



Effect of hazardous wastes storage and handling Project activities The handling and storage a significant hazardous wastes inside plant boundary might be a potential risk of soil contamination. Based on Table 3.9, regular hazardous wastes are oily wastes (426m3/year), sludge from ETP (5,204 tons/year), ash generated from incinerator (2,100 tons /year), spent replacement materials (1,760 tons /year), spent catalysts (1,110.8 tons in every 4-5 years), spent absorbents (17.32 tons in every 4 years), spent desorbent (1,116 tons in every 20 years), catalyst grading materials (49 tons in every 4 years), spent caustic (1,623 m3/year), etc. from different process units. Potential Impacts The release/fall out hazardous wastes may pollute not only soil environment, but also ground water. However, NSRP LLC will establish waste management plan in which hazardous material/waste disposal may be introduced for easy identification, ensuring responsibilities, right disposal destination and tracking. So, the significance of these impacts is considered as moderate during the operation phase. 3.2.2.1.5 Marine ecosystem Impact by continuous intake water system Project activities

The Refinery and Petrochemical Complex will require continuous supply of large volume of sea water (Max 42.8 m3/s) for cooling purpose. Potential impact Cooling water intake can impact aquatic organisms basically in two ways including:

The first is entrainment, which is taking of small organisms with the cooling water including plankton, fish eggs and larvae, etc. In practice, intake water is taken from intake channel (in between breakwater and low crested breakwater) where sea water is already settled down. Moreover, the phytoplankton community of Nghi Son bay was not diversity and community indices was classified as bad level, but The zooplankton community was relatively diverse and diversity indices was relatively high (Table 3.29). However, the intake volume is small in comparison with Nghi Son bay capacity and the affected organisms are insignificant with the reproductivity of the open bay as Nghi Son sea.

Table 3.29 Summary plankton and benthos in Nghi Son bay

Parameters Phytoplankton Zooplankton Benthos Number of species 43 59 156 Density 8.8 x 108 cells/m3 915 ind./m3 351.7 ind./m2 Biomass (g/m2) - - 9.45 Diversity indices H(s) Bad levels Relatively high Rather good



The second way is impact to aquatic life such as fish, cuttle-fish, shrimp through entrapment-impingement. This is the blocking of larger entrained organisms that enter the cooling water intake by some type of physical barrier. According to distribution ground of the Research Institute of Marine Products in Hai Phong on fishing, shrimp, cuttle-fish grounds, there is only cuttle-fish ground at nearshore area where cooling water intake channel situated. However, the intake channel is installed at the seashore with 350m in length, 70m in width and -7.92 in depth. It is designed with the purpose of taking water slowly and reducing fine particles to the intake system and screens. This design also prevents aquatic species entering to the system. Moreover, there are two levels of screens, screen 25mm and screen smaller than 3mm, to prevent rubbish. These screens also have functions to avoid small fish entering to the system. Therefore, potential impact to aquatic life is low and the environmental impacts of intake water are considered as minor.

Impact by effluent discharge

Project activities

The Refinery and Petrochemical Complex is required continuous discharging a large volume of effluents (Mean of 129,364 m3/h and Max of 154,000 m3/h) in which 105,200m3/h is cooling water; 23,000m3/h is from treated FGD effluent, 600m3/h is treated effluent from ETP and 564 m3/h is from RO unit. Potential impacts

The effluent discharge including cooling water will impact in different ways. In some respects, mainly in improving the growth rate, an increase in temperature may even be advantageous. The discharge has some unfavourable effects because it attracts fish and thus causes indirectly food shortage, deterioration of the condition. The primary effects of thermal pollution are direct thermal shock, changes in dissolved oxygen and the redistribution of organisms in the outfall. Because water can absorb thermal energy with only small changes in temperature, most aquatic organisms have developed enzyme systems that operate in only narrow ranges of temperature. These stenothermic organisms can be killed by sudden temperature changes that are beyond the tolerance limits of their metabolic systems. Based on thermal dispersion plume (Figure 3.8 and Figure 3.9) at outfall 6km, at the spring tide, the plume traveling north about 5-6 km and the tail of the plume spread out to encompass the coral beds and sensitive fishing grounds at the Hon Me Archipelago. The temperature around the archipelago is between 0.2oC and 0.4oC above the ambient temperature. That means thermal plume will not cause significant effect to aquatic habitat and coral reef around Hon Me island.

On the neap tide, the plume extends north and makes contact with the coastline and also extends south to surround the Hon Me Archipelago. At the site of the discharge the excess temperatures rise as a result of the much lower tidal currents and weaker advection and dispersion. That means thermal plume will cause significant effect to aquatic habitat in the range of 300m surrounding the outfall. But the thermal plume in the coastline and the archipelago varies in range of 0.6 – 0.8oC and is well within the environmental requirements (≤3oC). Therefore, the impact level is considered as small at the outfall and minor to coastal aquatic habitat and coral reef around Me island.



3.2.2.2 OPERATION OF THE OFFSITE FACILITIES (HARBOR, BREAKWATER, CRUDE PIPELINE AND SPM)

3.2.2.2.1 Air environment 1. Emission gas Project activities When the project comes into operation phase, the main sources of air quality impacts caused by marine facilities are from unloading activity of crude oil at the SPM and loading of petroleum products at the jetties. For loading process, petroleum products will be transferred to the product tank farm to export via 7 berths and directly loaded to the vessel. Gasoline and Diesel will be dispatched via the ocean berths, while Jet fuel, fuel oil, benzene, paraxylene and partly Gasoline and Diesel will be dispatched via the coastal berths. For safety reason, LPG will be loaded in indicated berth. Potential impacts The loading of above liquid products will generate significant quantities of hydrocarbon vapour, these activities will cause long term and significant effects to the environment. However, volatile products like Gasoline, Benzene and paraxylene generating volatile organic compound (VOC) will be recovered in common return vapor recovery system. Displaced vapour from ship will be returned to the shore via a vapour return piggybacked to a loading arm. The recovered liquid will be re-injected into gasoline product loading line stream of metering package. After completion of loading, the loading arm/manifold will be purged with nitrogen into the out board section of the loading arm. Any remaining material in the loading line and manifold will be drained into slop drums. For the LPG, displaced vapour from ship will be routed back to the mixed LPG spheres. Non-volatile products like Jet fuel and Fuel oil are loaded to the ships through respective loading arms. These above activities shall control and reduce VOC released to the environment. Therefore, impact level to air environment is considered as minor during operation phase. Due to the nature and frequency of emissions from the jetty vent it is concluded that releases from this source are insignificant. As such, these emissions will not be included as part of the air dispersion modeling for offsite facilities. Loading solid sulphur product has potential risk of dust exposure. Sulphur forming unit and solid sulphur bulk storage are located at the jetty, therefore dust formation is significantly minimized while conveying. Impact level is considered as minor. Offloading of crude oil at SPM will generate a small amount of hydrocarbon. However, since the SPM is located 33.5 km offshore, hydrocarbon generated will be well dispersed and only minor environmental impact is anticipated.



2. Noise Project activities

During operating phase, main sources of noise are from the operation of equipment, truck movement, shipping activities (engines and whistling) and maintenance dredging. Potential Impacts

Noise impact generated from harbor and shipping activities are peak noise coming from metal contact or foghorn. These noise events will be occasional. Therefore, the significance of the noise impact during the operation is assessed as minor. 3.2.2.2.2 Water environment Impact of crude offloading at SPM Project activities Crude offloading process will be carried out at SPM from tankers 300,000 DWT to the Refinery crude tank farm. Floating hoses are used to transfer crude from the ship to the SPM and a pipeline end manifold (PLEM) is sited on the seabed below the SPM for connecting horses to the SPM. The SPM is tied to the Refinery crude tank farm by a double 48" submarine unloading pipeline. Upon an incident to the SPM in which it is not operational the transfer of crude oil to the Refinery will be carried out by ship-to-ship transfer to 30,000 DWT vessels offshore from the refinery and shuttled into the harbor for unloading. In order that the Refinery output is not affected two 30,000 DWT vessels are required. Potential impacts According to NSRP marine consultant, the chance that the wind and wave height of a severe typhoon pass the SPM terminal is small but realistic and conditions differ significantly from the 100-year return environmental conditions. Based on feedstock for the Refinery, there are a maximum of 33 parcels of transported crude from the Kuwait to Nghi Son Bay with an interval between parcels of 10 days. The offloading of large crude tankers at the SPM will take approximately 24 hours/ship. For the tanker arriving at the SPM, the cut off time for berthing is 1.5 hours before sunset. Therefore, berthing occupancy of tanker at SPM might be more than two days. The crude offloading from large ships at Nghi Son Bay will take place for year round. Area used for normal offloading operation at SPM and support activities will permanently occupy 31ha, while normal crude pipeline operation seems not cause significant effect to seawater quality. However, these above-mentioned activities might cause high potential risk of oil spill at SPM and on crude pipeline system, especially of ship to ship transfer by 30,000DWT vessel in the case of incident to the SPM. In the case of accident of SPM, all crude oil from tanker will be loading by 30,000DWT ships. It is estimated that there are about 10 times loading crude from 300,000 DWT tanker to 30,000DWT ships. Crude will be transported to the harbour and then continue loading by pipeline system to plant’s tankage system.



The above-mentioned activities of crude loading and transportation will cause high potential risk of oil leakage at SPM area, increase shipping density and increase shipping collision at harbour area. Depending on oil spill tier, affected area might be a partly or all Nghi Son coastal area. Impact level depends tolally on oil spill level. The detail of oil spill scenarios will be mentioned in the oil spill response plan report. In the case of oil spill occurs at SPM or crude oil pipeline, spilled oil will drift to Nghi Son bay and shoreline in the first day and its impact level will be considered from significant to severe, due to SPM and crude pipeline system locations are too close to the shoreline. The significance of the impact will depend much on spilled time and tier scale, spilled oil might affect further to Southern direction (in the Northeast monsoon) or to Northern direction in the Southwest monsoon. Impact of product loading at jetties Project activities It is planned that 95% of the refinery products will be distributed by ship. The products will be routed by pipeline from product tank farm and loaded directly into vessels/tankers through loading arms at the ocean /coastal berths. The berths turnaround times for the ocean berths and the coastal berths are estimated at 22 and 16 hours respectively. It is estimated that about 92.71% of refinery products will be exported via the coastal berths and about 6.29% are exported via ocean berths. Total number of tanker/vessels (1,000 – 10,000 DWT) will be 1,179 ships/year (Table 3.30).

Table 3-30 Berth occupancy in the operation phase

Product Mass exported (T/SD) No. of ships per year LPG 158 44 RON 92 3,610 142 RON 95 3,610 142 Jet 1,709 168 Kerosene - - Premium Diesel 6,043 238 Regular Diesel 4,029 158 Fuel Oil - - P-X 1,849 135 Benzene 693 84 Poly-propylene 1,074 40 Sulphur 740 28 Total (Liquid Product Berth) 21,701 1,111 Total (Solid Loading Berth) 1,814 68 Total 23,515 1,179

Source: NSRP LLC, November 2009 The loading time is in the range of 3-7 hours for vessel 3,000 tons, from 5-11 hours for vessel 5,000 tons, 4-5 hours for vessel 10,000 tons and 12-14 hours for ocean ship 30,000 DWT. It is estimated that 8 vessels may occupy the channel at any one time. All the vessels in the channel must be traveling with a minimum gap of 15 minutes between vessels. Total berth occupancies are in the range of 33-54% for the coastal berths, about 10-29% for ocean berths and about 5% for LPG berth. The harbor topsides is



capable to load several tankers with the same product at the same time or one Ocean tanker and two Coastal tankers can be loaded with one product at the same time. Potential impact

The product loading activities at the harbor will impact to water quality by tankers/vessels propellers and mooring. Other potential impacts include the effects of anti-fouling paints, the types used for vessels to undergo cleaning in the harbor. The estimated area affected by activities at the area of harbor, access channel, breakwater and cooling sea water intake channel is about 193 ha. During routine loading operations, small leakages of oil products may occur at the harbor due to human error, for example. These include the tightening of equipment performance and compliance requirements for tank structural components, valves, and plugs, supporting and anchoring devices and other fittings. The impact level is considered as small and be limited in the harbor area. Since the Project harbor is constructed nearby the specific port of Nghi Son Cement Factory (in the South) and sea way transport route leading to PTSC Port will cut across the Project area of crude oil pipeline and access channel, so the vessel density at this area will increase significantly and also cause high risk of collision between ships. Although NSRP has given effective mitigation and prevention measures to minimize potential risks, impact level of this activity is assessed as moderate during operation phase of the Project. Total effects caused by vessels activity will be mentioned in detail in Item 3.2.3. It is important to note that the density shipping activities at harbor and access channel might cause high risk of ship collision and oil spill. The density of petroleum products is generally lower than that of water, so in the case of product spillage into the sea; the product itself is extremely volatile at ambient temperature and always floats on the surface. Since it is quickly dispersed into the air, the risk of long-term environmental impact to sea water quality will be significant. Oil spreading and assessment will be analyzed in detail in the separately report named “Oil Spill Response Plan” for NSRP.

Impact of periodical maintenance dredging Project activities Maintenance dredging activities will be carried out after 4 years for the harbor and access channel and last for 06 months. Estimation of maintenance dredged volume is approx. 2.9 million m3 in which 0.7 M m3 in the harbor area and 2.2 million m3 in the access channel. It is planned that dredged materials will be disposed at the same dumping location in the construction phase, 6.7 km away from the South of Hon Me Island). Initial dredging activity for the first stage of the Project will be carried out, assessed and chosen dumping location by NSPM. Potential impact Choose dumping location As mentioned in Section 2, sea bed sediment at harbor basin is much diversified from very loose to dense, fine sand to silt sand. At some locations, mud is status of loose / soft clayey sand. At 2 m under the sea bed, the sediment layer is very hard, including stiff to very stiff clay. Above types of dredged



sludge are not suitable for site leveling of the Project or other onshore projects. Hence, the optimum option is dumping at location out of the Project area. Dumping location must meet requirements of environmental protection and safe for vessel activity. The dumping site in this phase is considered as follows:

- Water depth must be suitable in order not to prevent vessels transportation; - Appropriate distance between the access channel and SPM so that flow of sediments will not

impact on dredging site; - Main direction of wastes movement; - Enough space for receiving dredged sludge; - The transport distance from the harbor is minimum to reduce emission gas and dredging cost; - Minimize negative impacts on marine ecosystem, especially the area of coral reef at Me island; - Avoid or limit to dump at fishing grounds;

According to research/consideration of dredging for marine constructions [12], 04 positions considered to choose as dumping site are as follows:

- Position I: the South West area of Me island; - Position II: the North West area of Me island; - Position III: the area between Nghi Son island and Me island, near small islands; - Position IV: the area locates near the South West islands of Me island.

Analysis of sea bed features and dredged sludge receiving ability and environmental impacts of 4 positions are presented in Table 3.31 and Figure 3.10.

Table 3.31 Comparison of proposed dumping sites

Proposed dumping sites Criterion

I II III IV

Water depth -20 m -15 m -11 m to -13 m -15 m

Distance from dredging site to the harbor

18.5 km along route A 19.1 km along route B

12,5 km away from the North area

11.2 km away from the South area

9,2km 10,7km

Sea bed topography

- Rather even and flat

- There are 02 narrow water areas with -18 m in depth

- Natural hole with depth of -21m

- The South natural hole with depth of -27.4 m

- Natural hole with depth of -19.8 m

- Natural hole with depth of -21.2 m

Receiving ability - Receiving area of 9km2

- Maximum receiving volume of 18 millions m3

- Receiving area of 1 km2

- Maximum receiving volume of 3 millions m3

- Receiving area of 0.65 km2

- Maximum receiving volume of 2.3 millions m3

- Receiving area of 0.58 km2

- Maximum receiving volume of 3.6 millions m3

Environmental sensitivity

- Low

- Not affect on coral

- High

- Affect on coral

- High

- Affect on coral

- High

- Affect on coral



Figure 3.10 Selectable dumping sites



Above comparison results show that position I locating 6.72 km away from the South West of Me island (Figure 3.11) is the most suitable for the Project. Moreover, in comparison with dumping site proposed by Thanh Hoa Port Authorities in February 2009, position I is further from the seashore and more suitable or following reasons:

Away 8.7 km from nearest pipeline; 6.72 km from Me island; 6.3 km from Dot island and 8.7 km from Mieng island;

Direction of sediment dispersion is the South, so the dumping site must locate in the South of the harbor and corridor of the pipeline;

Do not affect on ecosystem of coral around Me island;

Figure 3.11 Proposed dumping site According to calculation, volume of dredged sludge at dumping site is not higher than 1/10 of the sea level. Therefore, maximum allowable height of deposited sludge at dumping site must be 2 m. Due to dispersion of the sediment by time, an area in size of 3.0km x 3.0km with filling height of 2m may receive 18 millions m3. Beside advantage of space for dumping, this position also has an enough depth to mitigate impact of dredged sludge on current and disperse sludge by time. Moreover, 02 narrow water areas with -18m in depth will make impact of dumping more sludge insignificant. In order to keep balance of height between dumping site and surrounding area, dumping site must limit filling height of -18.0m. Current depth is about -19m in the West and -20m in the East compared with dumping site, average filling height is only about 1.5m. Therefore, with dredging frequency of 04 years and dumping sludge volume of 2.9 millions m3, it is necessary to have a dumping site in size of 1.4km x 1.4km. Effect of dumping activity Dredging (and dumping) activities at any scale may cause impact on water environment. Movement of the current will stir the sediment layer and increase turbidity in a large area. This will make the sediment layer be dispersed significantly. Calculation of 2.9 million m3 sludge by sludge dispersion model is carried out on the supposition that it must be discharged 800,000 m3/month. Since dredging activities will be done for each 4 year in any month in year, the model is



run for whole 12 months. The results show that maximum thickness at dumping site varies in range of 2.66 – 4.48m. Affected area with sludge thickness of 0.1m is about 160,000 – 220,000m2 up to time of dumping. Affected area of sediment layer with thickness of 01m is about 27,000 – 80,000m2 (Table 3.32 and Figure 3.12)

Table 3.32 Seabed area affected by dredging sludge

Affected area (m2) Month

Material thickness of 0.1m Material thickness of 1m Maximum thickness at

dumping site (m)

1 158,438 52,813 4.07 2 158,438 26,406 4.54 3 184,844 26,406 4.48 4 158,438 26,406 4.17 5 158,438 26,406 4.09 6 184,844 26,406 4.48 7 211,250 79,219 2.66 8 184,844 26,406 4.67 9 158,438 52,813 4.12 10 158,438 26,406 3.95 11 158,438 52,813 3.80 12 158,438 52,813 3.54

Dredging activities will strongly disturb the top sediment layer. These activities cause temporary instability for the sludge deposition process. Due to the strong disturbance, some particulates are suspended and some are re-deposited. These activities will increase organic content and nutrients (N, P và S-2) together with inorganic constituents (Na, Ca, K) in water. When outside sediment layer is removed, the anaerobic inside will be exposed. In this condition, all benthos are destroyed or dispersed.

In dredging process, suspended solid content will locally increase. Activities of the dredger ship take place in the sea. This will increase temporarily suspended solids and affect mainly on the top of water column. Dumping process will make the turbidity, pollutants and BOD increase, but concurrently decrease dissolved oxygen (DO) in water. This impact may last for 6 to 12 months. Impact level is assessed as moderate and short-term during dredging and dumping process.



January March

May July

September November

Figure 3.12 Diagram of dredged sludge dispersion



Impact by harbor effluent discharges Project activities Sources of effluent within harbor will consist of the following streams: clean water, oily water and sanitary effluent. Potential impact Typically storm water run-off from non-process or unused areas where there is no potential to pollute water-run-off is classified as clean effluent. Clean effluents are collected to gravity drainage systems and in open ditches at the harbor. Clean effluents normally have low or negligible content of pollutants and meet the discharge limits. Therefore, this effluent can be discharged, untreated, direct to sea. The discharge of clean effluents directly to the sea at the harbor will not pollute seawater. Sanitary effluent generated is based on an estimated flow of 300 liters/person/day. It is anticipated that the number of employees will be 42 persons and an allowance of 12 additional persons. The estimation sanitary volume is about 16.2 m3/day. The maximum daily pollution loads before treatment as a long term average is given in Table 3.33.

Table 3.33 Maximum daily pollution loads

Case Maximum daily load

Flow 16,200 kg/day Pollutants kg/day ppmw BOD5 3.24 200 TSS 3.78 233 NH4+-N 0.43 27 Total Phosphor 0.16 10

Source: Technical Document No. 3550-8110-PS-190-0180 - REV D1 Provided by FWL, November 2009 Notes: The pollution loadings are based on typical daily allowances per person: 300l/day of water, 60 g/day of BOD, 70 g/day

of SS, 8 g/day of NH4+-N & 3 g/day of Phosphorus. Normal flows are likely to be lower than the peak identified above but the pollution load is likely to be as identified for

extended periods of time thus the sewage strength is expected to normally be substantially higher than that indicated above for the peak flow.

This sanitary effluent will be treated by sewage treatment package at the harbor and then routed to project outfall. The treated wastewater will meet discharge standards of the project (see Item 0.2.2.3). The sludge will be transferred to the secondary treatment stage (biological) of the refinery effluent treatment plant (ETP). So sanitary effluent generated from harbor’s topsides will not cause direct impact to seawater. Project activities will be updated during EPC phase.



Impacts of wastewater and solid wastes from vessels Oily wastewater In the operation phase, there are about 33 very large tanker (300,000 DWT) transporting crude oil from Kuwait to SPM every year. These ships are equipped preliminary oily separator. Cleaning and runoff water sweeping oil sticking on the surface floor around the equipments will be collected and treated by the oil separator to ensure that oil content in treated wastewater must less than 40 ppm before discharged into the sea (offshore area beyond 12 nautical mile). On the other hand, the project’s crude tanker will only operate offshore at SPM which is 33.5 km far from the shore with frequency ship to SPM is one per every 10 days. Moreover, volume of oily wastewater from tanker is small and the mixing ability of the environmental receiver is very well, so discharging treated oily wastewater will cause insignificant impact on marine environment. At product export berths, there will be about 1,179 ships of 1,000 – 30,000 DWT every year going in and out, in which 93% of them are 1,000 – 10,000 DWT ships. As planned, the NSRP harbor will only receive double hull ships or having 2 containing holds, not for ships having ballast water. Moreover, according to the MARPOL signing progress, all these ships must have certification of the Vietnam Register of shipping before berthing in the harbor. The operation process of these tankers at the harbor will generate a small volume of oily runoff water since oil stains are swept away from the floor of the ship by rain water. This oily wastewater will be preliminarily extracted the lower layer because oil is lighter than water and will float on the surface. The above oily water layer will be collected and routed to a separate tank and treated periodically (when the tank is nearly full) by the onboard oil/water separator or a licensed company outside the harbor. Therefore, the NSRP harbor will not receive oily wastewater from product vessels and impact level on sea water environment is assessed as insignificant. Domestic wastewater Domestic wastewater generated onboard of crude tankers and product ships will be collected and preliminary treated before discharging into the sea. However, number of screws working on these specific ships is not much. Therefore, discharging treated domestic wastewater from ships will cause insignificant impact on the marine environment. Solid waste Domestic rubbish from canteen area as waste food generated from each ship is not significant. All amount of rubbish will be crushed into small pieces less than 25 mm in size and discharged directly into the sea without treatment. It is noted that small pieces of rubbish (≤ 25mm) should not be discharged nearshore due to effects on ship activities at the harbor. Normal operation of crude tankers and product ships will generate frequently amount of solid waste. These solid wastes are mainly non-hazardous waste as domestic rubbish and a small amount of hazardous waste as oily rag, batteries… As planned, all solid wastes generated onboard will be classified at source into separate bins before transporting to temporary storage area at NSRP harbor. At the harbor area, hazardous waste will be transported to specific storage area of the Complex and treated together with hazardous wastes of the Complex. Non-hazardous wastes will be transported and treated properly by a licensed treater company; and NSRP LLC will be responsible for hiring this company in accordance with current regulations. Therefore, impact level of solid wastes generated from ships on sea quality at Nghi Son gulf is assessed as minor. Amount of solid wastes generated from these tankers will be defined by the EPC Contractor in the detailed design phase of the Project.



3.2.2.2.3 Soil and groundwater environment Project activities Main activities caused potential soil impact are operation of 2km onshore pipeline, pipeline pigging and maintenance and solid wastes management at the harbor. Potential impacts Onshore pipeline system and loading activities Product loading at harbor will not cause significant impact to soil environment due to loading activities are operated on the harbor structure. Normal operation of crude and product pipelines connecting from Refinery and Petrochemical Complex to harbor will not cause soil pollution. In the case of occurring onshore pipeline failure/rupture, spilled oil/product will cause soil contamination along the pipeline right of way. In practice, pipeline tracks are buried at minimum of -1m in depth and isolated with the vicinity by fence and will be supervised by NSRP LLC. On the other hand, onshore oil spill/leakages are usually minor and easy to handle. Therefore, the impact level is considered as minor. During the periodic pipeline pigging, any deposit or fluids inside the pipeline will be discharged to the tank ahead at the pig receiving station in the plant. Therefore, the level impact of maintenance pigging on soil contamination is considered as negligible. Solid wastes Solid wastes generated from normal operation of jetty area are in small quantity. Most of the non-hazardous solid wastes are coming from the 42 persons working at Jetty Area Control / Admin Building. Domestic wastes from Jetty are estimated at 45.9kg/day which will be regularly collected and disposed by an accredited local Urban and Public Hygiene Company. 3.2.2.2.4 Marine Environment Project activities Main activities caused potential impact to marine habitat at this phase are offloading crude oil at SPM through pipeline system, product loading at jetties and maintenance dredging and material dumping. Potential impacts As above mentioned, normal offloading crude oil at SPM through pipeline system and product loading at jetties will be at high potential risk of oil spill. In the case of oil spill occurs, the main threat posed to living resources by the persistent residues of spilled oils and water-in-oil emulsions is one of physical smothering leading, in cases of severe contamination, to death through the prevention of normal functions such as feeding, respiration and movement. As damage is caused by physical contact, the animals and plants at most risk are those that could come into contact with contaminated water.



Maintenance dredging and material dumping activities will cause similar impacts as ones in the construction phase. However, the presence of contaminated sediments may be higher due to effluent discharges from industrial activities. The potential effects of these changes on marine life are:

Cause the removal of benthic animals at the dredge site.

Temporary increases in the level of suspended sediments in the water column which can give rise to increased turbidity, and the possible release of oxygen depleting substances (organic or anaerobic sediments), nutrients and contaminants.

Temporary reduction of algal/plant growth due to increased turbidity.

Disturbance to sensitive benthic animals and fish due suspended sediments, which may cause temporary disruption of migration of fish.

Temporary disturbance of marine animals from the depletion of oxygen due to release of organic-rich material.

Nutrient enrichment possibly causing increased food supplies/algal blooms.

Uptake of contaminants by marine life possibly causing direct toxic effects or effects further up the food chain.

Smothering of benthic animals and plants due to resettlement of suspended sediments.

The overall effect of maintenance dredging on the hydrodynamics and geomorphology of a site has all the complexity of a capital scheme but the impacts are less magnitude. In many cases the magnitude of dredging related alterations may fall well within the range of naturally occurring phenomena and probably impose little or no additional stress to marine features (IADC/CEDA 1998). For maintenance dredging, the extent of these environmental affects is near-field and temporary generally only lasting as long as dredging operations are taking place (ABP Research R707 1997; IADC/CEDA 1998). However, the presence of contaminated sediment may increase the impact of the maintenance dredging at the disposal site. The impact level is considered as significance. 3.2.3 CUMULATIVE IMPACT DURING OPERATION PHASE OF ONSHORE AND OFFSHORE

CONSTRUCTIONS ON OTHER PROJECTS IN THE LOCAL AREA Cumulative impact assessment of NSRP is based on overall development background of other projects in the local area. The Complex is constructed in Nghi Son economic zone (NSEZ), other industrial activities in NSEZ include: Petroleum Technical Services Corporation (PTSC) and Vinashin shipyard factory are in site leveling phase. PTSC

Port is 7 km away from the South of the Project. Current PTSC port mainly serves for domestic import/export of construction materials and cargo. The appearance of 5 new harbors will increase risk of ship collision and cause significant impacts on the environment and society.

Nghi Son Thermo-electric Plant with capacity of 1,800 MW locating in front of the PTSC Ports include Nghi Son 1 Plant (600 MW) and Nghi Son 2 (1,200 MW) and 6km away from the Project. The Plant will use 14 tons of coal/hour, the feedstock is from coal mine in Hon Gai, Quang Ninh province. Coal will be transported to the Plant by seaway and kept in the coal storage area. Operation of the Plant is a significant air pollution causing source. New product export berth of the Plant will increase risk of ship collision.



Nghi Son cement factory is 5 km far from the Project area. The factory locates near Road 513 but its jetty is built at Nghi Son Gulf. This jetty is near the harbor of NSRP, so ship activities of Nghi Son cement factory and NSRP may increase risk of ship collision.

In future, there will be a new harbor of NSEZ locating near the harbor of NSRP. This new harbor may prevent the sea traffic since it is too close to the harbor of NSRP. Due to this high potential risk, the new harbor of NSEZ will have a complete different access direction.

PTSC Ports and Nghi Son Thermo-electric Centre locate behind Chuot Chu Mountain with its height of 157m and is 6 – 7 km far from the Project area. On consideration of distance between projects and practical topography condition, emission gas and waste water dispersion of the Project will not cause cumulative impact on environmental constituents at Project area. However, growth of ship activities due to the development of trade ports and fishery activity will increase environmental risks, especially the oil spills. Therefore, it is necessary to assess cumulative impact between NSRP and other projects. Most of cumulative impacts will affect on:

Habitat; Biological diversity.

Although Nghi Son Cement Factory locates in NSEZ, this will not cause cumulative impact on air quality because:

According to EIA report of Nghi Son Cement Factory, SOx is not generated from the Factory since it is absorbed during cement production process. Average ground concentration of NOx is under allowable limit of TCVN (0.19 – 0.22 mg/Nm3). Average ground concentration of cement dust is in range of 0.19 – 0.21 mg/Nm3 at distance of 600m from the stack base. Therefore, affected area is limited in the area of Nghi Son Cement Factory.

Nghi Son Cement Factory is 5 km far from NSRP and behind Chuot Chu Mountain.

Operation and appearance of harbor constructions of different projects will generate cumulative impacts due to the increase of sea traffic and high potential risk of ship collision.

According to Thanh Hoa Port Authorities, Nghi Son integrated port (PTSC Port at present) may receive 10,000 DWT ships at berth 1 and 30,000 DWT ships at berth 2. The capacity of the port is about 900,000 – 1,400,000 tons/year with cargo such as rice, cement, iron, steel, fertilizer and coal. International ships going in and out Nghi Son integrated Port are mainly from Japan, Thailand, Malaysia and China. More than 80% of ship activities in Thanh Hoa province concentrate at Nghi Son gulf with density of 830 – 997 ships/year. Access channel routing to Nghi Son integrated Port, Vinashin shipyard factory and Nghi Son thermo-electric plant is from the South of Bien Son mountain and 9 km far from NSRP. Therefore, ship collision incident may occur in area from Buoy 0 to Nghi Son integrated Port, oil slick may affect directly on Nghi Son gulf and NSRP harbour. Polluted area may spread out if the incident occurs in time of March to August (Southwest monsoon). In this case, Me island, Nghi Son cement port, NSRP harbor and Thanh Hoa coastal area will be affected.

Nghi Son cement port is 1 km far from the South of NSRP harbor. 3 specific ships used to transport coal from Quang Ninh Province to the jetties name Development (12,000 DWT), Helitech (7,000DWT) and San Ho (14,000 – 16,000DWT); and a large ship (17.000 – 27.000DWT) used to transport clinker from Japan, plaster from Thailand and cement to Hiep Phuoc Port (HCMC). The capacity of the Port is about 1,100,000 – 1,300,000 tons of cement, clinker and coal per year. At present, density of vessels at Nghi Son Cement Port is low and there is no any ship collision incident. However, the access channel of this port is used flexibly for ships from the North (China, Quang Ninh…) passing access channel of NSRP harbor and ships from the South will also pass Me island. Hence, there will be



potential risk of ship collision when NSRP Harbor comes into operation phase. In case of incident at Cement Port or NSRP Harbour, oil will drift to Nghi Son coastal area and Me island in the first day in both monsoons.

In normal operation, frequency of ship going in and out NSRP Harbour is about 1,179 ships/year; and 150 – 186 ships/year for Nghi Son Cement Port. Risk of collision will be higher when a new trade port of NSEZ is constructed and operated near NSRP harbor (in the North). Based on consideration and assessment of ship activities at all harbors, situation and sea traffic at access channel, cumulative impact is assessed as significant.

Tankers at SPM may collide with ships going in and out Nghi Son integrated Port, Nghi Son Cement Harbor, future Port of the Thermo-electric Plant and Trade Port of NSEZ. Main risk to aquatic environment is oil spill accident from SPM, crude oil pipeline or ship collision at harbor or access channel of Nghi Son Cement Port. Although the frequency is low, the result is serious and unchangeable. These cumulative impacts will affect on biological diversity, especially coral, aquatic environment… Cumulative impact level is assessed as major and long-term. 3.2.4 SOCIO-ECONOMIC IMPACT ASSESSMENT Development of NSRP will affect on many aspects of the local community’s living including change of landuse, job opportunity and issues caused by the development. The main impacts mentioned in this item include:

Land acquisition; Compensation and resettlement; Training and recruitment plan; Job change and local supply opportunity.

NSEZ Management Board is responsible for resettlement of affected people in NSEZ. However, NSRP will carry out a due diligence of resettlement activities in the Project area in accordance with requirements of IFC. 3.2.4.1 Impacts caused by land acquisition Total acquired area for the Project is 394 ha in the area of Hai Yen, Mai Lam and Tinh Hai Communes. Most acquired land (65%) is agricultural. Around 2,607 HH (9,000 persons) will be affected by the Project. Among these APs, 687 HH will lose most of their land and their main houses and they have to relocate in another location. Three resettlement sites have been designed to accommodate these relocated APs.

Table 3.34 Scope of land acquisition

Total Productive

land Residential land Project components HH ha HH ha HH ha

Relocated HH

Loss of graves

Plant Site (B) 1,907 328 1,398 289 509 39 456 2,348

- Mai Lam 525 63 468 52 57 11 53 1,083

- Tinh Hai 600 117 450 105 150 12 101 832

- Hai Yen 782 148 480 132 302 16 302 433

Pipeline and Marine Facility (Areas E & J) 700 66 469 231 231 N/A

Total 2,607 394 1,867 289 740 39 687 2,348 Source: Resettlement Due Diligence report, February 2010



During the first survey, most of the HHs in the plant site were losing a significant part of their land (86.7% lost more than 30% of their total holdings) and 42% of HH who lost agricultural land declared that their remaining land was no longer viable.

As already indicated, all the APs already relocated in Mai Lam Commune had lost all their residential land.

Table 3.35 Affected land in the plant site and in the borrow areas

Affected area/Total area (%) 0-10% 11-30% 31-60% >61% Location

Number of

surveyed HH HH % HH % HH % HH %

Plant site 105 4 3.8 10 9.5 38 36.2 53 50.5 Already relocated APs in Mai Lam

25 0 0.0 0 0.0 0 0.0 25 100.0

Source: Resettlement Due Diligence report, February 2010

Table 3.36 Viability of remaining agricultural land

Remaining land viable Yes No (too small)

Location

Number of surveyed

HH HH % HH % Plant site 105 61 58.1 44 41.9 Already relocated APs in Mai Lam 25 0 0.0 25 100.0 Source: Due Diligence Surveys (2008-2009) 3.2.4.2 Impact caused by graves relocation In the Project area, graves locate mainly under the foot of Chuot Chu (area of borrow pits), Coc mountains and rice fields (the Plant site). Some graves are buried in the middle of rice fields or near home. Compensation rate for removing graves: APs had to move graves to new cemeteries. According to APs, the compensation for graves, between 800,000 VND and 3,600,000 VND, doesn’t reflect replacement cost. Most APs hire workers to move their graves. They said that the cost of workers is higher than the compensation proposed. The disturbance or loss of graves could potentially result in social and cultural disruption of traditional burial customs as well as traditional beliefs based on their relationship of ancestors to living beings. According to consultation with affected communes, compensation rate for graves relocation is lower than practical cost.

Situation of new cemetery in Mai Lam commune: a new cemetery was built in Mai Lam commune. However, APs and local authorities are very unsatisfied with the way it was built. Most of the relocated graves stones have fallen down, and are inclined due to the poor and careless construction of the new cemetery, which didn’t follow the approved design. The project will affect 1083 graves in Mai Lam commune, 433 graves in Hai Yen commune and 832 graves in Tinh Hai commune. Local authorities have compensated and moved all affected graves to cemetery of each commune. However, considering the number of affected graves and the belief of the people the significance of this impact is assessed as major.



3.2.4.3 Impact caused by compensation and resettlement

The responsibility of implementing the resettlement of affected people in NSEZ belongs to Tinh Gia District and NSEZ Management Board. However, NSRP is doing a follow-up of the current resettlement activities in the project area.

According to the Due Diligence Resettlement Report prepared in February 2010, around 2,607 HH (9,000 persons) will be affected by the project. Among these APs, 687 will lose most of their land and their main houses and will have to relocate in another location. Due to the number of households affected by the Project, the significance of this impact is serious.

Resettlement activities started in early 2008 for this project and are ongoing. The resettlement activities focused first on the plant site and utilities where compensation payments were made to households who had agricultural land and graves affected by the NSRP. APs in the plant site have now been fully compensated.

Due to change in the design, some new areas (areas E & J) are now under the project. A new resettlement site in Tinh Hai commune has also been developed. Due to this situation, the status of resettlement activities for the various components of the project is at different stages. Below table indicates the status of resettlement activities up to May 2010.

Table 3.37 Status of resettlement activities by commune, up to May 2010

Commune Impacts Status of resettlement activities Mai Lam 63 ha affected by NSRP;

525 HHs 57 HHs to be relocated 1,083 graves need to be

relocated

Plant Site: all compensation paid 54/57 HHs have already moved and handed over their land; 3

HHs have moved to other locations. All graves already removed

The plant site (B) 148 ha affected 782 HHs 302 HHs to be relocated 433 graves need to be

relocated

All compensation paid 104/302 HHs received land and building home in the RS. Graves: 433/433 graves already removed

Hai Yen

The pipeline and harbour areas (E & J) 66 ha affected 700 HHs to be relocated 231 graves need to be

relocated

Being investigated in detail

Tinh Hai 117 ha affected 600 HHs 101 HHs to be relocated 832 graves need to be

relocated

Plant site - All compensation paid; - 83/101 HHs received land and building home in the RS.

Graves: 780/832 graves already removed

Source: Investigation result, May 2010 Three resettlement sites are constructed to relocate people affected by the Nghi Son Refinery Project. They are: Mai Lam, Tinh Hai and Xuan Lam-Nguyen Binh RS. Two RS, Mai Lam and Tinh Hai, are located within the NSEZ and Xuan Lam-Nguyen Binh RS is located outside the NSEZ. All three RSs conform to the Master Plan of the NSEZ. In general, affected HHs are satisfied about the RS, except for



Mai Lam RS due to environmental condition and distance from the previous land to the new RS. These HHs are willing to deliver their land to the project and relocate temporarily or live with their relatives. A new RS will be built for HHs living in Tinh Hai Commune. The RS construction process is not the same for all the RS. Tinh Hai RS will be built later since local people want to move to a new RS. Up till May 2010, there are 104 of 302 HHs in Hai Yen Commune and 83 of 101 HHs in Tinh Hai Commune received land and constructing home in the new RS. The process for plot allocation to APs is as follows:

Priority is given to APs who were located in profitable/convenient locations of their former resident places;

Other APs are chosen randomly for their plots. The size of plots in each RS varies. Two main types of land plots with the size of: (i) 5 x 20 m; (ii) 10 x 18 m. Priority to allocate to agriculture households who will have to change their occupation from agriculture production to non-agriculture production. In addition, some plots have a size of 70 m2. Affected HHs will have option to build themselves their houses but following the regulation of house building under urban area issued by department of construction. The assistance policy for moving and relocation of APs applied for Nghi Son Economic Zone was issued by Thanh Hoa PPC by Decision No.2531/2008/QD-UBND dated 18 August 2008. The assistances are as follows:

Assistance for life stabilization and production stabilization Assistance for house rental Education assistance Training allowance Progress bonus Assistance for individual relocation

The residual impact on socio-economic conditions of the affected households related to the loss of residential land is strong according to the first Public Consultation of November 2008 and Due Diligence Resettlement Survey. 1. Resettlement

Resettlement site development and suitability constituted one of the most difficult issues in the Project. The construction of resettlement sites was severely delayed. NSEZMB planned to finalize all the RS by the end of April 2009. As of the date of the preparation of this report (May 2010), there are many HHs received land and are building their homes in the RS.

Mai Lam RS The resettlement site in Mai Lam Commune was not found to be satisfactory for APs in Mai Lam Commune nor by local authorities due to environmental reasons. Therefore, all APs in Mai Lam Commune refused to be relocated in the proposed RS and chose to be relocated by themselves. Currently, 54 HHs among 57 HHs from Mai Lam commune have already relocated; 03 HHs moved outside the NSEZ.



Tinh Hai RS APs in Tinh Hai commune refused the proposed location of the RS in 2008. A new RS was again proposed to them in 2009 by NSEZ and it has been satisfied APs. Two public meetings were organized in July 2009 by NSEZ. Now, the RS is nearly completed and there are 83 HHs building their houses in this RS.

Late construction progress of RS APs worry about the delays in relocation. They will move to the RS only when the infrastructures in the RS are fully completed. NSEZ promised the completion of the RS for April 2009. However, in October 2009, no APs had been relocated. As indicated above, the stabilization allowance, intended to cover expenses and loss of income during the transition period (currently for 6 months). So APs are asking for the extension of this allowance if the RS is not completed after 6 months. In practice, in the end of year 2009, Thanh Hoa PPC has decided to extend period of stabilization allowance up to 60 months with 30kg of rice/person/month, it is even better than their expectation.

Size of lots of land in RS APs found the size of land in the RS (200 m2) is too small. APs are asking for 500 m2 plots of land to be able to have a garden for growing vegetables and fruit trees. APs want to combine two types of land plots in the RS: one for housing and one for business. In the design of the RS, the locations of business and residential plots are separated. HH want to get two plots at the same location to be able to take care of their business during the night.

Plots of land in RS only for residential land with houses Some APs did not agree with the new Resolution No.128/2009/NQ-HDND of the Thanh Hoa People’s Committee on the moving and relocation policy applied for the Nghi Son Economic Zone; Article 3, Clause 2 of this resolution stated that to obtain a plot of land in an RS, HHs have to meet the three following conditions:

- HH with residential land (with existing houses on it) to be acquired by the Project; - HH should have permanent registration; - HH have to move their place of residence to the RS.

2. Replacement cost survey

A replacement cost survey was conducted in the Project area. Local authorities, affected persons and non-affected persons were met. To assess if the compensation prices paid to APs (based on Thanh Hoa PPC prices) meet replacement costs, a replacement cost survey was conducted. This survey focused mainly on residential land because compensation prices for this type of land are the most contested by APs.



Residential land Compensation rates established by Thanh Hoa PPC for residential land are below market rates for all locations and for all communes. This confirms the opinions of APs. However, APs are offered land for land compensation (plot in an RS). If they choose land for land compensation, they will not be affected by the low compensation rates for residential land.

Productive land

Compensation rates for agricultural land, according to PPC rates, are 22,000 VND/m2 in Thanh Hoa Province. However, this rate was raised from 22,000 to 55,000 VND/m2 for the Project area by Decision No.1151/2008/QD-PPC dated 28/04/2008 amending and adjusting some prices for agricultural land in Nghi Son Economic Zone. This new rate for agricultural land is satisfactory to Aps.

In 2010, following Decision No.4366/2009/QD-UBND issued to reflect the new Decree 69/CP issued by the GoV, the compensation rate for agricultural land has to be multiplied by 1.5. Therefore, the new compensation rate for agricultural land will be 82,500 VND/m2.

House

The investigation showed that the prices of construction materials have increased considerably due to the 25% inflation rate (it may be lower now). The prices for construction materials are 30 to 45% more than 6 months ago. Therefore, local authorities as well as affected people require the PPC to compensate by applying Decision No. 1048/QD-UBND dated 22nd April 2008 but following the inflation rate. The new compensation rates of Thanh Hoa PPC in Decision No.345/QĐ-UBND dated 25th January 2010 have been increased and equal to current market price.

3. Compensation To assess the process of resettlement and compensation, a due diligence survey was conducted for the plant site. 105 HHs were surveyed at the plant site to assess the process of resettlement and compensation. In 2008, at the time of the survey for APs in the plant site, APs had only been compensated for productive land and not for structures. Also, at this time no APs had been relocated. This is the reason why the new due diligence survey among the 25 already-relocated HH was conducted in October 2009.

Satisfaction with compensation During the first survey in the plant site, APs were generally satisfied with the compensation they had received for agricultural land (62%) and for trees/crops (51.4%). This showed that compensation prices for agricultural land generally met market prices. However, among the already relocated APs in Mai Lam Commune, all the APs complained due to the low compensation rates for residential land. The amount they received was not sufficient to get a similar plot of land in the same area.



Table 3.38 Satisfaction with received compensation

Satisfied with compensation received for land

Satisfied with compensation received for fruit trees/crops

Yes No (too low) Yes No (too low) Location Number of surveyed

HH HH % HH % HH % HH %

Plant Site 105 65 61.9 40 38.1 54 51.4 51 48.6 Already relocated APs in Mai Lam

25 0 0 25 100 25 100 0 0

Source: Resettlement Due Diligence Report, February 2010 In the plant site, some APs (19 %) complained to local authorities with no results. Most of the APs (75.2%) attended public meetings organized by local authorities. For already relocated APs, all the APs surveyed complained to local authorities. It should also be noted that in the plant site, although almost all APs (98.1%) were compensated before the start of the civil work, 3 APs declared that they were compensated after the start of the civil work. However, for the already relocated APs, all APs declared that civil works started before the compensation. The result of the due diligence survey conducted with 25 of 75 relocated APs in Mai Lam showed that all 25 surveyed APs complained that they did not receive full compensation and allowances before handing over the site to the Project. Three new allowances: an accommodation allowance (VND 12.0 Million per HH), support for purchasing construction material (VND 10.0 Million per HH), and a training allowance have still not been paid to APs. This was confirmed during the public meeting held in January 2010.

Table 3.39 fully compensated before start of civil works

Fully compensate before civil works?

Yes No Location Number of

surveyed HH HH % HH %

Plant Site 105 103 98.1 2 1.9

Already relocated APs in Mai Lam 25 0 0 25 100 Source: Resettlement Due Diligence Report, February 2010

4. Change in source of income Because many HH lost their productive land, which was their main source of income, several HH have to change occupations. In the plant site, agriculture was the main source of income for 81% of the APs before clearance; now only 61% have this main source of income. Several APs became workers and were hired by companies or by individuals. Secondary sources of income became the first source of income for some APs. Among the already compensated APs, most of surveyed HH (23/25) are still working on agricultural land while two are now hired laborers.



Table 3.40 Source of primary income before and after clearance for already relocated APs

Agriculture Trading Services Hired labor

Wages Forestry Aquaculture Government Source of primary income

Surveyed HH

HH % HH % HH % HH % HH % HH % HH % HH %

Before clearance

25 24 96 1 4

After clearance 25 22 88 2 8 1 4 Source: Resettlement Due Diligence Report, February 2010

Table 3.41 Source of secondary income before and after clearance for already relocated APs

Agriculture Trading Services Hired labor

Wages Forestry Aquaculture Government Others Source of primary income

Surveyed HH HH % HH % HH % HH % HH % HH % HH % HH % HH %

Before clearance

25 1 4 12 48 4 16 5 20 1 4

After clearance 25 1 4 1 4 13 52 3 12 1 4 1 4 2 8 Source: Resettlement Due Diligence Report, February 2010

5. Impacts on living standards Nearly half of the APs in the plant site declared that they are in a worse situation than before the clearance. At the time of the survey, APs in the plant site were in a transition period. They had received cash compensation but they had also lost their source of income. For some HHs, they had never had so much money and their living standards have risen, at least temporarily. An article published in June 2008 on Vietnam News showed that some APs in the Nghi Son economic zones made extravagant purchases. However, most of the APs didn’t see any change in their living standards while 45% estimate that their living standards are worse now. APs have been asking for some programs to help them change occupations. In 2009, this situation became even worse. 24 among the 25 already-relocated HH in Mai Lam Commune declared that their living standards were worse now due to the absence of a restoration program. They no longer have productive land for cultivation and they have also used part of the money they received from compensation for daily expenses. This situation has lasted for one year and a half now.

Table 3.42 Impacts on living standards

Living standards Same than before Better Worse Location

Number of surveyed HH

HH % HH % HH % Plant Site 105 51 48.6 7 6.7 47 44.8 Already relocated APs in Mai Lam

25 1 4.0 0 0 24 96.0

Source: Resettlement Due Diligence Report, February 2010



Main concerns of APs already compensated are follows: Compensation price for residential land too low

As indicated above, APs are not satisfied with the price of compensation for residential land. This was confirmed by the replacement cost survey. Prices are from 2 to 3 times lower.

Almost all relocated APs in Mai Lam commune also complained about lower compensation prices for residential land. They were fully compensated in July 2009 with the compensation rate for 2009. All APs have already received compensation but they are still complaining about the lower rate for residential land. Because they chose to relocate individually, the compensation received for residential land was not sufficient to buy a piece of land similar to the one they lost outside the NSEZ.

However, for APs relocated in an RS, the compensation will be land for land, so APs will not be affected by the low rate of compensation for residential land. In addition, the RS are provided with services that APs don’t benefit from at their current location (piped water, sanitation). The objective of the DRC is to move all the APs into an RS.

APs in Mai Lam also complained that the compensation rate they received in 2009 for residential land was much lower (640,000 to 800,000 VND/m2) than the one issued in 2010 for Hai Yen (1,035,000 to 1,418,000 VND/m2). APs from Mai Lam were the first ones to be relocated and compensated.

Compensation price for structures too low 1

Compensation rates for structures were established at the beginning of 2008. In 2008, the rate of inflation was high and by the end of 2008, compensation rates for structures didn’t reflect market prices. However, the due diligence survey conducted in October 2009 among 25 HHs showed that most of them (17/25 HHs, about 68%) were satisfied with the compensation rates for structures.

Compensation for remaining land

APs, especially in Hai Yen Commune, will be relocated in Xuan Lam – Nguyen Binh RS located 18 km away from their previous land. Some of the APs have remaining agricultural land not affected by the project. However, this land will not be acquired by the project. For APs who will be relocated far away, it will be quite impossible to cultivate the land due to the expenses linked to traveling. They are asking the authorities to acquire the remaining land. Relocated APs for Mai Lam Commune also required the Project to acquire remaining agricultural land.

Concern about their future source of income, especially during the transition period

1 We should note that since the survey (August 2008), the rate of inflation has increased from 20 to 35% in Vietnam due to the financial crisis.



During the first survey in August 2008, it was assessed that some APs who had already been compensated had lost their productive land for more than 6 months and were waiting for relocation in the RS. Relocation can take several months during which APs have no income. They have money due to the compensation they received. However, they cannot start any new activity because they are waiting to move. In addition, some APs misused the compensation they received. It is necessary to provide assistance to APs regarding managing money and ensuring that APs use the money properly. APs received an allowance for the transition period for 6 months to provide for loss of income. However, it is not known how long the transition period will last. If the transition period lasts more than 6 months, it will be necessary to extend the transition allowance until the RS is ready.

Jobs in the industrial zone APs want training to be able to be employed in the industrial zone. They want the NSEZ and NSRP to tell them in which field they should be trained to be able to be employed.

Older APs are very worrying about their future. According to persons met, it will be difficult for them to find new jobs.

Re-establishment of livelihood

In the plant site, in 2008, most of the HH would have preferred land for land compensation for residential land (57.3%). Land for land means a plot of land in one of the 3 serviced resettlement sites. In the pipeline and marine facility areas, most of the HH prefer cash compensation. The RS situation in 2009 (delays, environmental problems) probably incited APs to make their own arrangements.

Table 3.43 Preferred Form of Compensation

Preferred Form of Compensation Replacement land Cash Compensation Other Location

Number of surveyed

HH HH % HH % HH %

Plant site 171 98 57.3 73 42.7 0 0 Marine facility 267 72 27.0 99 37.1 96 36.0 Pipeline 14 3 21.4 11 78.6 0 0.0

Total 452 173 38.3 183 40.5 96 21.2 Source: Resettlement Due Diligence Report, February 2010

3.2.4.4 Impact on training and recruitment plan of NSEZ 1. Nghi Son economic zone (NSEZ) Land acquiring for NSEZ development will make thousands of farmers loss agricultural land. In the NSEZ, there are about 16,780 HHs (65,861 persons) and 44,593 laborers living in 12 communes of Nghi Son Economic Zone. On this, 11,786 laborers are looking for a job. Among these 11,786 laborers, 2,551 have been trained and 9,235 are unskilled.



NSEZ Management Board conducted a survey on the labor force in the 3 communes affected by the project (Hai Yen, Tinh Hai and Mai Lam) and 2 communes (Hai Thuong and Hai Ha) in the vicinity in April 2008. According to this survey, the number of laborers with training interest is 7,682, of which:

791 laborers have aspiration to follow high vocational college; 2,573 laborers have aspiration to follow intermediate vocational college; and 4,318 laborers to follow primary vocational college.

The survey also shown 1,366 trained laborers are looking for a job, of which:

01 person graduated university; 57 persons graduated higher vocational college; 398 persons graduated intermediate vocational college; and 910 persons graduated primary vocational college.

The above laborers are now working in different provinces in the South. However, if the refinery-petrochemical complex and other industrial factories need laborers then most of them have to be retrained. At present, a center of vocational training college is located in Tinh Gia District. This center is connected with other vocational colleges at different levels from central to provincial. Other vocational centers such as Truc Lam Higher Vocational College, Vinashin Shipbuilding College, and Licogi College of high vocational economics have training programs for laborers who are willing to work in Nghi Son Economic Zone and Refinery and Petrochemical Project. 2. NSRP LLC

NSRP LLC will implement traning courses for its own employees after recruitment. However, NSRP LLC will also partially sponsor training programs implemented by local authorities for APs via its proposed Social Support Program (SSP).

Construction Phase During the construction phase (2010-2013), 10,000 to 15,000 workers will be required. Most of the jobs will require specific skills (specialists, engineers, etc.). However, the Project will also need between 2,000 and 3,000 unskilled workers. This will constitue job opportunity for local people and especially affected persons. The construction period will also create a great demand for various services (food, accommodation, entertainment services, etc.) in order to serve the workers. The construction will generate a 2-3 billion VND turnover/day. Local people and APs could also benefit from this demand by providing these types of services.

Operation Phase During the operation phase (from 2014), about 1,000 skilled and unskilled employees will be employed. In the middle of 2010, the company will start to recruit and train its staff in Vietnam and overseas.



Priority will be given to local people if the recruitment requirements are met. The different types of workers needed are presented in Table 3.44. Workers will be hired only if they meet the company requirements, such as work experience, English ability, academic background, etc. The recruitment will be spread over the construction period from 2010 to 2013.

Table 3.44 Tentative recruitment plan for Operation phase

Qualification

No Occupation Number (person) Graduated

English (IELTS)

Background

1 Engineer 450 University 4 - 5 Chemical Engineering, Chemical, Mechanical, Electrical, Civil, etc

2 Operator 180 College 2 Chemical Engineering, Chemical, Mechanical, Electrical, etc

3 Technician 40 College 2 Chemical, Mechanical

4 Helper 100 High

School 1 -

5 Non-Technical Staff 80 University 5 Economics & Management, Applied Mathematics, etc

Source: NSRP-LLC, May 2010 Note 1: Evaluation: Entrance Examination & Interview Note 2: More than 5 years work experience will be required for Occupations 1, 2, 3 and 5

Table 3.45 Period of recruitment during operation phase

2010 2011 2012 2013

1-3 4-6 7-9 10-12 1-3 4-6 7-9 10-12 1-3 4-6 7-9 10-12 1-3 4-6 7-9 10-12 No Occupation Operation

1 Engineer (450) 10 40 80 70 70 90 90 2 Operator (180) 90 90 3 Technician (40) 40 4 Helper (100) 100 5 Non-technical

staff (80) 20 20 20 20

Source: NSRP-LLC, May 2010 NSRP will subcontract some services (outsourcing). This will also constitute a source of jobs for local and affected people. Both skilled and unskilled workers will be required as presented in the following tables.

Table 3.46 Need for skilled workers of contractors

No Occupation Number (person) Recruitment plan

1 Maintenance work 500

2 Fire Fighting 30 From March 2011

3 Marine works 20 From March 2012

4 Clinic 15 From September 2012

Source: NSRP-LLC, May 2010 - Basic Qualifications will be decided by the contractors - The number hired will be decided by the contractors.



Table 3.47 Need for unskilled workers of contractors

No Occupation Rough Number Recruitment plan

1 Security 30

2 Canteen 30

3 House keeping 20

From September 2012

Source: NSRP-LLC, May 2010 Note:

- No special qualifications will be required basically - The number hired will be decided by contractors.

NSRP Project has the potential to create a major significant positive economic impacts on workers employed during construction as well as their families. This impact will benefit to the local communities nearby the NSRP Project but will also be extended to other communities in Tinh Gia District, Thanh Hoa and Nghe An Provinces as well as other regions in Vietnam. During the construction phase, the Project will create about 20,000 skilled workers and 3,000 unskilled workers. The construction period will also create a great demand for various services (food, accommodation, entertainment services, etc.) in order to serve the workers. Local people and APs could also benefit from this demand by providing these types of services. In operation phase, NSRP will create 1,000 direct jobs for skilled and unskilled workers. Besides, there will be 650 indirect jobs through contracts between NSRP and service suppliers. When the Project comes into operation phase, it will meet more than 40% of total fuel demand of the country contributing to ensure national energy security and make a foundation for development of petrochemical industry and other services… The Project will contribute to national budget hundreds of million US dollars every year through taxes.

Support other training programs

NSRP LLC will have partial financial support for some training courses organized by local authorities through community support activities. The main purpose of the program is to improve living standard of local community through social projects. The support will be carried out based on the consultation of local authorities and people. Community support plan may be training, social activities and contributing to community’s fund.

However, NSRP LLC will not organize training courses for those applying for jobs before recruitment. NSRP LLC will train only for recruited employees.

3.2.4.5 Land and natural resources NSEZ has been established in 2006 by a Government Decree to develop the economic potential of Thanh Hoa Province. NSEZ covers 18,612 ha on 12 communes. The purpose of this economic zone is to attract more investment projects to the province. Thanh Hoa Province has invested significantly in NSEZ to develop infrastructures since 2006. The infrastructures comprise traffic-road works, wave control dykes, deep-water ports, seaport, raw water supply system, resettlement areas, access roads



etc. Following this Decree, the NSEZ has prepared a Master Plan for the development of the economic zone including the construction of a Refinery and Petrochemical Complex and port facilities. NSRP Project will have permanent impacts on the land use, property, and plantations in the Project Area. Land and natural resource impacts will arise mainly from land take for construction of the refinery and petrochemical complex (328 ha), the pipeline and road infrastructure (30 ha), and the port facilities (36 ha), but also from the quarry, borrow pits and disposal area. A total of 394 ha of land will be required for the Project. Three communes, Hai Yen, Mai Lam and Tinh Hai will be affected by land take. Agricultural land constitutes the most important land use for these three communes followed by Forestry land. Land use impacts will affect mostly agriculture, forest planted and residential lands. Key impacts addressed in this section are therefore:

Loss of agricultural land; Lost of residential land.

The loss of agricultural and residential lands represents the strongest impacts fell by the affected population based on the first and the second Stakeholder Meeting and Public Consultation event hold respectively on 4th and 5th November 2008 and 27th and 28th January 2010 for the NSRP Project. Most of the mitigation and compensation measures are already implemented by the Government of Vietnam through Thanh Hoa Province People Committee, Tinh Gia District People Committee and Nghi Son Economic Zone. Recommendations to reduce the impacts associated with land take have been proposed in the Due Diligence Resettlement Report (February 2010) and will be summarized in this section of the EIA Report. Only the remaining significant impacts will be presented in that section since some of the issues (for example: loss of plantation) have been solved by Tinh Gia District Authorities and agreed with the affected peoples. 3.2.4.6 Loss of agricultural lands to other uses Project activities During the pre-construction phase some agricultural lands have been permanently appropriated for the Project. This area will be used for permanent infrastructure as plant site, pipeline, accommodation for workers, storage area. Permanent agricultural lands (including agriculture, forest, marshes) affected by the Project account for 394 ha which represent 75% of the total affected land by the Project. Farmers will see their annual income significantly reduced by this land take. Potential impacts According to the Due Diligence Resettlement Survey, carried out in August-September 2008 amongst 105 households surveyed and affected by land take for the Plant site; 50% of the households surveyed have lost more than 60% of their agricultural land, and 36% between 31 and 60%. For 58% of the Households, the remaining land is too small to be viable. Impacts from loss of agricultural land may include:



Loss of annual and perennial crops; Decrease agricultural production due to decrease of agricultural land.

No other land agricultural lands are available in the same commune or the same district to replace all the affected farmers. More than 73% (Plant Site) of the affected people have agricultural activities as their main source on income so the impact on the APs will be very strong. Considering the number of households affected from the loss of agricultural land by the Project and the importance of this economic activity on their income, the significance of this impact is significant for the affected farmers. 3.2.4.7 Loss of forestry land Project activities During the pre-construction phase, some forestry lands are going to be permanently appropriated for the Project. Forestry lands affected by the Project are located in three communes Hai Yen, Mai Lam and Tinh Hai, on Chuot Chu mountains. Forestry lands will serve as borrow pits for the current Project as well as other industrial projects in NSEZ. Permanent forestry lands affected by the Project account for 199 ha which represent 20.6% of the total affected land by the Project. The three affected communes have a total of 800 ha of forest planted lands. Most of the planted forests belong to public owners as Tinh Gia District Forest Company. Potential impacts According to the Due Diligence Resettlement Survey carried out in February 2009 amongst 105 households affected by land take for the Plant site and other infrastructure, only one percent of the Affected Households have Forestry as their primary source of income and two percent as their secondary source of income. On the other hand, the three affected communes will lose 25% of their forestry lands. Since very few households having forestry land as their primary or secondary incomes have been affected by the Project, this adverse impact is assessed as significantly minor. 3.2.4.8 Loss of residential land Project activities During the pre-construction phase some residential lands are going to be permanently appropriated for the Project purposes. Residential lands affected by the Project are located mainly in three communes Hai Yen, Mai Lam and Tinh Hai. Residential lands will mainly be used for the plant site, the marine facilities and the pipeline. The three affected communes have a total of 146.6 ha of residential lands. Residential lands affected by the Project account for 39 ha which represent 8% of the total affected land by the Project. About 90% of APs in the project area have a LURC (Land Use Right Certificate). Some are still waiting for the issuance of the LURC. No APs without any rights on their land have been found.



Potential impacts According to the Due Diligence Resettlement Report prepared in December 2009, around 2,695 HH (9,000 persons) will be affected by the project. Among these APs, 687 will lose most of their land and their main houses and will have to relocate in another location. At the time of the report, clearance already took place in the plant site and APs have been compensated for their productive land. Structures were not yet compensated. Due to the number of households affected by the Project, the significance of this adverse impact is major. 3.2.4.9 Livelihood activities

Project activities Project development implies the loss of agricultural, forest planted and residential lands. Construction of the refinery and petrochemical complex and associated facilities will interrupt the economic activities of households that reside in the Project area and will be displaced but also for families who utilize land and resources that will be acquired for NSRP LLC. Potential impacts Land clearance for the construction of the refinery and petrochemical complex and associated facilities will affect 2,695 households (9,000 persons) including the relocation of 687 households that will be directly affected by economic displacement within the Project area. Most of these households will be permanently impacted by the Project. In the project area, the average HH monthly income is around 4,200,000 VND. It is higher than the average income in the North Central Coast (2,100,000 VND) and for all of Vietnam (3,200,000 VND). However, from an area to another the household income varies from 2,900,000 to 5,700,000 VND. The secondary source of income contributes to around one third of the total average HH income. According to the Department of Labor, Invalids and Social Affairs of Thanh Hoa Province, (DOLISA), those living in urban areas who earn VND 450,000 per capita per month (around 2,500,000 VND/HH/month) or less are considered poor. In rural areas, the threshold is 350,000 VND per capita per month (around 1,800,000 VND/HH/month). Average income in all project areas is higher than the poverty line. One of the main concerned related to resettlement is the ability of the affected households to re-establish household incomes and livelihoods following economic displacement. Most of the project affected people are involved in farming (61%) and aquaculture (13%) which represents their main source of income. 3.2.4.10 Education

Each affected commune has its own primary school. Secondary schools can be found in the district town (Tinh Gia).



Within 3 years from the date of handling over the site to the project, all pupils from primary school to high school who have to move and relocate in the resettlement sites will receive 100% of educational fees and other contributions. So, impacts on education is considered as minor. Children whose families resettled have to change their school. This move is affected to their study. However, from now on, they have more time for study (instead of helping their parents in agricultural works). Adults will recognize that increasing your knowledge is the best way to find out a job so that more and more people will take part in vocational courses. NSRP Project is a lever to develop NSEZ economic therefore NSEZ industrialization develops step by step. Job opportunities are increased gradually for them to do. Kid gardens, schools and vocational centre will be opened to satisfy their studying demand. 3.2.4.11 Disruption/Damage to Infrastructure and Services Project activities NSRP and its contractors will utilize the existing infrastructure and services present in NSEZ. There will be heavy vehicles on national, provincial and district roads coming to the Project Site. Most of the earthworks for site leveling carry out by the NSEZ are on going and will be partly completed when the NSRP will take over the site. Potential impacts Prior to the establishment of the Refinery and Petrochemical Complex, NSRP LLC and its contractors will need to use local infrastructure and services, especially roads and power lines. Since the Project is located within NSEZ most of the infrastructure and services are adequate and can be used for such project. Disruption of existing infrastructures by the Project will adversely cause short term moderate impact to the local population as well as industrial activities (Nghi Son Cement Factory) and Nghi Son Port activities. 3.2.4.12 Gender In accordance with Vietnam’s Law on Gender Equality, effective July 2007, and the recent decree for the implementation of law on gender equality (N70/2008/ND, 4 June 2008), the Project interventions should contribute to promoting gender equity and opportunities for women. Constitution and law of the Socialist Republic of Vietnam has defined gender equity is an important part of social equity. Constitution 1992 has affirmed “All male and female citizens have equalitarian right on every field of politics, economy, society, culture and in the family. All actions of differentiation and abusiveness dignity to the women are strictly forbidden”. Project activities In Viet Nam, females are generally responsible for a variety of tasks related to household as children education, family health, water supply, agricultural activities and income generation.



According to Due Diligence Resettlement Surveys 2008-2009, no significant differences for the level of education, between men and women head of households, have been noticed. Most of men and women have a relatively fair level of education (mainly lower secondary). Few women have been identified as head of households in the Project area. At the local level, the focal role of gender is undertaken by the Women’s Union (WU), there is organizational structure operated widely from central to provincial, district, commune and village levels. The WUs of different levels are authorized to officially represent women's interests and voice in national and local decision-making processes; it receives regular financial support from the state. Women among affected HH are strongly involved in the WU: more than 90% of women surveyed are involved in the WU. Women in the Project area join in all economic activities (agriculture, aquaculture, salty production and forestry). Moreover, they are also responsible for housework and breed cattle for home economics. Potential impacts There are many job opportunities for local women in the construction phase which contributes to improve and keep stable income source. Refinery and Petrochemical Development including associated facilities will result in the residential relocation (or physical displacement) of 687 households (2,800 people). Most of the relocated households are located in Mai Lam, Hai Yen and Tinh Hai Communes. Given their large responsibilities in regard to the family, women will be greatly affected specifically by the relocation of households. 3.2.4.13 Indirect employment and local procurement opportunities Project activities NSRP LLC and its contractors will rely on numerous vendors and service providers to meet the daily operating needs of the Project and also the domestic needs of its employees. In addition, the Project will induce secondary/tertiary economic activity due the immigration of people from outside the Project area who will require housing, food, and other supplies. Potential impacts Construction of the NSRP Project will create a range of sustained indirect economic opportunities at local, provincial and national levels. Local sourcing of goods and services will result in revenues for local businesses and entrepreneurs, provided they can offer sufficient quality and reliability and can meet Project standards, particularly on health, safety and environment. There is a risk that local people could be excluded from direct employment benefits because of low education and technical skill levels. The recent experience from Nghi Son Cement Factory shows that very few local workers have been employed permanently at the site. The Socio-economic survey carried during the Due Diligence Resettlement Survey indicates that more than 70% of the surveyed



households are interested to find a job in Nghi Son economic zone. In the same time, more than 77% of the surveyed households want to be trained to get a new job. The period corresponding to the end of the construction phase and the start of the operation could be difficult for the local communities since the workforce will be reduced by more than 70%. 3.2.4.14 Fisheries In coastal communes and Nghi Son peninsula, most of residents are living by fishery (80-90%). The remaining is salt-making, aquaculture, trading and agriculture. According to the statistical data from local authorities, total fishing boats along coastal areas is given in 3.48.

Table 3.48 Number of fishing boats of coastal communities

No Coastal commune Number of boat/ship Capacity (HP/unit)

1 Hai Thuong 52 6 – 12 2 Hai Yen 6 6 3 Hai Ha 189 40-90 4 Tinh Hai 44 12 5 Nghi Son 217 40-90

Source: Commune’ People Committee, 2009 In Nghi Son commune, there are 479 floating fish-cages (4,780m2) to feed typical fish such as Lutjanus.sp (Ca Hong), Cephalopholis nigripinnis (ca Mu) and Lutjanidae erythropterus (ca Hanh) are in Nghi Son sea area. Potential impact In the construction phase, the marine construction activities of SPM, crude pipeline, harbor, breakwater, intake water, outfall system as well dredging activities will significantly reduce fishing areas and disturb local fishing. The total surface area prohibited for fishing activities is 298 ha at Nghi Son bay. It is noted that the harbor construction will occupy nearshore fishing ground of local fishermen (see figure below). In addition, the project shipping activities for the transportation of construction materials, construction barges at the harbor will increase the shipping density at Nghi Son bay and might interrupt fishing boat access of local fishermen living in Nghi Son commune. The impact level is assessed as medium.

In operation phase, crude oil offloading at SPM and product exporting at jetties will cause long-term impact on local fisheries. Crude oil offloading by offshore pipeline takes at least 24 hours and there are



33 large ships mooring at SPM per year. In case SPM is out of work, crude oil from 300,000 DWT ship will be transferred to 30,000 DWT ship, then led to the harbor. This activity makes number of vessels in this area (from SPM to the harbor) more increase. Appearance of sub-marine constructions such as PLEM and 33.5 km paralleled pipelines may be affected by anchoring of fishing boats or using illegally mines which usually occur in Nghi Son gulf. As designed, intake channel with 350m in width and 70m in length is constructed between two breakwaters. Therefore operation of intake system of the project will not cause any effect to shipping activities in the area. The presence of effluent discharge system on the sea bottom at the distance of 6km far from the shore will not cause effect to shipping activities in the area due to all discharge system is buried under the sea bottom at suitable depth and only discharge outlets are installed at distance of 1m above sea bottom. However, the presence of discharge outlets on the sea bed and marine facilities will decrease 193ha surface water of coastal fishing area. There is no aquacultural activity at project area and location of fishing cages of Nghi Son commune is toward to the south about 5-6km far from project area. Therefore, normal operation of marine facilities, intake and discharge system do not cause effect to aquacultural area. In the case of oil spill occur, it is potential severe impact to shallow water and fishing activities of Nghi Son gulf and the vicinity. The unloading crude at SPM and regular product loading at harbour will cause long tern impact to fishing activity in the area. At Nghi Son gulf, high density of crude and product tankers going in and out of harbour will disturb local fishing boats and cause high potential risk of shipping collision between tanker and fishing boats. The impact level is considered as major and long term. 3.2.4.15 Access restrictions and diversions Project activities The Project will require acquisition of land and access roads used by local communities for daily activities and access to services. Directly affected people will be compensated for the loss of lands, assets and income related to land acquired for the Project; however there will be restrictions to access within the project area during the construction activities. Project construction activities will loss access route connecting from Hai Binh and Tinh Hai to road 513, causing difficulties for local economic development and job opportunities of Hai Binh and Tinh Hai people. These areas of the EZ will not be connected to the center of EZ until new road is built to replace. Potential impacts The Project construction activities will result in changes in access routes in Tinh Hai, Hai Yen and Mai Lam Communes. At least, one of these routes is important for the local population and deserves the centre of Hai Yen, Tinh Hai and Hai Binh Communes, given also access to the south to Hai Thuong,



Hai Ha and Nghi Son Communes. This road is also a short cut to reach Tinh Gia Town, the centre of the district, by reducing the distance by 4 km. Two earth roads given access to agricultural lands for the local population will also be located within the Refinery site. The significance of this adverse impact is major for the local population since they will loss direct access to the centre of their communes and services (school, health centre), affect economic activities along the road (businesses) and increase travel distance to get access to their current economic and social activities. Moreover, it may be quite difficult for the population living north of the Project to get access rapidly to employment for NSRP Project during the construction. There is a positive impact to this situation. The traffic in Hai Binh village should be reduced and especially for heavy vehicle. Road safety should then be indirectly improved in this village. 3.2.4.16 Impact on health Health Impact Assessment is considered for the workers and community as follows:

Workers who work in project’s onshore and offshore Community living nearby the Project.

Mai Lam, Hai Yen and Tinh Hai communes with around 1,582 households will be affected by the project. Among these affected persons, about 1,004 households will lose most of their land and their main houses and will have to relocate in resettlement location. The rest will be impacted by the project activities during the construction phase, Project activities The immigration of thousand of workers for the construction period and construction activities is the main source of health impacts Potential impacts The displacement of those currently living on the site could lead to health impacts associated with disruption to their communities and the loss of agricultural land and the loss of income. The inward migration of large numbers of workers and their family into the area are likely to increase the risks of infectious disease, gastro-intestinal illnesses, injuries, traffic accidents and psychological disorders including stress. There will also be health impacts associated with the greater demands on the area’s infrastructure and the general increase in affluence. The physical processes of construction and operation of the Complex will create impacts on traffic, air quality, waste management and water quality that will in turn result in potential human health impacts. In the absence of appropriate mitigation, the overall risks to health from infectious diseases are likely to be significant for both workers and the local community. The proposed mitigation measures to limit the spread of infection among workers, control vector populations, provide clean water, implement high standards of food hygiene and address the risks associated with STDs will substantially reduce the risks to health. The impact of infectious illnesses on the health of some workers and some members of the local population would still be significant but risks of contracting a serious infectious illness will be low for most individuals.



The non-infectious illnesses arising from the Project are likely to include stress, substance abuse, violence and possible occupational illness. These effects will arise during the construction phase and continue into the operational phase of the Project, at lesser extend, although the exact effects will evolve as the workforce and nature of operations change. Stress, substance abuse and violence are likely to be of greatest importance during the construction phase. These effects will be largely controlled by planned mitigation measures. Some individuals are particularly prone to these types of ill health and although the risks of significant effects are minor for most of the population, they will be moderate for a small proportion of both workers and local residents. 3.2.4.17 Impact on poverty Project activities Poverty levels in the Project area are relatively high. According to The Department of Labor, Invalids and Social Affairs of Thanh Hoa Province, (DOLISA), in 2007, among the 7,704 households in the 5 communes in which there are three effected communes by project, 2,299 (29.3%) are poor households. The poverty incidence has however decreased from 33% to 29.3% between 2006 and 2007. In the whole district the poverty incidence was 26% in 2007. The project is expected to create an average of 22,000 jobs during the construction period and around 33,000 for the peak of the construction period. In addition, the Project will contribute indirectly to create 100,000 jobs in the Project area through business development. These activities will require many un-skill workers Potential impacts The creation of a large number of jobs during construction activities of the Project should contribute greatly to the reduction of poverty not only in the affected communes but also in NSEZ (12 communes) and Tinh Gia District. 3.2.4.18 Economic activities Project Activities The Complex will enhance the development of a series other industries such as production of construction materials, light industry, production of home appliances, transportation, tourism, services, etc., and will create many kind of jobs for 150,000 to 200,000 jobs during the operation period. NSRP will rely on numerous vendors and service providers to meet the daily operating needs of the Project and also the domestic needs of its employees. Project employees will likely enjoy a high income level which will contribute to the demand for local products and services. Potential Impacts The implementation of Refinery and Petrochemical Complex will create a range of sustained indirect economic opportunities at local, provincial and national levels. Local sourcing of goods and services will result in revenues for local businesses and entrepreneurs, provided they can offer sufficient quality and reliability and can meet Project standards, particularly on health, safety and environment.



In construction phase, the Project will create about 20,000 jobs for skilled workers and 3,000 jobs for unskilled worker. Local services such as food, entertainment, accommodation… will also develop to supply for demand of these work force. This is an opportunity for local people to change job from agriculture to industry and other services. In operation phase, NSRP will create 1,000 direct jobs for skilled and unskilled workers. Besides, there will be 650 indirect jobs through contracts between NSRP and service suppliers. In construction and operation phase, NSRP will recruit a number of skilled workers and foreign engineers for operating the plant. However, the quantity of these employees are limitted to ensure creating job opportunities for national and local employees. NSRP LLC commits to strictly obey the Vietnamese labor Law in recruiting project employees and will not recruit non-skilled foreign people for NSRP. When the Project comes into operation phase, it will meet more than 40% of total fuel demand of the country contributing to ensure national energy security and make a foundation for development of petrochemical industry and other services… The Project will contribute to national budget hundreds of million US dollars every year through taxes. 3.2.4.19 Infrastructure and Service Project activities NSRP will utilize the existing infrastructure and services present in NSEZ during the operation. However, most of the import/export activities will be done through the new harbor facilities. There will also be additional heavy vehicles on national, provincial and district roads coming to the Project Site and going to the consumers. Potential impacts The Project will aim to result in no reduction in the quality, quantity or availability of existing local infrastructure. The Refinery and Petrochemical Complex will operate its own power plant as well as water supply and water treatment system. Moreover, NSRP will operate its own port for product export. Importation of oil from Kuwait will come directly from the sea through a Single Point Mooring Station and a pipeline system. Minor adverse impact is anticipated for the operation period due to the increase of traffic on local roads, Provincial Road 513 and National Highway 1A. Improvements to roads and provision of new community infrastructure such as school are expected to offset any long-term impacts associated with infrastructure and services that may arise from the Project.



3.2.5 POTENTIAL ENVIRONMENTAL ACCIDENTS CAUSED BY PROJECT IMPLEMENTATION 3.2.5.1 Fire and Explosion Potential source Fire & explosion risks including the accidental release of syngas (containing carbon monoxide and hydrogen), oxygen, methanol, and refinery gases from process operation will cause serious accident, even catastrophic accidents. Potential sources of fire and explosion of NSRP are identified from as follows:

Process units: CDU, LPG Recovery and Treatment Unit; KHDS, GOHDS, RHDS, RFCC, PPU, SHU and Ind Alk, HMU, HCDS, NAC;

Storage Tanks and pumping system; Fuel gas system; Berth Area; Spheres; Propane loading; Fuel Gas system.

Potential impacts Based on the Coarse Quantitative Risk Assessment (QRA) report for NSRP Refinery and Petrochemical Complex Project - August 2009 [13] undertaken by ABS Consulting Limited, the explosion risk to the workers is dependent on the protection afforded by various building as is thus dependent on building types. All the occupied buildings at this site have very low explosion risk. The over-pressure results are all lower than the anticipated damage from a 10-4 per year explosion scenario. Operator Shelter in the Jetty Area falls within the ALARP range for which mitigation should be considered to reduce the risks to as low as reasonably practicable. All the other occupied buildings are considered to be exposed to negligible risk from fire and explosion events. For the buildings at the site, there are a number of buildings at the site that require risk reduction measures. This includes 13 buildings where risk mitigation must be undertaken and 19 buildings where risk mitigation should be considered, and implemented as necessary, in order to demonstrate that the building’s risk status is ALARP. Even though the explosion risk at NSRP is low, it is recommended that best industrial practice should be used and building classification not be downgraded based on the results of this risk assessment For the societal risks, the village is considered to have approximately 320 dwellings with 5 people each on average. The construction of the dwellings is assumed to be basic, affording little protection from fire or toxic gas ingress. The F-N curve shows that the societal risks to the village population from the NSRP are unacceptable (Figure 3.13).



Figure 3.13 F-N Curve (Road users and villagers) Notes:

The risk levels in the F-N curve are represented as follows: - Red Region: Unacceptable; - Yellow & Green Region: Acceptable according to UK HSE document R2P2 definition; - Green Region: A conservative acceptability criteria used by some companies.

For the local commune to the East of the site (Area C)

The risk to the village population, both in terms of individual and societal is unacceptable. Assuming that the site location has been decided, the risk from the NSRP site to the village population are such that reasonable measures of reducing risks to an acceptable level could be impractical. The Societal risks can be reduced by reducing the population and reducing the frequency and magnitude of hazards from the site. However, the risk assessment here does not take account of the fact that the village is in the middle of wooded area which is susceptible to fire escalation. In light of this relocation of the village to a safer place should be given a serious consideration.

For the Road to the South of the plant (Area B)

The societal risks, excluding the village to the east (Area C) are shown to within the acceptable band of values. This implies that the numbers of fatalities at the road from hazards from NSRP site are not likely to be excessive. However the Individual Risk is greater than the acceptance criteria for the general population and therefore risk reduction measures should be considered where cost effective.

The Location Specific Individual Risk (LSIR) shows that the maximum LSIR at the 513 road area is 5x10-3/year. The occupancy ratio considered for the 513 road is 0.006 based on the traffic moving at 60 km/hour and any one individual traveling twice a day, six days per week across the site on this road. Therefore, the maximum individual risk at the road is 3x10-5/year which corresponds to the ALARP region based on the risk tolerability criteria.



In order to mitigate these risks, NSRP will establish an Emergency Response Plan for different scenarios and mobilize human resource as well as response equipment to avoid/prevent environmental risk and societal risks. When spheres containing LPG and Propylene are in danger, all gases in the spheres will be released and routed to HC Flare system to burn for safe of the Plant. 3.2.5.2 Toxic gas leakage Potential source Potential sources for toxic gas release are from following process units: CDU, SWS, ARU, SRU, RFCC, GOHDS, KHDS and RHDS unit. Potential impact During the operation phase, workers may be exposed to chemical hazards (through inhalation, or contact with chemical or catalysts). The risk of caustic and chloroethane in process may result in occupational health for workers such as personnel injury, cancer, odor nuisance, etc. The chemical hazards during process activities cause Workers’ occupational health.

Based on Toxic Gas (H2S) Dispersion modeling results for the 150mm hole size run by ABS Consulting Limited [Ref.13], the ERPG-2 and 3 contours to the Amine Acid gas on the SRU unit considering a 150mm hole size release is presented in Figure 3.14.

Figure 3.14 ERPG-2 and ERPG-3 Contours to the Amine Acid Gas on the SRU Unit In the case of H2S release at the ERPG-3 on the SRU unit, the health risk distance to project workers is in the range of plant boundary and Coc Mountain. While at the ERPG-2, health risk distance is over plant boundary in the range of 1,702m.



3.2.5.3 Hydrocarbon Spills Potential source When project comes into operation phase, offloading crude at SPM, presence of crude pipeline under sea water, loading refinery products at harbor and shipping activities are the main sources of oil/refined product spills. Following oil spill scenarios are chosen for oil drift modeling:

1. Oil spill at SPM 2. Crude pipeline interruptive 3. Shipping collision at access channel or at harbor area

During the loading/unloading period the tanker will be connected to only one line, meaning that the bow of the vessel will normally always point towards the current. This again means that any oil spilled will go along the hull of the vessel, so any boom formation should be positioned at the stern of the vessel. Also it is essential to have an assisting vessel stand-by with environmental equipment during loading/unloading procedure. The stand-by vessel can, by the use of an anchor or similar, deploy some booms behind the tanker to prevent spreading of the leaked oil. However, a second vessel will normally be required for emergency oil spill response operation. Potential impacts Owing to location of scenario 2 and 3 are very closely to shore and only location of scenario 1 is 33.5 km offshore. So in the case of oil spill occurred, spilled oil will be easy to drift to shore. The detail oil drift modeling result will be mentioned and discussed in separately OSCP report. If oil spill occurred at SPM with Tier II, spilled oil might drift as follows:

In Northeast monsoon (October to March), spilled oil will drift to the shoreline of Nghi Son bay in the first day toward to the south direction (Figure 3.15). All Nghi Son bay will be affected by spilled oil in the first and second day. Spilled oil might drift to Nghe An shoreline at the forth or fifth day depending on wind and wave states.

In the Southwest monsoon (May to July), spilled oil will drift toward the vulnerable resources in

Me island and shoreline of Nghi Son bay in the day 1 and then toward to the North (Figure 3.15). Spilled oil may reach shoreline of Ninh Binh after 4-5 days and Thai Binh shoreline after 8-9days with about 60% of remained oil.



Figure 3.15 Oil drifting in the case of oil spill at SPM in October and July

Figure 3.15 shows that in the case of oil spill occurred at SPM all Nghi Son bay will be affected by oil. The impact level much depends on oil spill tier and response measures. Generally, the main threat posed to living resources by the persistent residues of spilled oils is one of physical smothering leading, in cases of severe contamination, to death through the prevention of normal functions such as feeding, respiration and movement. Some species affected by contacting with polluted marine water surface, are organism living at coastal area, coral reef around Me archipelagoes and floating fish cages aquaculture located in Nghi Son bay.



The amount of recoverable plants and animals after oil spill incident as well as time for environmental balancing depend on the point of time that the incident occurring and its recovery level, as well as the restoring capability of each species. Species has a capability of rapidly reproducing and growing can repopulate an area rapidly when pre-spill conditions are restored, in contrast with slowly growing species which can just recover the quantity after many years. Summary of spilled oil to sensitive marine resource is as follows: Plankton

When oil spill incident happened, polluted oil can directly impact on planktons due to the different oil sensitivity of specific species or indirectly affect on a special species. The coastal area is easier to affect by drifting oil than other areas, in particularly the area where sand and mud are affected by low tide. While plankton (phytoplankton and zooplankton) living in submerged tidal areas are capable to suffer unfavourable conditions in a short time. They can die if affecting by toxic oil compounds or suffocating by oil and emulsions.

This problem will lead to the risk of shortage of natural nutrient resources for aquatic organisms as well as lacking of important food source for aquacultural area by extensive and improvement extensive aquacultures. In addition, many algae and zooplanktons, which are very abundant in this rainy season and used as food for young fishes and shrimps in breeding season, were died or disappeared.

Larvae, Fish Eggs and Young Fish

Contrary to adult fish, larvae, fish eggs and young fish are very sensitive and vulnerable to oil spill. An important caution should be taken into account is that if the incident happened in spawning season of many aquatic species from April to June (Pham Thuoc). At this time, prawn and fish parents usually come to coastal area, in particularly estuaries for breeding. Thus, polluting oil causes serious and permanent damages to prawn and fish ecosystem in the region makes exhaustion the natural post larva and fingerling source in the future.

Benthic

High quantity of suspended solid in water will increase the speed of the oil coagulation and settlement process. Light refined products containing high quantity of toxic substances can affect to mussel, sea urchins and sea worms. The penetration of oil into sediments can cause long-term effects in several years, and is capable to create death and infectious diseases to high economic value species. Oil settlement process can make benthic suffocating.

When being affected by oil, benthic can loose consciousness so that they are removed out of rock surface or drift out their caves. At that time, they are easy to become food for predators, or to drift to unfavourable living conditions areas. The complete recovery of the regular balance can take many years.

Coral reef Oil spills from harbour and access channel will cause major impact to coral reefs, since spilled oil can spread quickly to tidal beaches, floating fish cages and water area surrounding islands. The magnitude of the damage depends on volume of spilled oil. As result, such accident could kill



shrimp and fish. Fishing grounds will be lost or fish will migrate to other area due to oil pollution. Coral reefs and organisms will be serious affected. In the case of oil spills occurs at pipeline route and SPM in the northeast monsoon, spilled oil will cause strongly impact to coral reef at Hon Me islands.

Sea-birds

Sea birds living in this area can be affected at locations where oil drifted in large quantity, but effects will not be serious because almost of sea birds are sea sparrows, a bird species rarely contact with oil spill on the sea surface. However, polluting oil can affect to some kinds of bird living at bayside and estuaries such as storks, herons, etc. because food and the surface are polluted. They would have to eat oil contaminated food or staving to death when staying at this tainted ecosystem.

3.2.5.4 Ship Collision It is important to note that the shipping activities at harbor and access channel in construction and operation phases might cause high risk of ship collision and oil spill. The density of petroleum products is generally lower than that of water, so in the case of product spillage into the sea; the product itself is extremely volatile at ambient temperature and always floats on the surface. Since it is quickly dispersed into the air, the risk of long-term environmental impact to sea water quality will be significant. The detail oil spreading and assessment will be mentioned in detail in Oil spill Response plan. 3.2.5.5 Pipeline Rupture or Leakage The main causes of pipeline rupture and leak are corrosion (internal and external), construction damage, weld failure, incorrect operation, and third damage party like ship anchors and bottom trawls. Although partly pipelines are generally buried and incidents are relatively rare, they cannot be considered as “fit and forget”. Unless inspected and maintained, all pipelines may eventually suffer from leaks or ruptures. Engineering studies have identified 22 types of threat to the integrity of a pipeline, which are recognised in the American engineering code. Grouped into nine threat classes, these are:

External Corrosion; Internal Corrosion; Third Party Damage; Stress Corrosion Cracking; Manufacturing Defects; Construction Defects; Equipment Failure; Incorrect Operation; Weather Related / Ground Movement.

Some of these threats are considered to be time dependent (for instance, corrosion; a small area of corrosion could grow over time to cause a failure) while some are time independent (for example, Third Party Damage; a pipeline being struck by equipment during building construction near an established



pipeline would be characterized as a random event not dependent of the build-up of a condition over time). In the worst case, crude pipeline is broken during unloading crude at SPM. Affected area and impact level are mentioned in item 3.2.5.3. Response scenarios will be presented in separately report of oil spill response plan. 3.2.5.6 Radioactivity There are some activities related to radioactivity such as carrying out NDT (Non-destructive Testing) for tank, bullet, etc. Radioisotopes used by specialist EPC Contractor or Sub-contractors and these activities may cause hazard to employee and public due to exposure to high level of radiation. Activities radioactivity detected flaws of materials are RT (Radiographic Testing), PT (Liquid Penetrant Testing), MT (Magnetic Particle Testing) and UT (Ultrasonic Testing). Radiation exposure may arise to injury or serious illness to workers during the Construction phase. Since it is always carried out by trained and skilled employees, the significance of the impact is considered as moderate. The recommendations made by NSRP are given to EPC Contractor for Handling and usage in accordance with Vietnamese Decree No. 50/1998/ND-CP dated July 16, 1998, Vietnamese Standards (TCVN 6866:2002): Radiation protection – Dose limits for radiation workers and public and Circular No. 04/2008/TT-BLDTBXH dated February 27, 2008 guiding procedures for registration and verification of machines, equipment and supplies subject to strict labour safety requirements. With handling and usage of radioactivity in accordance with Vietnamese regulatory requirements, the residual impact of radioactivity during construction phase is assessed as minor. 3.3 EVALUATION OF DETAILED AND CONFIDENCE LEVEL OF THE ASSESSMENT 3.3.1 Determination of impact significance The assessment considers project-related impacts that are positive, negative, direct, indirect, cumulative, synergistic, reversible, and irreversible. The significance of an impact depends on the intrinsic value of the affected ecosystem component(s) (i.e., sensitivity, uniqueness, rareness, and reversibility) and also on the social, cultural, economic, and aesthetic values attributed to the component(s) by the population. The significance of impact also depends on whether the affected environmental components have already undergone modifications. Impact significance has been established by using the following criteria: The component is recognised by a law, policy, regulation, or official decision (e.g. a park,

ecological reserve, rare or endangered species, habitat for fauna or flora, archaeological site, or historical site);

The risks to the health, security, and well-being of the population;

Magnitude of the impact (i.e., spatial dimension such length or area);

Duration of the impact (i.e., temporal aspect and reversibility);

Frequency of the impact (e.g., intermittent occurrence);



Probability of the impact;

Indirect effect on other components (i.e., link between the affected component and other components);

Sensitivity or vulnerability of the component;

Uniqueness or rareness of the component;

Durability of the component and the ecosystems;

Value of the component to the community This methodology considers the intensity of the impact which integrates the degree of perturbation and environmental value criteria used for determining the intensity and significance of impacts are the following: The degree of perturbation assesses the magnitude of the modifications brought to the structural and functional characteristics of the affected component. The environmental value indicates the relative importance of the project-affected component and reflects both intrinsic and social values.

The significance of impacts considers also the extent of an impact that indicates the distance or relative area over which an impact will apply and the proportion of the component that will be affected, and the duration which specifies the temporal dimension of the impact 3.3.2 Assessment Method Following methods are used for assessment for NSRP project:

1. Statistical method: is used to treat the environmental analytical data, and the meteo-hydrological and socio-economic data;

2. Model method: is used to calculate and stimulate the air emission processes, the wastewater and the thermal dispersion caused by project activities. Some mathematic models are used for preparing this report including:

To assess air quality, the Atmospheric Dispersion Modeling System (ADMS) from CERC (Cambridge Environmental Research Consultants) with the UK Meteorological Office, National Power plc and University of Surrey is used by FWL. The first version of ADMS was released in 1993 and the current model is ADMS version 4.

To assess thermal effects to Nghi Son Bay seawater, US Environment Protection Agency’s CORMIX model has been used by FWL.

To assess explosion risk to the workers and community, Fire risk (BLEVE) model is used to predict to affect the neighboring village. Coarse Quantitative Risk Assessment (QRA) has been undertaken by ABS Consulting Limited for NSRP Refinery and Petrochemical Complex Project.

To assess oil spill effect in the Nghi Son bay, an oil drifting model is undertaken by CPSE to calculate different oil spill scenarios from project marine facilities.

To assess dredged material dumping by used mud and fluid dispersion model of Kverner Engineering A.S, Environmental Sandefjord, Norway. This model is carried out by CPSE for maintenance dredged material dumping every 4 years.

3. Field survey and measurement method: is used to take samples, measure on site and analyze at the laboratories (air, water, soil, sediment and biology samples) at the project area. Moreover,



this method is used to survey vegetation cover, take the photographs and interview in the field trips for colleting the existing environmental and socio-economic situation;

4. Social investigation method: is used to interview the authorities, departments and local residents at the project area;

5. Comparative method: is used to evaluate environmental quality of air, soil, water, sediment, and biology on the basis of comparison with current Vietnamese and International environmental standards.

Above methods are used in order to quantify environmental characteristics of the project area as well as forecast impacts of air emission, wastewater and cooling water discharged to receiving environment. Confident level of these methods can quantitative evaluate during project implementation. Almost Environmental impacts and risk assessments for NSRP are quantified by calculating and modeling based technical data and surveyed studies.



Section 4. MITIGATION MEASURES FOR NEGATIVE IMPACTS, PREVENTION & RESPONSE ENVIRONMENTAL INCIDENTS

4.1 MITIGATION MEASURES IN FEED DESIGN PHASE To ensure safety for local community and labour force working in the Plant; create good condition for operation phase and maintenance process; reduce risk and mitigate negative impacts in case of incident, etc. NSRP-LLC has considered energy saving technology as well as plot plan philosophy in optimum way and measurements as follows:

Ref. No. Mitigation measures

1. Apply saving energy technology

FT1

Energy recovery:

Preliminary heater to recover heat from off gas;

Air preheater

Pressure recovery turbine

Low grade heat recovery

CDU pinch analysis

FT2

Heat integration

Hot rundown (charge)

Inter-unit integration

FT3

Energy conservation equipment

High efficiency H-Ex

Variable speed motor

FT4

Others:

LLP off gas recovery system

H2 recovery from off Gas

Apply common facilities

2. Safety

FS1 Plot is planned in accordance with main wind direction. Administrative and control houses are not put at the downwind direction in comparison with process areas in order to avoid toxic substances generated from these areas.

FS2 Process units having high temperature and pressure are arranged at centre positions of the Refinery to mitigate negative impacts on local community.



Ref. No. Mitigation measures

FS3 The facilities which need the chemical or catalyst on stream should be located along to the road to be able to access the vehicle easily.

FS4 Administrative and product export area will be located in front of provincial road 513 in order to transport easily without passing through the Refinery area.

FS5 Crude oil and product tanks should be located in the North-East direction of the Refinery to reduce pipeline length between tanks and from SPM/harbour to tanks.

FS6 LPG tank should be located far from process unit to reduce fire & explosion risk.

FS7 Flare systems are designed to burn all maximum amounts of HC and acid gas in case of incident. Height of the flare is 180m and enough to keep thermal radiation in range of the Refinery in emergency case.

FS8 Road is built around process area for access of fire truck.

3. Environment

FE1 Apply energy saving technology to reduce amount of green house gas.

FE2 Emission gas generated from process units and sphere tanks will be burnt in the flare in order to avoid releasing directly into environment.

FE3 Guard basin is built to contain maximum effluent for 6 hours fire fighting or wastewater for 24 hours in case of incident in ETP to reduce negative impacts on environment.

FE4 SPM should locate far from Hon Me island and crude oil pipeline is sited in the North of this island to mitigate impacts in construction phase and oil leakage.

FE5 Plants will be grown around the Complex and some suitable locations so that green area must be at least 10% of total Project area in accordance with Vietnamese Standards

4.2 MITIGATION MEASURES FOR ONSHORE FACILITIES (REFINERY AND

PETROCHEMICAL COMPLEX AND SUPPORTED FACILITIES) 4.2.1 Construction Phase NSRP-LLC has prepared project HSE policy and conducted all mitigation measures during construction phase to minimize adverse impacts in construction phase on environment and social economic activities of local people. Mitigation measures for separated objects are shown in following sections. 4.2.1.1 Air Quality Air & dust emissions during the construction phase will be minimized by implementing the following measures:

Ref. No. Mitigation Measures

CA1 Daily water spray road and site of the Complex to reduce dust;

CA2 Usually sweep rock/soil litered in material transport road;

CA3 Introduce a site speed limit (20 km/h) to trucks and other vehicles for reducing dust;

CA4 Well ventilation for working areas created dust and exhausted gas such as welding, paint spraying, warehouse and supply safety individual equipment suitable for workers as hamlets, masks, protective clothes…




CA5 At paint spraying area, workers must be equipped with specific protective clothes, anti-toxic mask and oxygen cylinder in special case;

CA6 Do not use chemicals containing forbidden substances, such as asbestos;

CA7 Choose worldwide used paint to ensure that VOC content meet national and international requirements;

CA8 Low sulphur fuels to be used for vehicle;

CA9 On-site roads to be paved with dust free material to reduce dust generation;

CA10 Paving roads between washing facilities and site exits;

CA11 Cover materials of all free dusts during off-site road haulage;

CA12 Road maintenance; grading and compacting road surfaces to prevent uneven running surfaces, which create both noise and dust;

CA13 Install wheel washing facilities at appropriate positions from the site entrance within site boundary;

CA14 Limit vehicle age and/or condition and vehicle maintenance to reduce fuel use and poor air quality due to vehicle emissions;

CA15 Routing haul routes away from sensitive areas (schools, protective forest, etc.) wherever possible;

CA16 Ensure that dust generation from construction roads is managed; control conformity of covering canvas over material transport vehicles, speed limit and water spraying on transport road;

CA17 No open burning of wastes to be undertaken;

CA18 Take proper measures for polishing tank surface to reduce dust problem. Limit use sand spraying method.

4.2.1.2 Noise and vibration Noise generated from construction equipments will directly affect to health of construction workers and nearby communities. Impact level is assessed as moderate but uninterrupted during working process. The following mitigation measures will be applied:


CA19 Notify Hai Yen, Mai Lam and Tinh Hai residents prior to commencement of the construction phase. The notification should include the type of works being undertaken, the duration of the proposed works and a contact address as necessary;

CA20 Ensure that all Contractors on site have effectively controlled noise levels from equipment. Effective noise controls include:

Regular inspection and maintenance all vehicles and construction equipment working on-site;

Installation of sound suppressive devices (such as mufflers) on all mechanical plant as necessary;

Where practicable, vehicles and machinery that are used intermittently should not be left idling for long periods of time

CA21 Excessively noisy activities will be conducted between 6:00am – 18:00pm if they are likely to cause any nuisance to local residents;

CA22 Equipment used on-site will be the quietest reasonably available;




CA23 Equip ear-protection devices for workers at working site.

CA24 Haul routes for construction traffics entering and leaving the site will be selected to ensure noise levels at noise sensitive receptors are kept at a minimum;

CA25 Enforce speed limits in relation to road conditions and location of sensitive receptors (such as schools, population areas, etc.);

CA26 The adjacent residents will be notified prior to any noise events or noisy operation outside 6:00am – 18:00pm from Monday to Sunday

4.2.1.3 Soil quality Solid wastes generate from construction activities might cause impact to soil quality. Following mitigation measures are proposed including:


CB1 Construction wastes will be handled and disposed of in accordance with Governmental Degree 155/1999/QĐ-TTg (16/7/1999) on hazardous wastes management regulations.

CB2 Waste storage area should not be located near sewer or outfall system to avoid cause air pollution and generate odour;

CB3 Temporary storage of wastes at site designated areas. Hazardous wastes to be fully contained and stored undercover within retention bunds in order to avoid any leakage into the area; Hazardous solid wastes must be collected to labeled drums named “Hazardous wastes” and stored in temporary roofing storage house inside the complex boundary before transfer to treater who has given license of treating hazardous wastes.

CB4 Provide documentation in detail with dates of delivery and quantities of consignments, as well as instructions on the safe storage, use, collection and disposal of materials and waste products prior to transfer to the disposal places in accordance with Governmental Degree 155/1999/QĐ-TTg (16/7/1999);

CB5 Put waste baskets at each constructional section with at least 3 differrent coloured and labelled baskets to collect hazardous waste, non-hazardous construction wastes (Iron, steel, wooden ends, etc) and domestic waste at construction site;

CB6 Restrict access to hazardous waste storage area.

CB7 Minimize generated wastewater and reuse as much as possible. Minimize using Hazardous chemicals; segregated and stored in secondary containment.

CB8 Conduct refueling in designated area with secondary containment as far as practicable.

CB9 Where in-situ refueling required, follow procedures to reduce spillage.

CB10 Environmental awareness training compulsory for site construction workers.

CB11 Material Safety Data Sheets will be provided for all hazardous materials, in both English and Vietnamese languages, and stored or displayed in appropriate locations.

CB12 Access to hazardous materials will be restricted and notification of volumes and routine inspections of storage facilities will be made.



The waste will be separated into hazardous and non-hazardous: 1. Hazardous wastes Hazardous wastes generated during construction phase such as: paints, solvent, oil filter end, residue oil, waste oil, welding rods, etc. will be collected and stored in the special safety drums which are marked clearly to stringent controls. Beside, the project owner will strictly control contractor to ensure that collection, transportation and treatment measure are complied with Vietnam regulation as well as project standard. Detailed hazardous waste management & treatment of each source during construction phase is summarized in Table 4.1.

Table 4.1 Hazardous waste management & treatment during construction phase

No. Waste type Estimated quantity

(Ton/year)

Handling, storage, and transportation

Treatment and disposal

1 Engine,

Transformer oil

6

To be collected in to drums, labeling, and transfer to designated Hazardous waste storage area prior to offsite transportation to approved / licensed Lube oil recycling agencies.

Hire for used lube oil recycling through approved /Licensed Lube Oil Recycling Agencies. Requirements of Basel Convention to be followed in case of transboundary movement of wastes.

2 Waste fuel 1

To be collected in drums/tanker, labeling and transfer to designated hazardous waste storage area prior to offsite disposal to approved Units/ Plants (e.g. cement manufacturer, etc.) having adequate facilities to utilize NSRP waste oil/ tarry material/

In-house use or offsite disposal to approved Units/ Plants (e.g. cement manufacturer, etc.) having adequate facilities to utilise NSRP waste oil/ tarry material/ sludge without causing any harm to environment

3 Oil filters 3

To be collected in to HDPE bags/ drums, labeling, and transfer to designated Hazardous waste storage area prior to offsite transportation to approved / licensed Hazardous waste treatment and disposal facilities

Appropriate treatment of Hazardous waste e.g. Incineration, etc., followed by suitable landfill both through approved/ licensed Waste Management Facility

4 Empty

chemical drums

2 Labeling, drums to be transferred to designated hazardous waste storage area prior to offsite disposal.

In-house use or offsite disposal to approved Used Drum Handling Facilities with adequate facilities to decontaminate drums prior to its further use

5 Waste lube oil 2

To be collected in to drums, labeling, and transfer to designated Hazardous waste storage area prior to offsite transportation to approved / licensed Lube oil recycling agencies.

Hire for used lube oil recycling through approved /Licensed Lube Oil Recycling Agencies. Requirements of Basel Convention to be followed in case of transboundary movement of wastes

6 Cooking oil 12

To be collected in to drums, labeling, and transfer to designated domestic waste storage area prior to offsite transportation to approve / licensed cooking oil recycling or incineration agencies.

Hire for used cooking oil recycling through approved /Licensed Oil Recycling / incineration Agencies




(Ton/year)



7 Dry Batteries e.g., Li, Cd,

batteries <1

Used dry battery waste (Ni, Li, Cd,) to be separately collected in plastic bag, labeled and stored in a designated storage area or Hazardous waste storage area.

Waste to be disposed to approved recycling or hazardous waste disposal facility

8 Lead acid

Batteries/ acid 2

Wet/ Lead acid to be separately collected in puncture resistant plastic bag / drums, labeled and stored in a designated storage area or Hazardous waste storage area

Waste to be disposed to approved Lead acid battery recycling or hazardous waste disposal facility

9 Medical

/Clinical/ First aid waste

2

Medical waste to be collected in plastic bag labeled and sealed. Sharps to be placed in puncture resistant container Both container/ bag to be stored under control of medical staff

Medical waste to be incinerated at approved medical waste incineration facilities and incineration ash to be disposed to the licensed / approved secured landfill facility.

10

Solvents/ paints/ thinner

residue

3

Paint residue or dried paint/ thinner to be collected in waste storage containers/bag, labeled and stored at designated storage or Hazardous waste storage area

Waste to be disposed to approved Hazardous waste disposal facility

11 Sealants/ mastic 1

Waste to be collected in waste storage containers/bag, labeled and stored at designated storage or Hazardous waste storage area.


12 Spill

absorbents 2

Spill absorbent (contaminated with hazardous material) waste to be collected in waste storage containers/bag, labeled and stored at Hazardous waste storage area


13 Polluted soil 10

Contaminated soil waste to be collected in waste storage containers/bag, labeled and stored at Hazardous waste storage area


14 Asbestos

scrap/waste

Asbestos scrap/wastes to be collected in waste storage containers/bag, labeled and stored at Hazardous waste storage area


15 Used

Fluorescent tubes

< 2

Used fluorescent tube to be collected in puncture resistant container, labeled and stored at area designated for its storage

Waste to be disposed to approved waste land fill facility

16 Aerosol

containers/ cans

< 1

Empty /used aerosol cans to be collected in a puncture resistant container, labeled and stored at area designated for its storage

Waste to be disposed to approved waste land fill facility

17 Used smoke

ionic detectors < 1

Used smoke detectors to be collected in a separate container, labeled and stored at area designated for its storage

Waste to be disposed to supplier or through approved smoke detector waste disposal facility




(Ton/year)



18 Used Photocopy cartridges

< 1 Used cartridge to be collected in a separate container, labeled and stored at area designated for its storage

Waste to be disposed to supplier or approved waste disposal facility

19 Oil residue, cotton waste, rags, etc.

4


Appropriate treatment of Hazardous waste (e.g. Physical, Chemical, Biological or thermal oxidation, etc.) followed by suitable landfill both through approved/ licensed Waste Management Facility

20

Waste residue from air

conditioner /refrigerator

1



21 Pigging waste pipe cleaning

1



22 Contaminated

insulation material

5



23 Laboratory waste

1

Laboratory waste to be collected in separate puncture resistant bags/drums, labeled, and stored at designated storage facility near laboratory or at Hazardous waste storage area


24 Radioactive

waste < 1

To be carefully collected in to HDPE bags/ drums, labeling, and transfer to designated Isolated radioactive waste storage area prior to offsite transportation to approved / licensed radioactive waste disposal facilities

Used radioactive equipment / waste to be transported back to supplier for safe disposal of the radioactive material. Transportation and disposal to comply with national and international requirements pertaining to radioactive waste management.

25 Chemical

contaminated PPE

12

Used PPE (contaminated with hazardous material) waste to be collected in waste storage containers/bag, labeled and stored at Hazardous waste storage area




2. Non-Hazardous wastes During construction phase, solid wastes will be collected and stored in temporary landfill at the site. Depending on characteristic of each kind that will be treated suitably. The Non-Hazardous wastes management and treatment method during the construction phase is summarized in Table 4.2.

Table 4.2 Non-hazardous wastes management and treatment during the construction phase


(Ton/year) Handling, storage, and transportation Treatment and disposal

1 Insulation,

mineral -glass wool

15

To be transferred to the designated Non Hazardous waste storage area prior to offsite transportation to approved / licensed recycling agencies / scrap dealers

Disposed off to licensed waste recycling facilities. Non Hazardous waste landfill incase of non availability of waste recycling facilities

2 Scrap Metal -

Iron, Aluminium 100


Disposed off to licensed waste recycling facilities.

3 Cable drums 100


Disposed off to licensed waste recycling facilities. Non Hazardous waste landfill incase of non availability of waste recycling facilities.

4 Cable scrap 20


Disposed off to licensed waste recycling facilities. Non Hazardous waste landfill incase of non availability of waste recycling facilities

5 Tyres 15 Used tyres to be stored at area designated for its storage or at non hazardous waste storage area

Waste to be disposed to approved scrap dealers or inert waste disposal facility

6 Plastic bottle,

containers 3

Plastic waste to be collected in puncher resistant bags/ drums stored at area designated for its storage or at non hazardous waste storage area


7 Concrete waste 75

Concrete waste to be collected and stored in designated area or non hazardous waste/ inert waste storage area. Explore possibility to reuse concrete waste as filler or for grading/ land leveling

Wastes to be reused or landfilled in the approved inert waste landfill facility

8 Grit (construction & surface polish)

100

Grit waste to be collected and stored in designated area or non hazardous waste/ inert waste storage area. Explore possibility to reuse waste as filler or for grading/ land leveling


9 Glass wool 15

Insulation waste to be collected and stored in designated area or non hazardous waste/ inert waste storage area. Explore possibility to reuse waste as for other insulation purpose


10 Packaging

waste- Card board

50

Insulation waste to be collected and stored in designated area or non hazardous waste/ inert waste storage area. Explore possibility to reuse waste as

Waste to be disposed to approved scrap dealers / recyclers




(Ton/year) Handling, storage, and transportation Treatment and disposal

for other packaging purpose

11 Packaging

waste- wood 300

Insulation waste to be collected and stored in designated area or non hazardous waste/ inert waste storage area. Explore possibility to reuse waste as for other packaging purpose


12 Packaging waste

- Thermocol 20

Insulation waste to be collected and stored in designated area or non hazardous waste/ inert waste storage area. Explore possibility to reuse waste as for other packaging purpose


13 Drums (uncontaminated) 4

Used drums to be stored at area designated for its storage or at non hazardous waste storage area. Explore possibility of reuse of the drums

Waste to be disposed to approved scrap dealers or drum disposal facility

14 Glass 40

Used waste to be collected in puncher resistant bags/ drums stored at area designated for its storage or at non hazardous waste storage area


15 Paper waste 150 Office paper waste from shredding collected in plastic bags to be stored at area designated for its storage

Paper waste to be disposed to approved Paper waste recycling agency

16 Office furniture 5 Used waste to be stored at area designated for its storage


17 Office electronic wastes

5 Used electronic waste to be collected in a separate container, labeled and stored at area designated for its storage

Waste to be disposed to supplier or approved electronic waste disposal facility

18 Laboratory waste 2

Laboratory waste to be collected in separate puncture resistant bags/drums, labeled, and stored at designated storage facility near laboratory or at Non hazardous waste storage area

Waste to be disposed to approved inert waste disposal facility

19 Compostable

food and canteen waste

>10,000

Waste to be collected in domestic waste bins. To avoid unhygienic /septic condition/odour nuisance, the waste to be collected and disposed on periodic (at least daily) basis

Domestic waste to be collected and disposed as food for cattle or to approved/licensed municipal landfill /disposal facility

20 Domestic wastes 70

Waste to be collected in domestic waste bins. To avoid unhygienic /septic condition/odour nuisance, the waste to be collected and disposed on periodic (at least daily) basis

Domestic waste to be collected and disposed to approved/licensed municipal landfill /disposal facility

21 Domestic sludge 50 Sanitary waste /sludge to be collected and disposed on periodic basis

Sanitary waste to be collected and disposed to in house incineration facility or approved/licensed offsite municipal landfill /disposal facility

22 Used PPE (uncontaminated) -

Waste to be collected in separate bags/drums, labeled, and stored at designated storage facility or at Non hazardous waste storage area




4.2.1.4 Surface water The following mitigation measures will be applied to reduce the impact on sea water quality from construction of intake water and outfall effluent system, Cleaning and Hydrotesting after completing installation tankage system and in plant pipeline system, stormwater and domestic wastewater:

Ref. No. Mitigation measures for surface water

1. During constructing intake water and outfall system

CC1 Notify the process, working sites, implementation duration of the marine harbor to the local Authorities and fishermen. Set up a restricted area for the working site by using buoy system and signal-lamp (at night) to restrain the collision incident/accidents.

CC2 Select suitable trenching method in order to reduce seabed disturbance at the Nghi Son Bay;

CC3 Install concreted barrier to protect the head of outfall system;

CC4 Collect solid waste onboard, absolutely avoid discharging solid waste to sea water.

2. Cleaning and Hydrotesting

CC5 No discharge of contaminated effluents.

CC6 Reuse hydrotest water to limit generated wastewater. In the case of have to use, select less toxic chemicals which are listed in Annex 1 of the Guideline of chemicals using and discharge of Petrovietnam.

CC7 Treat cleaning and hydrotesting water before discharge:

Separate solid residue and oil generated in construction and tanks and pipeline installation phase;

Treat chemicals in temporary neutralization tanks at tankage area.

CC8 Do not discharge treated hydrotest water onsite. it should be discharged into the sea as far the shore as possible;

CC9 All other contaminated effluents from commissioning will be treated through on-site effluent treatment plant.

CC10 If wastewater is treated at other area, it should be removed oily residues and reduced turbidity prior to transport.

3. Storm water Discharge

CC11 A storm water collection system will be installed throughout the worksite to minimise soil erosion and reduce turbid water discharge to the nearshore area.

CC12 A storm water drainage system in trapezium shape will be installed in the Northern site to outlet safely total amount of runoff water to avoid flood for surrounding community; Runoff water in the Southern site will be routed to drainage system along provincial road 513 built by NSEZ;

CC13 Dyke around the site to control storm water to reduce over flow to the environment directly

4. Sanitary Wastewater Discharge

CC14 Treat sanitary wastewater to satisfy QCVN14:2008/BTNMT

CC15 Build temporary water closets at the site to collect and treat preliminary domestic wastewater generated in this phase;



Ref. No. Mitigation measures for surface water

CC16 Contract with local Environmental Sanitation Company (in Nghi Son or Tinh Gia District) to periodically suck septic tanks at construction and camping site and treat properly in accordance with in force regulation;

CC17 Do not discharge sanitary effluent to Lach Bang river. Treated sanitary wastewater shall then be routed to the sea via an outfall pipe at the location of adequate dilution and dispersion of effluent.

CC18 Regular monitoring of effluent from the construction site will be undertaken to ensure treatment efficiency.

4.2.1.5 Groundwater Sources causing effects to groundwater resources are from sanitary and cleaning and hydrotesting discharge, the following mitigation measures are proposed:


CC19 Control cleaning and hydrotesting process and quantity of chemicals used. Monitor discharging process;

CC20 Control and monitor sanitary discharge process;

CC21 Monitoring groundwater quality after construction phase.

4.2.1.6 Ecosystem Some following mitigation measures are proposed to reduce the impact on terrestrial ecosystem.


CD1 Vegetation clearance in construction period of pipeline and harbour site should be reduced as much as possible;

CD2 Prevention of trespass and hunting by staff and contracted personnel.

CD3 Plant green trees around the complex area and along onshore pipeline and some areas in the Complex (see Figure 4.1) in compliance with Vietnamese regulation on green area (not less than 10% of total project area).


Figu

re 4

.1 G

reen

are

a in

the

Com

plex

– N

SRP




4.2.1.7 Safety for the workers Working accidents in construction phase mainly concern with traffic, machine operation and faults caused by human. In order to keep safety for the workers in this phase, NSRP-LLC will ask EPC Contractor apply following mitigation measures:


CE1 Instruct employees to utilize equipments in construction activities (materials, lifting technique and limit weight);

CE2 Limit load/unload, transport heavy goods by hand;

CE3 Choose tools and arrange working area to reduce effort and time;

CE4 Clean usually wastes and overflow effluents in construction site;

CE5 Use anti-slipped boots;

CE6 Put barriers around deep area to avoid to fall down;

CE7 Train workers to use protective equipments properly as well as fall prevention system;

CE8 Set up procedures for working in height, fall prevention plan and fall down first aid;

CE9 Manage and use radioactive substance in accordance with regulations of Vietnamese Law

CE10 Use control and monitoring system to protect workers in dangerous cases;

CE11 Safely manage wastes with slide gutter system and assigned disposal area;

CE12 Avoid to generate splinters when operate/control heavy devices by clear the traffic road;

CE13 Evacuate workers out of construction site when carrying out explosion activity (mines, bombs…);

CE14 Equip appropriate protective clothes (safety glass with blanket, hard helmet and protective boots);

CE15 Develop traffic management system to minimize potential risks, such as isolate transport road area, limit speed, set up one way route…;

CE16 Ensure vision for workers when working or passing areas having heavy machines in operation; instruct workers how to test and protect eyes;

CE17 All mobile equipments have sirens with suitable volume;

CE18 Check and maintain carefully lifting equipments (cranes…)

CE19 All workers should be trained about industrial safety before working in limited spaces;

CE20 Apply work permit for all workers, supervisors in construction area;

CE21 Implement preventive measures such as breathe support devices, lifeline, monitoring station to observe safety for workers with first aid and rescue tools);

CE22 Personnel protective equipments must be available and enough;

CE23 Provide clothes used in humid weather for all workers;

CE24 Workers should be check for health before entering working site, especially those doing heavy work or in dangerous area;

CE25 Keep roads from construction area to camp site safe and clean in bad weather condition;

CE26 Prepare high capacity pump system enough to pump rain water out of flooded area.



4.2.1.8 Water way and road traffic

Ref.No. Mitigation Measures

Water way traffic

CF1 Arrange reasonably berthing schedule for materials and construction equipments transport ships to avoid to slow down the Project progress and water way traffic in local area;

CF2 Inform local authority and community about pipeline and SPM installation schedule to avoid high density traffic;

Road traffic

CF3 Arrange reasonably operation schedule and number of transportation vehicles for materials and construction equipments to avoid local traffic jam. Limit to transport in rush hours.

CF4 Choose reasonable transport route and avoid away from heavy traffic roads;

CF5 Loading/unloading materials activities must be acted as quick as possible to avoid traffic jam;

CF6 Project emergency response plan should include case of traffic accident occurring outside of the Project area;

CF7 Implement strictly safe driving for whole company, all contractors and local community;

CF8 Implement propagandize safe traffic for workers;

4.2.1.9 Mitigation measures for natural calamity To ensure safe for all persons taking part in the Project, the Project owner has prepared health, safety and environment (HSE) plan to manage project activities and asked contractors comply with:

HSE standards for Contractors;

HSE plan at construction site;

Requirements on escape in emergency cases;

Requirements in construction activity in storm and heavy rain weather;

Requirements in construction phase;

Requirements on temporary works;

HSE and security guidelines for Contractors. Before implementing activities in construction site, EPC Contractor must submit NSRP all safe procedures in detail for approval. EPC Contractor should be aware of incidents caused by earthquake, storm and rising sea water level to prepare mitigation and repair measures. Calamities cause damages not only for materials but human lives. Therefore, NSRP-LLC will require EPC Contractor apply some following measures to mitigate negative impacts of calamity and storm/flood.



Ref.No. Mitigation Measures

CI1 Actively protect working sites and implement safe measures for under construction site in case of being forecasted of storm;

CI2 Assign storm watch-men to receive incident information;

CI3 Prepare plan, alternatives and measures to ensure construction schedule progress, safe for dyke, intake channel and not causing effects on residential area, production units (inside/outside of project area), minimize damage in case of flood, storm, tide, heavy storm or other calamities;

CI4 Check drainage system of construction site to sure that rain water is not stagnant causing flood in construction area and it vicinity;

CI5 Check electricity supply system served for construction; Shutdown electricity system during storm/flood to ensure safe.

CI6 Co-operate with local authority and people to prevent calamity and response incidents if necessary;

CI7 Get necessary response force ready (communication, person, response tools…) in case of incident;

CI8 Prevent rascals in unusual weather condition.

4.2.2 Operation Phase 4.2.2.1 Air Quality In operation phase, environmental target of NSRP is to comply with project standard mentioned in Section 0 - Item 0.2.3.3 which complies with national standards and WB/IFC requirements including:

Treating generated flue gas (FG) to meet allowable of project standard at discharge points; Ensure the dispersion ability of FG to meet as ambient environment standard; Using technical solutions. Ref. No. Mitigation Measures

Air emission from point source

OA1 Apply FGD system by sea water scrubbing for the flue gas from boilers

OA2 Provide De-NOx and De-SOx system for RFCC;

OA3 The stack heights have been defined based on emission of SOx, NOx, CO and PM10 and will be verified by air emission model to confirm that ambient ground concentration of pollutants always meet standards and guidelines of ambient air quality;

OA4 Provide Low-NOx burners for SRU, Gas turbines, CDU, ETP incinerator, RHDSs, NACs, KHDSs, GOHDS and Ultra-low-NOx burner for HMU;

OA5

Establish and maintain continuous emission monitoring system (CEMS) at following discharge source:

FGD / Boiler stacks – For SO2, NOx and PM RFCC Co Boiler stacks– For SO2, NOx and PM Gas turbine stacks – For NOx

OA6 Monitor (every 6 months) of ambient air quality for NOx, SOx and PM in the upwind and downwind directions




OA7

Provide vapor recovery system in the tankage farm and balancing system for Jetty area;

Provide closed system for dedicated collection of benzene contaminated water to prevent atmospheric emission of benzene;

Provide flow balancing system for dedicated collection of spent caustic effluent to prevent atmospheric emission of H2S;

OA8 Closely controlling liquid product loading/unloading processing to minimize product leaking and spillage incidents.

OA9 Install leakage detector, spillage control equipments and emergency shut-off valves at closing magnetic type to prevent leakage/spillage at fuel storage tank area.

OA10 Provide fire and gas preventing and fighting system;

OA11 Maintain two sets of portable stack testing equipment for NOx, CO, SOx and HC emissions from combustion sources that do not have CEMs;

OA12

Consider deploying a mobile ambient air quality monitoring station capable of measuring ground level concentrations of NOx, SOx and total hydrocarbons at a minimum, along with limited meteorological parameters such as wind speed, direction, temperature, humidity and rainfall.

For Flue Gases Desulphurization (FGD) To reduce the concentration of SO2 from the NSRP utility boiler flue gases prior to a stack and discharged to atmosphere, the FGD technology is selected based on a sea water scrubbing. Seawater is used to scrub SO2 from flue gases, using the bicarbonate content of the seawater as a reagent. Sulphur dioxide would be contacted with a “once-through” flow of seawater in a tower and the resultant liquor would be contacted with additional seawater and aerated to convert the sulphur content of the resultant liquor to sulphate. Sea water is pumped from a pump basin into a packed scrubber tower where the SO2 contained within the flue gas is contacted with and removed in the sea water to produce a stack emission from the scrubber which complies with regulatory limits. The waste water from the scrubber tower is then treated in a SWTP before being routed to the sea outfall. Sea water FGD has synergies when used in conjunction with sea water cooling due to utilisation of common facilities i.e. Sea water intake, pumping and outfall. The general scheme is shown in Figure 4.2. Beside the desulphurization, a large of dust will be rejected together SOx in flue gases flow.



Figure 4.2 FGD Sea Water Flow Schematic Pollutant contents in emission gas and wastewater before and after treated in FGD are presented in Table 4.3 and Table 4.4.

Table 4.3 Content of air pollutants in input and output emission gas of FGD

Pollutant Input

(mg/m3) Output (mg/m3)

Project Standard (mg/m3)

SOx 1,591 65 200 Particulate 170 20 50

Table 4.4 Content of pollutants in input and output waste water of FGD

Pollutant Input (mg/l)

Output (mg/l)

Project Standard * (mg/l)

DO 6 5 >4** COD 2.1 SW+5 90 TSS 13 SW+1 30 pH 7.2-7.5 6 (min) 6-9

Source: NSRP-LLC, June 2010 Note: (*) Project Standard on industrial waste water

(**) Coastal sea water quality Treatment principle of FGD is based on chemical reactions (*) as followings:

SO2 (gas) + H2O → SO32- + 2H+ absorption (1)

SO32- + ½O2 → SO42- oxidation (2)

HCO3- + H+ → CO2 + H2O neutralization (3)

(Note: * above chemical reactions are referred from Document 3550-8110-RP-0022 provided by FWL)



In reaction (1), SO2 is absorbed by sea water and reacted with oxygen to form Sulphite and Hydro ions. Increase of Hydro ion concentration make acidity increase and pH decrease. In reaction (2), SO32- ion combines with oxygen to form Sulphate ion. Therefore, Chemical Oxidation Demand (COD) will be mainly affected by SO2 concentration. Sea water continues to be oxidized to acceptable DO level in water environment before discharge. In reaction (3), bicarbonate ion in sea water will react with Hydro ion, so acid neutralization affects sulphur absorption and pH increase. Advantage of FGD treatment system is to create dissolvable salt (Na2SO4 and MgSO4). For RFCC off-gas De-SOx and De-NOx system Off-gas from RFCC CO boiler will be removed SOx and NOx before released by following treatment technology: De-SOx unit: apply SOx absorption method with humid sodium. SO2 in emission gas will react with NaOH** to

create Natri Sulfite and Natri Hydrosulfite.

2NaOH + SO2 →Na2SO3 + H2O Na2SO3 + H2O + SO2 → 2NaHSO3

Note: ** above chemical reactions are referred from documents of Regulations and New Pollution Prevention Technology issued by Japanese Environmental Management Association in industrial section, published in 2008.

After absorbed SOx, wastewater will be routed to ETP for further treatment.

De-NOx unit: apply SOx absorption method with NH3 and catalyst (stable catalyst layer). NH3 is sprayed on off-gas

stream, and then NOx will be converted into N2 and H2O by catalyst (Al2O3 & V2O5, Fe2O3,… activated catalyst) at temperature of 250 - 450oC.

4NO + 4NH3 + O2 → 4N2 + 6H2O NO + NO2 + 2NH3 → 2N2 + 3H2O

For VOC from tanks and offloading system

Product of the Refinery will be stored and managed in compliance with strict storage and handling procedures, and regular inspection, maintenance and testing of valves, seals and volatile fuel storage units. Following specific measures will be proposed during the operation phase as follows:


OA13 Provide vapor recovery systems in the tankage farm (Isomerate, light Naphtha FCC, Benzene, Paraxylene and leaking steam in loading process of RON 92 and RON 95 gasolines to tanker) (Figure 4.3)

OA14 Closely control liquid product export/import process to minimize leaking and spillage incidents.




OA15 Install leakage detector, spillage control equipments and emergency shut-off valves at closing magnetic type to prevent leakage/spillage at fuel storage tank area.

OA16 Install the automatic fire detector and automatic fire fighting equipment system at fuel tank areas and fuel pump station.

OA17 Install safety vents on fixed roof tanks of diesel, jet kerosene, LSWR export and refinery fuel oil tank;

OA18 For loading racks of gasoline, diesel, jet kerosene and benzene export system (1 loading bay at jetty) – implement submerged loading with vapor capture (efficiency of 90%) and vapor recovery/destruction (efficiency of 95%) to achieve an overall VOC control efficiency of 85%;

OA19 Consider covering open works (i.e., aeration tanks) at wastewater treatment plant and routing vapors to a recovery unit;

OA20 For components related to benzene, select equipment to minimize benzene emissions, e.g., pumps with double seals, specialized valves, etc.; and

OA21 A periodic leak detection and repair (LDAR) program for leakage components such as valves, flanges, pump seals, etc. and timely repairs on components leaking > 1,000 ppm of VOC.

Steam

So

lven

t b

efo

re a

bs

orb

ed

So

lven

t A

fter

ab

sorb

ed

S

olv

ent

Aft

er a

bso

rbed

EntranceWeight stations Tanker

Isomeratetanks

Light FCC Naphtha tanks

Released gas

Benzenetank

Paraxylene tank

Absorbent: heavy FCC Naphtha

Heavy FCC Naphthatank

Heavy FCC Naphtha

Figure 4.3 HC recovery system for tank area and truck loading area



4.2.2.2 Noise control During the operation phase, to ensure comply with the Project and Vietnamese Standards. The Project Owner will implement mitigation measures as follows:

Ref. No. Mitigation Measure

OA22 Follow routine Operation & Management (O&M) procedures specified by equipment vendor such as regular oil changes, tuning, lubrication, alignment and balancing of rotating parts, etc., which ensures operation at the rated capacity and consequently reduces source noise levels.

OA23 Select and locate equipment within the process areas such that noise level of 85 dB(A) is maintained along the battery limits; provide attenuation measures for noisy equipment such as pressure/steam relief valves, vents and flare.

OA24 Conduct noise measuring for the final configuration of equipment and their locations – generate revised noise contours to identify work areas requiring hearing conservation program and demonstrate fence line noise levels within acceptable standards.

OA25 Equip ear-protection devices for workers at working site.

4.2.2.3 Water quality

In the operation phase, the NSRP will take a large volume of sea water (Max 42.8 m3/s) for cooling purpose, continuous effluent discharge to the sea, offloading crude oil from SPM, loading refined products will impact on water quality around the intake and outfall area. The following mitigation measures will be applied:


1. Cooling Water Intake

OB1 Online control velocity and temperature of inlet seawater.

OB2 Use small dredger to carry out maintenance dredging in intake channel to avoid intensive high content of TSS and accidents with nearby facilities (main breakwater and low crest breakwater);

OB3 Dredged material will be disposed offshore at location permitted by local authority.

2. Effluent discharge (Industrial, sanitary, cooling water, RO and FGD effluents)

OB4 Reuse cooling water for De-SOx purpose at FGD unit.

OB5 FGD effluent will be aerated to reduce COD before mixing with cooling water to the outfall:

After used for cooling purpose, a part of sea water will be routed to absorption tower. At here, SO2 will be oxidized to SO42- by oxygen in seawater. As a result of this, COD will increase but DO will decrease. Therefore, effluents from FGD meet industrial discharge standard.

OB6 All effluents are pre-treated at source (first stage) then routed to the effluent treatment plant (ETP) for further treating. The treatment process of wastewater in the refinery plant is summarized as follows:




First stage treatment process

For sanitary wastewater

Sanitary wastewater will be collected in the septic tank in the plant then routed to the ETP plant by dedicated drainage for further biological treatment. The sanitary system septic tanks will require a vacuum truck service for sludge removal.

De-oiled wastewaters

Oily Wastewater (via COC sewer and header) flows are collected in a flow balancing tank (Oily Water Equalization Tank), where gross oil contamination can be skimmed.

A Corrugated Plate Interceptor (CPI) oil separator further separates solids and entrained oil from the wastewater, and additional oil removal is effected in a Flocculation Flotation Unit (FFU, also known as DAF – dissolved air flotation). Collected oil is sent to the refinery slop oil system and oily sludge is collected for treatment.

The characteristic of CPI and outfall effluent are as follows:

Discharge oil concentration to be less than 60 mg/l

CPI to be designed with head space purge (swipe air) to the vent extraction fan for air emission control

After that, these will be routed to the FFU, the effluent will be more further treating, in this unit

Coagulant and polymer dosing system to be provided

The coagulant and polyelectrolyte dosing rates will be optimized based on regular Jar Test and the initial design rates are 50 and 5 mg/L of Fe2(SO4)3 and active polymer respectively

The characteristics of first stage treated effluent are presented bellows:

Output oil concentration must be less than 10 mg/l;

Output suspended solids concentration must be less than 25 mg/l.

The sludge from CPI and FFU units will be collected and treated at sludge incinerator. The outfall effluent from FFU unit will be continually routed to the ETP for further treating.

Second stage treatment process (ETP)

The de-oiled wastewater is mixed with the sanitary effluent before passing to biological treatment. The plant utilizes conventional activated sludge process with a contact chamber, a pre-de-nitrification reactor and aeration basins for COD and TKN oxidation, clarifiers and sludge and mixed liquor recycle. Waste sludge is sent to aerobic storage which is operated as a batch thickener to reduce sludge volumes.

Tertiary stage treatment process

Two-staged tertiary treatment is required in order to meet strict effluent treatment project standards. Initial physio-chemical treatment utilizing a coagulant and PAC (powdered activated carbon) will remove a significant part of the remaining COD. Sludge generated will be separated in a downstream clarifier before being routed to sludge treatment. Ozonation of the settled effluent is necessary to oxidize sufficient part of the remaining COD to meet the discharge standard.




Treated effluent flows to treated wastewater tank that provides retention sufficient for analyses to be performed and the results confirmed before final discharge to the seawater return header. Effluent not complying with the discharge standards can be diverted to the guard basin. This basin also acts as a check basin for AOC flows in excess of FFB capacity and effluent can be stored by closing off the outlet and allowing the basin level to rise. Firefighting runoff from either the AOC or diverted from the CSW systems can also be retained in the same manner.

The guard basin can also store partially treated effluent from the ETP by the use of a bypass header that allows diversion of partially treated wastewater from any process stage of the ETP for subsequent treatment.

Oily sludge is sent to the oily sludge storage tank where they are steam heated to enhance oily water and solid separation in the downstream phase separator (such as a two phase hydro-cyclone). Separated oily water returns to the oily water storage tank for oil/water separation in the CPI. Sludge is combined with the thickened biological and tertiary sludge for dewatering before being incinerated.

In order to meet the Project air emission standards, especially for benzene and H2S, all equipment upstream of Bio-treatment, including oily water storage tank, CPI, FFU/DAF, as well as the oily sludge storage tank are covered with the vent directed to a Bio-tower for benzene and H2S treatment and air emission control.

Quality of treated effluent at the outfall of ETP will meet as project standard and Vietnamese standard QCVN 24:2009/BTNMT.

General outline of treatment process for wastewater (ETP) is illustrated in Figure 4.4.

OB7 Treated effluents from ETP, FGD and RO will be mixed with cooling water (Figure 4.5) before discharging to the sea in order to ensure that concentration of all pollutants at the mixing zone are similar to the concentration in coastal water.

OB8 The outfall structure should be divided into different diffusers and risers pipes for maximum dilution capacity and reducing outlet velocities

OB9 The outfall location shall be about 6km offshore and at least 5.5m of water depth.

OB10 Online monitor flow rate at input and temperature and Chloride at output of cooling system. Temperature at the outfall shall be lower or equal 40oC and temperature of mixing zone shall not exceed 3oC above the temperature of the coastal ambient water.

OB11 Online monitor effluent quality at input and output of ETP.

OB12 Period dredging drainage system of the Complex annually

OB13 Regular carry out monitoring program (every 6 months) of coastal water quality at intake water, outfall location and their upstream and downstream.



Figure 4.4 Scheme Effluent Treatment Plant (ETP) for NSRP project

Slu

dg

e

Oill

y w

ate

r

Bio

slu

dg

e

Fe

rric

/AC

do

sin

gSlu

dg

e L

iqu

ors

Slu

dg

e

Slu

dg

e

Slu

dg

e

Slu

dg

e

de

wa

terin

g

Slu

dg

e

inc

ine

ratio

n F

BI

Inc

ine

rato

r a

sh t

o o

ff-s

ite

dis

po

sal

Tert

iary

tre

atm

en

t

ph

ysi

co

ch

em

ica

l

Tert

iary

tre

atm

en

t

oxid

atio

n

No

rth

Tra

pe

zoid

al C

ha

nn

el

No

rth

Tra

pe

zoid

al C

ha

nn

el

Se

aw

ate

r O

utf

all

NN

F

NN

F

Gu

ard

Ba

sin

Sa

nita

ry S

ew

ag

e

N

orm

ally

op

en

va

lve

NN

F

N

orm

ally

no

flo

w

KEY:

Oily

wa

ste

wa

ter

FFB T

rea

tme

nt

Sp

en

t c

au

stic

Cle

an

pro

ce

ss w

ate

r

ne

utr

alis

ed

de

min

re

ge

n w

ate

r

CSW

FFB

Ove

rflo

w

Cle

an

su

rfa

ce

wa

ter

Se

aw

ate

r re

turn

Re

co

ve

red

oil

to d

isp

osa

l

Ae

rob

ic s

tora

ge

Bio

tre

at

Oily

slu

dg

e

Tre

atm

en

t

Flo

at

Slu

dg

eSlu

dg

e

Oily

flo

ats

FFU

CP

I O

ily w

ate

r

eq

ua

lisa

tio

n

Skim

me

d o

il

Tre

ate

d w

ate

r ta

nk



Figure 4.5 General diagram of combined wastewater treatment process

390



Loading and quality of effluents before and after treated in ETP system are presented in Table 4.5 and Table 4.6.

Table 4.5 Loading of effluents in ETP system

Effluent Loading (kg/h)

Domestic wastewater 14,036 Oily water from tanks 5,917 Oily water from the surface site 25,327 Waste water from SWS unit 104,858 Waste water from desulphurization system of RFCC unit 21,750 Waste water from boiler 69,819 Caustic solution 496 Benzene contaminated water 562 Desalted water 92,521

Total 335,286 Source: NSRP-LLC, June 2010

Table 4.6 Quality of effluents before and after treated in ETP system

Parameter Unit Input Output

Loading * kg/h 321,249 339,411 COD ppm 733 72 BOD ppm 332 25 TSS ppm 103 30 Oil ppm 634 1 TKN-N ppm 47 3 NO3-N ppm 17 7 P ppm 2 1 Phenol ppm 152 0.2

Source: NSRP-LLC, June 2010 Note: (*) domestic loading (14,036kg/h) is not included in input flow but output flow.

Quality of waste water before and after treated in tertiary oxidation treatment unit is presented in Table 4.7.

Table 4.7 Quality of wastewater before and after treated in tertiary oxidation treatment unit – ETP system

Parameter Unit Input Output Loading kg/h 339,411 339,411 COD ppm 100 72 BOD ppm 30 25 TSS ppm 30 30 Oil ppm 1 1 TKN-N ppm 3 3 NO3-N ppm 7 7 P ppm 1 1 Phenol ppm 0 0




4.2.2.4 Groundwater To control the impact on groundwater quality, NSRP LLC will apply mitigation measures as follows:


OB14 Closely monitor the final disposal of hazardous and non-hazardous wastes to ensure that conformity of the Project Owner to International and Vietnamese Standards.

4.2.2.5 Soil quality Loading/unloading feedstock and product and handling and storage significant hazardous wastes inside plant boundary during the operation phase are potential sources of impact on soil condition. These measures of collecting, storage and treating of chemicals and hazardous wastes will be strictly monitored during the operation phase and ensure that all processes are stipulated the Vietnamese regulations and related laws on hazardous waste storage and treatment which were mentioned in the introduction section of this report.


Hazardous Materials Handling

OC1 MSDS provided for all hazardous materials; handling procedures in place.

OC2 Storage tanks should be surrounded by oil tight bund walls to prevent escape of chemicals and petrochemical products into the environment in the event of a major spillage or tank failure.

OC3 Hazardous liquids are segregated and securely stored in appropriate secondary containment.

OC4 Identify areas prone to leaks/spills and provide adequate secondary containment

OC5 Spill prevention and clean-up plan in place.

OC6 In case of spillage incident, prevent absorb or contain liquid with sand, earth, sawdust or other spill control materials from entering drains, ditches or waterways.

OC7 Containment and covered storage of aggregates designed to reduce surface water runoff.

Hazardous Wastes Storage and Handling

OC8 Waste separation at source

OC9 Spent catalyst waste from RFCC unit will be collected and transported to a cement factory where spent catalyst wastes can be treated by Co-processing method as raw material for the cement processing.

Spent catalyst from CCR and PENEX-DIH units containing Pt and RHDS unit containing Ni, V and Mo will be recovered metals by catalyst suppliers or licensed recovery companies.

ETP wastes and spent oil from PP unit will be burned in incinerator.

The others hazardous will be treated by licensed treatment companies.

OC10 Oily wastes will be collected in to HDPE bags/tanks and transported to the plant’s incinerator.

OC11 The waste sludge will be collected and treated by incinerator of the Plant

OC12 Incineration ash will be collected into HDPE bags, labeled and transferred to designated hazardous waste storage area before transfer to licensed treatment companies.



OC13 Used lube oil will be collected in to drums and transferred to domestic waste storage area prior to licensed lube oil and cooking oil recycling agencies.

OC14 Build waste storage area in the Plant to make convenient condition for transfer and storage of hazardous and non-hazardous wastes before transporting to approved waste management area. Waste storage area is designed based on waste generation rate and maximum storage duration of 90 days. Additional area will be built to keep hazardous waste untreated properly.

OC15

Waste storage area should meet following requirements of design and safety:

1. Design requirement

The waste storage shall be located in the downwind direction and at safe distance from the process Units/ utilities and other building areas.

The storage facilities shall be designed and constructed in such a manner that risk of loss is minimized.

The hazardous waste storage area shall be roofed with adequate ventilation and lighting arrangements and shall meet building and fire code requirements

Flooring in waste storage area shall be impervious and sloped to facilitate proper drainage and collection of spilled liquid. A liquid waste collection system comprising of drainage channel, wastewater sump and pumping system shall be provided for collection of liquid waste spilled from the storage area.

Area around the storage area shall be properly kerbed to prevent any leakage of the spilled material from the storage area and to control the runoff water flowing in to storage area.

The storage area shall be divided into different categories according to the chemical characteristics of the hazardous wastes and provision shall be made for isolated storage of reactive, flammable and toxic wastes.

Materials of construction of storage facilities shall be consistent with the safe long term storage of the chemicals or wastes under consideration.

Changes in the chemicals or wastes to be stored in a given facility shall not be permitted until a competent assessment has been made of the suitability of the facility for such a change in service.

The degree to which measures are taken to ensure the integrity of a storage facility shall be dictated by the severity of the potential environmental, health and safety effects of the loss of the product to be stored.

Where possible, storage facilities shall not be located where, in the event of a spill, waste product may enter a natural watercourse or a sewage or drainage system, or contaminate potable surface or groundwater supplies, or contribute to air contamination and bad odor.

Emergency measures such as eye wash fountains, deluge showers, etc. must be provided and maintained in good repair, commensurate with the identified level of risk.

Adequate fire protection system shall be provided to handle Fire emergency arising from flammable and reactive wastes.

2. Safe requirement

Following are some of the key safety requirements for a Waste storage facility

Access to and exit from the storage facility will be restricted either through locked gates, door, or both. A sign visible from 8 meters (25 feet) distance away shall be placed on all access roads and entrances to the storage facility. The sign shall have the legend: "Danger - Unauthorized Personnel Keep Out,"



Personal Protective Equipment (PPE) should include the use of impervious gloves ( type and material), coveralls, boots (rubber or safety), eye protection (safety glasses/chemical goggles), details of respiratory equipment (particulate respirator, half face piece respirator, full face piece respirator, self contained breathing apparatus or supply air respirator certified by NIOSH) if required.

Eyewash/deluge showers will be provided within 10 seconds and within 100 feet of travel distance for both long- and short-term storage facilities (in conformance with Emergency Eyewash and Shower Equipment, ANSI Standard Z 358.1-1981).

Only non-leaking containers that are safe to handle and correctly labeled shall be stored in this facility. The containers shall be stored according to type and in such a manner as to facilitate inspection and removal with a minimum of handling.

Worker training in the proper use, care and maintenance of any required personal protective equipment, including fit testing of respiratory equipment, if used, must be provided.

Management & treatment measures of hazardous and non-hazardous wastes for each discharge source during operation phase of the Complex are presented in Table 4.8 and Table 4.9.

Table 4.8 Hazardous waste management & treatment measures in operation phase


Unit Handling, storage and transportation of wastes

Treatment and disposal of wastes

1 Spent catalyst 1,111 ton/ 4-5 years

2 Spent Hydrotreater catalyst

153 ton/ 4 years

3 Spent solid phosphoric acid catalyst

224.6 ton/ 2 years

4 Spent catalyst (CR3S) from SRU

140 ton/ 5 years

5 Spent catalyst (TG 107) from SCOT

70 ton/ 5 years

6 Spent absorbent 17,323 ton/ 4 years

7 Spent catalyst 1,760 ton/year

8 Replacement of inert material

52 ton/year

9 Spent absorbent 603 ton/ 04 years

10 Spent absorbent 1.3 ton/year

11 Spent desorbent 1,116 ton/ 20 years

12 Spent desorbent 2,63 ton/year

13 Catalyst grading material (from HDS reactor)

49 ton/ 4 years

14 Spent selective hydrogeneration catalyst

10 ton/ 4 years

To be collected into HDPE bags/ drums, labelling and transfer to designated hazardous waste storage area prior to offsite transportation to Hazardous waste management facility.

Appropriate treatment of hazardous waste (e.g. Physical, chemical, biological or thermal oxidation, reuse as feedstock of cement factory etc.) followed by suitable landfill both through approved/ licensed waste management facility

15 Clay treater waste 154 ton/ 6 months

16 Waste oil from air and - ton/year To be collected into drums, labelling Sent for used lube oil recycling






Nitrogen compressor and transfer to designated hazardous waste storage area prior to offsite transportation to approved / licensed Lube oil recycling agencies.

through approved /Licensed lube oil recycling agencies. Requirements of Basel convention to be followed in case of transboundary movement of wastes.

17 Sludge from API of the ETP

800 ton/year

18 Sludge from CPI of the ETP

800 ton/year

19 Sludge from FFB of the ETP

800 ton/year

20 Sludge from biological treatment section of the ETP

964 ton/year

21 Sludge from tertiary treatment section of the ETP

1,840 ton/year

To be collected into HDPE bags/ drums, labelling, and transfer to designated hazardous waste storage area prior to ETP Waste Incineration facility

Burnt at incinerator of ETP

22 Ash from incinerator of the ETP 2,100 ton/year

To be collected in to HDPE bags/ drums, labelling, and transfer to designated hazardous waste storage area prior to offsite transportation to hazardous waste management facility.

Sent to licensed hazardous waste treatment facility

23 Waste fuel - ton/year

To be collected in drums/tanker, labelling and transfer to designated hazardous waste storage area prior to offsite disposal to approved Units/ Plants (e.g. cement manufacturer, etc.) having adequate facilities to utilise Refinery waste oil/ tarry material/ sludge without causing any harm to environment.

In-house use or offsite disposal to approved Units/ Plants (e.g. cement manufacturer, etc.) having adequate facilities to utilise Refinery waste oil/ tarry material/ sludge without causing any harm to environment.

24 Empty chemical drum - ton/year To be transferred to designated hazardous waste storage area prior to offsite disposal.

In-house use or offsite disposal to approved used drum handling facilities having adequate facilities to decontaminate drums prior to its further use.

25 Waste lubricant - ton/year

To be collected into drums, labelling, and transfer to designated Hazardous waste storage area prior to offsite transportation to approved / licensed Lube oil recycling agencies.

Sent for used lube oil recycling through approved /Licensed Lube Oil Recycling Agencies. Requirements of Basel Convention to be followed in case of transboundary movement of wastes.

26 Cooking oil - ton/year To be collected in to drums, labelling, and transfer to designated

Sent for used cooking oil recycling through approved






domestic waste storage area prior to offsite transportation to approved / licensed cooking oil recycling or incineration agencies.

/Licensed Oil Recycling / incineration Agencies.

27 Dry battery e.g Li, Cd batteries

Lead acid battery - ton/year

To be separately collected in plastic bag, labelled and stored in a designated storage area or Hazardous waste storage area.

Waste to be disposed to approved recycling or hazardous waste disposal facility

28 Medical waste - ton/year

Medical waste to be collected in plastic bag labeled and sealed. Sharps to be placed in puncture resistant container Both container/ bag to be stored under control of medical staff

Medical waste to be incinerated at approved medical waste incineration facilities and incineration ash to be disposed to the licensed / approved secured landfill facility.

29 Toner (from copiers) - ton/year

Used toner to be collected in a separate container, labeled and stored at area designated for its storage.

Waste to be disposed to Vendor or approved waste disposal facility

30 Solvent/paint/thinner residue

- ton/year

31 Sealants/mastic - ton/year

Waste to be collected in waste storage containers/bag, labeled and stored at designated storage or Hazardous waste storage area.

32 Spill absorbents - ton/year

Spill absorbent (contaminated with hazardous material) waste to be collected in waste storage containers/bag, labeled and stored at Hazardous waste storage area

33 Contaminated Soil - ton/year

Contaminated soil waste to be collected in waste storage containers/bag, labeled and stored at Hazardous waste storage area.

Waste to be disposed to approved Hazardous waste

disposal facility

34 Used Fluorescent tubes - ton/year

Used fluorescent tube to be collected in puncture resistant container, labeled and stored at area designated for its storage

35 Aerosol containers - ton/year

Empty /used aerosol cans to be collected in a puncture resistant container, labeled and stored at area designated for its storage.

Waste to be disposed to approved waste land fill

facility

36 Used smoke ionic - ton/year Used smoke detectors to be collected in a separate

Waste to be disposed to Vendor or approved smoke






detectors container, labeled and stored at area designated for its storage.

detector waste disposal facility

37

Laboratory waste e.g. Expired

chemicals, sample rejects, etc

- ton/year

Laboratory waste to be collected in separate puncture resistant bags/drums, labeled, and stored at designated storage facility near laboratory or at Hazardous waste storage area

38 Used PPE (contaminated) - ton/year

Used PPE (contaminated with hazardous material) waste to be collected in waste storage containers/bag, labeled and stored at Hazardous waste storage area.


39

Off Spec products generated during Start-up and process upset conditions

- ton/year

Explore possibility for recycle or reuse of waste. Off spec waste to be collected in waste storage containers/bag, labeled and stored at Hazardous waste storage area.

PP off spec waste to be disposed to approved recycling facilities for production of low grade products. Other waste to be disposed to approved Non hazardous waste disposal facility.

40 Teal Oil liquid waste 280 m3/year

To be carefully collected in to HDPE drums, labeling, and transfer to designated Hazardous waste storage area prior to offsite transportation to approved / licensed Hazardous waste treatment /incineration facilities


41 Hydrocarbon drains 145 m3/year

To be carefully collected in to HDPE drums, labeling, and transfer to designated Hazardous waste storage area prior to offsite transportation to approved / licensed Hazardous waste treatment /incineration facilities

Waste to be disposed to approved Hazardous waste

disposal facility



Table 4.9 Non-hazardous handling & treatment measures in operation phase


Unit Handling, Storage and transportation


1 Tyres -

ton/year To be stored at area designated for its storage or at non hazardous waste storage area.

2 Plastic bottle, containers

-

ton/year

To be collected in puncher resistant bags/ drums stored at area designated for its storage or at non hazardous waste storage area.


3 Drums /container (non contaminated)

-

ton/year

To be stored at area designated for its storage or at non hazardous waste storage area. Explore possibility of reuse of the drums.

Waste to be disposed to approved scrap dealers or drum disposal facility

4 Glass

-

ton/year

Used waste to be collected in punchure resistant bags/ drums stored at area designated for its storage or at non hazardous waste storage area.


5 Waste paper

-

ton/year

Office paper waste from shredding collected in plastic bags to be stored at area designated for its storage.

Paper waste to be disposed to approved Paper waste recycling agency.

6 Office furniture wastes

- ton/year

Used waste to be stored at area designated for its storage.


7 Office Electronic wastes

-

ton/year

Used electronic waste to be collected in a separate container, labeled and stored at area designated for its storage.

Waste to be disposed to Vendor or approved electronic waste disposal facility

8

Laboratory waste e.g. broken glass wares, equipment/ instruments, etc.

-

ton/year

Laboratory waste to be collected in separate puncture resistant bags/drums, labeled, and stored at designated storage facility near laboratory or at Non hazardous waste storage area


9 Domestic waste

-

ton/year

Waste to be collected in domestic waste bins. To avoid unhygienic /septic condition/odour nuisance, the waste to be collected and disposed daily.

Domestic waste to be collected and disposed to approved/licensed municipal landfill /disposal facility.

10 Domestic sewage

-

ton/year Sanitary waste /sludge to be collected and disposed on periodic basis.

Sanitary waste to be collected and disposed to in house incineration facility or approved/




Unit Handling, Storage and transportation


licensed offsite municipal landfill /disposal facility.

11 Used PPE (Non-contaminated)

-

ton/year

Waste to be collected in separate bags/drums, labeled, and stored at designated storage facility or at Non-hazardous waste storage area


12

Spent catalyst sludge from scrubber at RFCC Unit

-

ton/year

Waste to be collected in separate bags/drums, labeled, and stored at designated storage facility or at Non-hazardous waste storage area

Waste to be disposed to approved inert waste disposal facility/ Cement Manufacturers, Brick manufacturer, inert land fills, filler in bituminous mixtures, etc

4.2.2.6 Marine ecosystem


Terrestrial ecosystem

OD1 Set up fauna monitoring program around plant boundary and onshore pipeline system

Aquatic ecosystem

OD2 Monitor temperature of outlet wastewater to ensure that it is lower than 40oC and shall not exceed 3oC above the temperature of the ambient water at the edge of a scientifically defined mixing zone.

OD3 Entrapment and impingement to lower flow as proportionally fewer animals will be subject to contact with the intake structure, including:

System as follow: sea water → intake channel → intake basin→ Screen 1 → Screen 2;

Intake channel at the shore is 350m in length, 70m in width and at depth of -7.92 HN72;

Screen 1 used to prevent 25mm debris and Screen 2 for less than 3mm matters.

OD4 Monitor Cl2 content in seawater cooling water to avoid a shock in seawater outlet

4.2.2.7 Road traffic In operation phase, transporting products by tankers will increase traffic density in provincial road 513 and National road 1A. NSRP LLC will apply some mitigation measures as follows:


OE1 More use waterway to transport goods, products and equipments instead of road way;

OE2 Set up new bus route for workers from central area of communes to the Project area to reduce number of traffic vehicles.



4.3 MITIGATION MEASURES FOR OFFSITE FACILITIES (HARBOUR, BREAKWATER, CRUDE PIPELINE AND SPM)

4.3.1 Construction Phase 4.3.1.1 Air Quality Air emissions during the construction phase to be minimized by implementing the following measures:


HA1 Introduce a site speed limit (20 km/h) for trucks and other vehicles;

HA2 Low sulphur fuels to be used for constructional equipment;

HA3 Roads to be paved with dust free material to reduce dust generation;

HA4 Cover materials of all free dusts during off-site road haulage

HA5 Road sweeping and spraying daily;

HA6 Road maintenance; grading and compacting road surfaces to prevent uneven running surfaces, which create both noise and dust;

HA7 Install wheel washing facilities at an appropriate distance from the site entrance within site boundary;

HA8 Limit vehicle age and/or condition and vehicle maintenance to reduce fuel use and poor air quality due to vehicle emissions

HA9 Routing haul routes away from sensitive areas (protective forest, schools, hospital…) wherever possible;

4.3.1.2 Noise and Vibration To reduce the impact of noise generated during offsite construction activities, following measures will be applied.


HA10 Avoid piling and dredging works as well as breakwater placement at night to reduce noise and vibration impacts and avoid any environmental incidents.

HA11 Avoid using noisy constructional equipment within 6:00pm to 6:00 am.

HA12 Provide anti-noise machine to workers



4.3.1.3 Soil Environment Onshore construction of harbor, new access and breakwater cause soil pollution. The following mitigation measures are proposed as below to reduce the impact on soil:


Construction activities

HB1 Make fences/barriers at two ends of project area (area J) to avoid damaging of nearby coastal protective forest.

HB2 Precautions should be taken to prevent damage to cultivated or paved surfaces and to growing trees, shrubs, or hedge are not scheduled for removal. Vegetation shall be protected from damage due to spillage of harmful material to plants or to suffocation of roots by the raising of ground levels around them. Any damage arising to these items caused by the Contractor’s works should be made good at the Contractor’s expense.

HB3 Store materials and fuels at higher elevation and as far as shoreline to avoid oil leaching to the shore.

HB4 Do not store large volume of fuel at landfall construction site. Build small dyke around fuel drum to avoid oil spill/leakages.

HB5 Reuse construction solid wastes (soil, stones, broken brick, used cement, etc.) for filling new access.

Solid wastes

HB6 Classify hazardous and non-hazardous at source into different skips before transferring to waste treater.

HB7 Solid wastes classified as non-hazardous and hazardous wastes from ship/tanker will be transferred to jetty (the same procedure as plant waste management and handling) and then stored temporary at jetty storage area before transferring to treater.

HB8 Solid wastes will be periodically collected, transported, treated and disposed by licensed waste treatment Company.

HB9 Food waste will be ground to 25mm before discharging to the sea

HB10 Regularly control and monitor efficiency of waste treatment and handling of the contractor.

4.3.1.4 Water environment During construction phase, EPC contractor will carry out following mitigation measures as requirements of Vietnam marine regulations and maritime administration of Thanh Hoa province:


SPM and crude pipeline construction

HC1 Notify the process, work sites, implementation duration of the offshore pipeline and SPM to the local Authorities and fishermen.

HC2 Establish restricted area for the working site along pipeline route and SPM; do not allow fishing boats entering to the working zone. Strictly control illegally used explosives of local fishermen nearby construction area;

HC3 Used radioactive source for NDT testing is strictly controlled and carefully preserved to hand over




to suppliers after completion

HC4 Coordinate with local authority and maritime police agency (or environmental police) to ensure marine security.

Breakwater and Harbor construction

HC5 Notify the process, working sites, implementation duration of the marine harbor to the local Authorities and fishermen. Set up a restricted area for the working site by using buoy system and signal-lamp (at night) to restrain the collision incident/accidents.

HC6 Dredged materials will be dumped offshore location which is far from Me island at least 6.7km toward to the south.

Pipeline Cleaning and Hydrotesting

HC7 Choose only chemicals listed in “Petrovietnam Guidelines on the Implementation of Requirements on use and discharge of chemicals and drilling fluids in petroleum operations offshore Vietnam” for hydrotest process.

HC8 Treat hydrotesting water before discharging to the sea:

Separate solid residue and oil generated from construction activity and pipeline installation;

Treat chemical by neutralization method injecting directly neutralizing substances to the pipeline before discharge.

HC9 Control discharge speed of treated Hydrotest water at SPM location.

HC10 Check and monitor used chemicals and water quality before and after discharge;

HC11 Assess in detail hydrotest process when used chemical type and dose are exactly known.

Domestic wastes from barges/vessels

HC12 Reduce waste volume by using bags which create less waste; Use sufficient materials and Reuse materials whenever possible;

HC13 Waste food on laying barges and service vessels will be grinded to less than 25mm before discharging to the sea;

HC14 Solid wastes on construction vessels shall be classified on board and then transported to jetty for further treatment.

HC15 Oily effluent generating from vessel will be treated on board, to ensure oil content is less then 15ppm as requirement of IMO, by CPI equipment before discharging to the offshore.

HC16 On board sanitary effluent will be treated by septic tank system before discharge to the sea.

4.3.1.5 Biological environment To rehabilitate the biological environment (flora and fauna), following mitigation measures are proposed:


HD1 Vehicle routing to avoid nearby coastal protective forest

HD2 Replant trees at along transportation road and entrance of harbor and at some places in Tinh Gia district



HD3 Prohibit all project employees hunting activities in the area

HD4 Protect/sustainable use other common species (e.g. butterfly lizards, frogs, water birds).

4.3.2 Operation Phase 4.3.2.1 Air quality The main sources of air quality impacts caused by marine facilities are from unloading activity of crude oil at the SPM and loading of petroleum products at the jetties. The following mitigation measures will be applied:


HE1 Install vapour recovery system to take back vapour from loading refined products (RON 92, RON 95, Benzene and Paraxylene) to tankers (Figure 4.6).

HE2 Loading arms and lines should be fitted with vapour recovery systems to reduce fugitive emissions during bulk loading and unloading operations at product export port.

HE3 Equip specific protection cloths, boots, mask, and glasses for the people working in Sulfur Formation Unit.

Waste oil system

Solvent

After ab

sorbed

Solvent

Before absorbed

Berth for large ship 4A/4B

Berth for sm

all ship 2A/2B

Steam

Weight station Ships

Paraxylene

BenzeneReleased gas

Gasoline 95

Gasoline 92

HC recovery system for product export port

Gasoline 95

Gasoline 92

Absorbent: Gasoline

Figure 4.6 Diagram of HC recovery system for product export port



4.3.2.2 Noise and Vibration During operating phase, main sources of noise are from the operation of equipment, truck movement, shipping activities (engines and whistling). The following mitigation measures will be applied:


HE4 Provide anti-noise equipments to those working at too noisy area;

HE5 Periodic health check for workers

4.3.2.3 Soil environment Almost all solid wastes generated from normal operation of jetty area are small and non-hazardous waste.The following mitigation measures will be applied:


HF1 Solid wastes classified as non-hazardous and hazardous wastes from ship/tanker will be transferred to jetty (the same procedure as plant waste management and handling) and then stored temporary at jetty storage area before transferring to treater.

HF2 Hazardous wastes at jetties will be transferred to plant’s hazardous waste storage area and be treated as plant’s hazardous wastes.

HF3 Solid wastes will be periodically collected, transported, treated and disposed by local licensed waste treatment Company.

HF4 NSRP will regularly control and monitor efficiency of waste treatment handling of the contractor.

4.3.2.4 Water Resources Crude offloading at SPM Following mitigation measures are proposed for crude offloading at SPM:


HI1 Inform to local authority and fishermen the location of crude pipeline route in order to avoid anchoring and illegal explosive.

HI2 Deploy oil boom around tanker while offloading operation taken place and berthing at SPM.

HI3 Provide a standby supply boat and response equipment within offloading operation to prevent and on time response any spill or leakage.

HI4 Regularly check and maintain pipeline, valves, flanges and equipment especially shutdown valve system in emergency cases;

HI5 Utmost care must be exercised when handling cargo in order to avoid oil spills. No oil, nor any water, which may possibly contain oil, is to be discharged overboard or allowed to escape overboard.




HI6 Procedure will be prepared describing spillage and pollution prevention actions along with the pollution handling.

HI7 Any leakage or spillage must be reported immediately to the Operator, and all efforts to recover or limit the spill must be taken. Operator will inform the local environmental authority accordingly.

HI8 Berthing and hose handling operations will be carried out during daylight hours with sufficient visibility. For the tanker arriving at the SPM, the cut off time for berthing is 1.5 hours before sunset.

HI9 A fully manned mooring tug will be available to assist in the approach, mooring and unmooring of tankers and tank barges. The tug maintains surveillance around the vessel for spills, assists in emergencies, maintains a 24/24 hose watch, and monitors all radio communications. No vessel will be permitted to lay in the berth unattended at the SPM;

Pollution Prevention Equipment at SPM The following pollution prevention equipment and precautions will be provided to prevent accidental spills during offloading activities at SPM:


HI10 Set an exclusion zone within a 295m radius of the SPM;

HI11 Use loading arms with shutoff valves. Valves should be located on the PLEM for emergency shut-off and for change out of the underbuoy hoses. The valves should be hydraulically actuated and controlled from control panel on the SPM.

HI12 Fit extensive navigational aids such as buoys, lights and foghorns and monitoring of vessel movements using radar and regular communication;

HI13 Set up maintenance base for the SPM – storage for oil spill equipment and area for testing /inspection of equipment;

HI14 Provide service vessels to assist with offloading operations;

HI15 Use double walled loading hoses to reduce risk from wear;

HI16 Use breakaway couplings in the event of hoses taking excessive strain;

HI17 Each floating hose string will have a blank flange and shutoff valve at the vessel end;

HI18 The marine facilities will have communication equipment that provides two-way voice communication with the vessel’s officer in charge of cargo transfer, the marine harbor supervisor in charge of the cargo transfer;

HI19 Hoses are examined internally and externally, and defective hoses are replaced.

HI20 Seabed line will be inspected by a diver where visible.

HI21 Buoys and anchor chains are inspected and repaired or placed as necessary.

HI22 Flanges, gaskets and valves at SPM are checked annually for leaks.



Prevention during Loading activities at the Harbor Safe and efficient procedures will be the responsibility of the vessel’s master, following mitigation measures will be proposed during loading activities at harbor:


HI23 Strictly control product loading/unloading procedure and pipeline. Check obstacles in front of harbor in order to reduce as low as possible oil leakage and oil spill;

HI24 Reasonable schedule for vessels/tankers berthing at the harbor in order to avoid the waiting, traffic jam and shipping collision;

HI25 Tankers calling at the harbor will be accompanied by assist tug, both mooring and unmooring, as required;

HI26 No other vessel will be permitted to come alongside or remain alongside a vessel in berth while transferring cargo without the approval of the vessel’s Master and the harbor manager;

HI27 Two connections from the jetty fire water systems are available at each berth for connection to the ship’s fire main, one forward and one after of the vessel’s manifold;

HI28 When bad weather or rough wave, tankers/ships have to move to harbour area according to harbor manager’s order.

HI29 Regular carry out maintenance activity for equipments, shut-down valves and product pumps to avoid product leakage and spills;

HI30 Monitor system pressure in order to immediately leakage accident;

HI31 Limit risk of the pipeline leakage or broken by clearly mark and regularly monitor the pipeline trenching area;

HI32 Regular check shutdown and collection system as well as OSCP equipment in order to on-time response;

HI33 Coordinate with local authority and related agency (Nghi Son Port) or companies (NS Cement Plant) in setting up emergency response network;

HI34 Regular practice/train fire fighting procedures and emergency response plan;

HI35 Set up connect point for a 1,500m oil spill containment booms from the harbor shoreline;

HI36 Provide for spill containment measures at the jetty to clean spills and contain impacts on marine environment.

HI37 Fire extinguishing equipment will be maintained by the vessel. In the event of fire, the cargo transfer is suspended immediately and the vessel made ready to move away;

HI38 Constant communications will be maintained between the harbor and vessels, the mooring tug;

HI39 When loading or off-loading at harbor, sufficient number of crew, vessel Master and harbor Manager will be on duty to perform operations safely;



Maintenance dredging Maintenance dredging activities will be carried out after 4 years for the harbor and access channel. The potential environmental impact of maintenance dredging are assessed as the same as mentioned in the construction phase, but affected area will be smaller and impact level is less than the capital dredging. To reduce the impact of maintenance dredging, following mitigation measures will be applied:


HI40 Plan dredging schedule to avoid peak shipping activities.

HI41 Dredging activity shall be carried out in daytime to avoid ship collision in the harbor and access channel

HI42 Dredged material shall be dumped offshore at least 6.5km south of Me island.

Effluent Discharges Sources of effluent within harbor will consist of the following streams: slop oil/oily surface water and sanitary effluent. Oil/oily surface water and sanitary effluent can impact on sea water quality. So, the following mitigation measures will be applied:


HI43 Oily effluent generating from harbor shall be collected to a sump and then transferred to plant ETP for treatment.

HI44 Sanitary effluent is treated at Jetty by sewage treatment package (STP) and then routed to plant outfall about 6km far from the shore.

HI45 Sludge from STP will be transferred to the Refinery effluent treatment plant (ETP) for further treatment.

Wastes from tankers/ships

Wastewater generated from crude tankers and product ships will be collected, treated and disposed as IMO requirements including:


HI46 Cleaning and runoff water sweeping oil sticking on the surface floor around the equipments will be collected and treated by the oil separator to ensure that oil content in treated wastewater must less than 40 ppm before discharged into the sea (offshore area beyond 12 nautical mile).

HI47 Oily runoff water on board will be collected and routed to a separate tank and treated periodically (when the tank is nearly full) by the onboard oil/water separator or a licensed company outside the harbor.

HI48 Domestic wastewater generated onboard of crude tankers and product ships will be collected and preliminary treated before discharging into the sea.



HI49 Waste food generated from each ship will be crushed into small pieces less than 25 mm in size before discharging into the sea.

HI50 Do not discharge indecomposable wastes such as cans, bottle, plastic bags, etc. into the sea.

Classify at source into separate bins before transporting to temporary storage area at NSRP harbor.

4.3.2.5 Onshore biological environment


HJ1 Plant trees standing against sea-breeze along access road and around harbour area if possible;

4.3.2.6 Ecosystem Offloading crude oil at SPM through pipeline system and product loading at jetties will be high potential risk of oil spill. The following mitigation measures will be applied to reduce impacts on marine habitats:


HL 1 Consider timing of dredge to avoid sensitive periods for benthic communities in the access channels from April to June;

HL 2 To avoid effect to coral area, crude and product transportation routes shall not pass across Hon Me archipelagoes.

HL3

Establish Marine Protection Plan including:

Implement a comprehensive marine monitoring program, which entails identification of indicator species and key indices – through periodic surveys and sampling, determine trends for the above to discern impacts, if any; and

Develop a program for periodic sampling and analysis of sediments and seawater for physical/chemical parameters, as applicable, such as temperature, salinity, dissolved oxygen, pH, etc. at different depths and constituents of concern such as hydrocarbons, BTEX, PAH and heavy metals, to determine cumulative impacts.

Also develop a programme to validate the marine environmental quality (may be once in year as feasible) by using methods such as sampling / analysis of biomonitors, assessment of benthic and pelagic fauna, sea grass, corals, etc., to ascertain cumulative impacts from refinery operations.



4.4 MITIGATION MEASURES FOR ACCIDENTS AND ABNORMAL EVENTS 4.4.1 Fire and Explosions


Technical Solution

AA1 Ensure that the design specifications for all plant include performance standards such that plant failure, and thus hydrocarbon release scenarios, will be minimised through design;

AA2 Reduce the hazard magnitude through the installation of gas (toxic and flammable) detectors with emergency shutdown (ESD) systems within the critical hazard locations. Emergency shutdown valves to be located outside fire impact zone. If the valve is located inside a fire/explosion zone then fire proofing is necessary to provide protection for a specified period of time in line with API 2001;

AA3 Minimize the presence of ignition sources around the process units;

AA4 Where possible, consider leak point minimization for all equipment (e.g. welded, rather than flanged pipe connections, fail safe valves, spring loaded manual valves, flange covers);

AA5 Stop traffic in provincial road 513 in case of fire & explosion incidents to prevent local people and vehicles from damage;

AA6 Install fire warning system and alarm procedure board when occurring accidents;

AA7 Put fire banned board at high sensitive areas;

AA8 Deploy hand-held fire fighting tools at assigned areas for ease to approach in case of small fire accidents.

Local Communities

AA9 Propose to Vietnamese authorities to extend resettlement to area C to ensure security in case of explosion at the Refinery and Petrochemical Complex.

AA10 Implement the detailed QRA during the detail engineering phase and take proper counter measure to mitigate the risk of fire and explosion;

AA11 Reduce risk to road users by early warning on leak and closure of access;

4.4.2 Toxic Gas Release


AB1 Inform local population and authority in case of incident at Plant area;

AB2 Establish Site Emergency Response Plan during the Detailed Design. Emergency procedures should be put in place and followed if a leak is detected. Good procedures and training for emergency response are essential.



4.4.3 Shipping collision

In order to minimize the risk of ship collision and oil spill, the following mitigation measures are proposed:


AC1 Establish insurance and maritime safety management plan for each port/harbor and access channel;

AC2 Provide boom and oil spill response equipment at each port and harbor;

AC3 Establish cooperative training program in oil spill response plan and fire fighting plan between ports, harbors, jetties and local authorities;

AC4 Regular maintain cooperative exercises and notification system on oil spill and fire fighting scenarios between harbors/ports, jetties and Nghi Son Frontier Post, Nghi Son police station and coastal People Committees;

AC5 Train fishermen how to response whenever they find oil slick on the surface and oil pollution;

AC6 All shipping activities (ship movement and anchoring) in the Nghi Son bay taken over by one Port authority are highly recommended.

AC7 Put marking buoy and signal light system to specify access channel and instruct vessels in harbour area of the Complex;

AC8 Forbid all mooring activity at area of marine facilities, such as access channel, crude oil pipeline, SPM and outfall position.

4.4.4 Emergency Response Planning for oil spills Oil Spill Response organization and equipment specification of Nghi Son Refinery Project will be presented separately in oil spill response plan which will be improved by Thanh Hoa People Committee.

The proposed mitigation measures for oil spill incidents are as follows:


AD1 Available Project Oil Spill Contingency Plan and Environmental Sensitivity Map for decision maker to decide response strategy and define priority area in the case of oil spill occur at project facilities.

AD2 Equip and maintain oil spill response facilities for the SPM and the harbor including skimmers, oil booms (sorbent booms and inter-tidal beach booms for trapping of oil), “oil bags” and containers for additional, temporary storage of recovered oil at sea and on beaches on recovery vessels which will be standby at the harbor;

AD3 Equip special tools, pumps, hoses, sorbents (coconut husk mats or rice straw bales), containers, etc. to response efficient beach clean-up;

AD4 Prepare some small flat-bottomed multipurpose boats with very shallow draught and high speed for towing to allow fast containment (reduction of initial spreading) or deflection of drifting oil;

AD5 Adopt appropriate clean-up techniques for restoring the range of habitats;

AD6 Establish an emergency response team and undertake regular training and provide and test suitable equipment;

AD7 Develop agreements with “local authorities” where local people can be notified and some protection works can be done, focusing on protection of beaches.



The Nghi Son Refinery facility is aiming to be able to respond to tier 1 and tier 2 oil spills in the port and for the SPM. Summary oil spill response plan in the case of oil spill is listed as below: Oil Spill Response Strategy

Tiered category

Oil type

Spilled volume

Strategy required

Response time

1

White & Black Oils 10 tones

Port terminal Equipment

Immediate


Immediate

White Oils

10 – 500 tones

Other sources 6 hours


Immediate

2

Black Oils

<200 tones

Other sources 6 hours

White Oils

>500 tones

3 Black Oils

>500 tones

Mechanical Containment and Recovery

24 hours

A range of different spill scenarios exist which may conceivably arise during crude oil offloading and product loading in the port. Outside the harbor, spills can occur due to damage to ships (e.g. collision or accidental) and discharge from oil tankers. Incident Response Organization

Overall responsibility in case of a spill

The Harbor Master (or his nominated deputy) is often assigned to have overall responsibility for the conduct of oil spill response operations in case of a tier 1 and tier 2 spill and for casualty / salvage management within the ports area of jurisdiction. Depending on the actual established organization an overall responsibility needs to be assigned.

Oil Spill Management Team

The oil spill management team will support the overall responsible in his role. An oil spill management team will be established at the harbor office, under the chairmanship of the assigned responsible. This will provide the command and control structure to co-ordinate and direct the incident response. In case of a small spill (tier 1) a smaller team will be activated (response team) and will initiate appropriate response actions.

Communication

Proper communication lines and schedules (flowcharts) need to be detailed for the response organization. The plan should include an up to date contacts list. Initially reports will be passed by



telephone both landline and mobile (consideration should be given when using mobiles for security reasons). VHF sets may be maintained, which would be issued to supervisors once a clean-up strategy has been established. It is essential that all events that occur during an incident are logged and recorded. To achieve this, all key personnel must keep logs. Entries in the log should detail as a minimum, events, actions taken, communications with outside agencies, decisions made and points relevant to the operations.

4.5 MITIGATION MEASURES FOR SOCIAL COMMUNITY IMPACTS 4.5.1 Pre-construction phase Due to this phase was taken over all site clearance, compensation and resettlement activities by the Thanh Hoa People Committee, so responsibilities of NSRP-LLC are to propose to local authority following recommendations in order to assist living condition of APs:

Ref. No. Recommendation measures to local authority

Disturbance of Cemeteries /Graves

SA1 Shall increase the compensation rates to cover the price of grave removal

SA2 Shall give additional compensation for APs affected through removal of graves at the time of compensation for structures

Loss of residential and agricultural lands

SA3 APs should be compensated according to 2009 rates since they were not compensated in 2008

SA4 Shall assist compensation rate of agricultural land for whole acquired agricultural area in accordance with Item a, Article 22 of Decree No.69/2009/NĐ-CP;

SA5 HHs losing agricultural land should be assisted once with another production plot for non-agricultural business;

SA6 Increase compensation rates for residential land to reflect replacement costs and to take into account inflation;

SA7 Take benefit of the transitional period to implement the Training Program;

SA8 Extend allowance period if construction duration of resettlement sites is more than 12 months;

SA9 Implement flood -mitigation measures and guarantee water quality supply for the resettlement site of Mai Lam Commune

SA10 Encourage APs send money to the bank after receiving the compensation at once to ensure the income and avoid to waste money.



Ref. No. Recommendation measures to local authority

Assist living stabilization

SA11 Assist local authority in developing and implementing a program for restoration of income and career transfer for APs;

SA12 Should have plan to assist relocation, life stabilization, training…

SA13 Assist to build temporary house for waiting a new resettlement site: 12 million VNĐ/HH for 5 months per resettlement HH and 4 months per HH rebuilding new house on the rest area (Decision No.2622/2009);

SA14 Assist construction materials cost: 10 million VNĐ/HH and HHs relocating outside NSEZ should be assisted 160 million VNĐ/HH (previous rate is 35 million VNĐ/HH in accordance with QD92531/2008);

SA15 Develop Training Program to APs in order for them to be employed by NSRP and other projects in NSEZ;

SA16 Develop a long term strategy for employment for APs;

SA17 Compensation in cash for agricultural, residential and plantation lands;

SA18 Life stabilization and production stabilization assistance for APs;

SA19 Education assistance for APs;

SA20 Training allowance assistance for APs.

Rearrange to relocated residents

SA21 APs will have the choice to be relocated in a fully serviced RS or to be relocated by themselves

SA22 For APs willing to be relocated in RS:

APs will receive full rights on their plot of land

APs will move to the RS only when the infrastructures will be fully completed

SA23 Compensate residential land and other structures by replacement cost

Social disruption to Host Communities

SA24 In each RS public building (market, health center, school, kindergarten, and community houses) will also be used the host population.

SA25 Secondary APs will be covered by the same provisions than other APs affected by the NSRP.



4.5.2 Construction Phase The summarized mitigation measures will be applied to reduce the social impacts in the construction phase as below.


Disruption/Damage to Infrastructure and Services

SB1

EPC Contractor will ensure that:

Provide its own sanitary treatment facilities;

Provide adequate construction camps or other housing strategies for staff;

Identify in advance damage for infrastructure or service;

Responsible to effecting repairs of any accidental disruption or damage caused by their activities and/or shall provide appropriate compensation in agreement with NSEZ.


SB2 NSRP LLC will implement Social Support Plan to improve infrastructure and service for affected people.

Access Restrictions and Diversions

SB3 Expand the Road 513 to provide adequate access to affected population;

SB4 Keep open the existing Road Tinh Hai – Hai Yen during the first construction time.

Others

SB5 Carefully planned borrow pits operation to reduce visual impacts;

SB6 Re-vegetation during excavation and complete restoration at the end of the earthwork phase;

SB7 Light sources will be pointed downward and away from primary receptors;

SB8 Using lowest light emission equipment keeping priority for safety purpose;

SB9 Provide vegetation barriers at sensitive areas.

4.5.3 Operation Phase Mitigation measures for social impacts during operation phase are summarized in below table:

No. Mitigation Measures


SB10 NSRP LLC will implement Social Support Plan to improve infrastructure and service for affected people



Resources

SB11 Light sources will be put downward and away from primary receptors;

SB12 Use vegetation barrier where appropriate to reduce visual impact

Disease

SB13 Quickly insolate the patients in case of occurring disease. Make disease arisen areas clean and disinfected. Inject vaccine (if avaiable) to healthy people to avoid spreading of the disease to those working in the Complex and local community.

SB14 Co-operate with local medical organizations (medical station, hospital…) to fist aid or cure timely for the patients when there is disease occurring in the Complex or local community.

Social order

SB15 To ensure social sercurity and order, NSRP LLC will co-operate with local authority, especially the police, to check and monitor implementation of temporary absent/residence registration and order in local area.



Section 5

ENVIRONMENTAL MANAGEMENT AND MONITORING PROGRAM

5.1 OBJECTIVES NSRP LLC is committed to being at the leading edge of environmental and social responsibility and to set its performance standards at the level that is comparable to leading industry practices. NSRP LLC is committed to continuously improving the operational performance of the Project to enhance environmental and social benefits and to limit adverse impacts to maximum extent practical. The Environmental and Social Management Plan (ESMP) is set up forth the framework for implementing the Project-specific actions that area necessary to comply with NSRP LLC Sustainable Development Policy. The Environmental Management Plan (EMP) as the requirement of Circular 05/2008/TT-BTNMT of MONRE is a main important part of ESMP. Therefore, in order to consistence with project ESMP, this section will mention both environment and social management plan. The ESMP presents the environmental management systems and monitoring programs to be implemented in the Project life. The ESMP establishes the policies, commitments, and resources that are needed to implement the management plans and programs required to mitigate the predicted impact of the Project. It provides an organizational structure for environmental management and social responsibilities. The objectives of the ESMP are to:

Establish a organization with safety and environment group/department;

Facilitate the implementation of the mitigation measures for the identified adverse impacts;

Define the responsibilities of the project proponents and contractors in order to effectively implement the ESMP;

Comply with Vietnamese and International Standards, Codes, and Best Practices applicable to the work being performed;

Define a monitoring mechanism and identify monitoring parameters in order to:

- Ensure the complete implementation of all mitigation measures;

- Ensure the effectiveness of the mitigation measure;

- Provide a mechanism for taking timely action in the face of unanticipated environmental situations

Identify training requirements.



The ESMP is established basing on Vietnamese and International Standards and satisfied the national requirement of Circular 05/2008/TT-BTNMT and HSE guideline of WB/IFC requirements. This ESMP is a living document and with its implementation it will be reviewed, updated, and modified as needed. To implement objectives as above-mentioned, organization and direction for program implementation is an important factor and include as follows:

Establish a Safety and Environment Unit and in cooperation with other departments such as technical, security departments... to monitor safety and environment matters;

Provide information related to organization, regulations and necessary guideline for implementing environment practices;

Establish and implement checking, monitoring, review and audit to ensure that environment management plan is appropriate;

Improve and complete environment management system. 5.2 ENVIRONMENTAL MANAGEMENT PROGRAM NSRP will develop its own Environmental Management System (EMS) based on ISO 14001. The project ESMS implementation will be based on raising the level of company-wide awareness of environmental and social requirements, expectations, and benefits. Health, safety, environmental, and community protection and development are among the highest Project priorities.

NSRP Environmental Management Information System will record all monitoring data compliance, management decisions and corrective actions including:

Active and obsolete printed versions on the ESMP All site active plans as approved by NSRP All communications with environmental and social implications All environmental monitoring reports from NSRP and EPC Contractor and Sub-contractors Monthly and quarterly reports Complaint register Training materials Training attendance registers Non-compliance reports Vietnamese environmental, social and health legislation Permits, legal documents and authorizing letters Occupational health and safety reports Environmental and social procedures

Environmental management program for NSRP project is established to prevent potential environmental risks and to ensure all the mitigation measures identified in the EIA are addressed.

This plan is applicable to the NSRP Project during the construction, commissioning and operation phases of this project.

The management program will be a good tool in order to ensure that environmental policies of project as well as related regulations will be implemented. Therefore, environmental management work is effective, sustainable and continuous.



5.2.1 Construction Phase NSRP will follow-up the implementation of the ESMP by the EPC Contractor through its own supervision team. NSRP will require EPC contractor to update the existing management plans and to conform to the current environmental and social assessment for implementation. EPC Contractor will prepare CESMP (Construction Environmental and Social Management Plan). This plan will define the procedures through which the Project environmental and social commitments will be implemented during the construction. 5.2.1.1 Air Quality Management Plan (Onshore and Offshore Facilities)

Objective To minimize the release of fugitive emissions to air from areas where construction and transport activities are occurring

Target No fugitive emissions (dust, smoke, fumes and odor) to air causing or likely to cause nuisance on or beyond the boundaries of the site and outside the ROW of the access roads

Action Introduce a site speed limit (20 km/h) for trucks and other vehicles;

Low sulphur fuels to be used for vehicle and mobile plant;

On-site roads to be paved as early as possible with dust free material to reduce dust generation;

Paving roads as early as possible between washing facilities and site exists;

Usually sweep rock/soil litered in material transport road;

Cover materials of all free dusts during off-site road haulage;

Daily road spraying for material transportation road and site area;

Road maintenance; grading and compacting road surfaces to prevent uneven running surfaces, which create both noise and dust;

Install wheel washing facilities at an appropriate distance from the site entrance within site boundary;

At paint spraying area, workers must be equipped with specific protective clothes, anti-toxic mask and oxygen cylinder in special case;

Do not use chemicals containing forbidden substances, such as asbestos;

Take proper measures for polishing tank surface to reduce dust problem. Limit use sand spraying method.

No open burning of wastes to be undertaken

Responsibility EPC Contractor is responsible to take action

Monitoring Visual inspections will be undertaken by EPC Contractor to check for evidence of excessive dust generation If necessary, dust monitoring will be undertaken in areas likely to generate dust that would affect nearby residents and workplaces to determine whether controls are being applied effectively NSRP LLC will supervise the mitigation measures by occasional monitoring and analyze complains received from affected people.

Reporting All complaints will be documented, acted on and monthly reported to NSRP LLC. NSRP LLC will make reports twice times per year to relevant authorities and lenders.



5.2.1.2 Noise Management Plan (Onshore and Offshore Facilities)

Objective To minimize the generation of noise emissions during the construction phase and to mitigate potential noise impacts

Target Comply with Noise Project Standards (Section 0)

Action The EPC Contractor will implement the following strategies during the construction phase of the project:

Notify Hai Yen, Mai Lam and Tinh Hai residents prior to commencement of the construction phase.

Ensure that all Contractors on site have effectively controlled noise levels from equipment. Effective noise controls include:

- Regular inspection and maintenance of all vehicles and construction equipment working on-site;

- Installation of sound suppressive devices (such as mufflers) on all mechanical plant as necessary;

- Where practicable, vehicles and machinery that are used intermittently should not be left idling for long periods of time

Excessively noisy activities will be conducted between 6h00 - 18h00 if they are likely to cause any nuisance to local residents;

Avoid piling and dredging works as well as breakwater placement at night to reduce noise and vibration impacts and avoid any environmental incidents.

Provide earplug/earmuff to workers at high noise level area

The adjacent residents will be notified prior to any noise events or noisy operation outside 6h00 - 18h00 Monday to Sunday

Responsibility EPC Contractor

Monitoring Noise Monitoring will be conducted according to Vietnam circular No.05/2008/TT- BTNMT

Reporting All complaints will be documented, acted on and monthly reported to NSRP LLC. NSRP LLC will make reports twice per year to relevant authorities and lenders.

5.2.1.3 Soil Contamination Management Plan

Objective Prevent soil contamination Manage contaminated soil

Target No new incidents of soil contamination caused by Complex’s activities. No receptor impacted by contaminated soil

Action The EPC Contractor will minimize the risk of ground contamination from all construction activities. Onshore Facilities:

Construction waste disposal will be handled and disposed of in accordance with Governmental Degree 155/1999/QĐ-TTg (16/7/1999).

Waste storage area should not be located near sewer or outfall system to avoid cause air pollution and generate odour;

Temporary storage of wastes at site designated areas. Hazardous wastes to be



fully contained and stored undercover within retention bunds in order to avoid any leakage into the area;

Hazardous solid wastes must be collected to labeled drums named “Hazardous wastes” and stored in temporary roofing storage house inside the complex boundary before transfer to treater who has given license of treating hazardous wastes.

Provide documentation in detail with dates of delivery and quantities of consignments, as well as instructions on the safe storage, use, collection and disposal of materials and waste products prior to transfer to the disposal places in accordance with Governmental Degree 155/1999/QĐ-TTg (16/7/1999);

Put waste baskets at each constructional section with at least 3 differrent coloured and labelled baskets to collect hazardous waste, non-hazardous construction wastes (Iron, steel, wooden ends, etc) and domestic waste at construction site;

Minimize waste, recycle and reuse as much as possible. Minimize using hazardous materials; segregated and stored in secondary containment.

Restrict access to hazardous waste storage area.

Conduct refueling in designated area with secondary containment as far as practicable.

Where in-situ refueling required, follow procedures to reduce spillage.

A storm water drainage system in trapezium shape will be installed in the Northern site to outlet safely total amount of runoff water to avoid flood for surrounding community;

Offshore Facilities:

Make fences/barriers at two ends of project area (area J) to avoid damaging of nearby coastal protective forest and beaches.

Build storage and workshop areas on a drain bunded cement platform at higher elevation and as far as possible from the shoreline to avoid hazardous chemical leaching to the sea.

Separate hazardous and non-hazardous wastes at source into different skips before transferring to waste treatment collector.


Monitoring Weekly inspection by EPC Contractor of all construction fuels and chemicals storage areas to ensure safe and proper containment and to bund. Any sites identified to be contaminated will be monitored in accordance with the requirements of the any relevant management plan

Reporting The EPC Contractor will report monthly to NSRP LLC. NSRP LLC will make reports twice per year to relevant authorities and lenders.

5.2.1.4 Surface Water Management Plan (Onshore Facilities)

Objective Minimize the discharge of contaminated surface water to the surrounding environment

Target Comply with QCVN 14:2008/BTNMT National technical regulation on domestic wastewater for sanitary wastewater discharge and comply with Industrial wastewater Project standard for cleaning & hydro-testing wastewater (Section 0)



Action Intake water and outfall effluent system:

Notify the timing, working sites, implementation duration of the marine harbour to the local Authorities and fishermen. Set up a restricted area for the working site by using buoy system and signal-lamp (at night) to restrain the collision incident/accidents.

Keep safety in waterway material transportation.

Collect solid waste completely onboard; absolutely avoid discharging solid waste to sea water.

Cleaning & Hydrotesting

Limit amount of chemical using. In the case of have to use, select less toxic chemicals which are listed in Annex 1 of the Guideline of chemicals using and discharge of Petrovietnam.

No discharge of contaminated effluents into the sea.

Recycle cleaning & hydro-testing water from commissioning plant, where possible to reduce amount of water discharging to the sea;

Treat cleaning and hydrotesting water before discharge by separating solid residue and oil generated in construction and tanks and pipeline installation phase; After that treat by chemicals in temporary neutralization tanks at tankage area.

Do not discharge cleaned and hydro-tested water at site. In the case of discharging to the sea, discharged cleaning and hydro-testing water as far the shoreline.

Sanitary Wastewater Discharge

Build temporary water closets at the site to collect and treat preliminary domestic wastewater generated in this phase;

Contract with local Environmental Sanitation Company (in Nghi Son or Tinh Gia District) to periodically suck septic tanks at construction and camping site and treat properly in accordance with in force regulation;

Do not discharge sanitary effluent to Lach Bang river. Treated sanitary wastewater shall then be routed to the sea via an outfall system at the location of adequate dilution and dispersion of effluent.

Regular monitoring of effluent from the construction site will be undertaken to ensure treatment efficiency.


Monitoring The EPC Contractor will conduct regular inspections of construction areas and site drain system and erosion mitigation measures. Inspections will be conducted on a weekly basis during the wet season as well as after each heavy rain occurred.

Reporting The EPC Contractor will report monthly to NSRP LLC on the following:

Compliance with approved erosion and sediment control plan

Incidents of erosion or water contamination

Results of weekly inspections

Results of any corrective actions The EPC Contractor will report to NSRP LLC any incident and surface water quality results twice a year. NSRP LLC will make reports twice per year to relevant authorities and lenders.



5.2.1.5 Surface Water Management Plan (Offshore Facilities)

Objective Minimize the discharge of contaminated surface water to the surrounding environment

Target Comply with Industrial Project standard for cleaning & hydro-testing wastewater (Section 0)

Action Notify the timing, work sites, implementation duration of the offshore pipeline and SPM to the local Authorities and fishermen.

Establish restricted area for the working site along pipeline route and SPM; do not allow fishing boats entering to the working zone. Strictly control illegally used explosives of local fishermen nearby construction area;

Used radioactive source for NDT testing is strictly controlled and carefully preserved to hand over to suppliers after completion;

Coordinate with local authority and maritime police agency to ensure marine security.

Dredging and material dumping

Dredged material shall be dumped offshore at least 6.5km south of Me island.

Control and monitor seabed sediment and water quality before and after discharge; Cleaning & hydro-testing

Choose only chemicals listed in “Petrovietnam Guidelines on the Implementation of Requirements on use and discharge of chemicals and drilling fluids in petroleum operations offshore Vietnam” for crude pipeline hydrotest process (less toxic chemicals which do not or cause low risk of environment, high biodegradation ability and without bioaccumulation capacity).

Treat hydrotesting water before discharging to the sea by separating solid residue and oil generated from construction activity and pipeline installation; and then treat it by injecting directly neutralizing substances to the pipeline before discharge.

Control discharge speed of treated hydrotest water at SPM location.

Monitor chemicals used and water quality before and after cleaning & hydro-testing water discharge.

Domestic wastes from barges/vessels

Food waste on laying barges and service vessels will be grinded to less than 25mm before discharging to the sea;

Solid wastes on construction vessels will be separated on board and then transported to jetty for further treatment.

Oily effluent generating from vessel will be treated o board, to ensure oil content is less then 15ppm as requirement of IMO before discharging to the offshore.

Onboard sanitary effluent will be treated by septic tank system before discharge to the sea.


Monitoring The EPC Contractor will conduct regular inspections of construction areas.

Reporting The EPC Contractor will report monthly to NSRP LLC on the following:

Incidents of water contamination Results of weekly inspections Results of any corrective actions

NSRP LLC will make reports twice per year to relevant authorities and lenders.



5.2.1.6 Groundwater Management Plan

Objective Minimize groundwater contamination Prevent impact on the receiving environment from contaminated groundwater

Target Minimize spills to ground No measurable effect on the receiving environment

Action Install sanitary waste system to collect and treat sewage and grey water from the various operations of the worksite and construction labour camp.

Control cleaning & hydro-testing process and quantity of chemicals used. Monitor discharging process;

Monitoring groundwater quality after completion construction phase.


Monitoring Groundwater sampling to collect information that can be used to determine:

The characteristics and trends of contaminated groundwater migrating offsite

Whether any contaminant plumes may be forming

Routine performance checks and monitoring of the operation of the recovery system

Reporting The EPC Contractor will report to NSRP LLC any incident and ground water quality twice a year. NSRP LLC will make reports twice per year to relevant authorities and lenders.

5.2.1.7 Terrestrial Flora Management Plan

Objective Minimize the impact on the surrounding environment, the entire operation of site clearing, trenching, pipe lying and rehabilitation will occur in the shortest practicable time.

Target Minimizing the disturbance of native flora;

Minimizing disturbance to native fauna.

Action Vegetation clearance should be reduced as much as possible at onshore area of harbour and pipeline route.

Plant green trees around the complex area and along onshore pipeline and some areas in the Complex in order to ensure that green area is not less than 10% of total project area.

Prevention of hunting by staff and contracted personnel.


Monitoring Rehabilitated areas will be monitored to ensure the success of the rehabilitation program by EPC Contractor and NSRP.

Reporting The following flora management information will be reported twice per year to NSRP LLC:

Results of surveys conducted in the annual year.

Results of any rehabilitation programs implemented.

A summary of any incidents related to native flora. NSRP LLC will make reports twice per year to relevant authorities and lenders.



5.2.1.8 Waste Management Plan

Objective Manage all wastes generated on site

Target Minimize generation of waste

Carry out waste management effectively by:

Maximizing reuse of waste and material; Maximizing recycling; Safety treating and disposing of all non-reusable and non-recyclable materials.

Action A waste management plan will be developed by EPC Contractor for the construction stage that include:

The scope and objectives of the waste management plan;

Capacities and actions to be taken to implement the waste management hierarchy;

Quantitative estimates of the expected wastes and emissions;

Have agreement with suppliers to take back the unused materials; Training in waste minimization skill / habit;

Monitoring / supervising;

Emergency response procedures;

Reporting

The actions to be undertaken include the following:

Non-hazardous waste The topsoil will be collected and disposed at assigned area in accordance with

NSEZ’s regulation;

Concrete, grit and sand/soil waste will be used for grading/land leveling.

Packaging waste will be collected and stored in non-hazardous waste area. Explore possibility to reuse waste as for other packaging purposes.

Compostable food and canteen wastes will be collected in dustbins and transported to the landfill of the province.

Scrap iron, cable drums, electric wires, containers… will be transferred to the designated Non-hazardous waste storage area prior to scrap dealers.

Domestic sludge from the construction camps will be collected for treatment and disposal

Hazardous waste

All hazardous wastes will be managed in compliance with Circular No.12/2006/TT-BTNMT issued by MONRE on Guidedance of practice condition and procedures of documenting, registering, licensing work permit, code of hazardous management.

Hazardous waste generated during construction and installation such as oil waste, used batteries, contaminated mineral and laboratory wastes will be separately collected in plastic bag, labeled and stored at Hazardous waste storage area.



Medical waste generated from health centre will be collected in plastic bag, labeled and sealed. The sharp things will be stored in specific containers under control of medical staff.

Responsibility EPC Contractor is responsible to implement.

Monitoring EPC Contractor will implement waste consignment notes indicating source/dates/ quantities of generation along with periodic analyses of constituents.

The following waste streams will be measured and reported:

Waste generation Waste re-use Waste recycling Waste treatment and disposal

Reporting The EPC Contractor will report monthly to NSRP amount of wastes and other relevant waste management issues.


5.2.1.9 Employment and Training Management Plan

Objective To ensure that the project affected people, the poor and the local communities benefit from the project.

Target Income restoration for project affected people. Reduction of poverty in Tinh Gia District.

Action NSEZ, Tinh Gia District and Training Organizations will undertake training program in order to maximize the number of local employees.

First priority for training and job opportunity will be given to family members of affected people and to the poor. List of priority people for training and job opportunity will be made available at commune level and NSEZ.

The EPC Contractor will hire local workers for further training in accordance with the construction schedule;

Contractor training obligations and employment policy will be identified in the NSRP-EPC contract agreement;

EPC Contractor will develop the local supply chain to be able to support the construction activities, and to maximize the economic benefits that flow from the Project to the NSEZ, Tinh Gia District, Thanh Hoa Province and the country.

Responsibility NSEZ and Tinh Gia District organize training NSRP LLC assist local authority EPC Contractor will hire and train workers

Monitoring EPC Contractor will monitor the number of direct and indirect workers hired disaggregated by gender, by skill level, and by area of origin.

Reporting Statistic regarding training activities and employment data will be reported to NSRP LLC twice per year by EPC Contractor. NSRP LLC will make reports twice per year to relevant authorities and lenders.



5.2.1.10 Health and Safety Management Plan

Objective To ensure that the project does not adversely affect the health of the employees, contractors or the public.

Target Zero reportable injuries and work-related illnesses.

Action The EPC Contractor will be required to prepare a Health and Safety Management Plan in accordance with the requirements of NSRP HSE Management System

Instruct employees to utilize equipments in construction activities (materials, lifting technique and limit weight);

Limit load/unload, transport heavy goods by hand;

Clean usually wastes and overflow effluents in construction site;

Use anti-slipped boots;

Put barriers around deep area to avoid to fall down;

Train workers to use protective equipments properly as well as fall prevention system;

Use control and monitoring system to protect workers in dangerous cases;

Evacuate workers out of construction site when carrying out explosion activity (mines, bombs…);

Equip appropriate protective clothes (safety glass with blanket, hard helmet and protective boots);

Develop traffic management system to minimize potential risks, such as insolate transport road area, limit speed, set up one way route…;

Ensure vision for workers when working or passing areas having heavy machines in operation; instruct workers how to test and protect eyes;

All mobile equipments have sirens with suitable volume;

Check and maintain carefully lifting equipments such as cranes;

All workers should be trained about industrial safety before working in confined space;

Apply work permit for all workers, supervisors in construction area;

Implement preventive measures such as breathe support devices, safety belt, monitoring station to observe safety for workers with first aid and rescue tools);

Personnel protective equipments (PPE) must be available and enough;

Keep roads from construction area to camp site safe and clean in bad weather condition;

Prepare high capacity pump system enough to pump rain water out of flooded area.

NSRP LLC and EPC Contractor will implement an HIV/AIDS and communicable diseases awareness campaign before the beginning of the civil works.

EPC Contractor will provide their own self-contained health and fire protection services



for the duration of their activities.

EPC Contractor will provide adequate construction camps or other housing strategies for staff coming from outside the Project Area.

To minimize HIV/AIDS and other STDs transmission during construction phase, the following measures will be implemented:

Conduct a needs analysis to determine current levels of understanding of HIV/AIDS issues among company management and staff;

Educate workers on HIV/AIDS and other sexually transmitted diseases.

Develop, test and introduce appropriate training materials for managers and employees;

Coach/drill trainers;

Provide basic medical care shall be provided at workers’ camps ;

Responsibility NSRP LLC and EPC Contractor

Monitoring The health and safety performance, including HIV/AIDS and other communicable diseases, will be monitored in accordance with the defined responsibilities of the EPC Contractor. Regular audits will be undertaken by NSRP LLC.

Reporting All health and safety initiatives and incidents will be reported monthly to NSRP LLC by EPC Contractor. NSRP LLC will make reports twice per year to relevant authorities and lenders.

5.2.1.11 Social Impact Management Plan

Objective Minimize detrimental social and/or community impacts from the construction workforce;

Maximize opportunities for local businesses during the construction period.

Target No complaints about social and community impacts.

Action Accommodation for workers

An accommodation camp will be provided for the construction workers to minimize conflicts between the Project worker and local people:

Accommodation camps will be located far from existing villages or settlements as much as possible to avoid disturbance to local communities;

Basic health and medical services will be provided reducing the demand on existing public facilities;

Buses will be provided to transport workers to the work sites each day.

Respect of local communities

The EPC Contractor will specify the behavior standards expected from all construction workers. This will be formalized in a code of conduct that will be agreed to and signed by every employee and sub-contractor.



Complaints about unacceptable behavior from the Project workers will be investigated and solved.

Communication

NSRP LLC will use a wide range of communication tools to ensure that any contacts in the Complex must be kept.

Employment and business opportunities

NSRP LLC will maximize opportunities for the involvement of local businesses in the project construction and operation and for the employment of local residents.

NSRP LLC and EPC will communicate the requirements of the project’s employment policy to the local community, relevant organizations and businesses. This will include information on positions available, skill requirements and recruitment procedures

To support local businesses, NSRP LLC and the EPC Contractor will commit to:

Ensuring potential local businesses are provided with relevant information in an equitable and timely manner;

Ensuring local businesses are provided with the opportunity to supply under the same terms and conditions as external businesses;

Ensuring that contracts are awarded competitively which will include due consideration of non-cost factors such as reliability, maintainability, servicing etc.

Infrastructure

EPC Contractor will be responsible for effecting repairs of any accidental disruption or damage caused by its activities under its responsibility and/or will provide appropriate compensation in agreement with NSEZMB, local authorities and affected parties

All planned diversions will be communicated to NZEZMB and local authorities prior to the actual works being undertaken.

Responsibility NSRP LLC, EPC Contractor, NSEZ, Tinh Gia District and Training Organisation

Monitoring Monitoring will be carried out by stakeholders feedback, review of complaints and statistics related to local resident employment and business development.

Reporting The EPC Contractor will prepare monthly reports on social management issues and corrective measures.




5.2.1.12 Capital expenditure for constructing main treatment and monitoring works NSRP LLC will invest to construct treatment and monitoring facilities as follows:

No. Facility/Invested system Treatment work Technical specification Estimated cost

(USD)

Desulphurization system in fuel gas from boilers

Efficiency of 96% 40,000,000

Sulphur recovery system (SRU and TGU)

Efficiency of 99,9% 145,000,000

Flare system 180m in height 0.57m in diameter

40,000,000

1 Control air pollution

Polypropylene dust recovery system - 650,000

2 Reduce noise Muffler 500,000

Effluent Treatment Plant (ETP) Designed capacity of 631m3/hour

Domestic waste water treatment system at the Plant

-

Domestic waste water treatment system at the harbor

-

Rain water drainage system -

Effluent outfall system Discharge pipe 6km away from the shore Q max discharge:= 42.8 m3/s

3 Waste water treatment

Sludge incinerator of ETP Designed capacity: 57,360 kg dehyrated sludge/day and 2,000 liters waste oil and plastic powder/day

110,000,000

Continuously air emission monitoring Online 1,600,000

Ambient air quality monitoring station - 500,000

Gas detectors (1,000 USD/unit x 15 Process Unit x 30 Units)

Online 450,000

Wastewater quality monitoring Online 200,000

4

Environmental monitoring

Wastewater quality monitoring Laboratory 500,000 Source: NSRP-LLC, December 2009 NSRP LLC will report MONRE, DONRE of Thanh Hoa Province and NSEZ Management Board in detail about construction plan progress, installation schedule of treatment facilities and environmental protection system in compliance with Article 11, Circular No.05/2008/TT-BTNMT.



5.2.2 Operation Phase 5.2.2.1 Air Quality Management Plan

Objective To minimize the release of air emissions at discharge sources and effect to the vicinity

Target Satisfy emissions project standard

Action Onshore Facilities

Apply FGD system by sea water scrubbing for the flue gas from boilers;

Provide De-NOx and De-SOx systems for RFCC unit;

Provide Low-NOx burners for stacks of SRU, Gas turbines, CDU, ETP incinerator, RHDSs, NACs, KHDSs, GOHDS and Ultra-low-NOx burner for HMU;

The stack heights have been established to get adequate dispersion of SOx, NOx, CO and PM10 and verified the dispersion results basing on air dispersion model to confirm that ambient air qualities meet related standards and guidelines;

Establish and maintain Continuous Emission Monitoring System (CEMS) at following discharge source:

o FGD / Boiler stacks – For SO2, NOx and PM o RFCC Co Boiler stacks– For SO2, NOx and PM o Gas Turbine stacks – For NOx

Monitor (every 6 months) of ambient air quality for NOx, SOx and PM in the upwind and downwind directions.

Provide vapor recovery systems in the Isomer products tank, light Naphtha FCC, Benzene, Paraxylene and vapor from export process of RON 92 and RON 95 gasoline;

Closely controlling liquid product export/import process to minimize leaking and spillage incidents.

Install leakage detector, spillage control equipments and emergency shutdown valves at closing magnetic type to prevent leakage/spillage at fuel storage tank area.

Install the automatic fire detector and automatic fire fighting equipment system at fuel tank areas and fuel pump station.

Offshore Facilities

Install vapor recover system for export process;

Equip specific protection cloths, shoes, mask, glasses for the people working in the Sulfur Formation Unit.

Responsibility NSRP LLC is responsible for implement

Monitoring Continuous monitoring of NOx, SOx and PM for stacks with huge emission. Quarterly monitoring of emission and ambient air quality.

Reporting NSRP LLC will make reports twice per year to relevant authorities and lenders.



5.2.2.2 Noise Management Plan

Objective To minimize noise generated from the Refinery and Harbor operation;

Target Noise levels must comply with Noise Standard of IFC and Vietnamese Standards TCVN 5949:1998

Action Install soundproofed wall around the equipment such as gas turbine, steam turbine, air compressor… to reduce noise;

Install the noise and vibration sensor at highly noise and highly vibration zone such as air compressor, turbines…;

Provide hearing protection for employees working in noisy area. The use of hearing protection should be enforced actively when the equivalent sound level over 8 hours reaches 85 dB(A);

Making period maintenance plan for equipment to minimize noise and vibration;

Perform medical hearing checks for workers exposed to high noise levels;

Implement noise control measures to ensure compliance with IFC and Vietnam Noise Standards

Establish a green-tree buffer zone between the project area and resident area. Responsibility NSRP LLC is responsible for implement

Monitoring Noise Monitoring will be conducted upon commissioning and then at twice a year in accordance with the Vietnam Circular No.05/2008/TT- BTNMT.

Reporting All complaints will be documented, acted on and reported in accordance with current site procedures; NSRP LLC will make reports twice per year to relevant authorities and lenders.

5.2.2.3 Soil Contamination Management Plan

Objective Prevent soil contamination

Manage contaminated soil

Target No incidents of soil contamination

Action Onshore Facilities

Hazardous Materials Handling

MSDS provided for all hazardous materials; handling procedures in place;

Storage tanks should be surrounded by oil tight bund walls to prevent escape of chemicals, petrochemical products into the environment in the event of a major spillage or tank failure;

Hazardous liquids are segregated and securely stored in appropriate secondary containments;

Identify areas prone to leaks/spills and provide adequate secondary containment

Spill prevention and clean-up plan in place;

In the event of a spillage, absorb or contain liquid with sand, earth, sawdust or other spill control materials. Prevent from entering drains, ditches or waterways.



Containment and covered storage of aggregates designed to reduce surface water runoff.

Hazardous waste storage and handling:

Waste separation at source;

Spent catalyst waste from RFCC unit will be collected and transported to a cement factory where spent catalyst wastes can be treated by Co-processing method as raw material for the cement processing. At the preparation time of this EIA report, Holcim Cement Plant in Kien Giang Province is the only one having enough ability and license to treat this spent catalyst waste;

Spent catalyst from CCR and PENEX-DIH units containing Pt and RHDS unit containing Ni, V and Mo will be recovered metals by catalyst suppliers or licensed recovery companies;

Oily wastes will be collected in to HDPE bags and transported to the incinerator of the Plant;

The waste sludge will be collected and treated by the incinerator of the Plant;

Incineration ash will be collected into HDPE bags, labeled and transferred to designated hazardous waste storage area prior to offsite transportation to hazardous waste management facility;

Used lube oil will be recycled in refinery as much as possibly, if not lube oil will be collected in to drums and transferred to hazardous waste storage area prior to licensed lube oil recycling agencies.

Offshore Facilities

Solid wastes

Classified solid wastes from ship/tanker into non-hazardous and hazardous wastes will be transferred to jetty (as waste management and storage procedures) and then stored temporary at jetty storage area before transferring to accredited collector.

Solid wastes will be periodically collected, transported, treated and disposed by licensed solid waste treatment Company as requirements of MONRE.

NSRP LLC will regularly control and monitor the efficiency of waste treatment handling of the collector.

In the case of soil contamination, following surveys will be carried out:

Stage 1: Pollution audit

Stage 2: Survey soil quality and risk assessment

Stage 3: Recovery


Monitoring Identification and reporting of any leaks or spills in accordance with the EMS Procedures.

Audit soil contamination twice times/year.

Reporting NSRP LLC will make reports twice per year to relevant authorities and lenders.



5.2.2.4 Surface Water Management Plan (Onshore Facilities)

Objective Prevent surface water pollution by not discharging contaminated water to the ambient environment

Target Water discharge will not cause negative effects on surface water quality of the Project area

Action Continuous water intake

Control velocity of seawater inlet and temperature;

Do not discharge backwash water directly to seawater, but through outfall sump; Backwash water shall be routed to settle sump to reduce TSS content before discharging to the sea through outfall;

Use small dredger to carry out maintenance dredging in intake channel to avoid intensive high content of TSS and accident with nearby facilities (main breakwater and low crest breakwater);

Dredged material will be disposed offshore at least 6.5 km away toward to the South of Hon Me Island.

Wastewater discharge and thermal effect

Cooling water temperature shall be controlled and maintained below 40oC before mixing with other treated effluents.

Regular monitor water temperature at intake water location and mixing zone area. Temperature of mixing zone shall not exceed 3oC above the temperature of the coastal ambient water.

Reuse cooling water for De-SOx purpose at FGD unit.

FGD effluent will be aerated to reduce COD before mixing with cooling water to the outfall;

All effluents are pre-treated at source (first stage) then routed to the effluent treatment plant (ETP) for further treating;

Oily sludge will be treated by the incinerator;

Wastewater from ETP and FGD will be treated to meet effluent standard QCVN 24:2009/BTNMT and combined with cooling water before discharging to the sea;

Install concreted barrier to protect the head of outfall system.


Monitoring Quarterly effluents monitoring. Surface water monitoring twice a year to collect information on:

Water quality of the immediate receiving environment;

Performance checks of operational controls.

Reporting NSRP LLC will make reports about surface water quality twice per year to relevant authorities and lenders.



5.2.2.5 Surface Water Management Plan (Offshore Facilities)

Objective Prevent surface water pollution by avoiding oil spill incidents and polluted water discharge to the ambient environment

Target No effect to baseline surface water quality by offshore activities and water discharging

Action Crude offloading at SPM

Inform local authority and fishermen the location of crude pipeline route in order to avoid anchoring and illegal explosive;

Deploy oil boom around tanker while offloading operation taken place and berthing at SPM;

Provide a standby supply boat and response equipment within offloading operation to prevent and on time response any spill or leakage;

Utmost care must be exercised when handling cargo in order to avoid oil spills. No oil or oily water is to be discharged overboard or allowed to escape overboard;

Any leakage or spillage must be reported immediately to the Project Owner, and all efforts to recover or limit the spill must be taken. The Project Owner will inform the local environmental authority accordingly.

Berthing and hose handling operations will be carried out during daylight hours with sufficient visibility. For the tanker arriving at the SPM, the cut off time for berthing is 1.5 hours before sunset.

Product loading at jetties

Strictly control product loading/offloading procedure and pipeline. Check obstacles at harbor basin for reducing oil leakage and oil spills.

No other vessel will be permitted to come alongside or remain alongside a vessel in berth while transferring cargo without the approval of the vessel’s Master and the harbor manager;

Approaching adverse weather or sea state conditions may require that the moored vessel depart the berth, they only leave when harbor manager approves;

Monitor system pressure in order to immediately discover leakage accident;

Limit risk of the pipeline leakage or broken by clearly mark and regularly monitor the pipeline trenching area;

Regular check shutdown and collection system as well as OSCP equipment in order to response on time;

Regular practice/train fire fighting procedure sand emergency response plan;

Coordinate with local authority and related agency (Nghi Son Port) or companies (NS Cement Plant) in setting up emergency response network;

Do not carry out product loading at night time;

Monitor sanitary and oily effluent discharge at harbor area.

Set up connect point for an 1,500 m oil spill containment booms from the harbor



shoreline;

Provide for spill containment measures at the jetty to remove spills and contain impacts on marine environment;

Provide Prevention measures during Loading Activities at the Harbor;

Do not permit any ships containing ballast water needed to be treated arrive the harbor;

Maintenance dredging

Characteristics of sediments (appearance of potential pollutant) will be surveyed / identified before dredging;

Plan dredging schedule to avoid peak shipping activities;

Dredging activity shall be carried out in daytime to avoid ship collision in the harbor and access channel;

Dredged material shall be dumped offshore at least 6.5 km away toward to the South of Hon Me Island. Control and monitor dredged material dumping process.

Wastewater

Oily effluent generating from harbour shall be collected to a sump and then transferred to plant ETP for treatment;

Sanitary effluent is treated at Jetty by sewage treatment package (STP) and the routed to plant outfall at 6 km far from the shore;

Sludge from STP will be transferred to the Refinery effluent treatment plant (ETP) for further treatment.

Responsibility NSRP LLC is responsible for implement Vessel Master for safe and efficient procedures during import/export activities at the harbor

Monitoring Surface water monitoring if any incident Quarterly effluents monitoring Surface water monitoring twice a year to collect information on:

Water quality of receiving environment;

Performance checks of operational controls.

Reporting NSRP LLC will make reports about surface water quality twice per year to relevant authorities and lenders.



5.2.2.6 Groundwater Management Plan

Objective Minimize groundwater contamination Prevent impact on the receiving environment from contaminated groundwater

Target No effect to ground water quality

Action Set up groundwater quality monitoring during operation phase.

Follow-up the final disposal of solid wastes and hazardous wastes to make sure that they comply with International and Vietnamese standards.

Responsibility NSRP is responsible to take action

Monitoring Groundwater sampling and analyzing twice a year to collect information that can be used to determine:

The characteristics and trends of contaminated groundwater migrating offsite

Whether any contaminant plumes may be forming or not

Routine performance checks and monitoring of the operation of the recovery system

Reporting NSRP LLC will make reports about groundwater quality twice per year to relevant authorities and lenders.

5.2.2.7 Marine Habitat Management Plan

Objective To maintain the abundance, diversity, geographic distribution and productivity of fauna at species and ecosystem levels through the avoidance or management of adverse impacts from project activities.

Target Minimizing disturbance to natural habitat of native fauna.

Action Onshore Facilities Continuous intake water system

Reducing cooling water flow for minimizing potential entrainment impact;

Entrapment and impingement to lower flow as proportionally fewer animals will be subject to contact with the intake structure;

Set up electro-chlorination at the water inlets to prevent fouling occurring on the screen bars.

Wastewater discharge

Online Control and monitor flow rate, cooling water temperature and chlorine content at the outfall. Cooling water temperature shall be maintained as lower than 40oC as possible;

Regular monitor water temperature at intake, outfall location, mixing zone area and surrounding Hon Me Island. Temperature of mixing zone shall not exceed 3oC above the temperature of the coastal ambient water;

Regularly check outlets by divers and take out bivalve species.



Offshore Facilities

Dredging activities should avoid sensitive period (from April to June) for benthic organisms;

Select appropriate dredger to minimize re-suspension of sediments;

Develop and implement Marine Protection Plan including: o Implement a comprehensive marine monitoring program, which entails

identification of indicator species and key indices – through periodic surveys and sampling, determine trends for the above to discern impacts, if any; and

o Develop a program for periodic sampling and analysis of sediments and seawater for physical/chemical parameters, as applicable, such as temperature, salinity, dissolved oxygen, pH, etc. at different depths and constituents of concern such as hydrocarbons and heavy metals, to determine cumulative impacts.

Responsibility NSRP LLC

Monitoring Rehabilitated areas will be monitored to ensure the success of the rehabilitation program. Monitoring the rehabilitated areas will ensure that any areas requiring remedial work are identified. Maintenance procedures will be carried out where necessary. The frequency of monitoring and maintenance will decrease as rehabilitation progresses.

Reporting The following fauna management information will be reported to relevant authorities and lenders in the annual environmental report:

Results of surveys if any recovering program implemented;

A summary of any incidents related to local aquatic community. 5.2.2.8 Waste Management Plan

Objective To minimize the quantity of generated waste and the environmental impacts caused by these wastes.

Target As a minimum, together with completed waste transfer forms, record of on site wastes stored and records of training. NSRP LLC shall develop waste management manual for the operation phase of Refinery.

Action Non-hazardous waste

All waste generated in the complex shall be classified in accordance with Vietnamese standards and World Bank Guidelines for Refining. TCVN 6705:2000 covers the classification of non-hazardous solid wastes.

Non-hazardous waste shall be controlled and separated at source into those that can be recycled or re-used, and those which must be sent to disposal. They shall then be stored in bags or tanks of given colors as specified by the law, as required by Decree No 59/2007/ND-CP, Solid Waste Management.

The specific actions for non-hazardous waste generated in the operation phase include: o Office paper waste from shredding will be collected in plastic bags to be stored

to licensed paper recycling agencies; o Scrap metals such as iron, aluminum and cable drums will be transferred to the

designated non hazardous waste storage area prior to offsite transportation to scrap dealers;



o Domestic wastes will collected and treated at landfill of NSEZ by the local waste treatment company.

o Used tyres, plastic bottle and glass will be collected in puncher resistant bags stored at area designated for its storage or at non hazardous waste storage area.

o Used PPE will be collected in separate bags, labeled, and stored at non-hazardous waste storage area.

Hazardous Waste

All hazardous waste will be managed in compliance with Circular 12/2006/TT-BTNMT issued by MONRE – Guidance of practice condition and procedure of documentation, registration, practice license and hazardous waste management code. Minimize and classify hazardous wastes generated from the Refinery; o Package hazardous wastes according to their categories in proper packing or

containers, which satisfy the technical safety requirements, and the signs and marks there on must be clear as prescribed by the regulatory of MONRE;

o Store hazardous wastes safety within the facility before transfer to the companies having license of collecting, transporting, keeping, treating and disposal.

The specific actions for hazardous waste generated in the operation phase include: o Spent catalysts will be collected into HDPE bags, labeled and transferred to

hazardous waste storage area prior to offsite transportation to catalyst Vendor; o Used lube and oil from will collected in to drums, labeled and transferred to

designated Hazardous waste storage area prior to offsite transportation to licensed lube oil recycling agencies;

o Spent adsorbents, sulpholane solvent, clay treated waste, used cartridge filter, tank residue waste and solid waste from maintenance activities of storage tanks will be collected in to HDPE bags, labeled and transferred to Hazardous waste storage area prior to offsite transportation to approved.

To survey results of NSRP LLC about actual qualification of companies having function of hazardous waste collection, transport and storage in the Northern area in 2009, hazardous waste generated from the Project will be treated by one of following companies: 1) Moi Truong Xanh Production – Commercial Service Company, Ltd., Block 15,

Nam Sach Industrial Park, Hai Duong Province; 2) URENCO Bac Son Joint Company, Nam Son Commune, Soc Trang District, Ha

Noi City; 3) URENCO Dai Dong Joint Company, Dai Dong Commune, Van Lam District,

Hung Yen Province. Radioactive Waste

Storage and use of radioactive substances and waste shall be in accordance with Decree No.50/1998/ NĐ-CP detailing the implementation of the ordinance on radiation safety and control and other recognized standards.

Responsibility NSRP LLC is responsible to take action

Monitoring Implement waste consignment notes indicating source/dates/quantities of generation along with periodic analyses of constituents;



Control waste treatment agencies on the process of waste collection, transportation, treatment and disposal;

Copy relevant valid licenses of the employed waste transporters and waste collectors;

Records of quantities of reused and recycled waste.

Reporting Recorded data as well as mitigation and disposal measures will be reported twice per year to relevant authorities and lenders.

5.2.2.9 Social and Community Management Plan

Objective Minimize social and/or community effects from the Project operation Maximize opportunities for local businesses

Target No complaints about social and community impacts

Action NSRP LLC will maximize opportunities for the involvement of local businesses in the project operation and for the employment of local residents NSRP LLC will communicate the requirements of the project’s employment policy to the local community, relevant organizations and businesses. This will include information on positions available, skill requirements and recruitment procedures To support local businesses, NSRP LLC will commit to:

Ensuring potential local businesses are provided with relevant information in an equitable and timely manner;

Ensuring local businesses are provided with the opportunity to supply under the same terms and conditions as external businesses;

Ensuring that contracts are awarded competitively which will include due consideration of non-cost factors such as reliability, maintainability, servicing…;

Provide support for local community organizations.


Monitoring Monitoring will be by stakeholders feedback, review of complaints and statistic related to local resident employment and business development

Reporting Communal issues will be reported annually to relevant authorities and lenders. 5.2.2.10 Employment and Training Management Plan

Objective To ensure that the affected people, the poor and the local communities may get benefit from the Project

Target Income restoration for the affected people Reduction of poverty in Tinh Gia District

Action NSEZ, Tinh Gia District and Training Organizations will organize a training program in order to maximize the number of employees coming from the Project area.

NSRP LLC will maximize Vietnamese participation and give a priority to the people affected by this project, where it is justified in respect of considerations of cost and quality.

NSRP LLC will emphasize selection and recruitment of high-performing Vietnamese



construction employees who will transition across to operation roles.

NSRP LLC will inform its local suppliers, contractors of this plan and the requirement to comply with the procedures.

NSRP LLC will develop the local supply chain to be able to support the operation activities, and to maximize the economic benefits that flow from the Project to the NSEZ, Tinh Gia District, Thanh Hoa Province and the country.

Responsibility NSRP LLC, NSEZMB, Tinh Gia District, Thanh Hoa Province Vocational Schools

Monitoring NSRP LLC will monitor direct and indirect employment numbers disaggregated by gender, by skill level, and by area of origin.

Reporting Statistic regarding training activities, employment data will be reported annually to relevant authorities and lenders.

5.2.2.11 Health and Safety Management Plan

Objective To ensure that the operation does not adversely affect the health of the employees, contractors or the general public

Target Zero reportable injuries and work-related illnesses

Action Prepare the Health and Safety Management Plan in accordance with the requirements of NSRP LLC HSE Management System


Monitoring The health and safety performance will be monitored in accordance with the NSRP LLC HSE Management System

Reporting Health and safety performance will be reported annually to relevant authorities and lenders.

5.2.2.12 Emergency response plan

Objective Minimize risk of incidents

Target Zero reportable injuries

Action Fire & explosion incident

Equip toxic / flammable gas detectors with emergency block valve (EBV). EBV must be installed outside of flammable area. If not, it must be covered with fire resistance layer in compliance with API 2001 Standards;

Check all equipments to minimize leaking risk (such as pipeline connection welds, safe valve in case of incident, manual liquid loading valve, flange covers);

Minimize risk for passers by early warning in case of leaking incident and blockading quickly entrance;

Monitor traffic roads in case of fire & explosion accident in the Plant. Toxic gas leaking

Evacuate labor out of dangerous area;

Inform local community and authority about the accident;



Prepare an Emergency Response Plan in the Plant; put it in working area and apply at once in case of accident;

Emergency response training and drilling. Oil spill incident

Prepare Oil Spill Response Plan (OSRP) for quick and more efficient response in case of incident;

Equip and maintain oil spill response equipment at SPM and harbor area, including: skimmer, containment boom (used for offshore area and tidal shore), oil containment bags, additive tank; temporarily store recovered oil in response ship at harbor;

Equip specific devices: pump, risers, oil absorbent, container… to clean the shoreline;

Apply suitable clear technology to restore diversity of environment;

Set up an emergency response team with suitable equipments and well training and drilling;

Organize training and drilling yearly with onshore and offshore response options for whole company including decision makers.

Sign agreements with local authority about seashore protection activities.


Monitoring Appropriate monitoring in accordance with HSE system of NSRP LLC

Reporting Report yearly to relevant authorities and lenders

5.3 PROJECT ENVIRONMENTAL MONITORING PLAN Environmental monitoring program is established based on Circular No.05/2008/TT-BTNMT issued by MONRE and Petrovietnam guidelines about monitoring of the environment in the vicinity of onshore and offshore petroleum facilities.

Monitoring activities for onshore facilities will include water quality, ambient air quality, soil quality and biology. Only facilities generating emission and wastes will be monitored.

Monitoring activities for offshore facilities will involve monitoring of sediments and the water column, including biota and other constituents.

In addition, the World Bank/IFC General EHS Guidelines specified the requirements for Continuous Emissions Monitoring (CEM) are applied. Environmental monitoring program will be carried throughout all project implementation phases, from pre-construction, construction and operation phases of plant with following purposes:

Identify all environment changes which may cause adverse effects on environment by the project implementation;

Monitor discharge sources (air emission, wastewater, cooling water and solid waste) and operation of environmental protection equipments in order to ensure that these activities will comply to legislative requirements;

Prevent potential fire and explode incidents in plant;



Propose appropriate environmental protection measures based on environmental monitoring results.

Environmental monitoring works for this project include three types as follows:

Continuous and periodical monitoring at discharge sources of plant area; Periodical monitoring environment surrounding project area; Supplement monitoring.

5.3.1 Monitoring Program for the Discharge Sources The purpose of regular monitoring program for discharge sources is to ensure that i) wastes have been treated to meet discharge standards before discharging into environment; and ii) is to check efficiency of treatment systems in order to adjust in time in case of the emissions are not met the project standards. The environmental monitoring program of project includes: Continuous Emission Monitoring System (CEMS) shall be provided for the following sources:

- FGD / boiler stacks – for SO2, NOx and PM - RFCC co boiler stacks– for SO2, NOx and PM - Gas turbine stacks – for NOx.

CEMS for parameters (temperature, pH, COD) will be installed at the outfall of industrial wastewater treatment system (ETP).

The parameters of continuous monitoring at plant site are presented in Table 5.1.

Table 5.1 Continuous Monitoring Parameters

Location Annual Stack Emission Testing Parameters Continuous Emissions Monitoring Parameters

Boilers (between 20-50 MWth)

- SO2, NOx and PM - NOx only for gaseous fuel fired boilers - SO2 can be calculated based on fuel

quality certification if no SO2 emission control equipment used

- SO2 (continuous monitoring for plant with SO2 control equipment)

- NOx (continuous monitoring or indicative emissions using combustion parameters)

- PM (continuous monitoring of emission, opacity or indicative emissions using combustion parameters/visual monitoring)

Gas Turbines

- SO2 and NOx - NOx only for gaseous fuel fired boilers - If annual stack emission testing results

show emissions constantly less than 75% of required levels for 3 consecutive years the frequency of testing can be reduced to every two or three years

- SO2 (continuous monitoring for plant with SO2 control equipment)

- NOx (continuous monitoring or indicative emissions using combustion parameters)

In normal operation, flare will be continuously monitored by camera system (ITV) from control room. Continuous monitor station for output discharge of ETP will be installed at the end of treated waste water pump. Information about equipments package for ETP at storage tank will be developed in detail in the next stage. Mixture effluent treated at ETP, output sea water and waste water treated at habour



area will be blended in outfall pipeline. Initial discharge point is planned to be 6km far from the seashore. Final discharge point will be defined exactly in detailed design stage. Periodic Environmental monitoring includes:

- Air emission;

- Effluents: Sanitary, treated wastewater, cooling water. All wastewater streams discharge to the environment will be monitored such as: (i) Effluent discharges will be measured on a daily basis; (ii) Drainage monitoring and testing program to prevent soil and groundwater contamination in the event of underground drain failure.

The parameters of periodical monitoring stations are presented in Table 5.2.

Table 5.2 Regular Monitoring at Discharge Sources – NSRP LLC

Discharge sources

Sampling location 1 Frequency Parameters

Air emission - At the process stacks - At the stacks of combustion units - At the flares (last two parameters)

- SO2, CO, NOx, PM - Hydrocarbon, NH3 - Record the quantity and

characteristics of fuel, content of sulphur

- Observation of opacity

Wastewater (including FGD & ETP effluents)

- At the outlet of treatment system plant (ETP)

- At the outlet of FGD treatment system

- pH, Temp., smell, color, TSS, BOD5, COD, Total oil content, Cyanide, Phenol compound (Phenol and cresol), Ammonia, Chloride (Cl2), Sulfur, Floride, Total Nitrogen, Total Phosphor, coliform.

- Heavy metals (Zn, Cr, Cu, Cr(III), Cr(VI), Ni, Hg, Cd, Pb, As, Mn, Fe)

- Discharge flow rate and wastewater volume

Storm Water At the outlet of treatment system (storm water pond) - COD, TSS, pH, Oil content

Domestic Waste Water At the outlet of treatment system - BOD5, pH, Coliform

Cooling Water At the outlet of cooling system

4 times / year

- Temperature, pH, Cl2 Above monitoring results will be cR Notes

Rbe recorded and reported to relevantn Proposed regular air and water sampling stations for

ompared with Project Standard at Item 0.2.2.3, Section 0 of this eport.

1: Coordinates of proposed point sources monitoring are referred to coordinates of 19 stacks and 2 flares mentioned in Table 3.18 Emission Input Data of Point Source.

Coordinates of outlet of ETP, cooling, FGD and domestic effluents will be determined at commissioning stage.

egular monitoring is carried out by direct measurement or sampling and analyzing. These results will authorities in order to have suitable solution to prevent any

egative impact to environment.

the discharge sources is given in Figure 5.1.



Figure 5.1 Regular sampling stations for the discharge sources at the Refinery and Petrochemical Complex Project



5.3.2 Monitoring Program for the Surrounding Environment Monitoring program for ambient environment of NSRP LLC will be implemented throughout project execution in order to assess environmental impacts caused by the project, to immediately identify environmental pollution sources and propose treatment measures. Implementation of this program will be divided into 3 phases as follows: 5.3.2.1 Pre-construction phase Environmental program in this phase is considered as environmental baseline monitoring. The results of this monitoring program are evidence to assess environmental impacts of Project’s activities in the future. This baseline was carried out as a part of EIA report in accordance with Petrovietnam guidelines and IFC requirements. Environmental baseline monitoring for project area had been implemented three times including two monitoring survey during the rainy season 2008 – 2009 (August 2008 and June 2009) and one during the dry season (February 2009). Only environmental baseline monitoring in August 2008 was carried out before onshore pre-construction activities took place. Location and coordinate of sampling stations are presented in Table 5.3 and Figure 5.2 and Figure 5.3. Location of measuring station for noise and vibration are presented in Figures 5.4.

Table 5.3 Sampling Station in Project area Rainy Season (August, 2008) and Dry Season (February 2009)

Coordinate

Sample Station Location Y (m) X (m)

Parameters

B-1 Lach Bang river mouth 582403 2145255

B-2 Lach Bang river 580628 2145943

B-3 Dumping site of project’s subsoil materials

580881 2142931

B-4 Proposed treated wastewater discharging site of the complex

583207 2141610

B-5 Proposed intake cooling water site of the complex

583467 2140543

B-6 Proposed cooling water discharging site for the complex

583630 2139896

B-7 585726 2136850

B-8 585882 2135532

B-9

Around Nghi Son integrated port and its access channel

586049 2134913

B-10 In the middle area between B1 and B4 582736.2 2143735.6

Coastal water, bottom Sediment and biological community at received environment of discharged effluents

B-11 Close to Nghi Son fishing village 586893.4

2138191.2

(1) River and Coastal water samples - pH, Temperature, salinity (in

situ) - TSS, BOD, Total N, Total P,

CN-, TOC, Oil and grease, Benzene, Phenol, Coliform

- Metals (Pb, Cu, Zn, Cr, Cd, Hg, V, Fe)

(2) Seabed sediment samples - Particle size distribution - Hydrocarbons - Metals (Pb, Cu, Zn, Cr, Cd,

Fe, Hg) (3) Biological sample - Benthic samples - Plankton samples

K-1 595662 2143171

K-2 Close to crude shipping channel (Me islet) 594440 2139681

Sediment & water at SPM, crude pipeline K-3 Single point mooring (SPM) – old

alternative 596385 2143282

(1) Offshore sediment samples - Particle size distribution - Hydrocarbons (total oil

content, hydrocarbon



Coordinate Sample Station Location

Y (m) X (m) Parameters

K-4 Mieng island 595199 2142263

K-5 591327 2141057

K-6 Along submarine crude oil pipeline system – old alternative 588818 2140978

K-7 Close to Nghi Son fishing village (floating fish cage)

586110 2139096

K-8 Sea gate connecting Nghi Son cement jetty to Nghi Son integrated Port

585387 2138651

K-9 Nghi Son integrated Port 585714 2135279

K-10 586340 2134219

K-11 587569 2132741

K-12

Shipping channel to Nghi Son integrated Port

588187 2132357

E-1 585762.76 2143557.49

E-2 588461.64 2144867.48

E-3 592060.14 2146614.13

E-4 595984.88 2148519.14

E-5 610800.35 2150864.72

E-6 619621.00 2152261.20

E-7 610969.00 2147829.16

E-8 623391.97 2147257.12

E-9 613487.41 2144316.58

E-10 623522.01 2141907.16

E-11 605454.85 2145306.70

E-12 615673.93 2141840.15

E-13 621035.21 2153675.41

E-14 624806.18 2148671.33

E-15 624936.22 2143321.37

E-16 622107.80 2140492.95

E-17

Along crude pipeline and proposed SPMs

614259.72 2140425.94

E-18 584413.33 2141702.50

E-19 588911.45 2142585.81

E-20

Along proposed access channels

592509.95 2144332.47

E-21 593863.2 2140144.1

E-22 595216.1 2139207.4

E-23 598120.3 2139050.7

SPM, crude pipeline and access channel

E-24

Around Me archipelago

598088.3 2141721.9

elements) - Trace metals (Pb, Cu, Zn, Cr,

Cd, Hg, V) (2) Offshore sea water samples - Site measurement (DO, pH,

Temp. salinity) - TSS, BOD, Total N, Total P,

NH4+, NO3-, NO2-, CN-, THC, Phenol

- Metals (Pb, Cu, Zn, Cr, Cd, Hg, Fe)

G-1 579714 2139604

G-2 Refinery plant area

581571 2140920

Groundwater samples

G-3 Along proposed onshore pipeline system

583088 2139762

- pH, Color, Hardness - TDS, COD, SO42-, Cl-, NH4+,

CN-, NO3-, Mineral oil and fat, Benzene, Phenol, Coliform,



Coordinate Sample Station Location

Y (m) X (m) Parameters

G-4 Nghi Son fishing village 586212 2135223

G-5 Product export harbour 586042 2138253

G-6 Eastern corner of refinery plant, close to the beach

582102.0 2141271.0

G-7 Refinery plant area 581014.7 2141872.5

Fecal coliform - Metals (Pb, Cu, Zn, Cr, Cd,

Hg, Fe, Mn)

D-1 Dumping site of project’s subsoil materials

580881 2142931

D-2 Area A – Refinery plant 579697 2140014

D-3 579714 2139604

D-4 581571 2140920

D-5

Refinery plant area

581919 2140049

D-6 Coastal area 583088 2139762

D-7 Nghi Son fishing village 586212 2135223

D-8 Nghi Son Integrated port 586042 2138253

Soil samples

D-9 Refinery plant area 581014.7 2141872.5

- THC, TOM, Metals (Hg, Cd, Zn, Fe, Pb, Cr, Cu)

A-1 Populated area near Lach Bang river

581809 2145674

A-2 Populated area of Hai Yen commune

581262 2142614

A-3 581571 2140920

A-4 Refinery plant area

579741 2139607

A-5 School area of Mai Lam commune 582102 2141271

A-6 Coastal area 583085 2139745

A-7 Nghi Son fishing village 586207 2135224

Air samples

A-8 Nghi Son Integrated port 586274 2138406

TPS, PM10, CO, NOx, SOx, H2S, THC, Benzene, Xylen, Noise, Vibration

Grid: UTM, Datum: VN2000



expansion ar ea

t r ¹ m biÕn ap

220/110KV

cÇul au

®uêng hÇm qua nói

hå

quÕ s¬n

f ut ur e

x·

mai l ©m

wsw

w

sw

sssw sse

e

ese

se

wnw

nnnw

nw

nne

ene

ne

§uêng èng xuÊt s¶n phÈmvÞ t r Ý mai l ©m

hßn v¸ t

gul f

§ª ch¾n c¸ t

l uång vµo bÕn xuÊt s¶n phÈm

bÕn sè 1&2 c¶ng Nghi s¬n

bÕn xuÊt s¶n phÈm l áng

bÕn phôc vô x©y dùng - xuÊt s¶n phÈm r ¾n

bÕn t Çu phôc vô cña c¶ng

nói xuí c

nói chuét t r ï

nhµ m̧ y xim̈ ng nghi s¬n

t r ¹ m biÕn ̧ p - power st at ion 110/22KV

®¶o

nghi

s¬n

t onkin

hßn géc

hßn miÖng

vòNG NEO TÇUD = 1000 M

SCALE:ASA

t æng mÆt b»ng khu l iª n hî p l äc hãa dÇu nghi s¬n

l uång vµo bÕn nhËp dÇu t h«

h¶i yÕn vil l age nhËp dÇu t h«t uyÕn ®uêng èng

s«ng b¹ ng

hßn b«ng hßn häp

bÕn nhËp dÇu t h«

hßn vang

hßn mªhonme

over al L sit e pl an of nghi son r ef inEr y and pet r ochemical compl ex

ent r ance channel of impor t ber t h

submar ine cr ude oil pipel ine

bong isl and

pr oduct expor t pipel ine

l iquid pr oduct expor t ber t hs

nghi son isl and

t ug ber t hs

ber t h f or const r uct ion wor k and sol id pr oduct expor t

ber t h exist no1 and No2

embankmentent r ance channel of pr oduct expor t ber t hs

®«ng

biÓn

nghi son cement f act or y

TRu mount ain

power st at ion220/110KV

que sonl ake

më r éng

khu vùc

x· h¶i yÕn

mai l am vil l age

isl and hop

isl and goc

isl and mieng

isl and vat

isl and vang

Hai t huong

mai l am Sit e

DWG: No3-01

Stations for Surface Water, Bottom Sediment and Biological samples - offshore (Total: 12)Stations for Surface Water, Bottom Sediment and Biological samples - onshore (Total: 09)

Stations for Ground Water samples (Total: 05)Stations for Air and Noise samples (Total: 08)Stations for Soil samples (Total: 08)

K1K2

K3

K4

K5

K6

K7

K8

K9

K10

K11

K12

B1

B2

B3B4

B5

B6

B7

B8

B9

A1

A2

A4

A3

A5

A6

A7

A8

D1

D2D3

D4

D5

D7

D6

D8

G1

G2

G3

G4

G5

Figure 5.2 Onshore Sampling Stations in August 2008 (Rainy Season) and February 2009 (Dry Season)

E1

E2

E3

E4

E5

E6

E7E8

E9

E10

E11

E12

E13

E14

E15

E16E17

E18

E19

E20

E21

E22 E23

E24

Figure 5.3 Offshore sampling stations in dry and rainy season 2009 (February & June)



Tinh Hai Commune

Connection point of soft ipeline and crude oil pop rt

N01

N02

N03N05

N04

N06

N07

N08

N09N10

N11 N12N13

N16N14

N15

Coc Mountain Hai Yen

Commune

Mai Lam Commune

Nghi Son Border Post

Product Export Port of Nghi Son Cement Factory

Cam Mountain

Figure 5.4 Measurement stations for noise and vibration at the Plant boundary

5.3.2.2 Construction phase According to Circular No.05/2008/TT- BTNMT- Appendix 4, all waste sources generated in construction phase need to be monitored. Therefore, EPC Contractor and Sub-contractors will have the responsibility to monitor at the project execution area in order to ensure that they are not causing environment pollution and respect the project standards as follows:

Irregular source: cleaning and hydrotesting water, storm water or effluent in emergency case. These sources will be monitored by bath;

Regular source: Domestic wastewater and solid wastes will be monitored quarterly (4 times/year).

In case of occurring oil/chemicals spill, EPC Contractor must have responsibility for monitoring soil and groundwater samples to assess effects of the accident and propose mitigation measures. EPC Contractor will undertake the following monitoring surveys:

- Construction equipments will be inspected regularly for proper functionality and any damage to silencers/acoustic. A proper maintenance program for all vehicles should include inspection of exhaust system and silencers efficiency.

- Periodic noise monitoring (by octave band analyser type) will be implemented and reported every six months. The results will be retained at least for 3 years.

- ‘Housekeeping” inspections will be implemented periodically to ensure dust (fugitive emissions) is minimized.

- The generation and disposed of waste will be monitored. Summary of the quantity of waste produced during the construction will be presented to NSRP LLC every month.



- Regular site visits will be carried out to check and control any groundwater and soil contamination at the facility. Detailed monitoring program in construction phase will be prepared by EPC Contractor in order to comply with requirements of Circular 05/2008/TT- BTNMT (Annex 4) and adopted by NSRP LLC. 5.3.2.3 Operation phase In order to rapidly detect and prevent pollution and environmental incidents during operation phase, NSRP LLC will carry out environmental monitoring for onshore and offshore site facilities. 1. Air, Water, Noise and Vibration Monitoring Monitoring for surrounding environment of Nghi Son Refinery and Petrochemical complex will be implemented at least 2 times per year (every 6 month). Location of sampling and measurement stations are defined based on modeling results and risk of impacts. The sampling locations, analytical parameters and frequency of monitoring surrounding environment of NSRP Project are shown in Table 5.4, Figure 5.5 and Figure 5.6.

Table 5.4 Monitoring Plan at Surrounding Environment of NSRP

Environment Number of sampling station

Proposed sampling locations Frequency Parameters

1 At storm water pond, before discharge to the receiving water body (Storm water)

- COD - TSS - pH - Oil content

1 At intake channel 1 At the North of intake channel 4 At riser outlets of outfall system 3 Around outfall system 1 At head of breakwater, near the jetty 3 1 At Harbour basin between jetty 1 and 2 2 At Harbour basin between jetty 2 and 4 1 At Harbour basin between jetty 4 and 5 1 At Harbour basin between jetty 5 and 6

1 At the South of harbour basin 1 At SPM (N19021’ 59.48”; E 106005’ 57.57)

2 Around SPM site

Water

2 Proposed dredged material dumping area

- TSS - COD - DO - Florua (F-) - Sulphur (S-2) - Total oil content - Cyanide - Phenol compound

(Phenol and cresol) - Ammonia - Heavy metals ( Zn, Cr

(III), Cr (VI), Cu, Ni, Hg, Cd, Pb, As, Fe, Mn)

- pH - Temperature - Coliform - Radioactive - Radioactive β

Seabed sediment 22

At the same 22 above-mentioned water sampling locations

2 times/year

- Particle size distribution - Hydrocarbon - Metals (Pb, Cu, Zn, Cr, Cd,

Hg, V)

- Benthic



Number of Environment Proposed sampling locations Frequency Parameters sampling

station

1 Primary school at Tinh Hai commune as receptor

1 Primary school at Mai Lam commune as receptor

Air samples

1 Primary school at Hai Yen commune as receptor

- TPS, PM10, CO, NOx, SOx, H2S, THC, Benzen, Xylen, NH3

1 1 At the boundary of plant and near main gate

1 1 at Primary school at Hai Yen commune as receptor

Noise and Vibration

1 1 at Primary school at Tinh Hai commune as receptor

- Noise - Vibration

Notes: Monitoring parameters are based on QCVN 10:2008/BTNMT for Coastal Water Quality The proposed coordinates of some main monitoring sites at SPM, Outfall and intake water are listed as follows:

Proposed coordinate as VN-2000 No. Proposed some major monitoring sites

Easting Northing 1 SPM 106005’ 57.57 N190 21’ 59.48”; E 2 Intake water - - 3 Effluent outfall (6km) 588608.056 2143631.635

These proposed coordinates will be reconsidered in detail engineering phase.

Figure 5.5 Proposed sampling location of surface water at outfall and intake channel



2. Groundwater Quality Monitoring Groundwater monitoring is implemented to identify the quality and extent of any groundwater contamination caused by the Project activities. Based on Circular 05/2008/TT-BTNMT dated on 08th December 2008 and Petrovietnam monitoring guideline for surrounding environment for onshore petroleum facilities, groundwater shall be monitored as follows:

- In operation phase, monitoring groundwater stations are set up in relation to any potential oil leakage affected areas. Location of wells at the site area will be reconsidered again during the detail basis design phase. These locations will be based on project activities like process area, crude oil tank farm, product tank farm, loading/unloading jetties and solid waste storage area will be required. Preliminary location of these wells and identification of the groundwater quality parameters are shown in Table 5.5 and Figure 5.6.

- In the case of oil leakage, oil spill or chemical spill which might cause negative impacts to groundwater, it is

necessary to supplement periodic monitoring stations at downstream aquifer of potential affected area. In addition, reference station shall be set up at the upstream aquifer for comparison.

Table 5.5 Location and parameters of permanent groundwater monitoring wells

of the NSRP Project during operation phase No. Well location Frequency Parameters *

1 Outside the plant boundary near the process units area

2 Outside the plant boundary near the Intermediate tankage area

3 Outside the plant boundary near the Polypropylene unit area

4 Outside the plant boundary near the crude oil tanks area

5 Inside the plant at the guard basin area

6 One site at the Northeast corner of the plant near the pipeline

7 Outsite the plant boundary near the spheres tankage area

8 One site at the North of product harbour

2 times/year

- pH - Hardness (as CaCO3) - TSS - COD (KMnO4) - NH4

+- N

- Cl -

- Nitrite (NO2- - N)

- Nitrate (NO3- N)

- SO4-2

- Florua (F -) - Sulphur (S2-) - Total oil content - Cyanide (CN-) - Total Phenol - Heavy metals ( Zn, Cr (VI), Cu, Zn, Hg,

Cd, Pb, As, Fe, Mn, Se) - Ecoli - Coliform - Radioactive - Radioactive β

Notes: Monitoring parameters are based on QCVN 9:2008/BTNMT for groundwater quality NSRP LLC is a member of NSEZ, so NSRP LLC will closely co-operate with NSEZ Management Board in environmental management and protection activity. NSRP LLC will present an environmental management and monitoring plan with NSEZ to find the best solution for environmental sustainable development.



Figure 5.6 Proposed monitoring locations of air, noise and groundwater of the NSRP Project during operation phase



5.3.3 Additional Environmental Monitoring Surveys Beside monitoring for discharge sources and surrounding environment, the NSRP LLC will carry out other monitoring as follows: Turnaround maintenance of the process and emergency case At the time of turnaround maintenance of the main process, a large volume of irregular wastewater and solid wastes will be generated. NSRP LLC will have responsibilities to carry out an additional monitoring survey at the discharge sites. In emergency case inside the plant boundary: NSRP LLC will undertake an additional monitoring program for air, water, soil and groundwater in both project area and the vicinity. Number of samples and sampling sites will be determined based on scale of the accident occurred. In the case of oil spill occurred at one of marine facilities (SPM, crude pipeline, harbour), NSRP LLC will undertake monitoring program for air, sea water, seabed sediment (both chemical and biology) and economic damage assessment. Detail monitoring program will be based on scale of the accident and affected area. Pipelines Monitoring According to the Petrovietnam guideline about monitoring of the environment in the vicinity of offshore petroleum facilities, there is a cascade of environmental monitoring to be carried out before pipeline installation. The location of sampling stations will be along the pipeline route. Environmental monitoring of pipelines is only required in the event of an accidental spillage. Pipeline pump or compressor stations should be monitored if there is any emission to the environment. Coastal sea bed monitoring Due to continuously seawater intake and effluent discharging at coastal area, NSRP LLC will carry out periodical monitoring program (3 years/time) of erosion of coastline and sea bed condition at intake, outfall sites and the vicinity. The survey sites will be set up at intake and outfall location and upstream and downstream of these sites. 5.3.4 Proposed budget for environmental monitoring program Proposed cost for environmental monitoring program of the Project is preliminary estimated as follows:

- Construction phase: 100,000 USD/year - Operation phase: 100,000 USD/year



Section 6.

PUBLIC CONSULTATION

6.1 PUBLIC CONSULTATION AND DISCLOSURE 6.1.1 Regulations and Requirements

The IFC Performance Standard 1 on social and environmental assessment and management systems require that the project owner of a project undertakes a process of consultation in a manner that provides the affected communities with opportunities to express their views on project risks, impacts, and mitigation measures, and allows the project owner to consider and respond to them. Effective consultation:

Should be based on the prior disclosure of relevant and adequate information, including draft

documents and plans; Should begin early in the social and environmental assessment process; Should focus on the social and environmental risks and adverse impacts and the proposed

measures and actions to address these; and Should be carried out on an ongoing basis as risks and generated impacts. The consultation

process should be undertaken in a manner that is inclusive and culturally appropriate.

In accordance with legislative requirement of Circular No 05/2008/BTNMT of MONRE, NSRP LLC has to organize a combined consultation meeting with the representative of three affected communes including:

Meeting with chairman of three affected commune People Committee (CPC) and Committee

for Fatherland Front (CFF) of affected communes and propose local authorities send their opinions on project implementation.

Feedback and commitment of Project Owner after receiving opinions from affected communes.

6.1.2 Public Consultation and Disclosure Program In compliance with IFC requirement, two stakeholder consultations were held on 4 November 2008, at the beginning of the project, and on 27 January 2010, after completion of the preliminary ESIA Report, in Tinh Gia district. Also, two public consultations were carried out on 5 November 2008 (Tinh Hai Commune) and on 28 January 2010 (Hai Yen Commune) in the Project area.

The purpose of the stakeholder and public consultations were to (i) disclose information on Nghi Son project; and (ii) consult participants on potential environmental issues that may generate from the construction and operation of the Project. Also conducted, were consultations with various government agencies during the preparation of ESIA modules as well as socio-economic survey and meetings for



preparation of the resettlement due diligence survey. Table 6.1 provides a summary of the consultations conducted.

Table 6.1 Summary of stakeholder and public consultations

Date and Location Participants Topics/Issues Discussed 4 November 2008 at Tinh Gia PC

Chairman of Thanh Hoa PPC; Chairman of Tinh Gia District PC; Chairmen and land management officers of Hai Yen, Tinh Hai and Mai Lam Communes PC; Director of NSEZMB Number of participants: 37 persons

IFC policy on environment and resettlement

Environmental issues during construction and operation

Relocation requirement due to the project

Resettlement sites Compensation policy Income restoration strategy including

NSRP LLC recruitment strategy 5 November 2008 Office of Tinh Hai Commune PC

Chairmen and land management officers of Hai Yen, Tinh Hai and Mai Lam communes PC; Director and Deputy Director of NSEZ Management Board Representatives of affected households Number of participants: 33persons




NSRP LLC recruitment strategy

27 January 2010 Office of Tinh Gia District PC

Chairman of Tinh Gia District PC; Chairmen and Fatherland front representatives of Hai Yen, Tinh Hai, Mai Lam Commune PC, Manager of Environmental and Resource of NSEZ Management Board Environmental and resources and resettlement officers from Tinh Gia District Number of participants: 33persons

IFC policy on environment and resettlement

Environmental issues during pre-construction, construction and operation phases



NSRP LLC recruitment strategy Current situation regarding

resettlement, environmental and social issues (pre-construction)

28 January 2010 Office of Hai Yen Commune PC

Chairman of Hai Yen Commune PC Director of Resettlement for Tinh Gia District PC Manager of Economic and Financial Department of NSEZ Management Board Morning Session: Representatives of affected households from the three communes (42 persons) Afternoon Session: Representatives from the three communes (27 persons)

Environmental issues during pre-construction, construction and operation phases

Resettlement and Compensation policy for affected peoples by environmental impacts

Current situation regarding resettlement, environmental and social issues (pre-construction)



6.2 PUBLIC CONSULTATION RESULTS 6.2.1 The First Consultation (4 & 5 November 2008)

The first Stakeholders Consultation was held on 04th November 2008 at Tinh Gia PC. The main project stakeholders were invited to this stakeholder consultation. The meeting included the following stakeholder representatives: Chairman of Thanh Hoa Province, Chairman and Vice-chairman of Tinh Gia District, District Party Committee Secretary, Chairmen or Vice-Chairmen of the affected Commune and different district departments. Total number of participants is 37 persons. The first Public Consultation was held on 05th November 2008 at Tinh Hai Commune. The project affected people were invited to this public consultation. The meeting included also the following stakeholder representative: Vice-Chairman of Tinh Gia District, Chairmen or Vice-Chairmen of the affected Commune and representatives of Nghi Son Economic Zone Management Board. Total participants were 56 persons. Main issues discussed and responses: Project Overview

Project Overview and recruitment strategy were presented by NSRP LLC in which information about Owner, feed stock, products, project benefits as well as living improvement opportunities for local people were addressed.


Environmental issues were presented by the Environment Consultant in which the national and international legal requirements, standard requirements, the project standards, the process of EIA, OSCP as MONRE requirement and ESIA, ESMP as IFC requirement were discussed. The Consultant indicated that the project owner will comply with most stringent IFC international and national environment, health and safety standards and integrate Environmental Design Basis into engineering, construction and operation phases.

Relocation requirement due to the project and Resettlement sites (RS) Resettlement and social issues for NSRP Project were presented by the Resettlement Consultant in which the IFC requirement for land acquisition and involuntary resettlement (PS5), the conformity of Project Policy with IFC Performance Standards as well as status of resettlement activities were assessed and presented.

Compensation policy The progress of compensation and resettlement activities for NSRP Project was presented by representative of NS Economic Zone Management Board in which all efforts of Thanh Hoa Province, the difficulties and implementation plan are mentioned.

Discussed issues and results of the first consultation are as follows:



1. Chairmen or vice chairmen of three affected communes (Mai Lam, Hai Yen and Tinh Hai) have summarized the agreement and disagreement related to the compensation policy and rate. The main issues of affected people (APs) are focused on compensation rate, resettlement sites and job opportunities.

2. In general, all local authorities and APs highly supported NSRP implementation at Tinh Gia

District. However, proposed compensation rates for residential land and structure have not yet reflect market value prices. Thanh Hoa PC shall reconsider compensation rates for residential land structures and graves in order to reflect replacement costs and take into account inflation. The RS construction progress is too slow, it was required Thanh Hoa Province Committee shall push up RS construction progress as much as possible.

3. It was proposed to give priority to APs for jobs during the construction period (will be mentioned in contractors’ contract). NSRP LLC should provide Tinh Gia PC a long term strategy of employment for APs (permanent job in the refinery or in other industries in the Nghi Son Economic Area).

6.2.2 The Second Consultation (27th & 28th January 2010) The Second Stakeholders Consultation was held on the 27 January 2010 at Tinh Gia PC. The main project stakeholders were invited to this stakeholder consultation. The meeting included the following stakeholder representatives:

1. Chairmen of three affected Commune People Committee (CPC) 2. Chairmen of three affected Front Father Committee (FFC) 3. Chairmen of three affected Communist Party Committee, and 4. Repsentatives of different district departments.

The second public consultation was held on 28 January 2010 prior to ESIA finalization. The purpose of the public consultation will provide the opinions from affected persons related to resettlement issues and environmental and social impacts as well as proposed mitigation and compensation measures. The Second Public Consultation meeting has been divided into two sessions to avoid concentrating discussion on resettlement issues. The subject of the morning session was about resettlement issues. The people invited were members of project affected households by resettlement issues. The afternoon session was dedicated to environmental and social issues. The participants (42) attending to the morning session have been selected by the People Committee of the three affected communes (Hai Yen, Tinh Hai and Mai Lam). The participants (27) attending to the afternoon session have been selected by the People Committee of each of the three communes affected by NSRP Project (Hai Yen, Tinh Hai and Mai Lam). The participation of the people was free and everybody was able to present their concerns and requests to the authorities. Some of the participants (7) were also present to the morning session since their concerns were difficult to address in the morning (current dust problems and erosion (sludge runoff and flooding of their lands causing resettlement issues). The main issues discussed during the meeting were:

1. Project summary and Recruitment Plan were presented by NSRP LLC in which the project capacity, project schedule, feed stock, products, project strategy and project benefits as well as living improvement opportunities for local people were addressed.



2. Resettlement and social issues for NSRP Project including the International Financial Cooperation (IFC) Performance Standard on resettlement (PS5), the policies of Government of Vietnam, Thanh Hoa province and NSEZ, project impacts & status of resettlement activities, problems met during implementation, actions taken by Thanh Hoa province people committee (PPC), Tinh Gia Resettlement Committee (TGRC), NSEZ and the conformity between project policy and IFC Performance Standards as well as recommendations were assessed and presented by the resettlement consultant.

3. Environmental issues including the general project description, national and international legal

requirements, standard requirements, the project standards, environmental and social baseline studies, the impact sources, major impacts and mitigation measures (air emission, effluent discharge, solid wastes and environmental treatment system), environmental and social management plan (ESMP) as MONRE and IFC requirements were presented by CPSE. The project owner will comply with the more stringent international (IFC) and national environment, health and safety standards as well as efficiency and safety operation for project and employees.

4. The International consultant emphasizes on dust pollution and traffic safety as current (pre-

construction) major environmental issues that need to be discussed in order to find the best mitigation measures, especially for local students traveling every day along with dense heavy traffic on provincial road 513.

5. The responsibilities of different phases (pre-construction, construction and operation) were

informed/emphasized by NSRP LLC. The responsibilities of pre-construction phase belonged to local authorities and NSPM. NSRP LLC will have the responsibility for construction and operation phases. NSRP LLC will apply strict environmental standards and will not affect people located around the refinery site.

6. In general, the compensation and resettlement policies applied in NSEZ seem the best ones in

Vietnam, especially for the NSRP Project. Households affected by NSRP Project have received special compensation rates from Thanh Hoa PC. Most APs are satisfied with the resettlement policy applied in Hai Yen, Mai Lam and Tinh Hai communes especially due to the new Decision No. 4366/2009/QD-UBND dated 5 December 2009 reflecting the new Decree 69/CP issued by the Prime Minister.

7. Compare to Performance Standard 5 (PS5), Project policy meets generally IFC objectives on resettlement; the main remaining issues are the absence of restoration of income program and training program.

8. NSRP Project will give priority to APs for jobs during the construction and operation period.

9. The Chairmen of Commune PC/Chairmen of Front Father Committee/Chairmen of Communist

Party Committee of three affected communes (Mai Lam, Hai Yen and Tinh Hai) summarized their views on compensation, allowances and resettlement progress. The main issues of affected households (APs) focus on compensation/allowance rate, resettlement sites, job opportunities and environmental issues.

10. It was required NSRM and constructional contractors to urgently solve environmental pollution

of dust, noise, flooding and road damages.



6.3 OPINIONS OF LOCAL COMMUNAL PEOPLE COMMITTEE AND FRONT FARTHERLAND COMMITTEE

6.3.1 Consultation with Mai Lam Commune Opinions of Commune People Committee (CPC) According to Letter No.12/NSRPLLC sent by NSRP LLC to Mai Lam CPC on 19th January 2010 about public consulting for Nghi Son Refinery Project and contents of the summarized Environmental Impacts Assessment (EIA) report of the Project, Mai Lam CPC found that NSRP had applied very strictly environmental policy and standards of Vietnam and International requirements. All sources of air pollution and wastewater are both estimated and detailed assessed in order to avoid causing negative impacts on environment. Solid waste generated from construction and operation phase is collected and treated properly. The report focused on considering compensation, resettlement issues and effects on local community and proposal of specific and feasible mitigation measures for each phase of the Project. Mai Lam CPC have mutual consensus and confirm socio-economic benefits that the Project bring locality and country with. Mai Lam CPC advocates deploying the Project and basically agreeing with contents of the EIA report of the Project. However, during construction phase, Mai Lam CPC suggests NSRP LLC should concentrate on some following issues:

Compensation rates for residential land should be resolved reasonably; Local roads were downgraded seriously due to heavy traffic situation stringed from Project’s

transportation demands. It is suggested that NSRP LLC should support to upgrade these roads for local communities, especially affected pupils;

The cemetery in Mai Lam commune is being downgraded due to run-off water from the mountain. It is suggested that NSRP LLC should support to repair graves crashed down and inclined;

Create condition for households working very far from homeland to receive compensate. Opinions of Mai Lam Front Fatherland Committee (FFC) According to Letter No.12/NSRPLLC sent by NSRP LLC to Mai Lam FFC on 19th January 2010 about public consulting for Nghi Son Refinery Project and contents of the summarized Environmental Impacts Assessment (EIA) report of the Project presented in the second public consultation meeting held at Tinh Gia District People Committee on 27th January 2010 by the Project Owner, Mai Lam FFC have some ideas about carrying out NSRP Project in Mai Lam area as followings:

Compensation rates for residential land should be resolved reasonably; The access route was downgraded seriously due to heavy traffic situation from Project’s

transportation demands. It is suggested that NSRP LLC should support to upgrade these roads for local communities;

The cemetery in Mai Lam commune is being downgraded due to the run-off water from mountain. It is suggested that NSRP LLC should support to repair graves crashed down and inclined.

Mai Lam FFC wants to have a close cooperation between NSRP LLC and local authorities in dealing with problems generated from the activities of the Project in future.



6.3.2 Consultation with Tinh Hai Commune Opinions of Tinh Hai CPC According to Letter No.12/NSRPLLC sent by NSRP LLC to Tinh Hai CPC on 19th January 2010 about public consulting for Nghi Son Refinery Project and contents of the summarized Environmental Impacts Assessment (EIA) report of the Project, Tinh Hai CPC found that NSRP had applied very strictly environmental policy and Vietnamese Standards and International requirements. All sources of air pollution and wastewater are both estimated and detailed assessed in order to avoid causing negative impacts on environment. Solid waste generated from construction and operation phase is collected and treated properly. The report focused on considering compensation, resettlement issues and effects on local community and proposal of specific and feasible mitigation measures for each phase of the Project. Tinh Hai CPC have mutual consensus and confirm socio-economic benefits that the Project bring locality and country with. Tinh Hai CPC advocates deploying the Project and basically agrees with contents of the EIA report of the Project. However, during construction phase, Tinh Hai CPC suggests NSRP LLC should concentrate on some following issues:

Noise generated from stone shaker are too noisy both in day and night, it should be operated in working time;

There were 8 households located in provincial road 513 affected seriously by dust and water pollution. NSRP LLC should have plan to support for temporarily relocated households due to environmental problems;

Provide job opportunities for AP; NSRP LLC should entrust Tinh Hai CPC to set up a labour team for creating job in order to avoid negative and give AP losing land a chance to improve their living conditions.

Opinions of Tinh Hai FFC According to Letter No.12/NSRPLLC sent by NSRP LLC to Tinh Hai FFC on 19th January 2010 about public consulting for Nghi Son Refinery Project and contents of the summarized Environmental Impacts Assessment (EIA) report of the Project presented in the meeting hall of Tinh Gia District People Committee on 28th January 2010 by the Project Owner, Tinh Hai FFC have some ideas about carrying out Project in Tinh Hai area as followings:

Advocating NSRP Project carried out in Nghi Son Economic Zone;

NSRP LLC should take over the rest land of AP outside Project boundary in order to make them pleased to relocate in a new resettlement;

NSRP LLC must collect and treat all polluted soil caused by the Project;

For households having land use right certification but have no house, NSRP LLC should also allocate them plots in resettlement sites.

Close cooperation between NSRP LLC and local authorities shall be more strengthen in dealing with problems generated from the activities of the Project in future.



6.3.3 Consultation with Hai Yen Commune Opinions of Hai Yen Commune People Committee According to Letter No.12/NSRPLLC sent by NSRP LLC to Hai Yen CPC on 19th January 2010 about public consulting for Nghi Son Refinery and Petrochemical Complex Project and contents of the Environmental Impacts Assessment (EIA) report of the Project, Hai Yen CPC found that NSRP had applied very strictly environmental policy and standards of Vietnam and International requirements. All sources of air pollution and wastewater are both quantified and detailed assessed in order to avoid negative impacts on environment. Solid waste generated from construction and operation phase is collected and treated properly. On the other hand, the EIA report is also considered compensation, resettlement issues and effects on local community in order to propose specific and feasible mitigation measures for each project’s phase. Hai Yen CPC have mutual consensus and confirm socio-economic benefits that the Project bring to locality and country. Hai Yen CPC advocates deploying the Project and basically agreeing with contents of the EIA report of the Project. All HHs of Hai Yen Commune agree to relocate to new resettlement site. However, during construction phase, Hai Yen CPC suggests NSRP LLC to concentrate on some following issues:

It is required to requisition or pay for agricultural production losses caused by operating of borrow pits;

The rest land of AP outside Project boundary is required to compensate and requisition because the long distance from new resettlement site to production land.

A co-operative under commune’s management is required to establish in order to receive directly simple job requirements (Dockers, environmental worker, hygienist, stone collection, etc.) from construction contractors and then distribute to local labours.

Opinions of Hai Yen FFC According to Letter No.12/NSRPLLC sent by NSRP LLC to Hai Yen FFC on 19th January 2010 about public consulting for Nghi Son Refinery Project and contents of the summarized Environmental Impacts Assessment (EIA) report of the Project presented in the meeting hall of Tinh Gia District People Committee on 28th January 2010 by the Project Owner, Hai Yen FFC have some ideas about carrying out Project in Mai Lam area as followings:

Advocating NSRP Project carried out in Nghi Son Economic Zone;

The rest land of AP outside Project boundary is required to compensate and requisition in order to make APs pleased to relocate in a new resettlement;

Polluted soils generated from transportation trucks are required to collect and treat properly

For households having land use right certification (LURC) but have no house, NSRP LLC should also allocate them plots in resettlement sites.

Close cooperation between NSRP LLC and local authorities shall be kept in solving problems generated from future.

The official letters of NSRP-LLC sent to local authorities and response letters from three Commune People Committees, Mai Lam, Hai Yen and Tinh Hai to NSRP-LLC are presented in Appendix V.



6.4 FEEDBACK AND COMMITMENT OF PROJECT OWNER 6.4.1 Feedback From Project Owner After considering all questions and requirements from local communities and authorities, NSRP LLC realizes that these are logical and understandable. Based on scientific anticipation of inevitable adverse impacts and consultations of many Vietnamese and international experienced advisors and experts, NSRP LLC commits to give and strictly implement all mitigation measures in order to minimize negative impacts on local environment and society. Dealing with troubles of affected people in Mai Lam, Tinh Hai and Hai Yen communes in the public consultation, NSRP LLC will apply following measures:

Compensation and resettlement issue: As mentioned at the beginning that resettlement NSRP LLC will make recommendations to Tinh Gia District PC and Thanh Hoa PPC to reconsider legitimate aspirations about allowance fee for APs.

Job opportunities: NSRP LLC provided a tentative recruitment plan for operation phase accompanied with number of recruitment demand, required positions, professional and employment schedule to local authorities and local people. NSRP LLC also provided other information such as direct and indirect job opportunities at construction and operation phases. Based on this information, APs and local authorities can make plan for career transfer for local people. Priority is given to local people if recruitment requirements are met. NSRP LLC commits to make open and clearly recruitment in order to give opportunities to APs to work for NSRP.

Training support: NSRP LLC will partially sponsor for some training courses held by local

authorities via social support activities.

Environmental impacts: NSRP LLC will comply regulations on health, safety, secure and environment to protect employees and environment and to work closely with local communities in order to improve their livelihood and achieve sustainable development.

Eight (8) HHs of Tinh Hai commune living along provincial road 513 are strongly affected by dust pollution and flood due to material exploitation activity, NSRP LLC suggested NSPM to survey and assess impact level in order to have appropriate compensative solution for them. To solve this problem, NSPM has proposed to move 8 affected HHs to temporary area to wait for a new resettlement site, but they should give their land to NSPM. All house renting costs are paid by NSPM.

Internal traffic system of 3 affected communes: In pre-construction phase, NSRP LLC suggested Tinh Gia District PC, NSEZ Management Board and NSPM (PVN) quickly clear sludge/soil spilled in communal internal roads, especially in Mai Lam Commune so that local people may travel easier; and set up a free bus route along Provincial Road 513. In order to reduce traffic risk for local pupils, Tinh Gia District PC should build more classrooms or enlarge the high school in Tung Lam Commune to decrease number of pupils traveling in Provincial Road 513. In construction phase, EPC Contractor will be responsible for repairing the damage



caused by construction contractor and having suitable compensation in according to agreement with NSEZ Management Board, local authority and affected parties.

In construction and operation phases, NSRP LLC will closely co-operate with local authority in managing labour force, social assistance and health education programs for local community and workers.

On the other hand, NSRP LLC will maximize economic benefits, impulse the development of local supply chain and other industries, and robustly motivating the socio-economic development of the south Thanh Hoa and north Nghe An province and the vicinities. 6.4.2 Commitment of the Project Owner 6.4.2.1 Social Issues NSRP LLC will record and consider all public consultations carefully in order to have the most suitable solutions upon to local situation in time. Project will also comply with IFC requirements on social responsibilities expressed in regular Due Diligence Survey reports for resettlement and construction activities. NSRP LLC will also establish two grievance mechanisms to receive and facilitate resolution of the affected communities’ concerns and Project’s environmental and social performance as follows:

1. Grievance mechanism for compensation, resettlement and public safety issues; 2. Grievance mechanism for Project issues.

Specific roles and responsibilities are as followings: Pre-Construction phase

During the pre-construction phase, the compensation and site clearance activities are carried out by Tinh Gia District authorities in collaboration with the affected communes. Resettlement activities are carried out by NSEZMB. Basic site levelling and dredging activities are managed by NSPM. During this phase, NSRP LLC will discuss with the affected communes to understand their compensation, resettlement, environmental and social issues. NSRP LLC has undertaken Due Diligence Surveys to ensure that the International Standards (IFC) as well as the Vietnamese Standards are enforced for the above activities. However, NSRP LLC can only make recommendations to Thanh Hoa Province, NSEZMB and Tinh Gia District. In the second Public Consultation meeting, NSRP LLC will disclose preliminary NSRP Recruitment Plan including recruitment time, careers and job qualification to the public.

Construction Phase

NSRP LLC will keep and maintain communication with the three affected communes (Mai Lam, Tinh Hai and Hai Yen) and other stakeholders, and monitor the work done by the EPC Contractor.



NSRP LLC will announce NSRP recruitment and recruit employee. NSRP LLC gives a priority for Project affected people if they can meet the company’s requirement NSRP LLC will carry out to social support activities such as sponsoring public facility construction, scholarship, public funds, … These activities will be continued through out the operation phase. During the Construction Period, EPC Contractor and sub-contractors will be the main organisations responsible for hiring employees. NSRP LLC will establish contractual clauses to ensure that the EPC Contractor and sub-contractors will select in priority project affected people, the poor and women in the three affected communes, if they can meet their requirements.

Operation Phase

NSRP LLC will be responsible to hire more permanent Vietnamese staff to supersede foreigner step by step and give a priority for Project affected people if they can meet the company’s requirement. NSRP LLC will monitor annually the effect of the project on the three affected communes to improve their environmental and social quality via our social support activities.

6.4.2.2 Environmental Issues NSRP-LLC highly appreciates the opinions and recommendations of representatives of three affected communes in solving dust and safety traffic for the local people. NSRP-LLC will recommend to NSRM and all constructional contractors to apply above-mentioned measures to mitigate significant dust and keep safety traffic to HHs NSRP LLC will comply with all Vietnam Standards and IFC Requirements from pre – construction phase to decommissioning phase about all environmental aspects, such as air quality, soil, wastewater, solid waste, ecosystems and ambient environment. Pre – construction Phase

During the Pre-Construction period, NSRP LLC will undertake Due Diligence Surveys to monitor resettlement activities and construction activities. Recommendations will be sent to Tinh Gia District, NSEZMB and NSPM by NSRP LLC.

Construction Phase During the Construction period, NSRP LLC will carry out monitoring surveys. Recommendations will be provided to the EPC Contractor for immediate action.

Operation Phase NSRP LLC will apply more stringent environmental standards which satisfy Vietnam and IFC requirement.



NSRP LLC will also implement strictly all mitigation measures mentioned in Section 4 in order to reduce adverse impacts on environmental components and local economic - social situation. Annual monitoring will be carried out during operation phase by NSRP LLC. Recommendations will be prepared by NSRP HSE Manager or Public Relation Manager. NSRP LLC will set up an Emergency Response Plan for accidents such as fire and explosion, toxic gas release inside plant boundary and an Oil Spill Response Plan for marine facilities at SPM, harbor and crude oil pipeline system.



Section 7.

CONCLUSION, RECOMMENDATION AND COMMITMENT

7.1 CONCLUSION The “Nghi Son Refinery and Petrochemical Limited Liability Company” (NSPR-LLC), a Joint Venture between Vietnam Oil and Gas Group and international companies, aims to build a refinery and petrochemical complex in Thanh Hoa province. The project is located within the Nghi Son Economic Zone (NSEZ) at Tinh Gia district, Thanh Hoa Province, approximately 200 km south of Ha Noi capital. The capital investment for the refinery is estimated to be US$ 6 billion. The construction is expected to start in 2010, and the refinery and petrochemical complex to become operational by 2013. The Refinery and Petrochemical Complex is designed to process 200,000 BPSD of 100% imported Kuwait Export Crude (KEC) oil. The fuels section of the refinery includes Residue Hydrodesulphurisation and Residue Catalytic Cracking as the main upgrading units. The refinery is integrated with petrochemical production. The Aromatics plant produces Paraxylene and Benzene. A key product from the Residue Cracker is Propylene which is used to produce Polypropylene product. The main products of the refinery and petrochemical complex include LPG, Gasoline – 92/ 95 RON, Kerosene /Jet A-1, Diesel – Premium and Regular, Paraxylene / Benzene, Polypropylene and Sulphur. Total NSRP project onshore land-take is about 394ha and 259ha offshore of marine facilities. The main project components include:

Refinery and Petrochemical Complex including process units, associated utility and infrastructure facilities.

Onshore pipeline route

Marine facilities including SPM, crude pipeline system, harbor, breakwater, Jetties and access channel.

The NSRP will be the second major oil refinery in Vietnam after Dung Quat. This is one of the nation’s key projects that will ensure an adequate supply of energy to the country. It will promote the socio-economic development of the provinces and cities in the central part of Viet Nam and as a result the whole country in general. The NSRP project implementation will bring many advantages as follows:

Contributing to the national energy security, by securing long-term imported crude supply of at about 10 million tons per year, which will be processed by this Complex to produce voluminous fuels and petrochemicals.

To supply feedstock for the development of the Petrochemical Industry and to decrease the foreign dependence

http://en.wikipedia.org/wiki/Vietnam



Paving the way for the development of the petrochemical industries, associated industries and other related services.

Robustly motivating the socio-economic development of the south Thanh Hoa and north Nghe An province and the vicinities.

Creating jobs for dozens of thousand people during construction phase, and thousands of people during operation phase.

Developing local supply chain to be able to support construction activities, and maximize the economic benefits. Indirect employment and local procurement opportunities will have a significant long-term major positive impact.

Beside above benefits, project implementation will also cause impact on both environment and local people living in the project area as follows. In Pre-Construction Phase The site leveling and upgrading will cause direct effect to 3 communes named Hai Yen, Mai Lam and Tinh Hai. That changes theirs labour structure and bring advantages for local people such as give job, enhance intellectual standard, develop industrial and trade branches of three communes as well as Tinh Gia district. However, these activities cause following social disturbances to local communities: The Project will acquire area of 394 ha, in which 328 ha is agricultural land. Around 2,695 HH (9,000 persons) will be affected by the Project. Among these affected people

(APs), 687 HH will lose most of their land and their main houses and will have to relocate in another location. Three resettlement sites have been built to accommodate these relocated APs.

In general, APs were satisfied with the compensation they received for agricultural land (62%) and

for trees/crops (51.4%). This showed that compensation prices for agricultural land generally met market prices. In the plant site, most of the HH (75.2%) attended public meetings organized by local authorities. For already relocated APs, all the APs surveyed complain to local authorities about their future source of income especially during the transition period, compensations rate for residential land and structures, Jobs opportunities in the industrial zone, services to workers (housing, catering etc.). The Authorities had taken countermeasures to push up progress of construction of RS, compensation for remaining land, allowances and training in order to mitigate impacts to APs.

1083 graves in Mai Lam Commune, 483 graves in Hai Yen Commune and 832 graves in Tinh Hai

Commune have been relocated by Tinh Gia District Resettlement Committee. Besides, Earthwork equipment and transportation will generate noise; vibration and air quality at

borrow pit areas, access roads and the vicinity. In Construction phase The construction and installation of main plant, utilities, tankage farm and other facilities will disturb the soil structure, increase soil erosion, dust and noise to the environment. The excavation, pilling and



filling of the plant site at onshore facilities as well as the construction of the breakwater and the harbor will cause dust pollution problems in the Project area and the communities nearby (Hai Yen and Tinh Hai Communes). Waste generation may contribute to soil contamination. Anchoring of laying barge, crude pipeline trenching, burying activities and construction of breakwater, harbors, seawater intake and outfall will cause strong disturbance to the seabed surface and increase turbidity and organic matters of coastal water, make temporary un-stability of bottom sedimentation loading, and increase considerably of the suspended solid and pollutants within some kilometers from construction site by sloughing seabed sediment along the pipeline route. The construction of the harbor and breakwater will destroy the structure at the shoreline. Dredging (and disposal) activities will cause large-scale turbidity and strong disturbance to the benthic communities. In addition, the changes to wave and current patterns caused by dredging and the presence of the breakwater will interrupt or change the natural ecosystem. In addition, during construction phase, disruption of existing infrastructures by the Project will adversely cause short term moderate impact to the local population as well as industrial activities and Nghi Son Port activities. The Project will also result in changes in access routes in Tinh Hai, Hai Yen and Mai Lam Communes. During commissioning, the discharge of treated cleaning and hydrotesting water in to coastal water might cause oxygen depletion and high turbidity around the outfall area. During the Construction Phase, most of mitigation measures will be implemented by the EPC Contractor and its Sub-Contractors. NSRP LLC ensures that mitigation measures are implemented and control through effective monitoring. Therefore, negative impacts in the construction phase will be reduced significantly. In Operation Phase In the Operation phase, the content of pollutants (NOx, CO, SOx, PM10) in air emission at the 19 main stacks of the refinery plant and HC flare are much lower than the Vietnamese standards QCVN 05:2009. The maximum ground level concentrations of SO2, NOx, CO and PM10 are very low and well within the applicable of National and World Bank/IFC standards. In addition, VOC emissions from tankage farms are within acceptable limits of World Bank/IFC guidelines on petroleum refining. That taking continuously seawater and discharging treated wastewater and cooling water to the coastal area will cause minor thermal impact on coastal seawater quality surrounding outfall area. Almost pollutants are well diluted and are within allowable limit of coastal water standard QCVN 10:2008. Crude oil offloading at SPM and product loading activities at jetties might cause high potential risk of oil spill. In case of oil spill occurs at SPM or crude oil pipeline, spilled oil will drift to Nghi Son Bay and shoreline in the first day and its impact level will be considered from significant to severe, due to SPM and crude pipeline system locations are close to the shoreline. Briefly, the EIA has identified several potential positive and negative environmental and social impacts. Recommendations and mitigation measures have been elaborated to minimize the environmental and social impacts. Measures to enhance Project benefits are also in place relating to preferential hiring policies, social investment and implementation. The EMP defines the specific management plans that



will allow the implementation of the mitigation measures and identify who is responsible for the implementation. It also defines specific monitoring programs aimed at documenting the implementation and adequacy of control systems and mitigation measures and the reporting that is required to maintain transparency. With the effective implementation of the mitigation measures and monitoring programs defined in the Environmental and Social Management Plan, and with periodic updates to the EMP, NSRP LLC can indeed limit the adverse impacts of the Nghi Son Refinery and Petrochemical Complex and Marine Facilities to acceptable levels and conform to a standard that is generally accepted as good international industry practice.

7.2 RECOMMENDATION As above-mentioned, the NSRP is national project and to be the second. Due to the necessity of the project, the NSRP project owner will start construction in 2010 and put into operation in 2013. Therefore, it is kindly proposed the Ministry of Natural Resource and Environment (MONRE) to approve this EIA report to hasten the project progress. 7.3 COMMITMENT Recognize the importance of environmental protection, the NSRP LLC commits to strictly obey the Vietnamese Standards, the Word Bank (IFC) Standards, the advanced technical solutions, the mitigation measures for environmental pollution and the suitable environmental management plans as mentioned in this report including: In construction phase 1) All equipments of the Project will be imported in new and meet International Requirements. The

Project will apply modern technologies and try to be in top of 25% of Asian Modern Refineries. 2) Noise in working area: Noise limits for different working environments meet 85 dB(A) for a duration

of more than 8 hours per day without hearing protection and 110 dB (A) for average maximum sound level.

3) Noise for Community: The noise in nearby communities will meet 70 dB(A) from 6:00 am to

22:00pm and 50 dB(A) in the night time from 22:00pm to 6:00 am. 4) Hydrotest water will be treated at SPM. The Project will strictly control chemicals and monitor

disposal process. 5) Onboard waste water will be treated onsite by CPI system to ensure that oil content in waste water

is lower than 15 ppm as requirement of IMO before discharging into the sea. 6) Treated domestic waste water will be pumped into outfall at advantageous position for well

dispersion and dilution.



7) Solid waste will be collected, stored, transported and disposed in accordance with Vietnamese Law and Regulations in force.

8) EPC Contractor will be responsible for any incident or damage caused by the Project and have

appropriate compensation after being consensus with NSEZ Management Board, local authority and the aggrieved party.

In operation phase 1) Air emission. Air emission pollutants from process point sources (stacks and flares) will meet

Vietnamese standards for industrial air emission standards (QCVN 19:2009/BTNMT on Industrial Emission of Inorganic Substances and Dusts, QCVN 20:2009/BTNMT on Industrial Emission of Organic Substances and QCVN 22: 2009/BTNMT on Emission of Thermal Power industry) and World Bank (IFC) Standards for Petroleum Refining, Petroleum based Polymer manufacturing, Thermal Power Plants, and Large Volume Petroleum based Organic Chemicals Manufacture. The Project Standards are set up by precedence of World Bank (IFC) Standards, except for where the Vietnamese Standards are the more stringent, where there is no World Bank (IFC) Standard for a substance which is regulated by Vietnamese Standards or where World Bank guidelines allows to apply national standards.

2) Ambient air. Air emission pollutants from process point sources will meet Vietnamese standards

for ambient air quality (QCVN 05:2009/BTNMT) and the World Bank (IFC) standards. The Vietnamese Standards will take precedence over the World Bank (IFC) standards except for where there is no Vietnamese standard for a substance which is regulated by the World Bank (IFC).

Under emergency conditions, the ground level concentrations should be compared to the Emergency Response Planning Guideline (ERPG) values developed by the American Industrial Hygiene Association (AIHA).

3) Noise for Occupational Health and Safety: Noise limits for different working environments meet

85 dB(A) for a duration of more than 8 hours per day without hearing protection and 110 dB (A) for average maximum sound level.

4) Noise for Community: Noise caused by the Complex to community area will meet the most

stringent of the Vietnamese noise standards for public and inhabited areas (TCVN 5949–1998) and the World Bank standards. The noise in nearby communities will meet 70 dB(A) from 6:00 am to 22:00pm and 50 dB(A) in the night time from 22:00pm to 6:00 am.

5) Cooling water discharge. The cooling water will strictly comply with Vietnamese Standard QCVN

24:2009/BTNMT which requires that the temperature of cooling water discharged into a received environment is equal to or lower than 40ºC. The discharge water temperature does not result in a maximum temperature increase greater than 3ºC at the edge of a scientifically established mixing zone as specified in the World Bank General EHS Guideline.

6) Wastewater discharge. All effluents from the Complex, except some sanitary water, such as Port

area will be treated to meet Vietnamese Technical Regulation on Industrial Wastewater Discharge Standards (QCVN 24:2009/BTNMT) at the outlet of ETP. Treated effluents will be mixed with



cooling water before routing to outfall. Sanitary water in Jetty area will be treated to meet National Technical Regulation on Domestic Wastewater (QCVN 14:2008/BTNMT).

7) Dredged material discharge. Dredged materials shall be disposed to offshore area approved by

authorities to ensure no effect of dispersion plume to SPM, crude pipeline and coral reef nearby Me Islands.

8) Hazardous waste. The NSRP LLC will be responsible for the collection, storage, transportation,

treatment, and disposal of all hazardous waste in accordance with Vietnamese Law (Decree of hazardous waste management 155/1999/QD–TTg issued by the Prime Minister on 16 July 1999 and QCVN 07: 2009/BTNMT).

9) Non-hazardous waste. The NSRP LLC will take over for the collection, storage, transportation,

treatment, and disposal of all non-hazardous waste according to the hygienic security requirements of the Nghi Son Economic Zone.

The implementation of NSRP project will bring a great potential to increase the economic development of Vietnam, Thanh Hoa Province and especially Tinh Gia District. NSRP LLC is dedicated to improve the economic benefit of Tinh Gia District and affected communes by facilitating the employment of the local population and by developing a chain of business in the District and NSEZ. Furthermore, the NSRP LLC will closely coordinate with the state organizations and the local authorities to implement the project safely and to get the high economic and social effect. The NSRP LLC will bear responsibility for any breach of Vietnamese law.

Satisfying safety management requirements according to International standards; Strictly executing internal procedures in order to guarantee staffs’ safety; Propagandizing education and propagandizing all staffs to take part in environmental

protection; Regular organizing professional courses in order to improve specialist knowledge of health,

safety and environment for staffs; Protecting and reasonably using, saving natural resources; Minimizing, collecting, recycling and reusing wastes; Preparing plan, equipment and human resources to response in case of occuring oil spill

incident; Beside conformity with environmental management programs, environmental monitoring and mitigation measures in order to minimize negative impacts arising from the project, NSRP LLC will coordinate closely with environment organizations and local authorities to implement project safety and bring high socio-economic effect.

Documents

dự án lọc dầu Nghi Sơn