ADANI WELSPUN EXPLORATION LIMITED (AWEL ...environmentclearance.nic.in/writereaddata/EIA/211220183...Asian Consulting Engineers Pvt. Ltd. New Delhi December 2018 Rev-05 EIA Report

ADANI WELSPUN EXPLORATION LIMITED (AWEL)

Environmental Impact Assessment for Offshore Oil & Gas

Development and Production from Discovered Small Field of

B-9 Cluster Offshore Fields at Mumbai Offshore Basin.

Final EIA Report.

Asian Consulting Engineers Pvt. Ltd. New Delhi

December 2018

Rev-05

EIA Report - Offshore Oil & Gas Development and Production from Discovered Small

Field of B-9 Cluster Offshore Fields at Mumbai Offshore Basin.

Asian Consulting Engineers Pvt. Ltd.

QUALITY CONTROL PLAN

Project Title EIA Report - Offshore Oil & Gas Development and Production from Discovered

Small Field of B-9 Cluster Offshore Fields at Mumbai Offshore Basin.

Client Adani Welspun Exploration Limited (AWEL).

Contact Person Mr. Arvind Hareendran,

Vice President.

Document Prepared By Asian Consulting Engineers Pvt Ltd., India.

Original Date Prepared 04.07.2018.

Revision 1 Date 15.09.2018.





Approved By:

10.12.2018

(EIA Coordinator) (Date)

By signing, I certify, that the document/report has been prepared and reviewed as per the quality

assurance measures established in Asian Consulting Engineers Pvt Ltd, (ACE) “Quality

Management System”.

TTEERRMM OOFF

RREEFFEERREENNCCEE ((TTooRR))

EIA Report - Offshore Oil & Gas Development and Production from Discovered Small Field of


Asian Consulting Engineers Pvt. Ltd. i

TABLE OF CONTENTS

QUALITY CONTROL PLAN

TERMS OF REFERENCE (ToR)

EXECUTIVE SUMMARY

CHAPTER-1: INTRODUCTION

1.1 INTRODUCTION………………………………………………………………………………........... 1-1

1.2 NEED OF THE EIA STUDY …………………………………………………………...…………….. 1-4

1.3 PROJECT PROPONENT …………………………………………………………...…………………. 1-6

1.4 EIA CONSULTANT……………………………………………………….……………………....…… 1-6

1.5 POLICY AND LEGAL FRAMEWORK …………………………………………………………...…. 1-6

1.6 SCOPE OF THE EIA STUDY …………………………………………………………...……………. 1-7

1.7 APPROACHES AND METHODOLOGY OF EIA STUDY…………………………………….......... 1-7

1.8 STRUCTURE OF THE EIA REPORT…………………………………………………………...…….. 1-8

CHAPTER-2: PROJECT DESCRIPTION

2.1 PROJECT OVERVIEW………………………………………………………………………..….....… 2-1

2.2 PROJECT LOCATION …………………………………..……………………………………..…....... 2-5

2.3 PROJECT DESCRIPTION ……………………………………………………………......................... 2-5

2.3.1 Details of Proposed Pipelines…………………………………………………………….…… 2-6

2.3.2 Gas and Oil Processing ………………………………………………………………….……. 2-7

2.3.3 Overall Indicative Production Profile for B-9 Field.................................................................... 2-7

2.3.4 Drilling Phase Activity …………………………………………………………………..…… 2-8

2.3.5 General Platform Facilities Description ……………………………………………………… 2-8

2.3.6 Electrical System ……………………………………………………………………………… 2-9

2.3.7 Telecommunication System......................................................................................................... 2-10

2.3.7.1 VSAT System ............................................................................................................. 2-10

2.3.7.2 CCTV System ............................................................................................................. 2-10

2.3.8 Software…................................................................................................................................... 2-10

2.3.9 Supply Base….............................................................................................................................. 2-11

2.3.10 Staffing......................................................................................................................................... 2-11

2.4 PROJECT SCHEDULE AND COST…………………………………………………………………... 2-11

2.5 RESOURCE UTILIZATION ................................................................................................................... 2-11

2.5.1 Water Requirement .................................................................................................................... 2-11

2.5.2 Power Requirement .................................................................................................................... 2-11

2.6 NOISE, AIR EMISSIONS, EFFULENTS, AND SOLID WASTE GENERATION …………………. 2-12

2.6.1 Noise............................................................................................................................................ 2-12

2.6.2 Emission….................................................................................................................................. 2-12

2.6.3 Effluents and Solid Waste…....................................................................................................... 2-12

2.6.4 HSE Requirement….................................................................................................................... 2-13

CHAPTER-3 : DESCRIPTION OF THE ENVIRONMENT

3.1 INTRODUCTION…………………………………………..………………………………...………..... 3-1

3.2 STUDY AREA ………………………………………………………………………………………… 3-1

3.3 STUDY PERIOD AND LABORATORY INVOLVED ………………………………………………. 3-3

3.4 COMPONENTS OF BASELINE STUDY ……………………………………………………………. 3-3

3.5 METHODOLOGY …………………………………………………………………………………….. 3-3

3.6 APPLICABILITY OF COASTAL REGULATION ZONE (CRZ) ………………………..…………… 3-4

3.7 GEOLOGY OF MUMBAI OFFSHORE BASIN ………………………..………………………………. 3-6

3.8 CLIMATE AND METEOROLOGY ………………………..………………………………...……….. 3-6

3.8.1 Mean Sea Surface Temperature ………………………………………..........…………………. 3-7

3.8.2 Mean Air Temperature ………………………..………………………………...…………….. 3-7

3.8.3 Mean Wind Speed ………………………..………………………………...…………………. 3-7



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3.8.4 Waves and Tides ………………………..………………………………...…………………… 3-9

3.8.5 Rainfall ………………………..………………………………...……………………………… 3-9

3.8.6 Cyclones ………………………..………………………………...…………………………… 3-9

3.8.7 Circulation ………………………..………………………………...………………………….. 3-11

3.9 MARINE ENVIRONMENT ………………………..………………………………...………………… 3-12

3.9.1 Marine Environmental Monitoring…………………..………………………………...……… 3-17

3.9.1.1 Sea Water Monitoring ……………………………………………………………… 3-17

3.9.1.2 Sea Sediments Monitoring ………………………………………………………… 3-23

3.9.1.3 Biological Analysis ………………………………………………………………… 3-27

3.10 SOCIO-ECONOMIC ENVIRONMENT …………………………………………………………….... 3-35

CHAPTER-4: ANTICIPATED IMPACTS AND MITIGATION MEASURES

4.1 IDENTIFICATION AND ASSESSMENT OF IMPACTS……….…….………….……………....…… 4-1

4.2 INTERACTION OF PROJECT ACTIVITIES WITH THE ENVIRONMENT……………………...... 4-2

4.2.1 Quantification of Impact ……………………………………………………………….…….. 4-3

4.2.2 Impact on Air Environment........................................................................................................ 4-4

4.2.3 Impact on Noise Quality ..................................................................................................... ....... 4-4

4.2.4 Impact on Marine Water Quality .............................................................................................. 4-5

4.2.5 Impact on Sediment Quality ..................................................................................................... 4-5

4.2.6 Impact on Marine Biology …………........................................................................................ 4-5

4.2.7 Occupational Health Hazard …………………………………………………………………. 4-5

4.3 IMPACT EVALUATION................................................................................................................... ...... 4-6

4.4 IMPACT SIGNIFICANCE ……………………………………………................................................... 4-6

4.5 IMPACT MITIGATION MEASURES .................................................................................................... 4-8

4.5.1 Air Environment ........................................................................................................................ 4-8

4.5.2 Noise Environment ………………………………………………………………………….. 4-8

4.5.3 Water Environment ................................................................................................................... 4-8

4.5.4 Sediment Quality….................................................................................................................... 4-9

4.5.5 Marine Biology ……………………………………………………………………………… 4-9

4.5.6 Occupational Health Hazard ………………………................................................................. 4-9

4.5.7 Waste Generation and Effluent Management........................................................................... 4-9

4.6 IMPACT SIGNIFICANCE WITH MITIGATION MEASURE ……………………………………… 4-9

CHAPTER-5: ANALYSIS OF ALTERNATIVES

CHAPTER-6: ENVIRONMENTAL MONITORING PLAN

6.1 INTRODUCTION …………………………………………………….…….………….…….…...……. 6-1

6.2 ENVIRONMENTAL MONITORING PROGRAM ................................................................................ 6-1

6.3 BUDGET ............................................................................................................................. ..................... 6-4

CHAPTER-7: ADDITIONAL STUDIES

7.1 INTRODUCTION ............................................................................................................................. ...... 7-1

7.2 RISK ASSESSMENT .............................................................................................................................. 7-1

7.2.1 Risk Analysis ....................................................................................................... ....................... 7-2

7.2.2 Identification of Hazards in Offshore Oil and Gas Field Development..................................... 7-2

7.2.3 Major Hazards ............................................................................................................................ 7-3

7.2.4 Hazards- Nature and sensitivity of impact zones ....................................................................... . 7-5

7.3 CONTROL MEASURES FOR MAJOR IDENTIFIED HAZARDS……………………………….….. 7-7

7.4 DISASTER MANAGEMENT PLAN AND EMERGENCY ACTION PLAN ………………………. 7-9

7.4.1 Emergency Classification .......................................................................................................... 7-10

7.4.2 Emergency Action Plan .............................................................................................................. 7-10

7.4.2.1 Instrumentation and Safety System ........................................................................... 7-10

7.4.2.2 Telecommunication System ..................................................................................... 7-12

7.5 HEALTH, SAFETY AND ENVIRONMENT ……................................................................................. 7-13

CHAPTER-8: PROJECT BENEFITS



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8.1 PROJECT BENEFITS ……………………………………………………………................................. 8-1

CHAPTER-9: ENVIRONMENT COST AND BENEFIT ANALYSIS

CHAPTER-10: ENVIRONMENTAL MANAGEMENT PLAN

10.1 STRUCTURE OF EMP……………………………………………………………………………........ 10-1

10.2 PROPOSED ENVIRONMENTAL MITIGATION MEASURES…………………………………........ 10-1

10.3 ENVIRONMENTAL MANAGEMENT PLAN……………………………………………………........ 10-4

10.3.1 Waste Management Plan ............................................................................................................ 10-9

10.3.2 Oil Spill Contingency Plan ......................................................................................................... 10-10

10.4 CAPITAL AND RECURRING COST FOR POLLUTION CONTROL MEASURES ……………….. 10-11

10.5 ENVIRONMENTAL AWARENESS TRAINING .................................................................................. 10-12

10.6 ENVIRONEMENT MANAGEMENT CELL .......................................................................................... 10-12

CHAPTER-11: SUMMARY AND CONCLUSION

11.1 INTRODUCTION ……………………………………………………………………………….…...... 11-1

11.2 SUMMARY…………………………………………………………………………………….……..... 11-1

11.3 CONCLUSION……………………………………………………………………………………........ 11-1

CHAPTER 12: DISCLOSURE OF CONSULTANTS ENGAGED

12.1 INTRODUCTION................................................................................................................. ................... 12-1

12.2 QUALITY OF SERVICES....................................................................................................................... 12-1

12.3 AREA OF SPECIALIZATION................................................................................................................ 12-1

12.4 RESOURCES........................................................................................................................................... 12-2

LIST OF ANNEXURES

Annexure No. Title

Annexure I Form 1 and Pre-Feasibility Report (PFR).

Annexure II HSE’s Policy.

Annexure III Vessel Pictures and Documents.

Annexure IV ODAG Clearance Documents.

Annexure V Demobilization Letter to FODAG from Adani.

Annexure VI ODAG Inspection Pictures.

Annexure VII GPS Data Log.

LIST OF TABLES

Table No. Title Page

No.

Table 1.1 Salient Features of Project....................................................................................... ............... 1-2

Table 1.2 Expected Production from B-9 Clusters …………………....................................…………. 1-4

Table 1.3 Applicable Acts and Guidelines for the Proposed Project …………………………………. 1-6

Table 1.4 Compliance Report: Adherence to ToR Approved by MoEF&CC for the EIA Study ……. 1-10

Table 2.1 Project Details ……………………………………………………………........................... 2-1

Table 2.2 Proposed Products ………………………………………………………………………….. 2-2

Table 2.3 Block-Boundary Co-ordinates.……………………………………………………………… 2-5

Table 2.4 Well-Head Coordinates.……………………………………………………………….…… 2-5

Table 2.5 Pipelines Specification…………………………………………………………….………… 2-7

Table 2.6 Field Parameters ……………………………………………………………………………. 2-7

Table 2.7 Production Profile of B-9 Field…………………………………………………………….. 2-8

Table 2.8 Details of Platform Facilities …………………………………………………….…………. 2-9

Table 3.1 Data Validation Source ……………………………………………………………………. 3-4



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Table 3.2 Reservoir Rock in the Mumbai Offshore Basin ……………………………………………. 3-6

Table 3.3 List of Macrophytes in Study Area …………………………………………………….…… 3-14

Table 3.4 List of Macrofauna in Study Area …………………………………………………………. 3-14

Table 3.5 List of Fish Species in the Study Area …………………………………………………….. 3-16

Table 3.6 Specifications of Sea Water (SW) Sampling Location …………………………….……… 3-17

Table 3.7 Preservation of Water Samples ……………………………………………………………. 3-20

Table 3.8 Marine Water Quality Analysis …………………………………………………….………. 3-22

Table 3.9 Specifications of Sea Sediment (SS) Sampling Locations ………………………………… 3-23

Table 3.10 Preservation of Sediment Samples ………………………..……………………………….. 3-23

Table 3.11 Offshore Marine Sediment Quality Analysis ………………………..…………………….. 3-26

Table 3.12 Marine Biological Environment Analysis ………………………..………………….…….. 3-31

Table 3.13 Abundance of Phyto-Plankton Species………………………..……………………………. 3-32

Table 3.14 Abundance of Zooplankton Species ………………………..……………………………… 3-33

Table 3.15 Abundance of Benthic Species ………………………..………………………………........ 3-33

Table 4.1 Interaction Matrix for the Propsed Project …………………………………………………. 4-2

Table 4.2 Impact Evaluation Matrix …………………………………………………………………. 4-4

Table 4.3 Impact Significance Criteria ………………………………………………………………… 4-7

Table 4.4 Impact Significance of Project Activities (Without Mitigation Measures) ………………… 4-7

Table 4.5 Potential Environmental Impacts of Proposed Activities (With Mitigation Measures) ……. 4-10

Table 6.1 Environmental Monitoring Program ………………………………………………………. 6-2

Table 6.2 Budget for Environmental Monitoring Plan during Drilling/Installation …...……………… 6-4

Table 6.3 Budget for Environmental Monitoring Plan during Operation Phase ………………………. 6-5

Table 10.1 Proposed Environmental Mitigation Measures …………………………………………..… 10-1

Table 10.2 Environmental Management Plan – Mitigation Management Matrix (during drilling

phase) ………………………………………………………………………………………. 10-5

Table 10.3 Waste Management Plan ....................................................................................................... 10-9

Table 10.4 Environmental Budget …………………………………………………………………….. 10-12

Table 10.5 Environmental Management Cell .......................................................................................... 10-12

LIST OF FIGURES

LIST OF PHOTO PLATES

Photo Plate No. Title Page

No.

Photo Plate 2.1 A Typical Jack-Up Rig …………………………………………………………………. 2-8

Figure No. Title Page

No.

Figure 1.1 B-9 Cluster Field Location Map................……………………………………………….. 1-3

Figure 1.2 Study Area around B-9 Cluster Field Location (15 km Buffer) ……………………......... 1-5

Figure 2.1 Project Location from the nearest cities.…………………………..................…………... 2-3

Figure 2.2 Proposed Project Location and other AWEL Blocks.……………………………………. 2-4

Figure 2.3 Conceptual Sub-Sea Pipeline Layout Plan for B-9 DSF.………………………………… 2-6

Figure 2.4 Tentative Development Schedule ………………………………………………………... 2-11

Figure 3.1 Project Location…………………...………………………………...……………………. 3-2

Figure 3.2 Nearest cities to the Project Location ………………………..…………………………… 3-5

Figure 3.3 Sea Surface Temperatures ………………………..………………………………………. 3-7

Figure 3.4 Wind Speed and Wind Direction ………………………..……………………………….. 3-8

Figure 3.5 Windrose for the months of March to May 2018 …………………………...……………. 3-9

Figure 3.6 Cyclone Prone Area ………………………..………………………………...…………… 3-11

Figure 3.7 Sea Water Sampling Location with Vessel Route ………………………..……………… 3-18

Figure 3.8 Sea Water Sampling Locations within Study Area………………………………………. 3-19

Figure 3.9 Sea Sediment (SS) Sampling Location and Vessel Route ………………………………… 3-24

Figure 3.10 Sea Sediment (SS) Sampling Location and Vessel within Study Area…………………... 3-25

Figure 3.11 Chlorophyll Content in Mumbai Offshore Basin …………………………………………. 3-28

Figure 3.12 Graphical Analysis of Marine Biological Characteristics ………………………………... 3-35

Figure 4.1 Methodology for Environmental Impact Assessment …………………………………….. 4-1

Figure 7.1 Risk Matrix and Acceptability Criteria ……………………………………………… 6-2

Figure 7.2 Risk Categories and Significance Criteria ............................................................. 6-3



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Photo Plate 3.1 Fish Species in the Study Area …………………………………………………………... 3-16

Photo Plate 3.2 Marine Water Sampling ……………………….………………………………...……... 3-21

Photo Plate 3.3 Sediment Sample Collection from Mumbai Offshore Basin …………………………… 3-26

Photo Plate 3.4 Ecological Sample Collection from Mumbai Offshore Basin …………………………… 3-27

LIST OF ABBREVIATIONS

Abbreviations

AWEL Adani Welspun Exploration Limited

BOD Biological Oxygen Demand

BOP Blowout Preventer

CO Carbon Monoxide

COD Chemical Oxygen Demand

CPCB Central Pollution Control Board

CRZ Costal Regulation Zone

DG Diesel Generator

DGH Director General of Hydrocarbon

DMP Disaster Management Plan

DSF Discovered Small Field

EAC Expert Appraisal Committee

EPIC Engineering, Procurement, Installation & Commissioning

ERP Emergency Response Plan

ESD Emergency Shut-Down

FGS Fire and Gas Detection System

GPS Global Positioning System

HIPPS High Integrity Pressure Protection System

IS Indian Standard

IUG Instrument Utility Gas

KLD Kilo Liters per Day

MODU Mobile Offshore Drilling Unit

MoEF&CC Ministry of Environment, Forest and Climate Change

MPN Most Probable Number

ONGC Oil and Natural Gas Corporation

ODAG Offshore Defense Advisory Group

PM Particulate Matter

PLC Programmable Logic Controller

RSC Revenue Sharing Contract

RTU Remote Telemetry Unit

SAR Search and Rescue

SDP Shut Down Panel

SS Sea Sediment

SSSV Subsurface Safety Valve

TDS Total Dissolved Solids

TOR Terms of Reference

TSS Total Suspended Solids

VSAT Voice and Data Communication

VOC Volatile Organic Compound

WBM Water-Based Drilling Mud

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Asian Consulting Engineers Pvt. Ltd. 1

EXECUTIVE SUMMARY

1. INTRODUCTION

Adani Welspun Exploration Limited (AWEL) is a joint venture E&P Company formed by

two India based multinational business conglomerates Adani Group based out of Ahmedabad

and Welspun Group based out of Mumbai, to undertake upstream Oil & Gas business with

65% and 35% shares respectively. AWEL has been awarded contract area

MB/OSDSF/B9/2016 comprising of B-9 Cluster Offshore Fields and has signed the Revenue

Sharing Contract (RSC) with the Government of India (GoI). The field was originally

discovered by Oil and Natural Gas Corporation (ONGC) which was subsequently offered for

bidding under Discovered Small Fields (DSF) round, 2016. AWEL plans to develop the B-9

Cluster field by drilling wells and installing offshore facilities to produce natural gas and

crude oil. The B-9 cluster comprises three (3) DSF offshore fields namely B-9, B-7 (Gas

Fields) and BRC (Oil Field). The project envisages development drilling and installation of

well-head platforms and sub-sea pipelines in the Mumbai Offshore Basin. Consequently, it

involves identification of the potential environmental impacts of the project and suggestion of

mitigation plan.

2. PROJECT DESCRIPTION

Drilling operations shall be carried out at B-9 clusters offshore fields to extract the trapped

hydrocarbons. The gas and oil produced from the wells will be commingled and sent to

ONGC’s C-24 wellhead platform located nearly 80 km from the project site via 80 km sub-

sea pipelines. The processing of the oil and gas is envisaged to be done through existing

offshore platforms operated by ONGC. The proposed project does not include any facilities or

installations that pass through the Coastal Regulatory Zone (CRZ). Facilities existing beyond

the CRZ will be used for evacuation of hydrocarbons.

The salient features of the proposed project are elaborated in Table 1 below.

Table 1: Project Brief

Items Details

Project Name Development of B-9 Cluster Offshore Fields in the Discovered

Small Field (DSF), Mumbai Offshore Basin

Project Category ‘A’

Location Mumbai Offshore Basin (located beyond 12 nautical miles)

Project Fields

Three Discovered Small Fields (DSF)

a. B-9 138.5 sq.km Gas Field

b. B-7 22.7 sq.km Gas Field

c. BRC 22.03 sq.km Oil Field

Total Number of Proposed

Production Wells

12 Wells

a. B-9 Field Well

Well Head Platform 1 (B-9-

1 Area)

Surface Location of 4 wells

Well Head Platform 2 (B-9- Surface Location of 3 wells




Items Details

3 Area)

b. B-7 Field Well

Well Head Platform 3 Surface Location of 3 wells

c. BRC Field Well

Well Head Platform 4 Surface Location of 2 wells

Type of Hydrocarbon

Expected

Oil & Gas

Type of Rig to be Used Jack-Up Rig

Depth of Wells

2500 m to 4000 m Total Vertical Depth (TVD)

Wells may be deviated with horizontal displacement of around

1500 m

Drilling Period 45 - 60 days per well

Test Flaring of Gas 4 days per well during initial testing.

Proposed Drilling Fluid Water-based Mud System

Synthetic Oil Based Mud (SOBM) may be used as an option.

Drill Cuttings (during

drilling)

About 300– 500 m³ per well

Total Length of Proposed

Sub- Sea Pipelines

Laying of approx. 130 km sub-sea pipelines

Proposed Pipeline Facility a. Approx. 80 km sub-sea pipeline (upto 10”) from B-9 field

to a nearby existing platform

b. Approx. 10 km intra-field sub-sea pipeline (upto 8”)

within the B-9 area

c. Approx. 30 km sub-sea pipeline (upto 8”) from B-7

platform/ area to B-9 platforms /area

d. Approx. 10 km sub-sea pipeline (upto 6”) from BRC

platform/area to B-7 platform /area or B-9 platforms/ area

Nearest Railway Station

Nearest Airport

Railway Station: Delwada (Gujarat) – approx. 74 km

Airport: Diu Airport (Daman and Diu) – approx. 72 km

Nearest Town /City/ Village

Town: Diu (Daman and Diu) - approx. 72 km

City: Jafrabad (Gujarat) - approx. 75 km

Village: Delvada (Gujarat) - approx. 74 km

Expected Cost of the Project Tentatively INR 1600 Crores.

3. DESCRIPTION OF ENVIRONMENT

This chapter presents an overview of the existing environmental aspects related to the

development of B-9 cluster offshore fields in the discovered small fields (DSF) in the

Mumbai Offshore Basin. The knowledge of the characteristics of the local biological

environment allows an understanding of the potential impacts on the marine environment,

thereby adopting relevant control measures to mitigate the adverse negative impacts.

The state of the environment has been characterized on various marine components in the

project site and its surrounding areas. The project site comprises of 3 DSF, i.e., B-9, B-7 and

BRC fields in the Mumbai offshore basin, wherein B-9 and B-7 are Gas fields and BRC is an

Oil field. The study area pertains to 15 km radial distance from each of the three (3) DSFs and

proposed pipelines




3.1 MET-OCEAN CONDITIONS OF MUMBAI OFFSHORE REGION

Mumbai Offshore basin is located on the western continental shelf of India between

Saurashtra basin in NNW and Kerala Konkan in the south.

Meteorological Data

Climate

Mumbai offshore region has a tropical wet and dry climate under the Koppen climate

classification1. The region does not experience distinct seasons, but the climate can broadly be

classified into two main seasons the humid season and the dry season. Usually, the period

between October to May is relatively dry. The region gets southwest monsoon rains

beginning June to end September with peak rains occurring in July. Northeast monsoon

period occurs between December to February and during this period, it experiences high wind

speeds, but rainfall is negligible.

1. Mean Sea Surface Temperature

According to the National Oceanic and Atmospheric Administration (NOAA), the maximum

and minimum value of mean sea surface temperature in the Arabian Sea is of the order of

30.8ºC and 26.04 ºC, respectively.

2. Mean Air Temperature

As per available data with Physical Sciences Division, Earth System Research Laboratory,

NOAA, Boulder, Colorado,maximum and minimum value of mean air temperature in the

Arabian Sea is of the order of 30.2ºC and 24.04 ºC, respectively.

3. Mean Wind Speed

The study of average hourly wind speed in project area shows significant seasonal variation

over the course of the year. The windier part of the year lasts for 2.9 months, from June 1st to

August 30th, with average wind speeds of more than 10.6 miles per hour.

4. Waves and Tides


NOAA, Boulder, Colorado, Predominant significant wave height and zero-crossing period are

50 to 70 cm and 8 to 8.5 sec respectively. The predominant wave periods and wave heights

are 5-6 sec and 0.5 to 1.5 m respectively during the fair-weather season (October-May) and 5-

9 sec and 1-3 m respectively during the rough weather season (June-September). A wide

range of wave heights 0.5-5 m occurs during the rough season.

3.2 MARINE ENVIRONMENT

Water and sediment quality sampling was carried out in B-9, B-7 and BRC blocks of the

cluster offshore fields in the Mumbai Offshore Basin. The samples collected were further

considered for laboratory analysis.

Sampling Methodology

A survey vessel scrutinized by Offshore Défense Advisory Group (ODAG) was hired for

offshore sampling. The vessel was well-equipped with Global Positioning System (GPS) and

Radar for accurate positioning, radio communication and satellite telephone for

communication. The survey vessel was cruised to the sampling locations according to the

given geographical coordinates, i.e., latitude and longitude of the sampling locations. The

1 City Profile of Greater Mumbai, 2011.

https://www.ndrdgh.gov.in/NDR/Images/MumbaiOffshore/MumbaiOffshore.jpg




water and sediment samples were drawn from 2 levels in the sea, i.e., at the surface and

bottom levels for each of the five (5) sampling locations.

i. Sea Water Sampling

The sea water (SW) samples were collected from two (2) levels in the sea using a NISKIN

Sampler of 5 litres capacity. The depth levels are as follows:

a. Sample 1 – 3 m below the surface

b. Sample 2 – 32-42 meter above the sea bed

c. Results of Sea Water Monitoring

i. The observed pH value in the study region during the period of study is in the range of

8.0 to 8.2. The changes in pH are marginal as expected for natural marine waters

sustaining low primary productivity. The total hardness (as CaCO₃) in all the water

sample lies in the range of 8000 to 10000 mg/L. The value of alkalinity (as CaCO₃) was

in the range of 126 to 132 mg/l.

ii. The dissolved oxygen ranges from 4.4 mg/l to 5.2 mg/l.

iii. The concentrations of Chloride in all the sample were in the range of 18135 to 20419

mg/L. The contents of oil & grease in all sample was below detectable limit (BDL) in

all the sampling locations.

iv. The BOD levels in all water samples was found to be below detection limit (BDL)

wherein the detection limit for BOD is 2 mg/L.

v. It has been observed from the laboratory analysis that residual free chlorine, Cr⁶+, and

as were below detection limits in all the water samples. Whereas, there has been

observed a slight detection in few samples in regard to the concentration of lead, nickel,

zinc and mercury.

ii. Sea Sediments Sampling

Marine sediments play a very important role as repositories of organic matter and nutrients

for the ecosystem but at the same time, they are vulnerable to heavy metal and organic toxics

(from anthropogenic activities) especially in the offshore oil and gas. Five (5) sea sediment

(SS) samples were collected from the Mumbai Offshore Basin.

Results of Sea Sediment Monitoring

Oil and grease ranges from 0.1 to 0.7, Nitrite as Nitrogen found as 3 mg/kg at location SS1 &

SS5 rest of the location shown the values below detection limits. The Total Kjeldahl Nitrogen

ranges from 403 mg/kg to 528 mg/kg. The hexavalent chromium is found below the detection

limit at all the locations.

Among the heavy metals, iron varied from 39,243 mg/kg to 56,797 mg/kg and lead from 5 to

7 mg/kg, zinc showed variation of 60 to 69 mg/kg, cadmium was found below detection limit

and arsenic varied from 2.3 mg/kg to 4.2 mg/kg. The polyaromatic compounds are found

ranges from 0.23 mg/kg to 1.12 mg/kg.

iii. Marine Biological Characteristics

Marine environment is known to support vast population of organisms, found distributed in

both pelagic and benthic realms. Most of the organisms of the pelagic realm constitute the

plankton. Phytoplankton and zooplankton together constitute this community and form the

primary food source for most of the marine species. Their response to physio-chemical

characteristics of the water column determines their distribution, abundance, and

production.The occurrence of marine species both plants and animals has largely been

controlled by the physio-chemical properties of ocean water.

Analysis Results

The location-wise abundance of the various species of phytoplankton, zoo planktons, benthic

meio and the chlorophyll productivity has been observed.

EIA Report - Offshore Oil & Gas Development and Production from Discovered Small Field of B-9 Cluster Offshore Fields at Mumbai Offshore Basin.


Table 3.7: Marine Biological Environment Analysis

S. No. Parameters Unit

SS1 at B9-1 SS2 at B9-2 SS3 at B9-3 SS4 at B7 SS5 at BRC

S B S B S B S B S B

1. Chlorophyll-a mg/m³ 2.72 2.85 2.91 2.81 3.04 1.91 3.49 1.95 3.81 3.39

2. Primary Productivity- Gross mgC/m³/d 680 -- 640 -- 490 -- 600 -- 490 --

3. Primary Productivity- Net mgC/m³/d 190 -- 120 -- 150 -- 70 -- 80 --

4. Phyto-plankton No./ml 200 100 191 76 190 181 288 247 932 520

5. Zooplankton No./m3 1214 -- 1478 -- 1044 -- 1211 -- 1183 --

6. Benthic Meio No./m2 -- 25 -- 19 -- 12 -- 60 -- 17




4. ANTICIPATED IMPACTS AND MTIGATION MEASURES

This chapter of the EIA report discusses the identification as well as assessment of potential

impacts due to the proposed project on the environment and proposes suitable measures to

mitigate the identified potential adverse impacts. The information presented in these chapters

facilitates the identification of the interactions between the planned construction and

operation phases with the environment. The anticipated impacts and mitigation measures are

tabulated in Table 2 below, the anticipated impacts and mitigation measures for both the

phases, i.e., Drilling and Installation phases are identical.

Table 2: Proposed Environmental Mitigation Measures

S.

No. Component Impact Mitigation Measures

Responsibilities

Drilling and Installation Phase

1. Marine

Water

Quality

• Displacement of sea-bed

sediments may lead to

anoxic intertidal and

offshore mud, leading to

the local chemical

changes in water quality

• Water quality may be

affected by the

solid/liquid discharge

and accidental spillage

of chemicals

• The sewage shall be

treated on-board of the

rig according to the

MARPOL Regulations.

Residual chlorine of the

treated sewage shall not

exceed 1mg/L before

disposal.

• Occupier

(Environment)

• Deputy

Management

Representative

(Environment)

2. Marine

Sediment

• Activities like

deployment of rigs and

other sub-sea

infrastructure may

cause local and

temporary disturbance

to the sea-bed

• The layout of the

subsea infrastructure

shall be designed to

avoid sea bed features

considered to be geo-

hazards.

3. Marine

Ecology

• Adverse impact on

marine life due to

drilling activity, noise

generation, effluent

discharge.

• All precautionary

measures shall be

adopted to minimize

disturbance to the

marine animals due to

deployment and

operations of offshore

wells.

4. Air

Environment

• NOx, PM₁₀, and SOx

emissions from venting,

flaring and D.G. Sets.

• Good operational

controls and high level

of monitoring shall be

built into the design

operations.

• Regular maintenance of

engines and DG sets




S.


Responsibilities

shall be ensured.

• The existing and

proposed DG sets shall

comply with the

applicable emission

norms.

5. Noise

Environment

• Noise and Vibrations

from the heavy

machineries - large

power generation units,

diesel engines, fluid

pumps and mud pumps,

equipment and

transportation vehicles

• Mobile noise sources

such as rig, and vessels

shall be re-routed to

avoid disturbances.

• Avoid loud, sudden

noises, wherever

possible. Integral noise

shielding shall be used

where practicable and

applicable

6. Occupational

Health and

Safety

• Respiratory disease due

to inhalation of dust

• Auditory ailment due

to noise

• Occupational hazards

such as accidental falls,

fire hazards, etc.

• The use of personal

protective equipment

like ear muffs and dust

mask shall be made

stringent

• Water sprinkling

system for fugitive

dust generating areas

• Safety training to

workers

• Regular health check-

ups for workers/

employees

Operation Phase

1. Marine

Water

• The water quality of

the project site may get

affected due to

accidental spillage of

chemicals/oil/lubricants

from the routine

operational activities

• Usage of only low

toxicity chemicals

must be ensured on-

board of the rig and

transportation vessels

• Adequate well

management shall be

ensured during well

completion activities

to minimize produced

water production

• Occupier

(Environment)

• Deputy

Management

Representative

(Environment)

2. Marine

Sediment

• Sediment quality is less

likely to be affected

due to operational

discharges and








S.


Responsibilities


fuel/chemical/lubricant

during the routine



hazards

3. Marine

Ecology

• Sub-sea infrastructure

shall act as a physical

hindrance to the marine

organisms leading to

direct habitat loss

• The operational

activities are also likely

to have an impact on

the benthos in the

benthic zone


measures shall be

adopted to minimize

disturbance to the


deployment and


wells

4. Air • Air emissions may

result from gas flaring

activities during the

well testing only (1-2

days).

• Regular maintenance

of the transportation

vessels

• Regular ambient air

quality monitoring

must be carried out.

5. Noise and

Vibration

• Noise is likely to be

generated during the

operation phase due to

the operation of rigs,

generators, etc.

• Rubber padding/noise

isolators shall be

provided at

equipment/machineries


of all equipment and


shall be ensured

6. Occupational

Health and

Safety



fire hazards, etc.

• Strict enforcement of

PPEs on workers/

employees


workers

• Cordoning of

hazardous areas as ‘No

Smoking Zone’

• Bi-annual or annual

health check-up camps

for workers/ employees

5. ANALYSIS OF ALTERNATIVES

AWEL has been awarded contract area MB/OSDSF/B9/2016 comprising of B-9 Cluster

Offshore Fields and has signed the Revenue Sharing Contract (RSC) with the Government of

India (GoI). So, no alternative site is analyzed.




6. ENVIRONMENTAL MONITORING PLAN

An Environmental Monitoring Plan has been included which outlines the monitoring

parameters, frequency, and monitoring locations against specific mitigation measures. The

plan clearly defines the responsibilities for mitigation and monitoring and suggests time

bound schedules. The parameters and respective frequency of monitoring as part of

Environmental Monitoring Plan for drilling and operation phases are tabulated below in

Table 3 and Table 4 respectively.

Table 3: Environmental Monitoring Program (Drilling and Installation Phase)

Receptor Location Monitoring and Reporting

Frequency

Natural

Resource

Project Site

(Operation areas) Daily during Drilling

Drilling wastes Drilling Locations

• Daily monitoring &

recording of quantity

• Monitor and record the

generation quantity on daily

basis

Oil Spills

Drilling Locations

Daily during Drilling

Operation.

Noise &

Vibration

Project Site

(Operation areas)

Weekly during Drilling and

Installation phase

Water Quality

• Upto 1 km radius from Drilling

location/Wellhead platform site

• At every 5 km stretch of the sub-

sea pipeline and locations within

1 km radius of the pipeline

Once during Drilling and

Installation phase

Sediment

Quality







Installation phase

Ecological

Parameters







Installation phase

Table 4: Environmental Monitoring Program (Operation) Phase

Receptor Location Monitoring and

Reporting Frequency

Water Quality

• Upto 1 km radius Well/Wellhead platform

site

• At every 5 km stretch of the sub-sea

pipeline and locations within 1 km radius

of the pipeline

Once in a year

Sediment

Quality


site


Once in a year




Receptor Location Monitoring and

Reporting Frequency


of the pipeline.

Ecological

Parameters


site



of the pipeline.

Once in a year

7. ADDITIONAL STUDIES

The risk assessment study is aimed at identifying the potential sources which pose risks of a

hazard outbreak, determining the probability of such hazard occurrences and their

consequences. In doing so, the risk assessment exercise mitigates the severity of any accident

and facilitates preparation of an effective emergency response plan or disaster management

plan. Risk assessment includes the identification of risks involved in the drilling activities and

the associated activities in the drilling program, platform & pipeline installation activities

along with the assessment of probability of certain consequences.

8. PROJECT BENEFITS

The world consumes 12000 million tons of oil equivalent (mtoe) of energy resources, whereas

India consumes 4.4% of the world’s total (524.2 mtoe) according to FICCI. Of the total

primary energy consumption basket, oil and gas constitute 45% share in the total energy

basket mix. About 78 per cent of India’s petroleum consumption is met from imports (mostly

of crude oil), while about 25% of natural gas (including LNG) consumption comes from

imports. It is estimated that in the upcoming years, the import dependency for crude oil alone

would reach above 90% level.

Thus, development of existing oil and gas reserves has become a necessity to bridge the rising

demand-supply gap, reduce import dependency and make ourselves resilient to the external

factors of economic and political disruptions in the sourcing nations.

9. ENVIRONMENTAL COST AND BENEFIT ANALYSIS

This chapter aims to integrate economic and environmental consideration in decision making.

In general, the cost-benefit aspect of the project is analysed to weigh the costs of proceeding

with proposed development of B-9 cluster to produce natural gas and crude oil against the

benefits that would arise from it.

10. ENVIRONMENTAL MANAGEMENT PLAN (EMP)

The Environmental Management Plan is prepared to facilitate the field level implementations.

EMP is a key to ensure a safe and clean environment. The desired results from the

environmental mitigation measures proposed in the project may not be obtained without a

management plan to assure its proper implementation and function. The EMP envisages the

plans for the proper implementation of mitigation measures to reduce the adverse impacts

arising out of the project activities. This plan needs to be well implemented during drilling

and installation as well as operation phases of the project. The following plans are proposed

under the Environmental Management Plan:

• Waste Management Plan

• Oil Spill Contingency Plan




11. SUMMARY AND CONCLUSION

EIA study includes establishment of the present environmental scenario in the proposed

project area. EIA report consists of study of the specific activities related to the project and

evaluation of the probable environmental impacts, thus leading to the recommendations of

necessary mitigation measures. The entire EIA study has been carried out based on the

applicable environmental legislation, regulations and guidelines of the MoEF&CC.

The project involves offshore O&G development and production from DSF of B-9 cluster

fields of 183.23 sq.km at Mumbai Offshore Basin.

In the drilling and installation phase the vehicular & vessel movement, pipe-laying works and

operating of generators will have maximum impact, especially on air, noise, vibration and

ecological environment. Water quality and geology/soil will be affected due to the discharge

of wastewater (construction and domestic) and any leakage of oil etc.; from generators and

other equipment. On the other hand, during the operation phase; usage of maintenance &

cleaning chemicals and risk of gas leakages will affect the water, air, noise and biological

environment. With respect to occupational health, impacts are anticipated on the health of the

employees during drilling and installation phase. Personnel working near the noise generating

machines and handling of chemicals and lubricants are more susceptible of getting health

hazards and the effect of these will be minimized through various mitigation measures.

Overall, this project will bring economic benefits, increase energy security of the country and

generate employment opportunities.

12. DISCLOSURE OF CONSULTANTS ENGAGED

Asian Consulting Engineers (ACE) Pvt. Ltd., New Delhi is the EIA consultant for this

proposed project. ACE is a QCI-NABET accredited independent EIA consultant organization

(Certificate No.: NABET/EIA/1417/SA030) for various sectors including preparation of EIA

of onshore and offshore oil and gas exploration and development and transportation of oil and

gas through pipelines (Category A). ACE has been awarded ISO 9001:2015 certification by

RINA India.

11

IINNTTRROODDUUCCTTIIOONN



Asian Consulting Engineers Pvt. Ltd. 1-1

1. INTRODUCTION

1.1 INTRODUCTION

Adani Welspun Exploration Limited (AWEL) is a joint venture E&P Company formed by

two India based multinational business conglomerates Adani Group and Welspun Group to

undertake upstream Oil & Gas business with 65% and 35% shares respectively. AWEL has

been awarded contract area MB/OSDSF/B9/2016 comprising of B-9 Cluster Offshore Fields

and has signed the Revenue Sharing Contract (RSC) with the Government of India (GoI). The

field was originally discovered by Oil and Natural Gas Corporation (ONGC) which was

subsequently offered for bidding under Discovered Small Fields (DSF) round, 2016. AWEL

plans to develop the B-9 Cluster field by drilling wells and installing offshore facilities to

produce natural gas and crude oil, and process through the existing offshore facilities. The B-

9 cluster comprises three (3) DSF offshore fields namely B-9, B-7 and BRC.

The scope of proposed project comprises of the following:

• Drilling and completion of 12 Wells out of which 7 wells are in B-9 field, 3 wells in B-7

& 2 wells in BRC fields.

• Installation of two (2) wellhead platforms in B-9 area, and one (1) platform each in B-7 &

BRC areas. Alternately, sub-sea completion wells may also be explored during the

design stage.

• Laying of approximately 80 km sub-sea pipeline (upto 10”) from B-9 field to a nearby

operator’s existing well head platform and hooking-up with the offshore platform

facilities.

• Laying of approximately 10 km intra-field sub-sea pipeline (upto 8”) within the B-9 area

and hooking-up with the existing offshore facilities.

• Laying of approximately 30 km sub-sea pipeline (upto 8”) from B-7 platform/area to B-9

platforms /area and hooking-up with the platform facilities.

• Laying of approximately 10 km sub-sea pipeline (upto 6”) from BRC platform/area to B-

7 platform /area or B-9 platforms/area and hooking-up with the platform facilities.

The B-9 & B-7 are Gas fields, whereas BRC is an Oil field. The development drilling &

completion work are planned to be performed using a Jack-Up Rig at the Wellhead Platform.

The overall development cost tentatively is expected to be about US$ 250 million (INR 1600

Crores). Table 1.1 below presents the salient features of the project.

The location map of the B-9 Cluster Field is shown in Figure 1.1.

11




Table 1.1: Salient Features of the Project

Items Details

Project Development of B-9 Cluster Offshore Fields in the Discovered Small

Fields (DSF), Mumbai Offshore Basin

Project Fields Three DSF Fields

a. B-9 – Gas Field: 138.5 sq.km

b. B-7 – Gas Field: 22.7 sq.km

c. BRC – Oil Field: 22.03 sq.km


Project Activities 1. Drilling and Completion of Wells: 12 nos.

a. 7 wells in B-9 Fields

b. 3 wells in B-7 fields

c. 2 wells in BRC field

2. Installation of Wellhead Platform: 4 nos.

a. 2 in B-9 Field

b. 1 in B-7 Field

c. 1 in BRC Field

3. Laying of Subsea Pipelines: 130 km (approx.)

a. Approx. 80 km sub-sea pipeline (up to 10”) from B-9 field to

a nearby ONGC platform.

b. Approx. 10 km intra-field sub-sea pipeline (up to 8”) within

the B-9 area.

c. Approx. 30 km sub-sea pipeline (up to 8”) from B-7

platform/ area to B-9 platforms /area.

d. Approx. 10 km sub-sea pipeline (up to 6”) from BRC

platform/ area to B-7 platform /area or B-9 platforms/ area.

Type of Hydrocarbon

Expected

Oil and Gas.

Type of Rig to be

Used

Jack-Up Rig.

Depth of Wells 2500 m to 4000 m Total Vertical Depth (TVD). Wells may be

deviated with horizontal displacement of around 1500m.

Study Area Details • Located beyond 12 nautical miles, well beyond CRZ, thus the

project is not covered under the CRZ Notification, 2011.

• No human settlement (within 15 km of the project area).

• No Eco-Sensitive Zone (within 15 km of the project area).

• No Development activities on land.

Total Project Cost INR 1600 Cr.

EIA Report - Offshore Oil & Gas Development and Production from Discovered Small Field of B-9 Cluster Offshore Fields at Mumbai Offshore

Basin.


Figure 1.1: B-9 Cluster Field Location Map




The expected hydrocarbon production from the three DSF fields (B-9 Cluster Fields) is

presented in below Table 1.2:

Table 1.2: Expected Production from B-9 Clusters

Sl. No. Products Quantity

1. Gas (B-9 Field): 32 mmscfd

(peak production rate for a plateau period of 4 years followed

by declining profiles)

2. Gas (B-7 Field): 21 mmscfd



3. Oil (BRC Field): 800 bopd & 0.4 mmscfd



Mmscfd: Million standard cubic feet per day

BOPD: Barrels of oil per day

1.2 NEED OF THE EIA STUDY

The purpose of proposed project is development and production of oil and gas fields at

Mumbai offshore basin. The offshore O&G exploration, development and production

activities are covered under Schedule 1(b) of the EIA notification, 2006 and being a ‘Category

A’ project it requires Environmental Clearance from MoEF & CC.

An application for Environmental Clearance was submitted to MoEF&CC vide letter dated 12

December 2017 and the approval of Terms of Reference (TOR) for the EIA study was issued

by MoEF&CC vide letter No. J-11011/565/2017-IA. II (I) on dated 13th March 2018.

The location of the proposed project is beyond 12 nautical miles (NM) and falls in the

Mumbai Offshore Basin. In this EIA, 15 km radial distance from each block is considered as

the study area (as the 10 km buffer was not covering the entire block). There are no eco-

sensitive areas or biodiversity hotspots within 15 km of the fields. The nearest habitation is in

Diu located about 72 km from the field. The map of study area around 15 km distance from

the project location is shown in Figure 1.2.



Figure 1.2: Study Area around B-9 Cluster Field Location (15 km Buffer)




1.3 PROJECT PROPONENT

Adani Welspun Exploration Limited (AWEL) is a joint venture (JV) of E&P Company

formed by two India based multinational business conglomerates to undertake Oil and Gas

business, namely:

i. Adani Group (Ahmedabad).

ii. Welspun Group (Mumbai).

In this JV, Adani Group holds 65% through its flagship company Adani Enterprises Limited

(AEL) whereas Welspun Group holds 35% through Welspun Natural Resources Pvt. Ltd, a

subsidiary of its flagship company Welspun Enterprises Limited (WEL). Both these

enterprises are enlisted on various Stock Exchanges. AWEL holds key operated and non-

operated assets in Mumbai Offshore & Gulf of Kutch in the Western Offshore Basin. It has

carried oil and gas exploration programmes in India and across borders.

1.4 EIA CONSULTANT

Adani Welspun Exploration Limited (AWEL) proposes for the development of B-9 cluster

offshore fields. In line with the industry’s best practices and the regulatory obligations on

environmental protection, AWEL has proposed to conduct EIA for the project, engaging

Asian Consulting Engineers (ACE) Private Limited as the EIA consultant.

ACE is Quality Council of India-National Accreditation Board for Education and Training

(QCI-NABET) accredited EIA consulting organisation (Certificate No.:

NABET/EIA/1417/SA030) for 09 sectors including offshore and onshore oil and gas

exploration, development, production & oil and gas transportation pipelines. ACE is an ISO

9001:2015 certified company.

1.5 POLICY AND LEGAL FRAMEWORK

The Project Proponent will ensure that the project aligns with all the National legislations,

regulations, and conventions, relating to various aspects of Offshore Oil and Gas

Development and Production activities in India. Table 1.3 shows list of applicable Acts and

Rules as set by MoEF&CC and Central Pollution Control Board (CPCB).

Table 1.3: Applicable Acts and Guidelines for the Proposed Project

Components Applicable Legislation

Water

1) The Environment Protection Act, 1986 – Standards for liquid

discharge by Oil Drilling and Gas Extraction Industry as notified vide

notification dated GSR 176 (E) April 1996.

Air

2) The Environment Protection Act, 1986 – Guidelines for discharge for

gaseous emissions by Oil Drilling and Gas Extraction industry as

notified vide notification dated GSR 176 (E) April 1996.

3) The Environment (Protection) Second Amendments Rules, 2002 –

Emission Standards for New Generator Sets.

Hazardous

Substances

and Wastes

4) Hazardous and Other Wastes (Management and Transboundary

Movement) Rules, 2016.

5) Guidelines for disposal of solid wastes by Oil Drilling and Gas

Extraction industry as notified, vide notification dated GSR 546 (E)

August 2005.

6) The Petroleum Act, 1934.




Components Applicable Legislation

Safety and

Protection

against

Pollution of

Environment

7) Oil Mines Regulations, 1984.

8) Oil Field (Regulation and Development) Act 1948 and the Petroleum

& Natural Gas Rules, 1959 and amendments.

9) MARPOL Convention, 1973/78 for preventing and minimizing

pollution from ships-both accidental pollution and that from routine

operations.

10) International Convention for the Safety of Life at Sea (SOLAS), 1973,

as amended for safety of vessels.

11) Coast Guard Act, 1950 for combating marine pollution and security of

the maritime zones of India.

EIA 12) Environmental Protection Act 1986 and its amendments.

13) EIA notification 2006 and its amendments.

1.6 SCOPE OF THE EIA STUDY

The scope of the EIA study includes detailed characterization of the existing status of the

water and biological environment within the block area, identification of the potential

environmental impacts of the project and formulation of an effective environmental

management plan (EMP) to prevent, control & mitigate the adverse environmental impacts of

the project, thereby ensuring environmental compliance. The Terms of Reference (TOR) for

this project was approved by the Ministry of Environment, Forest and Climate Change

(MoEF&CC) vide F.No. J-11011/565/2017-IA II (I) dated 13th March 2018.

It is seen from the approved TOR by MoEF&CC that the Expert Appraisal Committee (EAC)

has recommended the standard TOR applicable for offshore and onshore drilling projects.

Table 1.4 below highlights the compliance framework adhering to the approved and standard

TOR by MoEF&CC for the preparation of the EIA study reports.

1.7 APPROACH AND METHODOLOGY OF EIA STUDY

i. Approach of EIA Study

The EIA study includes establishment of the present environmental scenario in the project

area. EIA report consists of study of the specific activities related to the project and evaluation

of the probable environmental impacts, thus leading to the recommendations of necessary

mitigation measures. The entire EIA study is carried out based on the applicable

environmental legislations, regulations and guidelines of the MoEF&CC.

ii. Establishment of Baseline Environmental Status

A comprehensive database on the baseline environmental status/conditions of the study area

has been established through review, compilation & analysis of:

i) Existing published secondary data/literature/information, and

ii) Primary data collection through field study, surveys and monitoring.

iii. Collection of Secondary Data

Besides inputs from the client on relevant information about the project, available relevant

secondary data/ information/ records and published literature with respect to the environment

of the study area is collected, reviewed and analysed to provide the overview and details of

the study area.




• Geology of the study area including the basin type and the different tectonic zones

within the basin.

• Metrological data consisting of parameters like temperature, wind speed, wave and

tides, rainfall and cyclone were collected and analysed.

• Biological data related to marine environment were collected and analysed.

iv. Field Study/ Monitoring for Generation of Primary Data

The collected secondary data was appropriately supplemented by necessary primary data,

which was collected through field study/monitoring. The field monitoring has been carried out

as per the guidelines of the Central Pollution Control Board (CPCB) and requirements of the

MoEF&CC.

a) Marine Water Quality: The marine water samples were collected and analysed to assess

the quality of marine water in the project area.

b) Marine Sediment Quality: Sea sediment samples were collected using a Van-Veen Grab

Sampler and analysed from five (5) sediment sampling (SS) representative locations from

the study area.

c) Biological Ecology: Zooplankton, Phytoplankton and Benthos species present at five (5)

representative locations were identified and their abundance was calculated. Secondary

information on other marine species were collected, reviewed and presented.

v. Impact Identification and Mitigation Measures

Impacts with respect to air, noise, water, sediment, marine and socio-economic environment

were identified based on the environmental as well as socio-economic baseline conditions.

Following the impact identification, based on the severity of impacts, suitable and viable

mitigation measures are proposed either to nullify the adverse impacts or to enhance the

positive impacts.

vi. Preparation of Environment Management Plan

Environmental Management Plan (EMP) is the key to ensure a safe and clean environment. It

basically comprises of all the mitigation measures, which have been proposed for all the

identified potential impacts. Further, the cost for EMP implementation during capital and

maintenance dredging phase is provided. The following plans are part of EMP

• Waste Management Plan

• Oil spill contingency Plan

1.8 STRUCTURE OF THE EIA REPORT

As per Appendix III of EIA Notification, 2006, the report is structured and organized in the

following chapters:

Chapter 1: Introduction gives a brief description about the project portfolio, project

proponent and environmental legislations/permits applicable to the project. It

also highlights the approved Terms of Reference (ToR) for the

Environmental Impact Assessment (EIA) Study.

Chapter 2: Project Description provides the operations associated with the project

along with the need and justification of the project.

Chapter 3: Description of the Environment describes the background environmental

characteristics and the other socio-economic activities in the area.




Chapter 4: Identification of Impacts and Mitigation Measures presents the potential

environmental impacts and recommends the cost-effective mitigation

measures to counter the negative impacts of the project activities.

Chapter 5: Analysis of Alternatives presents the alternative analysis with respect to the

project location and activities.

Chapter 6: Environmental Monitoring Plan describes the mechanism to address the

adverse environmental impacts during different phases of the project along

with frequency and the sampling locations.

Chapter 7: Additional Studies illustrates the Risk Assessment & Disaster Management

Plan highlighting an emergency action plan for prior preparedness in case of

an emergency related to the project activities.

Chapter 8: Project Benefits details out the positive outcomes of the project in

accordance to the socio-economic as well as environmental parameters.

Chapter 9: Environment Cost and Benefit Analysis provides the details of

environmental cost and benefits.

Chapter 10: Environmental Management Plan provides a mechanism to address and

mitigate the adverse impacts of the project.

Chapter 11: Summary and Conclusion provides a synopsis of the major findings of the

EIA study and delineates the conclusion drawn out of the study.

Chapter 12: Disclosure of Consultants Engaged provides the details about the

consultant’s organization and the nature of consultancy engaged in to carry

out the EIA study.



Table 1.4: Compliance Report

Adherence to ToR Approved by MoEF&CC for the EIA Study

S. No. Terms of Reference (ToR)

Reference in the EIA Report

Chapter

No.

Section

No. Page No. Title/Remarks

1. Executive Summary of the Project. Enclosed with the EIA report.

2. No. of development wells for which environmental clearance is

accorded and No. of new wells proposed during expansion.

Status and No. of wells which are completed and closed.

2 2.1, 2.2 &

2.3

2-1 to 2-6 The detailed description of the project

along with the salient features, no. of

wells, no. of well head platforms are

given.

3. Project Benefits. 8, 9 8.1, 9.2 8-1 9-2 The Benefits of the project is given.

4. Cost of project and period of completion. 2 2.1 2.1 to 2.2 Project overview.

5. Employment to be generated

6. Distance from coast line. 1 1.2 1-4 Nearest distance from the coastline is

approximately 72 km (aerial distance).

7. Details of sensitive areas such as coral reef, marine water park,

sanctuary, and any other eco-sensitive area

1, 3 1.2 1-4 There is no eco sensitive areas around 15

km distance from the project location.

8. Recommendation of SCZMA/CRZ clearance as per CRZ

Notification dated 6th January 2011 (if applicable).

CRZ is not applicable as the project is located beyond 12 nautical miles.

Nearest Landfall point is approximately 72 km (aerial distance).

9. Details on support infrastructure and vessel in the study area. Not available currently.

10. Climatology and meteorology including wind speed, wave and

currents, rainfall, etc.

3 3.5 3-5 -

11. Details on establishment of baseline on the air quality of the

areas immediately affected by the development drilling and also

particularly with reference to hydrogen sulphide, sulphur

dioxide, NOx and background levels of hydrocarbons and VOCs

- - -

-

12. Details on estimation and computation of air emissions (such as

nitrogen oxides, sulphur oxides, carbon monoxide,

hydrocarbons, VOCs, etc.) resulting from flaring, DG sets,

combustion, etc. all project phases.

- - - -





Chapter

No.

Section


13. Baseline data collection for surface water for one season leaving

the monsoon season within 1 km for each development well,

particularly in respect of oil content in the water sample and

sediments sample.

3 3.6 3-9 to 3-

19 -

14. Fisheries study w.r.t. benthos and marine organic material and

coastal fisheries. 3 3.6 3-29 The fish species found in the study area

are mentioned.

15. Source of fresh water and detailed water balance, waste water

generation and discharge. 2 2.1 2-1 -

16. Noise abatement measures and measures to minimize

disturbance due to light and visual intrusions in case of project

site closed to the coast. 4, 6, 10 4.5, 4.5.2 4-7

The project location is far from the

nearest coast (72 kms.). The mitigation

measures are suggested to minimize the

impacts of noise pollution.

17. Procedure for handling oily water discharges from deck

washing, drainage systems, bilges, etc. 10 10.2.3 10-10

The waste management plan along with

oil spill contingency plan is provided.

18. Procedure for preventing spills and spill contingency plans. 10 10.2.3 10-10

The waste management plan along with

oil spill contingency plan is provided.

19. Procedure for treatment and disposal of produced water.

2 2.5.3, 2-20

The appropriate measures for treatment

and disposal of produced water are

provided.

20. Procedure for sewage treatment and disposal and also for

kitchen waste disposal. 2 & 10 2.5.3,

10.3.1 2-20, 10-9

The waste management plan is given for

treatment and disposal of sewage waste,

kitchen waste.

21. Details on solid waste management for drill cuttings, drilling

mud and oil sludge, produced sand, radioactive materials, other

hazardous materials, etc. including its handling and disposal

options during all project phases.

2, 10 2.1, 2.5.3,

10.3.1

2-1, 2-20,

10-9

The details of solid wastes to be generated

are given along with its proper treatment

and disposal measures.

22. Storage of chemicals on site. 10 - - The measures are given for safe storage.





Chapter

No.

Section


23. Commitment for the use of water-based mud (WBM) and

synthetic oil-based mud in special case. 2 2.1 2-1

The Water-based mud will be used,

Synthetic oil based mud will be kept as

an option in special cases.

24. Details of blowout preventer installation.

Blow out preventer is an integral part of a

drilling rig and will be installed before

spud of every well. Details are rig

specific. Rig charter is still underway.

25. Risk assessment and mitigation measures including whether any

independent reviews of well design, drilling and proper

cementing and casing practices will be followed.

4 & 7 - The Risk assessment is incorporated in

the report.

26. Handling of spent oils and oil from well test operations.

10 - -

The oil spill contingency plan is provided

to handle the spent oil/oil spills to be

generated in the project activity.

27. Details of all environment and safety related documentation

within the company in the form of guidelines, manuals,

monitoring programmes including Occupational Health

Surveillance Programme etc.

- - -

Company HSE’s policy is annexed as

Annexure II.

28. Restoration plans and measures to be taken for decommissioning

of the rig and restoration of onshore support facilities on land. - - - Not applicable.

29. Documentary proof for membership of common disposal

facilities, if required. - - -

Not applicable.

30. Any litigation pending against the project or any directions/order

passed by any Court of Law against the project. If so, details

thereof.

- - - No litigation pending.

31. Total capacity and recurring cost for environmental pollution

control measures. 10 10.4 10-11 The capital cost and recurring cost is

provided.

22

PPRROOJJEECCTT

DDEESSCCRRIIPPTTIIOONN




PROJECT DESCRIPTION

2.1 PROJECT OVERVIEW

Adani Welspun Exploration Limited (AWEL) has been awarded the Offshore Contract Area

MB/OSDSF/B9/DSF (B-9) Cluster and has signed the Revenue Sharing Contract (RSC) with

the Government of India. AWEL intends to fast-track the project to produce the ‘first-gas’

from the field at the earliest.

The contract area MB/OSDSF/B9/2016 comprises of three (3) Discovered Small Fields (B-9,

B-7 and BRC), located in the Mumbai Offshore Basin. While B-9 & B-7 are Gas Fields, BRC

is an Oil Field. Well-Head platforms are aimed to be minimum facilities platforms which will

be unmanned with periodical visits through helicopter to conduct routine maintenance, well

maintenance and any other related repair work. The project details has been tabulated in the

Table 2.1 below.

Table 2.1: Project Details

Items Details

Project Name Development of B-9 Cluster Offshore Fields in the

Discovered Small Field (DSF), Mumbai Offshore Basin.

Project Category ‘A’


Project Fields Three Discovered Small Fields (DSF)

a. B-9 138.5 sq.km Gas Field

b. B-7 22.7 sq.km Gas Field

c. BRC 22.03 sq.km Oil Field

Total Number of Proposed

Production Wells

12 Wells

a. B-9 Field Well

Well Head Platform 1

(B-9-1 Area)

Surface Location of 4 wells.

Well Head Platform 2

(B-9-3 Area)

Surface Location of 3 wells.

b. B-7 Field Well

Well Head Platform 3 Surface Location of 3 wells.

c. BRC Field Well

Well Head Platform 4 Surface Location of 2 wells.

Type of Hydrocarbon

Expected

Oil & Gas

Type of Rig to be Used Jack-Up Rig.

Depth of Wells

2500 m to 4000 m Total Vertical Depth (TVD).

Wells may be deviated with horizontal displacement of around

1500 m.

Drilling Period 45 - 60 days per well.

Test Flaring of Gas 4 days per well during initial testing.

22




Items Details

Proposed Drilling Fluid Water-based Mud System.

Synthetic Oil Based Mud (SOBM) may be used as an option.

Drill Cuttings (during

drilling)

About 300– 500 m³ per well.

Total Length of Proposed

Sub- Sea Pipelines

Laying of approx. 130 km sub-sea pipelines.

Proposed Pipeline Facility

a. Approx. 80 km sub-sea pipeline (upto 10”) from B-9 field

to a nearby existing ONGC platform.

b. Approx. 10 km intra-field sub-sea pipeline (upto 8”) within

the B-9 area.

c. Approx. 30 km sub-sea pipeline (upto 8”) from B-7

platform/ area to B-9 platforms /area.

d. Approx. 10 km sub-sea pipeline (upto 6”) from BRC

platform/area to B-7 platform /area or B-9 platforms/ area.

Nearest Railway Station

Nearest Airport.

Railway Station: Delwada (Gujarat) – approx. 74 km.

Airport: Diu Airport (Daman and Diu) – approx. 72 km.

Nearest Town /City/Village

Town: Diu (Daman and Diu) - approx. 72 km.

City: Jafrabad (Gujarat) - approx. 75 km.

Village: Delvada (Gujarat) - approx. 74 km.

Expected Cost of the Project Tentatively INR 1600 Crores.

Figure 2.1 & 2.2 depicts the project location map along with the distance from the nearest

city.


fields of 183.23 sq.km at Mumbai Offshore Basin. The proposed products/utilities are

mentioned in Table 2.2.

Table 2.2: Proposed Products

S. No Products Quantity

1. Gas (from B-9 Field) 32 mmscfd

(Peak Production Rate (PPR) for a plateau period of four (4) years

followed by declining profiles).

2. Gas (from B-7 Field) 21 mmscfd

(PPR for a plateau period of four (4) years followed by declining

profiles).

3. Oil (from BRC Field) 800 bopd & 0.4 mmscfd

(PPR for a plateau period of two (2) years followed by declining

profiles).



Figure 2.1: Project Location from the nearest cities.



Figure 2.2: Proposed Project Location and other AWEL blocks




2.2 PROJECT LOCATION

Details of Blocks

Block boundary co-ordinates of various fields is tabulated below in Table 2.3.

Table 2.3: Block Boundary Co-ordinates

Sl. No Field Points Latitude Longitude

1. B-9

A 20°10’53.88” N 71°22’44.13” E

B 20°04’20.03” N 71°29’43.40” E

C 20°00’29.86” N 71°28’49.56” E

D 20°00’23.72” N 71°26’04.36” E

E 20°06’44.21” N 71°25’01.02” E

F 20°06’32.26” N 71°20’13.92” E

G 20°08’56.76” N 71°18’52.32” E

2. B-7

A 19°59’29.60” N 71°07’29.00” E

B 19°59’36.37” N 71°09’13.69” E

C 19°59’27.67” N 71°11’48.86” E

D 19°58’18.92” N 71°12’00.32” E

E 19°57’31.03” N 71°07’47.36” E

3. BRC

A 19°53’59.72” N 71°09’58.11” E

B 19°54’00.32” N 71°12’59.65” E

C 19°51’32.77” N 71°12’59.10” E

D 19°52’11.67” N 71°09’38.40” E

Details of Well head Platforms

The Coordinates of Well-Head platform are given below in Table 2.4.

Table 2.4 Well-Head Coordinates

S. No. Field Latitude Longitude Remarks

B-9 Field Well Co-ordinates

1. Well-Head Platform 1

(B-9-1 area) 20°08'19.09"N 71°21'59.92"E

Surface location

of 4 wells

2. Well-Head Platform 2

(B-9-3 area) 20°05’39.63"N 71°26’0.92" E

Surface location

of 3 wells

B-7 Field Well Co-ordinates

3. Well-Head Platform 3 19°58’45.33" N 71°08'39.4" E

Surface location

of 3 wells in B-7

BRC Field Well Co-ordinates

4. Well-Head Platform 4 19°53’05.911”N 71°10'51.267" E

Surface location

of 2 well in BRC

2.3 PROJECT DESCRIPTION

Drilling operations shall be carried out at B-9 clusters offshore fields to extract the trapped

hydrocarbons. The gas produced from the wells will be co-mingled and sent to ONGC’s C-24

RP platform located nearly 80 km from the project site via 80 km sub sea pipelines. The




processing of the oil and gas is envisaged to be done by ONGC facilities. No onshore

facilities are envisaged in the current concept.

The platforms are planned to be minimum facilities well-head platforms comprising of well-

head, production & test manifold, well-head control panel, scrapper launcher, instrument gas

system, local power generation (solar or other), heli-deck, jib-crane, fiscal metering, real-time

production data transfer to Director General of Hydrocarbon (DGH) through satellite

communication, etc.

On-bottom stability analysis study will be performed at the design stage and appropriate

requirements for protection of pipeline, environment & other consideration like security will

be finalised during the design phase.

The development for B-7 field & BRC field will include installation of 2 well-head platforms,

inter-field sub-sea pipelines and hooking up at B-9 area. The BRC platform is also envisaged

to include facilities to handle, stabilise, store and export oil.

The conceptual sub-sea pipeline layout plan for B-9 DSF Cluster Fields development is

shown in Figure 2.3.

Figure 2.3: Conceptual Sub-Sea Pipeline Layout Plan for B-9 DSF

2.3.1 Details of Proposed Pipelines

The proposed development project also comprises of :

• Laying of approx. 80 km sub-sea pipeline (upto 10”) from B9 field to a nearby ONGC

platform and hooking-up with the platform facilities.

• Laying of approx. 10 km intra-field sub-sea pipeline (upto 8”) within the B-9 area and

hooking-up with the platform facilities.

• Laying of approx. 30 km sub-sea pipeline (upto 8”) from B-7 platform/ area to B9

platforms/area and hooking-up with the platform facilities.




• Laying of approx. 10 km sub-sea pipeline (upto 6”) from BRC platform/ area to B-7

platform /area or B-9 platforms/ area and hooking-up with the platform facilities. The

details are to be finalised during the design phase of the development. (Table 2.5)

Table 2.5 Pipelines Specification

S.

No.

Length of Sub

Sea Pipelines

Size

From To Remarks

1. 80 km 10” B9 ONGC To be hooked-up with the

nearby ONGC platform.

2. 10 km 8” B9 Within

B9 block

Hooking up witthin B9

platform facilities.

3. 30 km 8” B7 B9 To be hooked-up from B7 to

B9 platform and facilities.

4. 10 km 6” BRC B7

To be hooked-up from BRC

platform to B7 platform

facilities.

The project is planned to be executed through a EPIC (Engineering, Procurement, Installation

& Commissioning) Contract and the Contractor would perform detailed design, procure,

fabricate/construct platforms & jackets, install platforms, jackets & pipeline, hook-up and

commission. Platform jackets being considered as mono-towers or three-legged jackets or

alternatives. The platforms & jackets will be fabricated at a remote fabrication yards (in India

or abroad), transported to the offshore field through barges, installed and commissioned. The

pipelines will be sourced from reputed mills, corrosion/weight coated, transported to the field

through barges/vessels, installed sub-sea, hooked up with the platforms and commissioned.

The basic field parameters are mentioned in Table 2.6.

Table 2.6: Field Paramters

Field

Parameters B-9 B-7 BRC

Area (sq. km) 138.5 22.7 22.03

Water Depth (m) 32 - -

Hydrocarbon Natural Gas Natural Gas Oil

Development Wells Seven (7) Three (3) Two (2)

The fields are proposed to be operated unmanned with periodical visits through helicopter/

boat-landing to conduct routine maintenance, well interventions and any related repair work.

The estimated life of the field is nearly 10 years. At the end of the project lifecycle, the

offshore platform facilities will be decommissioned according to the standard oil field

practices.

2.3.2 Gas and Oil Processing

Processing of the oil and gas is envisaged to be done at existing third party facilities. Gas will

be further routed by the third party to their existing on-shore gas processing complex from

where the gas buyers’ off take point will be identified later. No onshore facilities are currently

envisaged in the project.

2.3.3 Overall Indicative Production Profile for B-9 Field

The profile of overall production for B9 field is shown below in Table 2.7.




Table 2.7- Production Profile of B-9 Field.

Date

(dd-mm-

yyyy)

B-9 Profile B-7 Profile

Gas Rate

(MMscf/day)

Cum Gas

Produced

Bscf

Number of

Producers

Gas Rate

(MMscf/day)

Cum Gas

Produced

Bscf

Number of

Producers

4/1/2019 15.0 0.0 3.0

4/1/2020 32.0 11.7 7.0

4/1/2021 32.0 23.4 7.0 21.0 7.7 3.0

4/1/2022 32.0 35.1 7.0 21.0 15.3 3.0

4/1/2023 25.4 46.1 7.0 21.0 23.0 3.0

4/1/2024 16.6 53.7 7.0 21.0 30.7 3.0

4/1/2025 10.5 58.6 7.0 13.6 35.6 3.0

4/1/2026 6.5 61.7 7.0 8.8 38.9 3.0

4/1/2027 3.9 63.6 7.0 5.7 41.0 3.0

4/1/2028 1.8 64.4 7.0 3.7 42.3 3.0

4/1/2029 1.2 64.9 7.0 2.4 43.2 3.0

4/1/2030 1.6 43.8 3.0

Production potential from the BRC field is being evaluated. Profiles will be estimated after

detailed G & G evaluation.

2.3.4 Drilling Phase Activities:

Upon the completion of the drilling preparation, the drilling rig and associated equipment will

be moved onto the location. Drilling of the wells shall be conducted by Jack-Up Rig, which is

the most popular type of mobile offshore drilling unit (MODU) for offshore exploration and

development purposes. The drilling rigs and the spread includes supply vessels which will

primarily run on diesel and power that will be generated within the rigs/vessels through diesel

generators (DG sets). Maximum capacity of cranes is expected to be 100 Tons. Wells are

tentatively planned to be drilled with 4 casing policy having 30” Conductor, 20” Surface

Casing, 13-3/8” & 9 5/8” Intermediate Casings and 7’ Production Liners. Completion strings

will be 3 ½” Tubings with gas-tight connections. Wells are planned to be completed with

sand-screens. The rig will either be transported to location by outside vessel such as tug/barge

or has their own propulsion method for transport. A typical Jack-Up Rig is shown in Photo

Plate 2.1.

Photo Plate 2.1: A Typical Jack-Up Rig




2.3.5 General Platform Facilities Description:

The well-heads planned are integrated wellhead-4CP 10K type with matching Christmas-

trees. The well-head facility will consist of production & test manifold, pig launching and

receiving facility for pipeline and receiving facility for well fluid, closed drain & open drain

system and cold vent system. The main function of the well-head is to maintain surface

control of the well. The electrical power for the platform is generated by means of Solar

Power System and distributed through power distribution boards and for deck crane, power is

generated by diesel engine generator system. Further, the platform shall have instrument &

utility gas system, corrosion inhibitor injection system, material handling and safety

equipment. Each well online monitoring to be performed by using orifice meter. Well testing

to be performed by using multi phase flow meter. The well testing will be a manned

operation. Platform facilities are mentioned in Table 2.8.

Table 2.8: Details of Platform Facilities

Fields

Parameters

B-9

(7 Wells)

(2 Platforms)

B-7

(3 Wells)

(1 Platform)

BRC

(2 Wells)

(1 Platform)

Orifice Flow Meter One per well One per well One per well

Multiphase Flow Meter One per Platform One per

Platform One per Platform

Production Manifold

Test Manifold

Comingling Manifold

Available

Available

Available (B9-1)

Available

Available

Available

Available

High Integrity Pressure

protection System Available Available Available

Pig Launcher

Pig Receiver Available Available Available

Cold vent System Available Available Available

Closed and Open Drain

System Available Available Available

Diesel System Available Available Available

Chemical Injection System Available Available Available

Instrument and Utility Gas

System:

Fire & gas Detection

System

Remote Telemetry Unit

Available Available Available

Potable Water System

(Wash Water System for

Deck & Toilet)

Available Available Available

Material Handling Facilities Available Available Available

Safety and Evacuation

Items Available Available Available

Solar Power System Available Available Available

Navigational Aid System Available Available Available

Cathodic Protection System Available Available Available




2.3.6 Electrical Systems

The electrical system is designed to provide:

a. Safety to personnel and equipment

b. Reliability of service

c. Minimal fire risk

d. Operational flexibility

e. Optimization of available space

f. Ease of maintenance and convenience of operation

The environment and site conditions on the platform will be extremely saline, humid,

corrosive and hostile marine environment. All the electrical equipment, systems, apparatus

and material for installation on the platform to be suitable for operation service under this

extreme environment conditions.

In general, all outdoor electrical equipment, systems and apparatus to be designed for 40°C

temperature and relative humidity of 100% while the indoor equipment, systems and

apparatus to be designed for 45°C temperature and relative humidity of 100%.

The design life for all the platform electrical equipment to be minimum 10 years except for

the cathodic protections system whose design life to be same as jacket design life (minimum

of 15 years).

2.3.7 Telecommunication System

To facilitate the platform for Voice, Data & Security Surveillance, a telecommunication

system is proposed as given below:

a. VSAT SYSTEM- (Voice and Data communication)

b. CCTV SYSTEM- (Security Surveillance)

Communication System shall be designed in such a way that the required data from the

Well-head platform is transmitted to the cloud server at Directorate General of Hydrocarbon

(DGH) and AWEL Facility.

2.3.7.1 VSAT system

VSAT system to be the primary Communication for Voice & Data. VSAT Telecom

Facilitator/operator will be fully responsible for delivering the data collected from all

proposed platforms and C24-RP (existing platform) to AWEL Facility and DGH. VSAT

system shall also be considered for voice communication between/within B-9-1, B-9-3, B-7

and BRC well-head platforms for voice through Walkie-Talkie.

2.3.7.2 CCTV System CCTV security camera to be provided at all unmanned platforms for the security

surveillance. The images from the camera to be routed through VSAT to AWEL facility with

governance of VSAT telecom facilitator/operator.

2.3.8 Softwares

The SACS software developed and marketed by Bentley, to be the primary structural analysis

tool for the jacket and topsides design. Release 5.7 version to be used. The software

comprises several compatible structural analysis modules that can perform the following:

a. Interactive full screen modelling and editing

b. Generation of environmental loads

c. Non-linear soil, pile and structure interaction




d. Static analysis and code checking

e. Dynamic analysis

f. Deterministic fatigue analysis

g. Flotation and Upending analysis

2.3.9 Supply Base

The supply base is very important for the successful completion of drilling programme. The

Company’s supply base is available at Pipavav. The main advantage of this is its proximity to

operational area. Offshore Support Vessels (OSV’s) can reach the location in less than 10

Hrs.

2.3.10 Staffing

The remote Well-head Platforms are to be automated for unmanned operation, with personal

presence required for routine checks, replenishing consumables (diesel, utility water,

chemical etc.), maintenance, and restart following an emergency shut-down. Sufficient

operating data is to be communicated to onshore station to monitor the status of safety and

production of critical systems.

2.4 PROJECT SCHEDULE AND COST

The proposed project involves offshore O&G development and production from three (03)

discovered small fields (B-9, B-7 and BRC) located in Mumbai Offshore Basin. The

development schedule for all the three fields in the contract area is given in Figure 2.4

Figure 2.4: Tentative Project Schedule

The overall tentative development cost is about 1600 Crores Indian Rupees.

2.5 RESOURCE UTILIZATION

2.5.1 Water Requirement

It has been estimated that 45-55 kilo litres per day (KLD) of water for each well shall be

required during drilling and installation activities. The water requirements for domestic use

shall be met from the sea water, which shall be treated prior to its use. Potable water to be

supplied through tanks.

2.5.2 Power Requirement

Diesel to be supplied from boat to diesel storage tank at platform. It has been estimated that

8-12 KLD of high speed diesel shall be required for running captive gensets of drilling rigs,




deck crane operation, and offshore vessels. The solar power system is the only source of

electrical power to feed the entire platform loads without any alternate power sources.

Electrical loads and sizing of the solar power system to be determined based on the

requirement of the navigational aids system loads, lighting loads and all Instrumentation &

Telecommunication loads. Components of power supply system to be of highest available

quality for reliability and long service life. Power supplies for all transmitters, controllers,

signal converters, electric system and components in shutdown system to be supplied from

uninterruptible power supplies. Power distribution to each consumer to be through proper,

independent switch and fuse. Protective fuses to be of indicating cartridge type mounted in

fuse holders.

The power generated from the solar power system feeds various basic platform loads and

charges the battery in normal conditions, i.e. during the day time and the energy stored in

battery feeds the loads under during night or ‘NO-SUN’ conditions for minimum 7 days.

There are four (4) separate/individual solar power systems for feeding the below listed system

loads which are categorised based on the criticality of the loads with output voltage level of

24V DC ±10%.

SYSTEM-I : Solar Power System for Navigational Aids System.

SYSTEM-II : Solar Power System for Lighting & Instrumentation System.

SYSTEM-III : Solar Power System for Remote Telemetry Unit (RTU) System.

SYSTEM-IV : Solar Power System for Fire & Gas Detection System.

In general, the following power supplies to be used for instrumentation and control: 24V DC

+5% / -10%, with Floating Earth / Unearthed except for RTU which is Negative Earthed

System.

2.6 NOISE, AIR EMISSIONS, EFFLUENTS, AND SOLID WASTE GENERATION

2.6.1 Noise

Noise is likely to be generated mainly due to operation of generator sets and pumps during the

project activities. Noise may also be generated due to movement of transportation vessels

during the project activities.

2.6.2 Emissions

Air pollution will be from burning of fuel in the generator sets required for power generation

during the project activities. The proposed drilling operations will require a number of

generator sets, to cater to the power requirement. However, these will be placed near to

eachother & hence their emissions, for all practical purposes, can be considered to be from a

single group source, instead of various point sources. Air emissions may result from gas

flaring activities during the well testing (four days per well).

2.6.3 Effluents and Solid Waste

The following types of wastes are likely to be generated during the project activities:

a. Waste Water: The sewage waste water to be generated will be treated though on board

STPs available on rig and Derrick and/or Lay Barges (DLB) as per MARPOL and

marine practices for treatment and disposal of waste water.

b. Drill Cuttings (DC) : The drill cuttings will be generated during drilling phase of wells.

Cuttings free from Water Based Mud (WBM) will be discharged offshore into sea as per

G.S.R. 546 (E), dated 30/08/2005, according to which the cuttings will be discharged to




sea intermittently, at an average rate of 50 bbl/hr/well from a platform so as to have

proper dilution and dispersion without any adverse impact on marine environment

whereas cuttings generated from Synthetic Oil Based Mud (SOBM) will be brought back

to on-shore for treatment and disposal in an impervious waste disposal pit.

c. Produced Water : The management of produced water is very crucial. Safe water

management practices and disposal of produced water are vital in protecting the surface

and ground water resources. The produced water, if any, separated during hydrocarbon

processing will be treated and disposed as per CPCB/MoEF standards.

d. Water-Based Drilling Mud (WBM): WBM will be generated during drilling activities.

Only WBM will be used during drilling operations. In case of any problem related to

geological formation, Synthetic Oil Based Mud (SOBM) a low toxicity oil based mud

will be used and it will be intimated to MoEF/SPCB. SOBM are designed to mirror oil-

based mud performance, without the environmental hazards. The range of chemical

agents added to achieve specific properties is much reduced compared to water based

mud systems. It typically consists of base oil, primary and secondary emulsifier,

viscosifier, barite, lime, water and other components depended on the condition of

drilling. As per G.S.R. 546 (E), dated 30/08/2005, low toxicity oil based mud of

aromatic content < 1% will be used. The toxicity of the chemical additive used in WBM

or SOBM will be biodegradable and will have toxicity of 96 hr LC50 value > 30,000

mg/L as per mysid toxicity or toxicity test conducted on locally available sensitive sea

species. WBM/SOBM will be recycled to the maximum extent. Thoroughly washed drill

cuttings separated from WBM and unusable portion of WBM (toxicity of 96 hr LC50

Value > 30,000 mg/L) will be discharged offshore into sea intermittently, at an average

rate of 50 bbl/hr/well from a platform so as to have proper dilution and dispersion

without any adverse impact on marine environment whereas unusable portion and drill

cuttings generated from SOBM (toxicity of 96 hr LC50 Value > 30,000 mg/L) will be

brought back to on-shore for treatment and subsequent disposal in an impervious waste

disposal pit.

e. Hazardous Waste: Hazardous waste such as waste lube/system oil from machinery,

used oil from generator sets (in case of operation) are likely to be generated. The waste

shall be handled as per Hazardous Wastes (Management, Handling and Trans-boundary

Movement) Rules, 2008. The hazardous area classification to be carried out in

accordance with the API. Hazardous areas to be classified as Zone 0, Zone 1 and Zone 2

according to degree of hazard in accordance with API RP 505. This code allows the use

of equipment designed and certified to IEC and NEC Article 505 Standards. Generally,

the hazardous area classification drawing to be the basis of selection of electrical

equipment for various locations.

The waste will be carefully stored in drums and transported to MoEF approved recyclers

for its final disposal.

2.6.4 HSE Requirement

The Facilities shall be designed and constructed as per standard existing oilfield practices,

and are to be operated and maintained to meet the safety philosophies and criteria outlined

hereunder. Key elements in achieving the safety objectives are:

a. The facilities shall be designed, constructed, and are to be operated and maintained such

that they are fail-safe and of high safety integrity.




b. The selected process configuration and equipment shall have proven safety and

operability characteristics.

c. The Facilities engineering design processes shall include thorough quantitative and

qualitative safety case assessments and safety reviews, including the HAZOP process etc.

d. The Facilities shall be constructed, installed and are to be operated and maintained in

accordance with safe work practices and procedures. The target site safety objective shall

be zero lost time injury (LTI) frequency rate.

e. Site emergency response and evacuation procedures shall be developed and personnel

will be trained /instructed in these procedural requirements.

f. All statutory compliance such as Environmental Clearance (EC), approvals from OISD,

State Maritime board, Defence / MHA/ MoD Clearances etc. shall be strictly enforced.

g. Safety studies such as HAZID, HAZOP, SIL Safety case, material handling, etc. would to

be conducted and all action items closed. All documentation shall be properly maintained

and made available to Authorities for verification.

h. The wells shall be drilled as per API & OISD standards. Drilling equipment and services

shall be selected as per the above Guidelines.

All well related safety devices such as Blow-out Preventers (BOP), Safety valves, etc. shall be

tested as per API, OISD or other Statutory Guidelines and records kept.

33

DDEESSCCRRIIPPTTIIOONN OOFF

TTHHEE EENNVVIIRROONNMMEENNTT

EIA Report - Offshore Oil & Gas Development and Production from Discovered Small Field

of B-9 Cluster Offshore Fields at Mumbai Offshore Basin.


3. DESCRIPTION OF THE

ENVIRONMENT

3.1 INTRODUCTION

The oil and gas development is proposed from the discovered small field (DSF) of B-9 cluster

field awarded to Adani Welspun Exploration Limited (AWEL). To identify and assess the

potential environmental impacts due to the proposed project, the evaluation of the prevailing

environmental conditions of the area is undertaken and discussed in this chapter.

As stated above, the assessment of the characteristics of various environmental components

allow an understanding of the potential impacts on the marine environment, thereby adopting

relevant control measures to mitigate the adverse negative impacts.

Scope of Work

The scope of work for establishing environmental baseline includes:

• Collection of water samples for monitoring hydrographical, chemical and biological

characteristics including contaminants like hydrocarbons and heavy metals.

• Collection of sediment samples for quantifying various components including hydrocarbon

deposition, heavy metal concentrations and benthic biota.

3.2 STUDY AREA

The project site is an offshore area located in the Arabian Sea approximately 177 km from

Mumbai and 72 km from Diu Coast. The nearest land parcel to the block falls between Diu and

Bhavnagar section on the Saurashtra coast. The state of the environment has been characterized

on various marine components in the project site and its surrounding areas. The project site

comprises of 3 DSF, i.e., B-9, B-7 and BRC blocks in the Mumbai offshore basin, wherein B-

9 and B-7 are Gas fields and BRC is an Oil field. The study area pertains to 15 km radial distance

from each of the three (3) DSFs and proposed pipelines. The project location with demarcated

oil and gas (O&G) field blocks is depicted in the Figure 3.1 below.

3



Figure 3.1: Project Location




3.3 STUDY PERIOD AND LABORATORY INVOLVED

The environment status of the project area was studied during Pre-Monsoon season, starting

March 2018 to May 2018. The Ultra-Tech Laboratory, Thane, were involved for the baseline

sampling and analysis.

3.4 COMPONENTS OF BASELINE STUDY

The components studied to assess the baseline scenario of the project area are listed below.

Detail description on each component is given in following sections.

➢ Geology

➢ Climate and Meteorology

▪ Mean Sea Surface Temperature

▪ Mean Air Temperature

▪ Mean Wind Speed

▪ Waves and Tides

▪ Rainfall Pattern

▪ Cyclones

▪ Circulations

➢ Marine Environment

▪ Sea Water

▪ Sea Sediments

▪ Marine Biology

• Chlorophyll

• Phytoplankton

• Zooplankton

• Benthos

▪ Marine Fisheries

3.5 METHODOLOGY

To get a comprehensive impression about environmental baseline of the study area, collection

of both primary and secondary data on relevant environmental attributes is essential. Primary

data have been collected through field survey, and monitoring of the environmental components

like, sea water, sea sediment, chlorophyll content, phytoplankton, zooplankton and benthos.

Detail methodologies, adopted for sampling and analyzing the above-mentioned components

are described in following sections designated to each component.

Secondary sources viz. maps, reports, scientific literatures, authentic websites etc. were used to

gather information on geology, climate and meteorology and marine fisheries, as well as for

cross verification of the primary data. The secondary data are further verified with available

governmental records (Table 3.1).

The collated data were analyzed to identify the impacts associated with the project, thereby

adopting relevant mitigation interventions for minimizing its adverse effect. The activities that

are likely to be studied for each environmental component are described in the subsequent

sections.




Table 3.1: Data Validation Source

S.

No.

Secondary Data Data Validation Sources

1. Geological morphological

characteristics • Geological Survey of India.

• National Data Repository- DGH, Ministry of

Petroleum & Natural Gas, Government of India

2. Climate and Meteorology National Oceanic and Atmospheric Administration

(NOAA).

3. Biological Data Maharashtra State Department of Fisheries

3.6 APPLICABILITY OF COASTAL REGULATION ZONE (CRZ):

Since the project area is located beyond 12 nautical miles (NM) from the coast line, the Coastal

Regulation Zone (CRZ) Regulations 2011, therefore, is not applicable. The map depicting the

project site and its distance from nearest cities is given in Figure 3.2.



Figure 3.2: Nearest Cities to the Project Location




3.7 GEOLOGY OF MUMBAI OFFSHORE BASIN

Mumbai Offshore basin is located on the Western continental shelf of India between Saurashtra

basin in NNW and Kerala Konkan in the South.

Type of Basin

Mumbai offshore is a pericratonic rift basin situated on western continental margin of India.

Towards NNE it continues into the inland Cambay basin. It is bounded in the northwest by

Saurashtra peninsula, north by Diu Arch. Its southern limit is marked by east west trending

Vengurla Arch to the South of Ratnagiri and to the east by Indian craton.

Different Tectonic Zones within the Basin

Five distinct structural provinces with different tectonic and stratigraphic events can be

identified within the basin viz. Surat Depression (Tapti-Daman Block) in the North, Panna-

Bassein-Heera Block in the east central part, Ratnagiri in the Southern part, Mumbai High-/

Platform-Deep Continental Shelf (DCS) in the mid-western side and Shelf Margin adjoining

DCS and the Ratnagiri Shelf.1

Reservoir Rock

Mumbai offshore basin has been blessed with both clastic and carbonate reservoir facies in

almost total Tertiary Section ranging from Palaeocene to Middle Miocene (Table 3.2).

Table 3.2: Reservoir Rock in the Mumbai Offshore Basin

Reservoir

S. No. Age Lithology/ Location

1. Middle Miocene Carbonate sections at Ratnagiri, Mumbai high & Diu

(Ratnagiri & Bandra formations)

2. Lower Miocene Represented by a thick pile of carbonates hosting huge

quantity of oil and gas over Mumbai High (Bombay,

Ratnagiri).

3. Oligo–Early Miocene Sands in the central and mid-eastern part of Surat depression

i.e. Tapti- Daman area, Daman formation.

Carbonates adjoining Mumbai High( Panvel formation )

4. Eocene and Early

Oligocene

E.Oligocene clastics of Surat depression (Mahuva Formation)

Deposition of thicker carbonate facies over the horst blocks in

Panna- Basein-Heera and Ratnagiri blocks (Bassein, Mukta &

Heera formations).

5. Paleocene Coarser clastic facies developed within the upper marine shale

sequence in areas of Mumbai High, Panna and Ratnagiri

(Panna Formation).

(Source: https://www.ndrdgh.gov.in.)

3.8 CLIMATE AND METEOROLOGY

Mumbai Offshore Basin has a tropical wet and dry climate under the Koppen climate

classification2. The area/region does not experience distinct seasons, but the climate can broadly

be classified into two main seasons the humid season and the dry season. Usually, the period

between October to May is relatively dry. The area comes under the influence of the South-

1 https://www.ndrdgh.gov.in 2 City Profile of Greater Mumbai, 2011.

https://www.ndrdgh.gov.in/NDR/Images/MumbaiOffshore/MumbaiOffshore.jpg

https://www.ndrdgh.gov.in/NDR/Images/MumbaiOffshore/TectonicMumbai.jpg

https://www.ndrdgh.gov.in/




West monsoon starting from June to September, it is usually very heavy, and majority of the

annual rainfall occurs in this season. North East monsoons period occurs between December to

February and during this period, it experiences high wind speeds, but rainfall is negligible.

The project area is in the Arabian Sea off the Northwest coast of India. The Arabian Sea that

forms the part of the Indian Ocean North of the equator is separated from the deep reaching

vertical convection areas of the northern hemisphere, by the Asian continent. Such an

asymmetric configuration leads to a weak circulation and poor renewal at depths in the Arabian

Sea.

3.8.1 Mean Sea Surface Temperature

According to the National Oceanic and Atmospheric Administration (NOAA), the maximum

and minimum value of mean sea surface temperature in the Arabian Sea is of the order of 30.8ºC

and 26.04 ºC, respectively(Figure 3.3).

Figure 3.3: Sea Surface Temperature




3.8.2 Mean Air Temperature


NOAA, Boulder, Colorado,maximum and minimum value of mean air temperature in the

Arabian Sea is of the order of 30.2ºC and 24.04 ºC, respectively.

3.8.3 Mean Wind Speed

The offshore winds are influenced by the four seasons i.e., Northeast monsoon (December to

February), Pre-monsoon (March to May), Southwest monsoon (June to September) and post-

monsoon season (October to November). During Northeast monsoon, offshore winds are

influenced by winds blowing from N-NE direction and similarly, during Southwest monsoon,

offshore winds are influenced by winds blows from W-SW direction (windiest part of the year).

Whereas, the period March to May is that of first transition season, where N-NE winds

decreases, and SW-W winds increases.

The study of average hourly wind speed in project area shows significant seasonal variation

over the course of the year. The windier part of the year lasts for 2.9 months, from June 1st to

August 30th, with average wind speeds of more than 10.6 miles per hour. Figure 3.4, shows the

variation in wind speed along with wind direction around the proposed project location.

Figure 3.4: Wind Speed and Wind Direction




The dispersion of pollutants is influenced by the wind speed and wind direction for an area. It

is considered as the important data for predicting the air quality impacts.

Figure 3.5 (a) (b) & (c) gives the wind class frequency distribution and wind rose of March,

April and May 2018. The prominent wind direction is from W-NW, W-NW and W during the

month of March, April and May. The highest wind speed was observed from W and SW during

May with wind speed of 5.5-8.8 m/s (10%). As earlier mentioned, this indicates that March to

May is a transition season, where W-NW wind decreases, and SW wind increases.

(a)

(b)

(c)

Figure 3.5 (a), (b) & (c): Wind Frequency Class Distribution and Wind Rose for the

Months March, April and May of 2018. (Source: ACE Study).




3.8.4 Waves and Tides


NOAA, Boulder, Colorado, Predominant significant wave height and zero-crossing period are

50 to 70 cm and 8 to 8.5 sec respectively. The predominant wave periods and wave heights are

5-6 sec and 0.5 to 1.5 m respectively during the fair-weather season (October-May) and 5-9 sec

and 1-3 m respectively during the rough weather season (June-September). A wide range of

wave heights 0.5-5 m occurs during the rough season.

The tides in the offshore area are of mixed semi-diurnal type with a large diurnal inequality.

The gulf water behaves as homogeneous one-layered structure due to high tidal range, low run-

off from land, shallow depth, and irregular bottom topography – all suitable for turbulent flow

field. Unpredictable rip currents may show up due to the difference in shelf / depth together

with weather pattern. The greatest tidal ranges are found in the Arabian Sea, notably at

Bhavanagar, in the Gulf of Khambhat (38 feet or 11.6 metres), and in the Gulf of

Kachchh (Kutch) at Navlakhi (25.5 feet or 7.8 metres).

3.8.5 Rainfall

The area is within the monsoon belt, experiencing South westerly, rain bearing winds from June

to September followed by dry wind spell from October to May. The land segment nearest to

the block falls between Diu and Bhavnagar section on the Saurashtra coast. The climate is semi-

arid with an average rainfall of 500 to 600 mm.

3.8.6 Cyclones

The west coast is less prone to depressions and cyclones as compared to the east coast of India.

The frequency of cyclonic disturbances varies significantly with the season. Generally, cyclonic

conditions prevail during May-June and become more frequent in July-November while, the

weather is relatively tranquil during February-March (Figure 3.6).

https://www.britannica.com/place/Gulf-of-Khambhat

https://www.britannica.com/place/Gulf-of-Kachchh

https://www.britannica.com/place/Gulf-of-Kachchh




Figure 3.6: Cyclone Prone Area

3.8.7 Circulation

Circulation in the gulf is mainly controlled by tidal flows and bathymetry. Strong currents

normally occur during mid-tide, i.e. 2-3 hrs. before and after low and high tides. The spring

currents are 60-65% stronger than the neap currents. The surface currents are moderate (0.7 to

1.2 m/s) but increases considerably (2.0-2.5 m/s) in the central portion of the gulf. The bottom

currents are periodically strong with bimodal directions generally parallel to the uneven bottom

contour. The associated tidal currents are fairly strong and bimodal in nature having two

dominant directions – upstream during flood and downstream during ebb in all-encompassing

oscillatory motions. The circulation pattern in the near shore areas however is modified

considerably due to the presence of creeks and inlets.




3.9 MARINE ENVIRONMENT

As described in above section 3.2, the project location falls within the Arabian Sea. The Arabian

sea is considered as highly productive ecosystem, the monsoon regime causes significant

seasonal variations in marine productivity. During the Northeast monsoon strong upwelling

occurs along the Western coast of India. This is the most intense seasonal upwelling system,

making Arabian Sea one of the most productive regions of the world’s ocean.

In view of valuable resource, the most valuable mineral resource is petroleum. Exploration for

offshore petroleum and natural gas also has been under way in the Arabian Sea and is believed

to have large reserves. Other than the countries of the Persian Gulf, only India produces

commercial quantities of oil from offshore areas, with a large proportion of its total production

coming from fields off the coast of Mumbai.

Sea Water Quality

Sea water resources are one of the major components of environmental resources where the

water quality plays the role of most important driving force in the marine ecosystem. The sea

water has a dense high-salinity layer (37 ppt) to a depth of about 400 feet (120 metres) because

of high evaporation rates at subtropical temperatures with moderate seasonal variations.

The quality of water affects both by the natural processes and anthropogenic causes. Marine

water quality nowadays becomes a serious concern for the marine life as well as human health.

According to Maharashtra Pollution Control Board (MPCB)3 water quality of Arabian sea near

Mumbai city coast is continually degrading due to untreated or poorly treated sewage discharge.

According to a research4 held at Veraval, Kodinar and Diu, for analysing the marine water

quality of Mumbai Offshore areas shows high pH values, conductivity, TDS, Turbidity, macro

nutrients content. The baseline monitoring for sea water done for the proposed project is

explained in section 3.9.1.

Sea Sediments

Marine sediments play a very important role as repositories of organic matter and nutrients for

the ecosystem but at the same time, they are vulnerable to heavy metal and organic toxics (from

anthropogenic activities) especially in the offshore oil and gas activities.

Marine Biological Characteristics

Marine environment is known to support vast population of organisms, found distributed in

both pelagic and benthic realms. Due to the upwellings that occur in several coastal regions of

the Arabian Sea cause nutrients to concentrate in surface waters, produces immense quantities

of phytoplankton that are the basis for large populations of commercially valuable marine

animals.

Their response to physio-chemical characteristics of the water column determines their

distribution, abundance, and production.5 Another important component of marine environment

is marine fishes, without which marine ecosystem cannot be completed. Despite great fishery

potentials in Arabian Sea, most commercial fishing is done by small-scale fishermen at lower

depths, while deep-sea resources (with the exception of tuna) remain poorly fished.6

3 http://mpcb.gov.in 4 Status of sea water quality at few industrially important coasts of Gujrat off Arabian sea. 5 Jeffrey, S.W. and Hallegreff, G.M., 1990. Phytoplankton ecology in Australian waters. In: Clayton, M.N. and

King, R.J. (Eds.]. Biology of Marine Plants, Longman — Cheshire, Melbourne. pp: 310-348. 6 https://doi.org/Offshore limit of coastal ocean variability.

https://www.britannica.com/science/mineral-chemical-compound

https://www.britannica.com/science/petroleum

https://www.britannica.com/science/natural-gas

https://www.britannica.com/place/Mumbai

https://www.britannica.com/technology/commercial-fishing

https://doi.org/10.1016/S0278-4343(02)00100-0




The marine biological features are described below:

▪ Primary productivity (Chlorophyll) and Phyto-planktons: The primary productivity

which involves conversion of inorganic material into living biomass, is the foundation

block of all the processes in the biosphere. Arabian Sea consists of high chlorophyll

concentration as compare to Bay of Bengal7. The chlorophyll concentrations at 25 km

distance from the coast are found to be higher than that 50 km and 100 km distances. In

general, the chlorophyll concentrations decrease from coast to deep sea.

Phytoplankton are the autotrophic organisms and contribute directly to the food available

in the surface water by building up their protoplasm and food reserves directly from carbon

dioxide. Phytoplankton are very important in food chains in estuarine environment, since

72% of the Earth is covered by ocean and also are the primary producers that feeds

everything from microscopic animal-like zooplankton to multi-ton whales.

▪ Zooplankton: Zooplankton are heterotrophic plankton which thrive on surface waters on

phytoplanktonic and other zooplanktonic food reserves. They are very important to the

oceanic food cycle. Their distribution is mostly affected by the nutrient availability (lead

by water column mixing) and abundance of phytoplankton.

▪ Benthos: Benthos are organisms dwelling in or above the sediment of water bodies. They

play a crucial role in nutrient and carbon cycling either directly or indirectly as deposit

feeders, suspension feeders, decomposers, predators, or scavengers and also to the potential

and sustainability of demersal or near bottom living resources. However, they are

significantly influenced by the trophic changes particularly arising from the anthropogenic

factors. Benthos are characterized according to their sizes, namely, micro (<63µm), meio

(63 - 500µm) and macro-benthos (>500 µm).

▪ Benthic Meiofauna and Macrofauna: Meiofauna are an important component of benthic

habitats due to their small size, abundance and rapid turnover rates and play important roles

in benthic food webs. Meiofauna feed on benthic microalgae, other microbes, and detrital

food sources and is, in turn, important food resource for grass shrimp and a variety of

juvenile fish that utilize shallow water nursery habitats. Through their feeding and

burrowing activities, meiofauna help to keep microbial communities active, which serve to

enhance productivity and the recycling of nutrient. Meiofauna have been used as

environmental indicators of human activities and pollution. Pollutant effects on meiofauna

have been shown to depend on pollutant type, the biology of the organisms themselves,

exposure levels and environmental setting. The secondary production of meiofauna may

equal or exceed that of macrofauna.

Benthic macrofaunal communities have8 been related to substrate type and sometimes

designated by the type of bottom sediment they inhabit9. In shelf waters it is now recognized

that, within a particular habitat type, biological interactions result in spatial and temporal

heterogeneity, even on soft bottoms where 'bioturbation' plays an important role in the

structuring and functioning of communities.10The major benthos organisms of the area

7 Comparison of chlorophyll concentration in the Bay of Bengal and the Arabian Sea using IRS-P4 OCM and

MODIS Aqua. 8Petersen, C. G. J.1913. “Valuation of the Sea. II. The Animal Communities of the sea bottom and their Importance

for Marine Zoogeography”. Danish Biol. Sta., Repts21(1–44). 9Jones, N.S.1950. Marine Bottom Commuities. Biological Reviews. 25(283-313). 10Rhoads, D. C. 1974. Organism-Sediment Relations on the Muddy Sea Floor. Oceanogr. Mar. Biol. Ann. Rev.

12(263–300).

http://web.vims.edu/bio/shallowwater/benthic_community/benthic_microalgae.html

http://web.vims.edu/bio/shallowwater/ecosystem_processes/detritus_formation.html

http://web.vims.edu/bio/shallowwater/ecosystem_processes/detritus_formation.html

http://web.vims.edu/bio/shallowwater/benthic_community/microbes.html

http://web.vims.edu/bio/shallowwater/human_effects/management_approaches.html

http://web.vims.edu/bio/shallowwater/ecosystem_processes/secondary_production.html




comprises of Mollusca, Arthropoda, Annelida (polychaetas), seaweeds, sponges, soft

corals, tunicates etc. Some of the example are given below 11.

Table 3.3: List of Macrophytes in Study Area

S.No Division Class Order Family Species

1. Charophyta Charophyceae Charales Characeae Chara baltica

2. Chlorophyta Ulvophyceae Cladophorales Cladophoraceae Cladophora rupestris

(L.)

3. Valoniaceae Valonia aegagropila,

4. Gomonticeae Monostroma nitidium

5. Ulvaceae Ulva fasciata

6. Enteromorpha intestinalis

7. Enteromorpha linza

8. Ochrophyta Phaeophyceae Ectocarapales Scytosiphonaceae Colpomenia sinuosa

Sphacelariales Sphacelariaceae Sphacelaria tribuloides

9. Rhodophyta: Florideophyceae Corallinales Corallinaceae Amphiroa tribuloides,

10. Ceramiales Rhodomelaceae Acanthophora specifera

11. Nemaliales Galaxauraceae Galaxaura oblongata

12. Gracilariales Gracilariaceae Grateloupia filicina

13. Gelidiales Gelidiaceae Gelidium pusillum

14. Gelidiaceae Gelidiella acerosa

15. Halymeniales Halymeniaceae Gracilaria verrucose

(Source. Prabhakar R. Pawar et.al, 201711)

Table 3.4: List of Macrofauna in Study Area

S.

No Division Class Order Family Species

1. Sponges Calcarea Leucosolenida Leucosoleniidae Leucosolenia complicate

2. Leucosolenia variabilis

3. Demospongiae Axinellida Axinellidae Axinella damicornis

4. Axinella verrucose

5. Halichondrida Halichondriidae Halichondria bowerbanki,

6. Hymeniacidon heliophile

7. Haplosclerida Haliclonidae Haliclona permollis,

8. Hadromerida Hemiasterellidae Paratimea constellate,

9. Suberitidae Protosuberitis epiphytum,

10. Poecilosclerida Hymedesmiidae Kirkaptrickia borealis

11. Microcionidae Clathria parthena

12. Homosclerophorida Plakinidae Plakina monolopha.

13. Coelenterates

(Soft corals)

Anthozoa Alcyonacea Nephtheidae Dendronephthya klunzingeri,

14. Dendronephthya hemprichi.

15. Flatworms: Rhabditophora Polycladida Leptoplanidae Leptoplana tremellaris,

16. Notoplanidae Notoplana australis

11 Prabhakar R. Pawar and Abdel Rahman Mohammad Said Al-Tawaha, 2017, “Checklist of benthic marine

macrophytes and macrofauna from Uran coast, Navi Mumbai, off the Arabian Sea”. Article Published in

Advances in Environmental Biology, 11(6) June 2017, Pages: 68-78




S.

No Division Class Order Family Species

17. Polychaetes:

Polychaeta Amphinomida Amphinomidae Hermodice carunculate.

18. Phyllodocida Nereididae Perinereis cultrifera,

19. Polynoidae Enipo gracilis

20. Crabs

Malacostraca Decapoda Grapsidae Goniopsis cruentata,

21. Leucosiidae Persephona mediterranea

22. Tokoyo eburnean

23. Matutida Matuta lunaris

24. Ocypodidae Uca annulipes

25. Portunidae Charybdis feriatus

26. Scylla serrata,

27. Leptodius exaratus

28. Sesamidae Aratus pisonii

29. Gastropods Gastropoda Archaeogastropoda Fissurellidae Diodora gibberula

30. Nacellidae Cellana radiata

31. Trochidae Trochus stellatus

32. Clanculus guineensis

33. Nertidae Nerita undata

34. Neritina pulligera

35. Buridae Bursa tuberculate

36. Bursa spinosa

37. Naticidae Natica didyma

38. Columbellidae Parvanachis obesa

39. Lottidae Lottia septiformis

40. Pelecypods Pelecypoda Arcoida Arcidae Arca granosa

41. Barbatia sp

42. Crassostrea virginica

43. Saccostrea sp.

44. Volachlamys tranquebaria

45. Hiatula diphos

46. Chamelea gallina,

47. Meretrix sp.

48. Cephalopods Cephalopoda Myopsida Loliginidae Loligo vulgaris

49. Octopoda Octopodidae Eledone cirrhosa

50. Octopus vulgaris

51. Sepiida Sepiidae Sepia officinalis

(Source. Prabhakar R. Pawar et.al, 201711)




▪ Marine Fisheries: As per CMFRI 2017-18 Annual Survey, in Maharashtra, Pelagic

resource contributed major share with 39%, followed by demersal fishes (29%),

crustaceans (21%) and molluscs (10%). The prominent species/groups were penaeid

shrimps (10.8%) non-penaeid shrimps (9.9%), Indian mackerel (9.8%), croakers

(9.6%), squids (7.3%), threadfin breams (7.2%) and Bombay duck (7.1%). Photo plate

3.1. shows fish species found in Arabian Sea. The dominant fish species found in the

study area are listed below in Table 3.5:

Starry triggerfish Arabian yellowfin seabream

Long snouted lancet fish Salalah guitarfish

Photo Plate 3.1 Fish Species in the Study Area.

Table 3.5 List of Fish Species in the Study Area.

S.

No. Species Common Name Family Habitat

1 Abalistes stellaris Starry triggerfish Balistidae Demersal

2 Acanthocybium solandri Wahoo Scombridae Pelagic-oceanic

3 Acanthopagrus arabicus

Arabian

yellowfin

seabream

Sparidae Pelagic-neritic

4 Acanthoplesiops indicus Scottie Plesiopidae Demersal

5 Acroteriobatus salalah Salalah guitarfish Rhinobatidae Demersal

6 Aldrovandia affinis Gilbert’s

halosaurid fish Halosauridae Benthopelagic

7 Alepisaurus ferox Long snouted

lancetfish Alepisauridae Bathypelagic

8 Alopias vulpinus Bigeye thresher Alopiidae Pelagic-oceanic

9 Amblyeleotris downingi Downing’s

shrimpgoby Gobiidae Demersal

10 Amblyraja reversa Reversed skate Rajidae Bathydermersal

11 Anodontostoma chacunda Chacunda

gizzard shad Clupeidae Pelagic-neritic

12 Branchiostegus Freckled tilefish Malacanthidae Demersal




S.

No. Species Common Name Family Habitat

13 Carcharhinus plumbeus Sandbar shark Carcharhinidae Benthopelagic

14 Pateobatis bleekeri Bleeker’s

whipray Dasyatidae Benthopelagic

15 Thryssa vitrirostris Orangemouth

anchovy Engraulidae Pelagic-neritic

(Source - https://www.fishbase.de/TrophicEco/FishEcoList)

3.9.1 Marine Environment Monitoring

Water and sediment quality sampling were carried out in B-9, B-7 and BRC blocks of the cluster

offshore fields in the Mumbai Offshore Basin. The samples collected were sent to laboratory

for the analysis.

Marine Sampling Methodology

A survey vessel scrutinized by Offshore Defense Advisory Group (ODAG) was hired for

offshore sampling. The vessel was well-equipped with Global Positioning System (GPS) and

Radar for accurate positioning, radio communication and satellite telephone for

communication. The survey vessel was cruised to the sampling locations according to the given

geographical coordinates, i.e., latitude and longitude of the sampling locations. The documents

for Vessel, ODAG clearance, Inspection pictures and details of GPS Data Log are annexed as

Annexure- III to VII.

3.9.1.1 Sea Water Monitoring

Sampling Location

The following elements were considered for selection of marine water sampling location:

• The sampling locations were selected so as to uniformly cover the entire project area.

• Sampling location were selected on the basis of hydrodynamics, effluent discharge

point, sewage outfall, dredging site etc.

The marine water sampling locations are given in Figure 3.7 and Figure 3.8 below. It

highlights the five (5) water sampling locations along with the route followed by the survey

vessel in the Mumbai Offshore Basin during the sampling and sampling location map at the

project site within the study area, respectively. Table 3.6 depicts the coordinates of sampling

locations, along with the sampling depths. All the five samples (surface and bottom) from the

3 designated O&G fields in the project location were collected during the study period i.e. in

May 2018.

Table 3.6: Specifications of Sea Water (SW) Sampling Location

S.

No.

Sampling

Location

Location

Code

Latitude

(N)

Longitude

(E)

Sea Water Sampling Depth

Bottom (m) Surface (m)

1. B9-1 SW1 20° 08’.23.0” 71°21’.42.7” 33 3

2. B9-2 SW2 20° 05’.37.8” 71°26’.23.6” 33 3

3. B9-3 SW3 20° 01’.48.1” 71°27’.34.4” 34 3

4. B7 SW4 19° 58’.34.4” 71°11’.37.1” 42 3

5. BRC SW5 19° 53’.36.4” 71°10’.54.2” 39 3

https://www.fishbase.de/TrophicEco/FishEcoList



Figure 3.7: Sea Water Sampling Locations with Vessel Route

(ONGC Platform)



Figure 3.8: Sea Water Sampling Locations within Study Area




Sea Water Sampling Method

The sea water (SW) samples were collected from two (2) levels in the sea (Table 3.3, above),

i.e., at the surface and bottom levels using a Niskin Sampler of 5 liters capacity. The depth

levels are as follows:

a. Sample 1 – 3 m below the surface

b. Sample 2 – 33-42 m (approx.) below the sea surface and few meters above the sea bed.

The quantity of sea water collected for different parameters along with the techniques for the

preservation of the samples are depicted in Table 3.7.

Table 3.7: Preservation of Water Samples

Photo Plate 3.2 shows the water sample collection activities at various sampling locations

during field data collection.

S.

No. Sample Particulars Sample Quantity Preservation

1.

Dissolved Oxygen 300 ml in glass stoppered

bottle/ BOD Bottle.

2 ml Wrinkler’s A (Manganous

Sulfate) followed by 2 ml

Wrinkler’s B (Alkaline Iodide

Sodium Azide Solution).

Oil and Grease 1 Liter in wide mouth glass

bottle.

Adjust pH to <2 with conc.

Sulfuric Acid or Hydrochloric

Acid.

Metals 1 Liter in PP container. Adjust pH to <2 with conc. Nitric

Acid.

Other Physio-

chemical Parameters

2 Liter in PP/PE container. Refrigerate at 4°C.

2.

Primary productivity 300 ml in glass stoppered

bottle/ BOD Bottle.

• Fixed immediately after

sampling as described for

Dissolved Oxygen preservation.

• Keep in dark or wrapped in

Aluminum wrapper and then

refrigerate.

Chlorophyll 1 Liter sample in wide mount

PP Bottle. ----------------------------

Phytoplankton 1 Liter water sample filtered

through plankton net.

Preserved with Lugol’s Iodine

immediately and stored in dark.

Zooplanktons 1 Liter water sample filtered

through plankton net.

Preserved with Formalin

immediately.




Marine Water Sampling using NISKIN

Sampler

On-Site Preservation of Samples

Sample Storage for Lab Analysis Marine Water Sampling using

NISKIN Sampler

Photo Plate 3.2: Marine Water Sampling (Source: ACE Survey).

Analysis Method:

The water samples were analyzed by the following methods suggested by Grasshoff (1983) and

APHA (1985). All the colorimetric estimations were done using double beam

spectrophotometer (Genesys 10 UV Thermo Spectronic). pH was measured using a pH meter

MK-Vl. The results of the marine water quality analysis are tabulated in Table 3.8.



Table 3.8: Marine Water Quality Analysis*

S.

No. Parameters Unit DL

SW1 at B9-1 SW2 at B9-2 SW3 at B9-3 SW4 at B7 SW5 at BRC

Surface Bottom Surface Bottom Surface Bottom Surface Bottom Surface Bottom

1. pH -- -- 8.1 8.0 8.1 8.1 8.2 8.2 8.2 8.2 8.2 8.2

2. Electrical Conductivity mS/cm -- 47760 46540 45240 44930 45370 45540 44930 44380 45190 44980

3. Dissolved Oxygen mg/L -- 5.2 5 4.8 4.6 4.9 4.5 4.6 4.4 4.8 4.6

4. Salinity Ppt -- 35.3 35.1 32.8 36.1 35.3 34.6 35.6 36.1 35.9 36.9

5. Total Dissolved Solids mg/L -- 31856 31744 30244 32158 31622 30122 33258 34692 33568 35482

6. Total Suspended Solids mg/L -- 77 86 45 93 77 70 91 91 63 86

7. Total Hardness as CaCO₃ mg/L -- 8000 10000 8000 10000 10000 8000 8400 9000 8600 8000

8. BOD (@ 27°C, 3 Days) mg/L 2 BDL BDL BDL BDL BDL BDL BDL BDL BDL BDL

9. Total Alkalinity as

CaCO₃ mg/L -- 126 130 130 126 130 132 130 130 130 128

10. Nitrates as NO³- mg/L 0.44 0.80 0.73 0.64 BDL 0.68 BDL BDL BDL BDL BDL

11. Sulphate as SO₄2- mg/L -- 3520 3570 3298 3454 2444 2474 2514 3536 3312 2590

12. Oil & Grease mg/L 10 BDL BDL BDL BDL BDL BDL BDL BDL BDL BDL

13. Chlorides as Cl mg/L -- 19563 19420 18135 19991 19563 19134 19706 19991 19848 20419

14. Residual Free Chlorine mg/L 0.1 BDL BDL BDL BDL BDL BDL BDL BDL BDL BDL

15. Iron as Fe mg/L 0.06 BDL BDL BDL BDL BDL BDL 0.41 BDL 3.1 0.9

16. Manganese as Mn mg/L 0.03 BDL BDL BDL BDL 0.05 BDL BDL 0.09 BDL 0.07

17. Cadmium as Cd mg/L 0.015 BDL BDL BDL BDL BDL BDL BDL 0.015 BDL BDL

18. Chromium as Cr⁶+ mg/L 0.01 BDL BDL BDL 0.01 BDL BDL BDL BDL BDL BDL

19. Lead as Pb mg/L 0.01 BDL BDL BDL BDL BDL BDL 0.02 0.01 BDL BDL

20. Nickel as Ni mg/L 0.02 BDL BDL BDL BDL BDL BDL 0.02 BDL BDL BDL

21. Zinc as Zn mg/L 0.02 BDL BDL BDL BDL 0.3 0.05 BDL 0.03 0.02 0.02

22. Mercury as Hg mg/L 0.0015 BDL BDL 0.0015 BDL 0.0027 BDL 0.0023 0.0016 BDL 0.0015

23. Arsenic as As mg/L 0.03 BDL BDL BDL BDL BDL BDL BDL BDL BDL BDL

(Source: Primary data generated for this project-Ultra Tech Laboratories).

*Note:

1. DL – Detection Limit

2. BDL – Below Detection Limit




Results of Sea Water Monitoring

The observed pH value in the study region during the period of study is in the range of 8.0 to

8.2. The changes in pH are marginal as expected for natural marine waters sustaining low

primary productivity. The total hardness (as CaCO₃) in all the water sample lies in the range of

8000 to 10000 mg/L. The value of alkalinity (as CaCO₃) was in the range of 126 to 132 mg/l.

The dissolved oxygen ranges from 4.4 mg/l to 5.2 mg/l.

The concentrations of Chloride in all the sample were in the range of 18135 to 20419 mg/L.

The contents of oil & grease in all sample was below detectable limit (BDL) in all the sampling

locations. The BOD levels in all water samples was found to be below detection limit (BDL)

wherein the detection limit for BOD is 2 mg/L.

It has been observed from the laboratory analysis that residual free chlorine, Cr⁶+, and As were

below detection limits in all the water samples. Whereas, there has been observed a slight

detection in few samples in regard to the concentration of lead, nickel, zinc and mercury.

3.9.1.2 Sea Sediments Monitoring

Sampling Location

The following elements were considered for selection of marine water sampling location:

• The sampling locations were selected so as to uniformly cover the entire project area.

• Sampling location were selected on the basis of hydrodynamics, effluent discharge

point, sewage outfall, dredging site etc.

Five (5) sea sediment (SS) samples were collected from the project site, Mumbai Offshore

Basin as depicted in the Figure 3.9 and Figure 3.10 below. The SS sampling location

coordinates along with the sampling depth are tabulated in Table 3.9.

Table 3.9: Specifications of Sea Sediment (SS) Sampling Location

S.

No

Sampling

Location

Location

Code

Latitude

(N) Longitude (E)

Sea Sediment

Sampling Depth

(m)

1. B9-1 SS1 20° 08’.23.0” 71°21’.42.7” 40

2. B9-2 SS2 20° 05’.37.8” 71°26’.23.6” 40

3. B9-3 SS3 20° 01’.48.1” 71°27’.34.4” 40

4. B7 SS4 19° 58’.34.4” 71°11’.37.1” 58

5. BRC SS5 19° 53’.36.4” 71°10’.54.2” 54

Sea Sediments Sampling Methodology

Sea sediment samples were collected using a Van-Veen Grab Sampler. It is an instrument to

sample sediment in water environments. The grab was lowered vertically from the stationary

boat until it touched the bottom. Sediment samples were collected and preserved for sediment

texture analysis and physico-chemical analysis. The quantity of SS collected along with the

techniques for the preservation of the samples are depicted in Table 3.10.

Table 3.10: Preservation of Sediment Samples

S. No Sample Particulars Sample Quantity Preservation

1. Marine Sediment 1 kg in leakage protective bag. Refrigerate at 4°C

2. Marine Benthos

Sediment collected from sea bed

sieved through 500-micron test sieve

stored in 125 ml wide mouth PP bottle

Preserved with

Formalin

immediately



Figure 3.9: Sea Sediment (SS) Sampling Location & Vessel Route

(ONGC Platform)



Figure 3.10: Sea Sediment (SS) Sampling Location & Vessel within Study Area




Photo Plate 3.2 shows the collection of sediment from the various sampling locations.

Photo Plate 3.3: Sediment Sample Collection from Mumbai Offshore Basin.

(Source: ACE Survey).

Analysis Method:

The results of the marine sediment quality analysis are tabulated in Table 3.11 below.

Table 3.11: Offshore Marine Sediment Quality Analysis

S.

No. Parameters Unit DL

SS1 at

B9-1

SS2 at

B9-2

SS3 at

B9-3

SS4 at

B7

SS5 at

BRC

1. pH (1:2.5: Sediment:

Water Extract) -- --

8.4

8.4 8.2 8.5 8.5

2. Oil and Grease % -- 0.7

0.5 0.4 0.4 0.1

3. Nitrate as Nitrogen mg/kg 2 3 BDL BDL BDL 3

4. Total Kjeldahl Nitrogen mg/kg -- 520 431 440 403 528

5. Hexavalent Chromium as

Cr(VI) mg/kg 0.01

BDL BDL BDL BDL BDL

6. Polyaromatic Hydrocarbon mg/kg -- 0.82 1.12 0.85 0.23 0.61

7. Arsenic as As mg/kg 2 4.2 2.9 BDL BDL 2.3

8. Cadmium as Cd mg/kg 2 BDL BDL BDL BDL BDL

9. Iron as Fe mg/kg 0.44 49318 56797 39243 46442 48497

10. Lead as Pb mg/kg -- 7 6 6 6 5

11. Mercury as As mg/kg 2 BDL BDL 3 BDL BDL

12. Zinc as Zn mg/kg -- 69 65 68 65 60

(Source: Primary data generated for this project- Ultra Tech laboratories).

Note: DL- Delection Limit

BDL-Below Detection Limit

Results of Sea Sediment Monitoring

Oil and grease ranges from 0.1 to 0.7, Nitrite as Nitrogen found as 3 mg/kg at location SS1 &

SS5 while in the rest of the locations, the values are below detection limits. The Total Kjeldahl

Nitrogen ranges from 403 mg/kg to 528 mg/kg.

The hexavalent chromium is found below the detection limit at all the locations.

Among the heavy metals, iron varied from 39,243 mg/kg to 56,797 mg/kg and lead from 5

mg/kg to 7 mg/kg, zinc showed variation of 60 mg/kg to 69 mg/kg, cadmium was found below

detection limit and arsenic varied from 2.3 mg/kg to 4.2 mg/kg.




Among the exchangeable nutrient fractions of nitrogen, nitrate was found 3 mg/kg at location

SS1 & SS5, at rest of the location it is below detection limit i.e. 2. The polyaromatic compounds

are found ranges from 0.23 mg/kg to 1.12 mg/kg, the amount of PAH is observed low.

3.9.1.3 Biological Analysis

To monitor biological characteristics of the marine environment, diversity of phytoplankton,

zooplankton and benthic organisms were assessed.

Sampling Location

Ecological sampling was carried out to conduct the analysis. Photo Plate 3.4 shows few

glimpses of the ecological sampling done in the B-9 Cluster block, monitoring locations. Sea

water samples have been collected for analyzing primary productivity, phytoplankton and

zooplankton diversity from the locations as mentioned in Table 3.7 above. For analyzing

diversity of the benthos, sediments have been collected from five locations as mentioned in

Table 3.9, above.

Preservation methodologies for the sea water samples and sediment samples are given in Table

3.7 and Table 3.10, respectively.

Photo Plate 3.4: Ecological Sample Collection from Mumbai Offshore Basin

(Source: ACE Survey).

a) Chlorophyll Analysis

Chlorophyll concentration is the result of the conversion of inorganic nutrients into living

biomass and acts as an indicator of the health and productivity of the estuarine ecosystem.

However, high levels of chlorophyll for a long duration indicate poor water quality while low

levels often suggest good quality.

Methodology

Chlorophyll was estimated following the methods published by UNESCO (1966). A known

volume of water sample was filtered through Millipore GF/C filter paper with MgCO3

suspension. Subsequently the filters were extracted with 90% acetone, centrifuged for 10

minutes at 5000 rpm. The extinction of the supernatant solution was measured using

spectrophotometer against a reference cell containing 90% acetone at 665, 645 and 630 nm and

the concentration was calculated using standard equations.

Results

The chlorophyll content around the project location is shown in Figure 3.11.




Figure 3.11: Chlorophyll content in Mumbai Offshore Basin

b) Phytoplankton, Zooplankton and Benthos Analysis

Analysis Methodology

Phytoplankton: Thirty (30) liters of surface water was filtered through phytoplankton net of

20µm mesh size made of bolting silk. The filtrate was preserved in 3% neutralized

formaldehyde/Lugol’s iodine solution. Quantitative analysis was done employing Sedgewick-

Rafter counting cell. Species identification was done using a Leica DM 2000 LED light

microscope.




Enumeration by Sedgewick-Rafter Counting Cell: The planktonic microalgae filtered from

30 liters of surface water were made up to a 10 ml volume concentrate. One (1) ml of this

sample was transferred to the Sedgewick-Rafter Counting Cell (volume of this chamber is 1ml).

The number of microalgae present in all the thousand grids in the Sedgewick-Rafter Counting

Cell was calculated. Counting was repeated for three times and an average was taken. The total

number of planktonic algal species present in one (1) liter of water sample was calculated using

the formula:

N = n x v

V

Where, N = No. of planktonic algae per liter of water filtered

n = Average no. of planktonic algae in one (1) ml of sample

v = Volume of plankton concentrates in ml

V = Total volume of water filtered in liter

Identification of phytoplankton: Phytoplankton groups were identified based on standard

keys (Allen and Cupp, 1935;Venkataraman, 1939;Cupp, 1943;Subrahmanyan, 1946;Hustedt,

1955;Desikachary, 1959;Hendey, 1964;Simonsen, 1974;Gopinathan, 1984; Jin Dexiang et al.,

1985;Desikachary and Sreelatha, 1989;Hallegraeff et al., 1995; Tomas et al., 1997).

Zooplankton: Samples were collected from the surface waters along each location by

horizontal surface towing of plankton net (Bongo Net, mouth area 0.25m2, mesh size 200µm)

for 10 minutes. Samples were collected in 250 ml plastic bottles and preserved in 4% buffered

formaldehyde which was later used for qualitative and quantitative analysis following Goswami

and Padmavathi (1996)16.

Zooplankton biomass is expressed as ml/1000m3 by using the formula as given below:

Biomass = Displacement Volume/ Volume of Water Filtered

The zooplankton taxa were sorted from the whole sample or from an aliquot (50%) using a

Folsom Splitter (Sell and Evans, 1982) and counted under a stereomicroscope. The zooplankton

was primarily sorted to the major taxonomic groups according to the standard identification

manuals (Newell and Newell, 1973; Todd and Laverack, 1991). The keys employed include the

works of Todd et al., (1996), Wilson (1932), Davis (1955), Kasthurirangan (1963),

Krishnapillai (1986) and Wickstead (1965).

The abundance is expressed as ‘ind / 1000 m3’ using the formula:

Abundance (ind/1000 m3) = No. of individuals of the particular taxa /volume of water filtered

Benthos: The sediment for analysis of benthos, both macro and meiofauna has been collected

using a standard Van-Veen Grab Sampler, with an area of 0.2 m2 (Anastasio Eleftheriou and

Alasdair McIntyre, 2005; Holme and McIntyre, 1971).

Macro-benthos: Macrobenthos were separated by sieving the sediment through 0.5 mm sieve.

The organisms retained in the sieve are considered as macrobenthos. The entire macrobenthic

specimen were picked out from the sediment and sorted out. Before sieving, samples were

treated with Rose Bengal in order to enhance the colour contrast of the organisms. Identification

16Gowsami and Padmavathi, 1996. Zooplankton Production, Composition and Diversity in the Coastal Waters of

Goa. Indian J. Mar. Sci., 25(91-97).




was carried out for major groups such as polychaetes and molluscs. The standard as well as

published references were used for identification of different macrofauna (Fauvel, 1953 and

other published works). Identification was followed by count of the individuals per species for

polychaetes and molluscs and group for rest of the organisms.

Meio-benthos: For the analysis of meiofauna, graduated glass corer, 30 cm long with an inner

diameter of 2.5 cm was used to sub sample meiofauna from 0.2m2 Van-Veen grab haul. The

corer was inserted into the undisturbed sediment, to a depth of 4 cm and samples were

transferred into labeled plastic containers containing 5% neutral formalin. The sediment

containing the meiofauna was stained with Rose Bengal biological stain (0.1 g in 100 ml of

distilled water). The organisms were separated and enumerated using a binocular microscope

and preserved in 4 % neutral formalin (Giere, 2008). The numerical abundance of organisms

was extrapolated in to no./10cm2. The standard as well as published references were used for

identification of the different meiofauna (Giere, 2008).

Analysis Results

The location-wise abundance of the various species of phytoplankton, zoo planktons, benthic

meio and the chlorophyll productivity are given in Table 3.12. The abundance of phytoplankton

genera, zooplankton genera and benthic phylum are separately shown in Table 3.13, Table 3.14

and in Table 3.15 respectively. The graphical analysis of the abundance of the species, location-

wise, is shown in Figure 3.12.



Table 3.12: Marine Biological Environment Analysis (S-Surface, B-Bottom)

S. No. Parameters Unit

SW1 at B9-1 SW2 at B9-2 SW3 at B9-3 SW4 at B7 SW5 at BRC

S B S B S B S B S B

1. Chlorophyll-a mg/m³ 2.72 2.85 2.91 2.81 3.04 1.91 3.49 1.95 3.81 3.39

2. Primary Productivity- Gross mgC/m³/d 680 -- 640 -- 490 -- 600 -- 490 --

3. Primary Productivity- Net mgC/m³/d 190 -- 120 -- 150 -- 70 -- 80 --

4. Phyto-plankton No./ml 200 100 191 76 190 181 288 247 932 520

5. Zooplankton No./ m³ 1214 -- 1478 -- 1044 -- 1211 -- 1183 --

1. Benthic Meio No./m2 -- 25 -- 19 -- 12 -- 60 -- 17





Table 3.13: Abundance of Phyto-plankton Species (S-Surface, B-Bottom)

Speciation of Phytoplankton Species Observed Total No.

of

Samples

Total No. of

Occurrence. S. No.

Phytoplankton

Genera SW-1 SW-2 SW-3 SW-4 SW-5

1 Amphiprora S B S B S B S B S B 10 4

- - + + - + - + - -

2 Amphora + - - - - - - - - - 10 1

3 Anabaena - - - - - - - - - + 10 1

4 Asterionellopsis + - + + - + + + - - 10 6

5 Ceratium - + - - - - + - - + 10 3

6 Chaetoceros + + + + + + + + - - 10 8

7 Corethron - - - - + - + + - - 10 3

8 Cyclotella - - - - - - - - + + 10 2

9 Cylindrotheca + + + + + + + + + + 10 10

10 Diploneis + + - - - - - - - - 10 2

11 Ditylum + + + + - + + + - - 10 7

12 Gonyaulax - - + - - - + + + - 10 4

13 Guinardia + + + + + + + + + + 10 10

14 Gymnodinium + + + - + + + + - - 10 7

15 Gyrodinium - - - + + + + + + + 10 7

16 Gyrosisma - - - - - - - - - + 10 1

17 Leptocylindrus - - - - - - + - + + 10 3

18 Lithodesmium - - - - + + + - - - 10 3

19 Mallomonas - - - - - - - - + - 10 1

20 Melosira + - - - - - - - - - 10 1

21 Navicula - + - - - - + - + + 10 4

22 Nitzschia + + - + + + + - - + 10 7

23 0dontella + + + + + + + + + + 10 10

24 Peridinium - - - - + - + - + + 10 4

25 Pleurosigma + + + + + - + + + + 10 9

26 Prorocentrum - + - - + - - - + - 10 3

27 Protooeridinium - + - - + - + - + - 10 4

28 Pseudo-nilzschia + + + + + + + + + + 10 10

29 Rhizosolenia - + + - + + + + + + 10 8

30 Skeletonema + - + - + + - - + + 10 6

31 Surirella - + + - + + - - + + 10 6

32 Thalassionema + + + + + - + + + - 10 8

33 Thalassiosira + + + + + + + + + + 10 10

34 Thalassiothrix - - - - - - - - + - 10 1

35 Triceratium - - - + + + - - - - 10 3

36 Trichodesmium - - - - - - - - - + 10 1





Table 3.14: Abundance of Zooplankton Species

Speciation of Zooplankton Species Observed (Surface) Total No. of

Samples

Total No. of

Occurrence S. No.

Zooplankton

Genera SW-1 SW-2 SW-3 SW-4 SW-5

1. Acetes sp. + + + + - 5 4

2. Amphioods + - - + - 5 2

3. Chaetognaths + + + - - 5 3

4. Copepods + + + + + 5 5

5. Ctenonhores - - - + - 5 1

6. Decapod larvae + + + + + 5 5

7. Foraminiferans + - - - - 5 1

8. Fish Eggs - - + - - 5 1

9. Fish Larvae + + + + + 5 5

10. Gastropods + + + + + 5 5

11. Isopods + + + + + 5 5

12. Lamellibranchs + + + + + 5 5

13. Lucifer sp. + + + + + 5 5

14. Medusae + - + + + 5 4

15. Mysids + + + + - 5 4

16. Polychaetes + + - + - 5 3

17. Siphonophores + + - + - 5 3


Table 3.15: Abundance of Benthic Species (Bottom)

Speciation of Benthos Species Observed Total No.

of Samples

Total No. of

Occurrence Sl.

No. Phylum Groups SS-1 SS-2 SS-3 SS-4 SS-5

1. Mollusca Gastropoda - - + - + 5 2

2. Mollusca Pelecypods + + - - + 5 3

3. Annelida Polychaetes + + - + - 5 3

4. Sipuncula Sipunculid - - - - + 5 1

5. Arthropoda Isoooda - - - + - 5 1

6. Arthropoda Brachyura + - + - - 5 2

7. Arthropoda Sergestids + - - + - 5 2

8. Chordata Fish larvae + - - - - 5 1

9. Nemetrea Nemetrea - - - - + 5 1





Concentration of Chlorophyll-a at Various Sampling Locations (Surface &

Bottom)

Abundance of Phytoplankton at Various Sampling Locations (Surface)

2.722.91

3.04

3.49

3.81

2.85 2.81

1.91 1.95

3.39

0

0.5

1

1.5

2

2.5

3

3.5

4

4.5

SS1 At B9-1 SS2 At B9-2 SS3 At B9-3 SS4 At B7 SS5 At BRC

Ch

loro

ph

yll

-a

Co

nce

ntr

ati

on

(m

g/m

³)

Surface Bottom

200 191 190

288

932

10076

181

247

520

0

100

200

300

400

500

600

700

800

900

1000

SS1 At B9-1 SS2 At B9-2 SS3 At B9-3 SS4 At B7 SS5 At BRC

Ph

yto

pla

nk

ton

s (N

o./

ml)

Surface Bottom




Abundance of Zooplankton at Various Sampling Locations

Abundance of Benthic Meio at Various Sampling Locations (Bottom)

Figure 3.12: Graphical Analysis of Marine Biological Characteristics


During the study, 36 Phytoplankton genera were observed. Among which the most abundant

was Cylindrotheca, Guonardia, Odontella, Thalassiosira and Pseudo-nilzschila which was

observed in all 10 samples of 5 sites. Similarly, 17 zooplanktons were observed, in which

Copepods, Decapod larves, Gastropods, Isopods, Lamellibranchs, Lucifer sp, were the most

abundant genera.

Likewise, benthos species were studied and were classified up to the groups. The species falling

under nine (9) different groups were identified among which, the most abundant groups were

Pelecypods and Polychaetes, followed by Gastropods, Brachyura, and Sergestids.

3.10 SOCIO-ECONOMIC ENVIRONMENT

The proposed project is an offshore oil and gas development and production project, thereby it

does not have any influence on the socio-economic environment of the project location.

SS1 At B9-1

(Surface)

SS2At B9-2

(Surface)

SS3 At B9-3

(Surface)

SS4 At B7

(Surface)

SS5 At BRC

(Surface)

0

200

400

600

800

1000

1200

1400

1600

1214

1478

1044

1211 1183

Zo

op

lan

kto

ns

(No

./ m

³)

SS1 At B9-1

(Bottom)

SS2 At B9-2

(Bottom)

SS3 At B9-3

(Bottom)

SS4 At B7

(Bottom)

SS5 At BRC

(Bottom)

0

10

20

30

40

50

60

25

19

12

60

17

Ben

thic

Mei

o (

No

./ m

2)

44

AANNTTIICCIIPPAATTEEDD

IIMMPPAACCTTSS &&

MMIITTIIGGAATTIIOONN

MMEEAASSUURREESS




1. ANTICIPATED IMPACTS

AND MITIGATION

MEASURES

4.1 IDENTIFICATION AND ASSESSMENT OF IMPACTS

The main purpose of Environmental Impact Assessment (EIA) study is to identify and assess

potential impacts due to the proposed project on the environment, thereby proposing suitable

mitigation measures to minimize or mitigate the adverse impacts. The key supporting

information required for the impact identification and assessment are detailed description of

both the project activities as provided in Chapter 2 and the baseline setting of the environment

of the proposed project site as depicted in Chapter 3. The information presented in these

chapters facilitates the identification of the interactions between the planned drilling,

installation and operation phases with the environment. The methodology adopted for the

impact assessment is shown in Figure 4.1.

Figure 4.1: Methodology for Environmental Impact Assessment

In this section, the interactions between the project activities and environment are outlined,

impacts on environmental components due to project activities are assessed and mitigation

measures are suggested.

The activities, which will be carried out both during installation and operation phases of the

proposed project are as follows:

• Positioning and deployment of rig.

4

Description of the Project

(Installation and Operation

Phases)

Hazard

Characterisation Environmental

Sensitivities

Hazard

Identification

Identification of Project -

Environmental Interactions

Description of the

Environment

Environmental Impact Assessment

Mitigation Measures




• Power generation at site.

• Drilling operations.

• Laying of sub-sea pipelines

• Installation of Wellhead platforms.

• Well completion.

• Transport of equipments and materials.

• Waste Water discharges.

• Solid waste generation.

• Fuel storage and handling.

• Wells hook-up.

• Commissioning and start-up.

• Routine Operation and Maintenance.

4.2 INTERACTION OF PROJECT ACTIVITIES WITH THE ENVIRONMENT

After identification of different activities during drilling and installation, and operation phases,

the next step is delineation of interaction between the identified activities with the environment.

Table 4.1 shows the Environment Sensitivities and Activity Interaction Matrix for the proposed

project. From the table, it can be inferred that, there are some domain where the impact will be

significant and on some domains the impact will be beneficial. The domains where the impacts

are significant can be minimized by applying suitable mitigation measures as discussed in later

sections.

Table 4.1: Interaction Matrix for the Proposed Project.

PROJECT ACTIVITIES.

Posi

tion

ing a

nd

Dep

loym

ent

of

Rig

Pow

er G

ener

ati

on

at

Sit

e

Dri

llin

g O

per

ati

on

Pip

elin

e O

per

ati

on

Inst

all

ati

on

of

Wel

lhea

d

Pla

tform

s

Wel

l C

om

ple

tion

Tra

nsp

ort

of

Eq

uip

men

ts

an

d M

ate

rials

Wast

ewate

r D

isch

arg

es

Soli

d W

ast

e G

ener

ati

on

Fu

el S

tora

ge

an

d H

an

dli

ng

Physical Environment

Air Quality - - -

Noise - - - -

Water Quality - - - - - - -

Sediment Quality - - - - - - - - -

Marine Biological Environment

Aquatic Flora - - - - - - - - - -

Aquatic Fauna - - - - - - - - - -

Local Fish Population - - - - - - - - - -

Socio-Economic Environment

Occupational Exposure &

General Safety - -

- - -

Employment +

Economy +

Legends + Beneficial Impact - Adverse Impact

Activity

En

vir

on

men

tal

Sen

siti

vit

ies




The proposed development project is in shallow water far away from the shore within Mumbai

offshore basin. Thus, there will be no threat to the nearby coastlines or habitations. As per the

above interaction matrix it is inferred that the significant impacts can be seen mainly for marine

water, sediment, ecological environment, air and noise environment. However, these impacts will

be short termed and, can be minimized by implementing effective mitigation measures.

The following sections explain the detailed impacts of proposed project on each environmental

sensitivity during drilling and installation phase (laying of sub-sea pipelines and installation of

wellhead platforms) as well as in operation phase. Subsequently, these impacts are evaluated, and

their mitigation measures are suggested.

4.2.1 Quantification of Impact

For the impact quantification, Leopold Matrix was used. In this matrix identified existing

environmental components is placed in the columns and the proposed project activities in the

rows. A plus (+) sign indicates a positive or beneficial impact while the minus (-) sign is used to

express negative or adverse impact. The process is summarized as follow:

The Leopold Matrix Table

• Columns represent identified existing environmental components

• Rows, proposed project activities

• Cells – x/y

where x = magnitude of identified impact, and y = importance or significance of impact.

(+) sign = positive or beneficial impact

(-) sign = negative or adverse impact.

The magnitude of identified impact and degree of importance/ or probability of identified impacts

is scaled from 1-10 where 1 represent low or negligible impact whereas 10 represents maximum

impact.

The magnitude (severity of impacts) is scaled as follows:

• 1 - 2 - negligible

• 3 - 4 - mild

• - 6 - moderate

• - 10 - severe

The degree of importance or probability of identified impacts:

• 1 - 2 - negligible

• 3 - 4 - low

• 5 - 6 - medium

• 7- 10 - high.

The result of total impact from the proposed project is given below in Table 4.2.




Table 4.2: Impact Evaluation Matrix.

Project Activities

Po

siti

on

ing

an

d D

eplo

ym

ent

of

Rig

Po

wer

Gen

erati

on

at

Sit

e

Dri

llin

g O

per

ati

on

Pip

elin

e O

per

ati

on

Inst

all

ati

on

of

Wel

lhea

d

Pla

tfo

rms

Wel

l C

om

ple

tio

n

Tra

nsp

ort

of

Eq

uip

men

ts a

nd

Ma

teri

als

Wa

stew

ate

r D

isch

arg

es

So

lid

Wa

ste

Gen

era

tio

n

Fu

el S

tora

ge

an

d H

an

dli

ng

Probability of

Impacts

Environment

Sensitivity


Air Quality -2/-2 -3/-3 -2/-2 -7

Noise -3/-3 -2/-2 -2/-2 -7

Water Quality -3/-3 -2/-2 -3/-3 -3/-3 -2/-2 -3/-2 -15

Sediment Quality -3/-3 -2/-2 -3/-3 -3/-3 -2/-2 -2/-2 -2/-2 -2/-2 -2/-2 -2/-2 -23


Aquatic Flora -2/-2 -1/1 -2/-2 -2/-2 -2/-2 -3/-2 -3/-3 -3/-3 -2/-2 -2/-2 -21

Aquatic Fauna -2/-2 -2/-1 -2/-2 -2/-2 -2/-2 -3/-2 -3/-3 -3/-2 -3/-2 -2/-2 -20

Local Fish

Population -1/-1 -1/-1 -2/-2 -2/-2 -2/-2 -2/-2 -2/-2 -2/-2 -2/-2 -2/-2 -18


Occupational

Exposure &

General Safety -2/-2 -3/-3 -2/-2 -4/-2 -9

Economy 8/10 10

Magnitude of

Impacts -16 -12 -12 -12 -10 -15 -10 -10 -13 -10 -110

Total Impact Score = sum of {(x) x (y)} for each environmental component and for each project

activity. The far-right column of the above table represents total impact on environmental

component while the lowest row represents total impact caused by each project activity.

4.2.2 Impact on Air Environment

High wind speed in the open sea area shall lead to greater dilution of pollutants, which shall

increase with increasing distance from the source. Moreover, absence of sensitive receptors shall

render the impacts due to air emission as negligible.

a) Drilling and Installation

• Air quality degradation from emission of pollutants (mainly NOx, PM₁₀, and Sox) in air from

engines, DG set, transportation vessels, emergency venting and gas flaring etc.

b) Operation Phase

• No major impacts on air quality are envisaged.

4.2.3 Impact on Noise Quality

a) Drilling and Installation Phase

• Impact on marine fauna due to use of large machineries, equipments and transportation

though minimal.




b) Operation Phase

• Temporary impact on marine fauna from operation of wellhead platforms and intermittent

movement of helicopter and supply vessels.

4.2.4 Impact on Marine Water Quality


The deployment of rig in the offshore and other sub-sea infrastructure and facilities has been

foreseen to cause short-term impact.

• Oxidation of anoxic intertidal and offshore mud due to the displacement of sea-bed

sediments.

• Local chemical changes in water quality due to subsequent decrease in pH and increase

in BOD levels. These impacts have been envisaged to be local and temporary, and it

expected the water will regain its original capacity within a short span.

• Effect on the water quality due to discharge/accidental spillage of

chemicals/oil/lubricants.

• Increase in water turbidity near discharge points due to drill cuttings and fluids.

b) Operation Phase

• Effect on water quality due to accidental spillage of chemicals/oil/lubricants from the

operation wells and/or transfer of hydrocarbons etc.

4.2.5 Impact on Sediment Quality


• Local and temporary disturbance to the sea-bed due to sediment suspension and changes

in the sea-bed morphology.

b) Operation Phase

• Effect on sediment quality due to operational discharges (liquid and solid discharges) or

accidental spillage of fuel/chemical etc.

4.2.6 Marine Ecology


• Disturbance and removal of sea bed sediments will impact the benthos.

• The noise generated from the operation of large machinery (diesel engines/gas

turbines/fluid pumps/mud pumps) equipment, and transportation vessels may affect on

marine life. It is temporary and will not cause any physical damage.

• Temporary impact on local seabed habitats and species.

b) Operation Phase

• Physical hindrance to the marine organisms and displacement of marine species in

immediate vicinity due to direct habitat loss from sub-sea infrastructure.

• Impact on the benthos in the benthic zone leading to its destruction, smothering or

displacement.

• Activities like accidental spillage of chemicals/oils/lubricants/operational discharges into

the sea will also have a significant impact on the marine biodiversity.

Even though the impacts during the initial phase have been envisaged to be significant, the

region is likely to regain its ecological balance in a short-span of time due to the adaptable

nature of the marine organisms.




4.2.7 Occupational Health Hazards Socio-Economic Environment

The proposed project activities are likely to have positive impact on the existing socio-

economic profile of the region:

• Generation of temporary employment.

• Likely creation of long-term employment opportunities during the operational life of the

fields.

• Discovered hydrocarbons will contribute in meeting the national demand of petroleum

resources.

4.3 IMPACT EVALUATION

Offshore installation and drilling activities are likely to increase the air emissions by medium

magnitude. However, the impacts of these emissions have been envisaged to be insignificant

due to highly dispersive environment of offshore location and absence of sensitive receptors.

Thus, the overall impact on local air quality shall be of minor significance.

Noise generated during the project activities will not adversely impacts marine fauna, however,

some marine mammals (within 1 to 3 km radius from the source) may be predicted to exhibit

avoidance reactions to the larger project vessels as they may have greater ability to disturb in

relation to their sound level than the ongoing drilling activities. However, no physical damage

has been envisaged and thus the anticipated impacts on marine organisms shall be minimal due

to their avoidance approach towards continuous and semi-continuous noise (Nedwell et al.,

2004 and Thomsen et al., 2006).

Impacts on marine water quality has been envisaged to be insignificant as the wastewater and

solid discharges from the project activities will be treated to meet requirements of stipulated

standards prior to its disposal. However, deployment of rig, and installation of offshore

structures shall temporarily increase the turbidity levels in local marine environment, but it has

been envisaged that the region is expected to regain its original characteristics in short span of

time.

Project activities shall temporarily affect the local seabed habitats and species, but the area

affected being a small percentage of the total area of similar habitats in this offshore location.

Also, the negative impacts of seabed structures on benthic communities are assessed as being

of minor significance.

4.4 IMPACT SIGNIFICANCE

Evaluation of impacts signifies the potential impacts in terms of its likelihood nature as per the

following criteria:

a. Intensity of the impact: This classification is based on the intensity, whether the impact

has high, moderate or low intensity.

b. Spatial Distribution: The impacts are further classified based on their spatial distribution,

i.e. local, when impacting an area of approximately 1 km radius from the project area,

moderate spread, when impacting an area of 1 to 2 km radius and regional beyond 2 km.

c. Temporal Scale: The impacts are classified as short term, moderate term and long term

in terms of their existence in temporal scale. Impacts less than 1-year existence is short

term, while those with 1 to 3 years is of moderate term and more than 3 years is of long

term.

d. Nature of Impact: The negative impacts are termed as adverse impacts while positive

impacts as beneficial.




The significance of environmental impacts of various involved activities has been evaluated

based on the criteria outlined in Table 4.3.

Table 4.3: Impact Significance Criteria

Impact Significance Criteria

Major Adverse

When the impact is of high intensity with high spread

and high duration/high intensity with medium spread

and medium duration.

Moderate Adverse

When the impact is of moderate intensity with high

spread and high duration/high intensity with low/

moderate spread and low duration.

Minor Adverse When the impact is of low intensity but with moderate

spread and moderate duration/moderate intensity.

Insignificant Adverse When the impact is of low intensity, low spread.

Beneficial When the impacts are positive.

Based on the above-specified criteria, Tables 4.4 describes the impact significance due to

development drilling in the cluster fields in the Mumbai Offshore Basin and associated

activities, without implementation of any mitigation measures. It is important to note that one

activity may have varying impacts on different receptors i.e. different components of the

environment. To avoid repetitions, this section describes various activities, which may have

wide impacts on many receptors.

Table 4.4: Impact Significance of Project Activities

(Without Mitigation Measures)

Environmental

Sensitivities

Nature of Likely Impacts Impact Significance

Intensity Area Duration

Lo

w I

nte

nsi

ty

Mo

der

ate

Inte

nsi

ty

Hig

h I

nte

nsi

ty

Lo

cal

Sp

read

Mo

der

ate

Sp

read

Reg

ion

al S

pre

ad

Sh

ort

Ter

m

Mo

der

ate

Ter

m

Lo

ng

Ter

m

Ad

ver

se

Ben

efic

ial

Insi

gn

ific

ant

Min

or

Mo

der

ate

Maj

or


Air Quality □ □ □ □ □

Noise □ □ □ □ □

Water Quality □ □ □ □ □

Sediment Quality □ □ □ □ □


Aquatic Flora □ □ □ □ □

Aquatic Fauna □ □ □ □ □

Local Fish Population □ □ □ □ □


Local Economy □ □ □ □ □

It is observed from Table 4.4 that the adverse impacts of the proposed project on air and water

quality will be moderate while the impact on noise, sediment quality, marine biological




environment will be minor. On the other hand, the project will have a positive impact on local

economy.

The impact on these environmental and social components is quantified in following section.

4.5 IMPACT MITIGATION MEASURES

4.5.1 Air Environment

a. Good operational controls and high level of monitoring will be built into the design

operational aspects of the project.

b. Regular maintenance of engines and DG sets will be ensured to keep the environmental

impact minimum. The DG sets shall comply with the applicable emission norms. High

efficiency generator sets will be provided with adequate stack height and modern emission

control equipment’s. Emission can be minimized further by use of low sulphur diesel (i.e.

present sulphur content of HSD utilized is 50 ppm).

c. Regular maintenance of the transportation vessels to be ensured to minimize level of emission

in the environment.

d. Regular ambient air quality monitoring must be carried out according to the specified norms.

4.5.2 Noise Environment

a. Mobile noise sources such as rig, and vessels will be routed in such a way that there will be

minimum disturbance to receptors.

b. Avoid loud, sudden noises, wherever possible. Integral noise shielding shall be used where

practicable and applicable.

c. Rubber padding/noise isolators shall be provided at equipment/machinery used during the

project activities.

d. Regular maintenance of all equipment and transportation vessels shall be ensured. Idling of

vessels or equipment shall be avoided when not in use.

e. The impact from noise is minimum as the propagation of sound through water is generally

affected by spreading losses and attenuation losses.

4.5.3 Water Environment

a. The sewage shall be treated on-board of the rig according to the MARPOL Regulations.

Residual chlorine of the treated sewage shall not exceed 1mg/l before disposal.

b. Oily wastewater from drainage system shall be treated using on-board oil traps and shall be

disposed to sea following Central Pollution Control Board (CPCB). According to MARPOL

Regulations, the discharge of oil content (without dilution) into sea shall not exceed 15 parts

per million (ppm).

c. Use of only low toxic chemicals for rig and transportation vessels.

d. Bulk discharge of drilling fluid in offshore shall be prohibited except in emergency situations.

According to a notification issued by MoEF dated 30th August 2005, G.S.R. 546 (E), Water-

Based Mud (WBM)/Oil-Based Mud (OBM)/Synthetic Oil Based Mud (SOBM) should be

recycled to a maximum extent. Unusable portion of WBM/SOBM shall be discharged

offshore into sea intermittently, at an average rate of 50 bbl/hr/well from a platform so as to

have proper dilution and dispersion without any adverse impact on marine environment.

e. Oil drilling operators must maintain daily record of discharge of drill cutting & drill fluid to

offshore and monitor daily the effluent quality.

f. In case of oily cuttings, they will be transported on shore for appropriate disposal.

g. Adequate engineering designs will be adopted to avoid any leakages/spillages from the

operation activities.




h. Oil Spill Contingency Plan (OSCP) (given in EMP) will be implemented in case of any

accidental leakage/spillage.

4.5.4 Sediment Quality

a. The subsea infrastructure layout shall be designed to avoid sea bed features considered to

be geo-hazards.

b. Adoption of suitable measures and implementation of waste management plan.

4.5.5 Marine Biology

a. Waste management plan will be implemented to mitigate adverse impacts on the marine

biology.

b. Fisheries Department shall be informed in case of

a. Decease of aquatic species,

b. Change in behaviour of the avi-fauna, or

c. Any unusual phenomenon.

4.5.6 Occupational Health Hazards

a. On-site workers working near high noise equipment shall use personal protective equipment

(PPE) to minimize their exposure to it.

b. Good working practices shall be implemented to reduce impact on the health and

environment.

4.5.7 Waste Generation and Effluent Management

The site would develop and adopt proper system for the management, storage and disposal of

the hazardous and non-hazardous waste, such as:

a. Solid waste including domestic waste, combustible and recyclable waste shall be collected,

segregated and stored in specified containers and will be transferred to authorized

contractors for their disposal.

b. Hazardous waste such as medical waste, waste lube/system oil from machinery, used oil

from generator set shall be handled as per Hazardous Wastes (Management, Handling and

Trans-boundary Movement) Rules, 2016. The waste will be carefully stored in drums and

transported to MoEF approved recyclers for its final disposal.

c. Sewage will be treated on-board the rig, so that residual chlorine of the treated sewage will

not exceed 1mg/L before disposal.

d. Drilling, wash water and oily water will be treated to conform to limits notified as per

MARPOL Regulations, before disposal into sea. The treated effluent will be monitored

regularly.

e. WBM or SOBM (to be used in special case only) will be disposed of as per G.S.R. 546 (E);

dated 30/08/05,

f. Thoroughly washed the drill cuttings separated from WBM and unusable portion of WBM

having toxicity of 96 hr LC50 Value> 30,000 mg/L will be discharged offshore into sea

intermittently, at an average rate of 50 bbl/hr/well from a platform so as to have proper

dilution and dispersion without any adverse impact on marine environment.

g. Unusable portion of SOBM will not be discharged into sea and shall be bought to onshore

for treatment and disposal in an impervious waste disposal pit.




4.6 IMPACT SIGNIFICANCE

The significance of assessed impacts after implementation of mitigation measures are analyzed

based on significance criteria as mentioned in Table 4.3, above. Table 4.5 below provides the

significant level of project impacts after implementation of proposed mitigation measures.

Table 4.5: Potential Environmental Impacts of Proposed Project Activities

(with Mitigation Measures)

Environmental

Sensitivities

Nature of Likely Impacts Impact Significance (After

Mitigation Measures) Intensity Area Duration

Lo

w I

nte

nsi

ty

Mo

der

ate

Inte

nsi

ty

Hig

h I

nte

nsi

ty

Lo

cal

Sp

read

Mo

der

ate

Sp

read

Reg

ion

al S

pre

ad

Sh

ort

Ter

m

Mo

der

ate

Ter

m

Lo

ng

Ter

m

Ad

ver

se

Ben

efic

ial

Insi

gn

ific

ant

Min

or

Mo

der

ate

Maj

or


Air Quality □ □ □ □ □

Noise □ □ □ □ □

Water Quality □ □ □ □ □

Sediment Quality □ □ □ □ □


Aquatic Flora □ □ □ □ □

Aquatic Fauna □ □ □ □ □

Local Fish Population □ □ □ □ □


Local Economy □ □ □ □ □

From the above Table 4.5, it is clear evident that all the anticipated impacts will be within

minor level upon implementation of the mitigation measures.

After the implementation of mitigation measures, the impact on bio-physical and social

components will be minor. Therefore, it can be inferred that the implementation of the proposed

mitigation measures will nullify the adverse impacts of the proposed project.

55

AANNAALLYYSSIISS OOFF

AALLTTEERRNNAATTIIVVEESS




ANALYSIS OF ALTERNATIVES

AWEL has been awarded contract area MB/OSDSF/B9/2016 comprising of B-9 Cluster Offshore Fields

and has signed the Revenue Sharing Contract (RSC) with the Government of India (GoI). The field was

originally discovered by Oil and Natural Gas Corporation (ONGC) which was subsequently offered for

bidding under Discovered Small Fields (DSF) round, 2016. AWEL plans to develop the B-9 Cluster

field by drilling wells and installing offshore facilities to produce natural gas and crude oil, and process

through the existing offshore facilities. So, no alternative site is analyzed.

5

66

EENNVVIIRROONNMMEENNTTAALL

MMOONNIITTOORRIINNGG PPLLAANN




2. ENVIRONMENTAL

MONITORING PROGRAM

6.1 INTRODUCTION

An Environmental Monitoring Program provides a delivery mechanism to address the adverse

environmental impacts of a project during its execution, to enhance project benefits and

finally to introduce standards of good practices to be adopted. An environmental monitoring

plan is important as it provides useful information and helps to:

• Assist in detecting the development of any unwanted environmental situation during

drilling and installation or operation phases, and thus, provides opportunities for adopting

appropriate control measures.

• Define the responsibilities of the project proponent, contractors and environmental

monitors and provides means of effective communication of environmental issues among

them.

• Define monitoring mechanism and identify monitoring parameters.

• Evaluate the performance and effectiveness of mitigation measures proposed in the

Environment Management Plan (EMP) and suggest improvements in management plan, if

required.

From the monitoring point of view, the important parameters are resource inventory, water

quality, sediment quality, noise quality, and biological components. The suggested monitoring

details are outlined in the following sections.

6.2 ENVIRONMENTAL MONITORING PROGRAM

An environmental monitoring program is suggested to monitor environmental parameters

during the project period Table 6.1 below.

66



Table 6.1: Environmental Monitoring Program

Receptor Location Monitoring Mechanism Monitoring and

Reporting Frequency

During Drilling and Installation (laying of sub-sea pipeline and installation of Wellhead Platform)

Natural Resource Project Site

(Operation areas)

• Quantity of each type of material used

including water consumption.

• Quantity of fuel used.


Drilling wastes Drilling Locations.

• Offshore discharge of unusable WBM, if

required, on meeting EP standards at a

intermittent rate of 50bbl/hr

• Any other waste to be stored on rig &

brought onshore for disposal.

• Daily monitoring &

recording of quantity

• Monitor and record the

generation quantity on

daily basis.

Oil Spills

Drilling Locations.

• Inventory of all oil spills/leakages and

quantity of each spill.

• Availability of facilities according to Oil

Spill Contingency Plan (OSCP).

• Presence of Oil Drip Plans in potential oil

leakages areas.


Operation.

Noise & Vibration

Project Site.

(Operation areas)

• Noise level monitoring.

• Machineries maintenance.

• No machinery running when not required.

• Use of ear plug by workforce.

Weekly during Drilling

and Installation phase.

Water Quality


location/Wellhead platform site.


pipeline and locations within 1 km

radius of the pipeline.

• pH, Conductivity, TSS, TDS, Heavy Metals,

BOD, COD, Oil & Grease, Total Petroleum,

Hydrocarbons (TPH) and Petroleum

Aromatic Hydrocarbons (PAHs).


Installation phase.

Sediment Quality • Upto 1 km radius from Drilling



• Texture, Organic matter, Nitrogen,

Phosphorous, Oil & Grease, Heavy Metal

Concentration, Total Petroleum,


Installation phase.



Receptor Location Monitoring Mechanism Monitoring and

Reporting Frequency





Ecological

Parameters






• Phytoplanktons, Zooplanktons, Benthos and

Chlorophyll estimation.


Installation phase.

Project Site

(Operation areas)

• Visual observations of the marine flora and

fauna will be done in routine through the rig

and surveillance vessels on round.

Daily during Drilling and

Installation phase.

Operation Phase

Water Quality

• Upto 1 km radius Well/Wellhead

platform site.




• pH, Conductivity, TSS, TDS, Heavy Metals,

BOD, COD, Oil & Grease, Total Petroleum,



Once in a year.

Sediment Quality • Upto 1 km radius Well/Wellhead

platform site.




• Texture, Organic matter, Nitrogen,

Phosphorous, Oil & Grease, Heavy Metal

Concentration, Total Petroleum,



Once in a year.

Ecological

Parameters

• Upto 1 km radius Well/Wellhead

platform site.




• Phytoplanktons, Zooplanktons, Benthos and

Chlorophyll estimation.

Once in a year.




The pre and post operational monitoring programme shall be carried out under the supervision

of the AWEL. The water, sediment and ecological monitoring (planktons, chlorophyll, and

benthos) shall be carried out as per the MoEF&CC guidelines by engaging MoEF&CC/

NABL accredited laboratories only.

The noise monitoring will be carried out on weekly basis using automated noise data logger.

Noise data logger shall be made available at rig or the offshore supply vessel. Inventory of

natural resources and wastes or spills/leakages and visual observation of marine flora & fauna

shall be carried out internally. Training on Environmental monitoring (resource inventory,

waste or spills/leakage inventory, visual observations of marine species, etc) and other HSE

related aspects shall be provided to the staff engaged for drilling and Installation activities and

shall be provided by the AWEL’s HSE Officer.

6.3 BUDGET

The monitoring and evaluation process will require a contingency budget. The cost required

for the Environmental Monitoring Program both for Drilling/ Installation Phase and Operation

phases are given in Table 6.2 and 6.3 respectively.

Table 6.2: Budget for Environmental Monitoring Plan during Drilling/ Installation

Sl.

No. Attribute Parameters

Per Sample

Cost

(in INR)

(A)

No. of

Sample

(B)

Total Cost

(in INR)

(D)

(A*B=C)

1. Water pH, Conductivity, TSS,

TDS, Heavy Metals,

BOD, COD, Oil &

Grease, Total

Petroleum,

Hydrocarbons (TPH)

and Petroleum

Aromatic Hydrocarbons

(PAHs).

8000 30 2,40,000

2. Sediments pH, Texture, Organic

matter, Nitrogen,

Phosphorous, Oil &

Grease, Heavy Metal

Concentration, Total

Petroleum,

Hydrocarbons (TPH)

and Petroleum

Aromatic Hydrocarbons

(PAHs).

8000 30 2,40,000

3. Ecological Phytoplanktons,

Zooplanktons, Benthos

and Chlorophyll

estimation.

9000 30 2,70,000

4. Occupational

Health and

Safety

General check-up,

respiratory and auditory

ailment.

2,00,000 - 2,00,000

Total 9,50,000/-




Table 6.3: Budget for Environmental Monitoring Plan during Operation Phase

Sl.

No. Attribute Parameters

Per Sample

Cost

(in INR)

(A)

No. of

Sample

(B)

Total Cost

(in INR)

(D)

(A*B=C)

1. Water pH, Conductivity, TSS,

TDS, Heavy Metals,

BOD, COD, Oil &

Grease, Total Petroleum,

Hydrocarbons (TPH)

and Petroleum Aromatic

Hydrocarbons (PAHs).

8000 30 2,40,000

2. Sediments Ph Texture, Organic

matter, Nitrogen,

Phosphorous, Oil &

Grease, Heavy Metal

Concentration, Total

Petroleum,

Hydrocarbons (TPH)

and Petroleum Aromatic

Hydrocarbons (PAHs).

8000 30 2,40,000

3. Ecological Phytoplanktons,

Zooplanktons, Benthos

and Chlorophyll

estimation.

9000 30 2,70,000

Total 7,50,000

An amount of approximately INR 9.50 lakh will be spent for the compliance of

environmental quality monitoring plan during drilling/ Installation phase. INR 7.50 lakh

will be spent annually during operation phase of the project.

77

AADDDDIITTIIOONNAALL

SSTTUUDDIIEESS




1. ADDITIONAL

STUDIES

7.1 INTRODUCTION

Adani Welspun Exploration Limited (AWEL) plans to develop the B-9 Cluster Field which is

a discovered small field (DSF) by Oil and Natural Gas Corporation (ONGC). Its

developmental activities will be including drilling of wells and installation of offshore well-

head platform facilities to produce natural gas and crude oil and lying of subsea pipelines.

The cluster field comprises of three (3) DSF offshore field namely B-9, B-7 and BRC.

The type of rig used during the drilling phase is planned to commence drilling using a self-

contained Mobile Offshore Drilling Unit (MODU), i.e., a Jack-Up Rig capable of performing

shallow water drilling activities. Risk assessment includes the identification of risks involved

in the drilling process and the associated activities in the drilling program, and the assessment

of probability of certain consequences. This chapter highlights the studies of the risk

assessment, disaster management plan and emergency action plan in the following chapters.

Salient Features of the Project

The overall project activity consists of drilling of twelve (12) wells and four (4) well head

platforms, subsea pipeline of approximately 130 km in length (50 Km intra-field pipeline and

80 Km export pipeline joining B-9-1 platform and C-24RP).

The platforms are planned to be minimum facilities well-head platforms comprising of well-

head, production & test manifold, well-head control panel, scrapper launcher, instrument gas

system, local power generation (solar or other), heli-deck, jib-crane, fiscal metering, real-

time production data transfer to Director General of Hydrocarbon (DGH) through satellite

communication, etc.

The development for B-9 field will include 2 well head platforms, while B-7 and BRC will

include installation of 1 well head platform each, inter-field sub-sea pipelines and hooking up

at B-9 area. The BRC platform is also envisaged to include facilities to handle, stabilise, store

and export oil.

7.2 RISK ASSESSMENT

The risk assessment (RA) study is aimed at identifying the potential sources which pose risks

of a hazard outbreak, determining the probability of such hazard occurrences and their

consequences. The risk assessment exercise mitigates the severity of any accident and

facilitates preparation of an effective emergency action plan (EAP) or disaster management

plan (DMP). Hydrocarbon operations are generally hazardous in nature due to the intrinsic

chemical properties of hydrocarbons, temperature, pressure or a combination of them. The

hazards associated with hydrocarbon operations are fire, explosion, release of chemicals or a

combination of these hazards. RA study helps to improve upon the integrity, reliability and

safety of hydrocarbon operations. The RA studies are based on the Quantitative Risk

Assessment (QRA) Analysis.

77




7.2.1 Risk Analysis

The most important step is to recognize all the possible hazards and their associated risks in

the site and its surroundings to ensure the safety and consistency of the drilling operations.

Risk analysis is the tool used to determine the consequence of operational failure in drilling

and related activities.

7.2.2 Identification of Hazards in Offshore Oil and Gas Field Development

Considering the applicability of different risks aspects to be undertaken in the proposed

project, various hazards associated with extraction of hydrocarbon in offshore productions are

as follows:

• Blowouts

• Collisions

• Helicopter crash

• Presence of H2S

• Process leaks

• Process and Non-Process fires/explosions

In addition, it is understood that the causative factors and mitigation measures for such events

will be adequately taken care of through existing safety management procedures and practices

of AWEL.

The above risks and hazard have been evaluated based on the likelihood of occurrence and the

magnitude of consequences. The significance of the risk is expressed as the product of

likelihood and the consequence of the risk event which is expressed as given below:

Significance = Likelihood x Consequence

Figure 7.1 below illustrates the risk matrix with all possible product results for the four

likelihood and consequence categories and the Figure 7.2 assigns risk significance criteria in

three regions that identify the limit of risk acceptability according to the policy and the

strategic objectives of the proponent. Depending on the position of the intersection of a

column with a row in the risk matrix, hazard prone activities have been classified as low,

medium and high, thereby qualifying for a set of risk reduction / mitigation strategies.

Severity of

Consequence

Likelihood of Occurrence

O A B C D E

1 Continuous Improvement

2 Risk Reduction Measures

3

4 Intolerable Risk

5

Figure 7.1: Risk Matrix and Acceptability Criteria




Risk Criteria Definition

Low (Continuous

Improvement)

The level of risk is broadly acceptable and no Specific

control

measures are required

Medium (Risk Reduction

Measures)

The level of risk can be tolerable only once a structured

review of risk reduction measures has been carried out

High (Intolerable Risk)

The level of risk is not acceptable and risk control

measures

are required to move the risk figure to the previous

regions

Figure 7.2: Risk Categories and Significance Criteria

7.2.3 Major Hazards

a. Hazards due to Installation of Pipelines and Platform

Installation of pipelines - During the pipeline installation, the possible hazards are-

• Dropped and dragged anchor chain from pipe lay vessel,

• Vessel collision during laying leading to dropped object, etc.

• Loss of tension drop of pipe end, etc.

• Damage during trenching, gravel dumping, installation of protection cover, etc.

• Damage during crossing construction.

Platform Operations - During the platform operations, the possible hazards are-

• Drop of objects into the sea.

b. Oil Spill

Minor Oil Spill - During the well testing operation, there exists a possibility of hydrocarbon

gases / oil getting released due to some unavoidable incidents. Once the flow of oil / gas from

well is stopped, then on-site access for clean-up is possible. If flow from well cannot be

stopped, a blowout situation exists.

Major Oil Spill - Significant hydrocarbon inventories will not be maintained at the rig. A

major spill can, therefore, only arise as a result of an uncontrolled flow from a well i.e.

blowout. Provided that ignition does not take place and the well head is not obstructed the

well can be shut in at the wellhead. If ignition occurs or other damage prevents access to the

wellhead then a blowout situation exists, and appropriate measures must be implemented.

c. Blowout

Blowout means uncontrolled violent escape of hydrocarbon fluids (gas with associated water,

gas with condensate and gas with oil) from a well. The oil and condensate concentrations are

very small and gas coming out from reservoir is already stripped out of both and saturated

with water. Its combustion characteristics are unlikely to be affected by oil.

Blowout followed by ignition which prevents access to the wellhead is a major hazard. The

various contributors to blowout are:




Primary

• Failure to keep the hole full.

• Mud weight too low.

• Swabbing during trips.

• Lost circulation.

• Failure of differential fill-up equipment.

Secondary

• Failure to detect and control a kick as quickly as possible.

• Mechanical failure of Blowout Preventer (BOP).

• Failure to test BOP equipment properly.

• Damage to or failure of wellhead equipment.

• Failure of casing.

• Failure of formation or cement bond around casing.

Blow Out Consequences and Effects: A blowout incident can take a variety of different

forms, ranging from a minor leak which can be stopped within minutes, to a major release

which continues out of control for days or even months. The consequences of a blowout event

will to a large extent depend on how the blowout scenario evolves and the following possible

scenarios are likely:

• Release of high pressure inflammable and explosive gas. This may have deleterious effect

on the coastal traffic

• Ignition of the flammable gas released resulting in a jet fire, pool fire or an explosion

Ignition of released gas can possibly result in considerable harm, with historical data showing

40 % blowout such incidences leading to more than significant damage to the drilling ship /

platform (WOAD database) and resulting in associated fatalities amongst drilling crew and

support personnel present on the ship / platform. Also, ignition has been recorded in about

30% of the blowout cases on an average (SINTEF offshore blowout database). However, on

positive side, with improvement of offshore drilling, production and product transfer-

transport technology, number of offshore blowouts occurring has significantly gone down in

the last decade.

Hazards in the platforms will be mostly from HC gas leakage and also from chemical spillage

(methanol or others). The leakage from process equipment (flange connections/instrument

tapings or catastrophic equipment flange failures) can occur. The rate of leakage will depend

upon system pressure, depth and opening size.

Risk Ranking for Blowouts

Likelihood Ranking – B; Consequence Ranking – 5; Risk Ranking –5B (High)

If the hydrostatic head exerted by the column of drilling fluid can drop below the formation

pressure then formation fluids will enter the wellbore (this is known as a kick) and a potential

blowout situation has developed. Fast and efficient action by operating personnel in

recognizing the above situations and taking precautionary measure can avert a blowout.

d. Collisions Involving Drill Ship (MODU)

A collision situation is considered for the risk assessment for the impacts on “Well Unit” by

heavy falling objects from other drill ships or other marine vessels working nearby or passing

by it.




The following possibilities have been taken into consideration:

• Visiting support vessels which approaches the MODU under their own power and

including supply vessels, standby vessels accidently release some objects and it hits the

well.

Consequences and Effects The analysis of collision consequences is generally based on the

principle of conservation of energy. The impact of a full-on collision may however be more

severe and may lead to damage to the well and may lead to a rupture or leak in the riser

resulting in a process leak or a blowout.

Risk Ranking for Vessel Collision

Likelihood Ranking – C; Consequence Ranking – 3; Risk Ranking - 3C (Medium)

e. Helicopter Crashes

The journey to-and-fro offshore rig has historically been one of the main reasons for

accidental death or injury to many offshore workers. For the AWEL drilling activities, crew

transport to-and-fro the MODU shall be by helicopter, due to its speed, convenience and good

operability under rough weather conditions. Several approaches exist to analyze probability of

helicopter crash risks.

A more reasonable approach involves the use of individual risk approach as a product of 3

components:

• Frequency of helicopter accidents per flight

• Proportion of accidents which involve fatalities

• Proportion of personnel on board in fatal accidents who become fatalities.

Consequences and Effects

Helicopter crashes involved with offshore oil & gas exploration and production have

happened in the past, especially in the North Sea offshore operations in Europe, with some

resulting in fatalities or injuries to crew members. In addition to the risk posed to the

helicopter occupants, accidents involving helicopters can also cause damage to the drill ship

itself by way of crashing into the ship during take-off or landing or by an accident when the

helicopter is on the helideck. However, the consequence of such risk may be considered to be

small compared to the other risks sources on the MODU.

Risk Ranking for Helicopter Crash

Likelihood Ranking – B; Consequence Ranking – 3; Risk Ranking - 3B (Medium)

7.2.4 Hazards - Nature and sensitivity of impact zones

Subsea Pipeline:

1) Natural hazards - Landslides

The generation of landslides that could potentially affect the pipeline integrity has been

qualitatively evaluated at the outset of the project for the entire pipeline route. It was

concluded that the pipelines are not threatened by landslide. The occurrence of a landslide is

due to the coexistence of various conditions such as:

i) Thick layers of very soft sediments lying on steep slopes

ii) Slope angles able to trigger the development of soil instability

iii) Triggering mechanisms causing the landslides (e.g. seismic loads, wave loads, rapid

accumulation of soft sediments)




No such conditions have been found along the pipeline routes. In addition the proposed

pipeline support system is designed after conducting on-bottom stability tests and maximum

free span lengths to take care of the subsea soil erosion (if any) and regular inspection of

pipeline route will caution of any likely damage.

2) Natural hazards - Extreme Storm

The following met ocean design conditions are used for the detailed design of the system

i) Seasonal and whole year directional extremes of wind, waves and currents

ii) Directional significant wave height

iii) Wave and current climate for fatigue analysis

Air temperature extremes and climate at landfall locations

i) Persistence of storm and calm conditions for onsite operations

ii) Variability of the sea level

iii) Hydrological sea water parameters (temperature, salinity and density)

Arabian sea is known for rough weather; since the production operational system and Subsea

pipeline will be near the sea bottom, it is unlikely to be affected much with rough weather.

3) Heavy Impact and Damage to pipeline due to dropping of heavy objects

A situation is considered for the risk assessment for the impacts on ―Subsea Pipeline‖ by

heavy falling objects from other drill ships or other marine vessels working nearby or passing

by it. The following possibilities have been taken into consideration:

i) Vessels which passes through the pipeline route may accidently release some heavy

objects/ anchors and it hits the Pipeline.

Consequences and Effects

The analysis of consequences is generally based on the principle of conservation of energy.

The impact of a complete contact with the object may however be more severe and may lead

to damage to the pipeline such as rupture or leak from the pipeline resulting in a process leak.

Risk Ranking Likelihood Ranking - C Consequence Ranking - 3 Risk Ranking - 3C

(Medium)

Failure Scenarios (Likely)

Subsea Pipeline

Subsea pipeline will be laid at sea surface. The sea water will exert pressure on the line which

can be high. Any opening in the operating pipe line (due to any damage or any other cause)

will result in gas leakage. Leaking gas will disperse (to some extent) due to wave motion and

come to surface in a wide area. The area of dispersion will depend upon depth of pipeline,

current / sea roughness, weather etc. However, for modeling (60%) part of the leakage have

been considered as concentrated at one place and catch fire, The rate of leakage will depend

upon pipe line pressure, depth and opening size. Considering these key parameters four

scenarios /cases are envisaged.

7.3 Control Measures for Major Identified Hazards

The preventive control measures to prevent/avoid occurrence of hazardous stance are given

below:




a) Pipeline and Platform Installations-

i. Limit lifting to certain zones, sectors, areas-

• This reduces/eliminates the frequency effectively.

• Often used when lifting heavy objects as BOP on rigs.

• The rig is withdrawn from the area when lowering the BOP.

• For pipe loading onboard a lay-barge only the crane on the side furthest away

should be used when laying parallel to or crossing existing line.

ii. Limit the type of objects lifted in certain zones-

• For example, only the cranes away from the vulnerable area may lift heavy

objects.

• Or to not allow pipe loading onboard bay barge within platform safety zone.

• Reduces/eliminates the risk efficiently.

iii. Introduce safety distance-

• The activity is either planned performed in a safe distance away from the

pipeline or vice versa (e.g. anchor handling).

iv. Increase the protection-

• Increased protection will reduce the damage to the pipeline. Increased

protection may be obtained by a variety of solutions. It should be noted that

some solutions might introduce a very high risk to the pipeline during

installation, in addition also introduce scouring problem during the lifetime.

b) Blowout

Precaution against Blowout

The following control equipment for drilling mud system shall be installed and kept in use

during drilling operations to prevent the blowout:

i. A tank level indicator registering increase or reduction in the drilling mud volume and

shall include a visual and audio –warning device near the driller stand.

ii. A device to accurately measure the volume of mud required to keep the well filled at all

times.

iii. A gas detector or explosive meter at the primary shale shaker and connected to audible

or visual alarm near the driller stand.

iv. A device to ensure filling of well with mud when the string is being pulled out.

v. A control device near driller stand to close the mud pump when well kicks.

vi. Blowout prevention drill shall be carried out once every week near the well during

drilling.

vii. Suitable control valves shall be kept available near the well which can be used in case

of emergency to control the well.

viii. When running in or pulling out tubing, gate valve and tubing hanger shall be pre-

assembled and kept readily available at the well.

Precaution after Blowout

On appearance of any sign indicating the blowout of well, all persons, other than those whose

presence is deemed necessary for controlling blowout, shall be withdrawn from the location.

While controlling of blowout is in progress, the following precautions shall be taken:

i. A competent person shall be present on the spot throughout.

ii. An area within the 500 meters of the well on the down wind direction shall be

demarcated as danger zone.




iii. All electrical installations shall be de-energized.

iv. Approved safety lamps or torches shall only be used within the danger zone.

v. No naked light or vehicular traffic shall be permitted within the danger zone.

vi. A competent person shall ascertain the condition of ventilation and presence of gases

with an approved instrument as far as safety of persons is concerned.

vii. These shall be available at or near the place, two approved type of self-contained

breathing apparatus or any other breathing apparatus of approved type for use in an

emergency.

viii. Adequate firefighting equipment shall be kept readily available for immediate use.

c) Vessel Collisions

A Vessel Management Plan will be formulated and implemented to reduce collision risk, both

vessel–vessel and MODU–vessel and shall address the following:

i. Mandatory 500 m safety zone around well location

ii. Operational restrictions on visiting vessels in bad weather

iii. Defined vessel no-go areas within safety zone; and agreed approach procedures to rig by

supply and safety vessels

Evacuation plan in case of vessel collisions –

i. Launching the lifeboats by embarkation and lowering.

ii. Deploying the chutes and rafts, going down with the help of chutes followed by

transferring the people from platform to rafts.

iii. Attach the towing line of rafts to lifeboats and/or rescue boats.

iv. Sail away from abandoned vessel.

v. Wait for rescue.

vi. Further rescue depends on availability of Search and Rescue (SAR) appliances on the

location of evacuation zone, like MRCC boats, helicopters or passing (re-routed) ships.

d) Helicopter Crash

i. Air worthiness of helicopter to be checked by competent authority or before helicopter is

hired.

ii. AWEL should ensure that the pilot/pilots who will be operating have got appropriate

training on similar craft.

iii. Effective arrangements for coordination would be developed with air traffic control

room at Base port, as also in the MODU.

iv. Helicopter operations to be restricted during night time and during bad weather

conditions.

v. All employees who are supposed to travel on helicopters would be receiving basic

training on rescue and survival techniques in the case of a helicopter crash at sea.

LDAR program

Hydrocarbon industry in general and Natural gas producing and processing facility is highly

hazardous in nature due to the inflammable/explosive nature and also toxic nature (if H2S is

there in Natural gas). Some of the chemicals used are also hazardous. The proposed project is

using pipelines, vessels, compressors, pumps, valves and other fittings in the transfer and

processing of gas/fluid from offshore wells to the terminal. To reduce fugitive emissions

proper Leak Detection & Repair (LDAR) program is required.

The proposed LDAR program is as follows:




i. Identification of sources: Valves, pipes, joints, pump and compressors seals, flanges

etc.

ii. Monitoring of Gas/Volatile Organic Compound (VOC) is to be carried out regularly

through permanent Gas monitors at strategic locations and also portable gas detector.

Monitoring frequency should be once in a quarter is required.

iii. Focus should be for prevention of fugitive emissions by having preventive maintenance

of pumps, valves, pipelines etc. A preventive maintenance schedule should be prepared

and it should be strictly adhered to.

iv. When monitoring results indicate Gas/VOC above permissible limit repairing should be

done immediately. The repair should be conducted in such a way that there is no

fugitive emission from the particular component.

Fugitive Emission

The following guidelines for fugitive emissions should be strictly followed:

ix. Fugitive emissions over and around vessels and other machineries transfer areas etc.

should be monitored regularly.

x. Enclosures to chemical storage area should be provided.

xi. Vapor balancing, nitrogen blanketing, isolated tanks etc., should be provided. Special

care will be taken for odorous chemicals.

7.4 DISASTER MANAGEMENT PLAN AND EMERGENCY ACTION PLAN

For meeting the emergencies caused by major accidents, planning of response strategies are

termed as Disaster Management Plans (DMPs). It shall cater to the worst-case scenarios with

reference to specific cases like oil/chemical spillage, fire, explosion, natural calamities like

tsunamis, earthquakes, cyclones, etc. It shall include early detection of emergency commands

and coordination of response organizations along with trained personnel, availability of

required resources, emergency response actions, effective communication facilities and

training facilities to the personnel. DMPs cannot be considered in isolation or act as a

substitute for maintaining good safety standards in a plant. The best way to protect against

major accidents occurrence is by maintaining very high levels of safety standards.

Generally, the following five (5) phases are involved in an emergency:

i. Discovery and Notification: An event with an imminent threat of turning into an

accident must first be discovered and the discoverer quickly notifies the same to the

plant safety officer and also Duty Officer on shore.

ii. Evaluation and Accident Control Initiation: Based on the evaluation of available

information, the safety officer makes a rapid assessment of the severity of the likely

accident and initiates the best course of action.

iii. Containment and Counter Measures: Action is first taken to contain and control the

accident by eliminating the causes which may lead to the spread of accident. Measures

are also taken to minimize the damage to personnel, property and environment.

iv. Clean-up and Disposal: After the accident is effectively contained and controlled, the

clean-up of the site of the accident and safe disposal of waste generated due to the

accident are undertaken.

v. Documentation: All aspects of accidents, including the way it started and progressed as

well as the steps taken to contain and the extent of the damage and injury, must be

documented for subsequent analysis of accident for prevention in future, damage

estimation, insurance recovery and compensation payment. It may be noted that some




aspects of documentation, such as, photographs of the site of accident and main objects

involved in the accident, survey for damage estimation, etc. may have to be carried out

before the cleanup and disposal phase. However, the effort in all cases is to recommence

the production as soon as possible.

7.4.1 Emergency Classification

Severity of accident and its likely impact area will determine the level of emergency and the

DMP required for appropriate handling of an emergency. Emergency levels and the action

needed for each level are indicated below:

i. Level 1- Emergency: A local accident with a likely impact only to immediate

surroundings of accident site, such as, local fires and limited release of inflammable

material. The impact distance may not be more than 15 m from the site of primary

accident and may require evacuation of the drilling area where accident occurred and

utmost the adjacent drilling rig.

ii. Level 2- Emergency: A major accident with potential threats to life and property up to

500 m distance requiring the evacuation of all personnel from the threatened area except

the emergency response personnel. Large fires and release of large quantities of

inflammable materials may belong Level-2 emergency.

iii. Level 3- Emergency: An accident involving a very serious hazard and with likely impact

area is extending beyond the operational area limit of the exploration rig, such as, major

fire, large release of inflammable material and big explosion. Major fires will usually

have the triggering effect resulting in the propagation of explosion. In a Level-3

emergency, evacuation populations near the development well periphery (if near coast)

and alert the fishing and other vessels operating in nearby areas.

On-site Disaster Management Plan (DMP) will meet the hazards created due to all Level-1

emergencies and most of the Level-2 emergencies. In addition to on-site DMP, off-site DMP

may also have to be put into operation for some Level-2 and all Level-3 emergencies.

7.4.2 Emergency Action Plan

The emergency action plan for the proposed project is given below:

7.4.2.1 Instrumentation and Safety System

The main features of instrumentation on each well-head comprises of Platform Monitoring

and Safety systems installed in the E&I Room comprising of the following:

i. Programmable Logic Controller (PLC) based Remote Telemetry Unit (RTU) for platform

Monitoring

ii. PLC based Fire & Gas Detection System (FGS)

Shutdown Panel (SDP) for topside emergency shutdown (Subsurface Safety Valve (SSSV) -

hydraulic, SSV/ topside shutdown valves – Pneumatic). Flow Meter (Orifice Plate) at each

Flow Arm for Real Time Data measurement. Pressure and temperature measurement as

indicated in P&ID. All the Process Field Instruments installed for status Monitoring of the

platform to be connected to Platform Remote Telemetry Unit (RTU) via Field Junction

Boxes. All shutdown related Process Field Instruments & Valves i.e. SSV, SSSV, Shutdown

Valves, LL/ HH Pneumatic Pressure Switches to be connected to the Platform Shutdown

panel (SDP) which will initiate platform shutdown during emergency. Fire & Gas Devices to

be installed at Field to ensure safe operation of un-manned wellhead platform. These Fire &




Gas Devices at Field to be connected to Fire & Gas Detection System (FGS) via Field

Junction Boxes.

a. Remote Telemetry Unit (RTU)

RTU to be microprocessor based and to be composed of standard hardware and system

software, which can be configured to meet the stated requirements. RTU shall have redundant

Processor, Power supply and Communication modules, Simplex I/O Modules. The scan time

of the PLC to be 250 milli-seconds or better. The Programmable logic controller (PLC) to be

“Fault avoidant” and to be based on high-reliability, high-availability programmable

electronic systems.

b. Fire and Gas Detection System (FGS)

F&G PLC to be microprocessor based and to be composed of standard hardware and system

software, which can be configured to meet the stated requirements. F&G PLC shall have

redundant Processor, Power supply, I/O Modules and Communication modules. FGS system

to be SIL-3 Compliant with Technical Inspection Association (TUV) safety certificates. The

scan time of the PLC to be 250 milli-seconds or better. The PLC to be “Fault avoidant” and to

be based on high-reliability, high-availability programmable electronic systems.

Manual Emergency Shut-Down (ESD) loop is also installed around the platform to initiate a

Shutdown in event of fire. Once the Operator or any personnel on the platform have a visual

of the fire, he shall press the manual ESD button strategically located around the around the

platform. Pressure transmitter located inside SDP will monitor the status of the Manual ESD

loop and provide shutdown via low pressure set point.

Hydrocarbon Gas detectors to be installed at various locations of the Process facilities to

cover entire platform and to detect the Gas leak in process facility.

These gas detectors to be hardwired to F&G PLC and will provide an alarm or shutdown the

platform in event of gas detection. 2oo3 voting philosophy to be applied for Hydrocarbon Gas

detection and 1oo2 voting philosophy to be applied for Hydrogen Gas detection. Smoke

detector to be installed inside E&I Room & Battery room.

c. Shut Down Panel (SDP)/ Well-Head Control Panel (WHCP)

Shutdown Panel (SDP) for topside emergency shutdown (Subsurface Safety Valves (SSSV) -

hydraulic, Surface Safety Valves (SSV)/ topside shutdown valves – Pneumatic) to be

provided. The panel will be fitted with Gas driven hydraulic pumps to provide the hydraulic

power required to hold all SSSVs in the open position under normal conditions and to close

these valves in case of a process upset or emergency. Additionally, the SDP shall also provide

the Gas pressure to operate the SSV and the actuated shutdown valves.

d. High Integrity Pressure Protection System (HIPPS)

HIPPS PLC to be microprocessor based and to be composed of standard hardware and system

software, which can be configured to meet the stated requirements. HIPPS PLC shall have

redundant Processor, Power supply, I/O Modules and Communication modules. The

Complete HIPPS system to be SIL-3 Compliant with TUV safety certificates. The scan time

of the PLC to be 250 milli-seconds or better. The PLC to be “Fault avoidant” and to be based

on high-reliability, high-availability programmable electronic systems.

The basic function of the HIPPS system is to detect high-high pressure in the Production

header and to reliably & quickly isolate the source of the high pressure through closure of

Primary and Secondary shutdown valves and to send signals to the Remote Terminal Unit




(RTU) & SDP. HIPPS System shall conform to Safety Requirements Specification according

to IEC 61511/61508.

The system shall employ three independent channels capable of receiving individual 4-20mA

analog signals from field pressure transmitters. The independent channels to be processed and

voted via 2oo3 architecture. The 2oo3 design shall allow each individual channel to be tested

and maintained online without bypassing and to be hot swappable. The three HIPPS pressure

transmitters are managed and monitored in 2oo3 voting logic, so in case of two HH (high-

high pressure) threshold exceeded, the HIPPS system close both Primary and Secondary

shutdown valve. HIPPS System to be connected to the RTU via a serial link Modbus for

transmitting the signal pertaining to alarms and statuses. All the instruments installed on the

topsides to be as a minimum suitable for use in a Zone 2 Group IIA T3 environment.

e. Environmental Protection

Instrument equipment will have minimum degree of protection IP-65 and paint finish will be

proven to be suitable for long term service in an offshore tropical marine environment.

f. Power Supply

Components of power supply system to be of highest available quality for reliability and long

service life. Power supplies for all transmitters, controllers, signal converters, electric system

and components in shutdown system to be supplied from uninterruptible power supplies.

Power distribution to each consumer to be through proper, independent switch and fuse.

Protective fuses to be of indicating cartridge type mounted in fuse holders. In general, the

following Power Supplies to be used for instrumentation and Control: 24V DC +5% / -10%,

with Floating Earth/Unearthed except for RTU.

g. Instrument Air / Gas

Instrument air supply shall conform to ISA S7.0.01 “Quality Standard for Instrument Air”.

Each pneumatic instrument supply to be provided with independent filter regulator. For

pneumatic instruments, dry instrument gas/ air supply to be as follows:

• 5.5 Kg/cm2 (Minimum)

• 7.5 Kg/cm2 (Normal)

• 10.5 Kg/cm2 (Maximum)

h. Hydraulic Supply

Hydraulic fluid to be used on Wellhead as an actuating medium for SSSV. Hydraulic supply

to be derived from Shut Down Panel (SDP). The primary objective of the SDP is to supply

the required hydraulic fluid to the wellhead Christmas tree valves SSSV. SDP to be provided

with the following hydraulic pressure headers:

• Medium Pressure (MP) header: 350 Kg/Cm2 (Design)

• Consumer for MP: SSSV

7.4.2.2 Telecommunication System

To facilitate the platform for Voice, Data & Security surveillance the below

Telecommunication system are proposed for the project as below:

a. Very Small Aperture Terminals (VSAT) SYSTEM - (Voice and Data Communication)

b. CCTV SYSTEM - (Security Surveillance)

Over all Telecom scope consists of providing above listed Telecommunication systems and




subsystems located at wellhead platforms.

CCTV System

Unmanned Well head platform (WHP) will be equipped with CCTV camera for surveillance.

The Camera images to be transmitted to the VSAT Telecom Facilitator/operator through

VSAT system.

7.5 HEALTH, SAFETY AND ENVIRONMENT (HSE)

Platform to be provided with Fire and Gas detection system, safety of navigation aids, air

craft warning light, emergency shutdown stations etc. All emergency and shutdown system

to be designed fail safe. External walls of Temporary Shelter shall have fire rating H60 and

blast rating 0.2bar. Cold vent tip to be located based on radiation limit for ignited vent (4.7

kW/m2) and flammable gases concentration (50% LFL) at platform deck. HIPPS system

shall conform to Safety Requirements Specification and Process Safety Time according to

IEC 61511 and IEC 61508 requirements.

All Safety Instrument Systems to be SIL verified and validated. Proof test intervals, Mean

Time to restore etc. to be discussed with and approved by company before SIL verification.

Equipment noise shall not exceed 85 db (A) at 1m. Human Factors to be considered in

accessibility, valve handling, emergency switches / buttons, local indicators etc. Platform

model review to be performed using relevant and specific human factors checklist. All

design safety requirements in applicable legislations/regulations to be implemented. EPC

contractor shall implement recommendation in Environment Clearance and Environmental

Impact Assessment performed by others.

Life Saving Appliances (LSA) / Fire Safety Appliances (FSA)

Each platform to be provided with minimum following LSA / FSA.

• 10 kg DCP extinguishers

• 5kg CO2 extinguishers

• Wheeled 50 L AFFF – Cellar deck & Helideck

• Wheeled 50 kg DCP - Cellar deck

• Helideck to be provided with portable fire extinguishers and crash rescue kit as per

DGCA requirements

• Life Raft (2 Nos.) & Scramble net (2 nos.) – 10 Personnel capacity

• Life ring buoys – One at each side of all levels and boat landing

• Life jackets in cabinet and temporary shelter

• Wind Sock

• Stretcher, first-aid kit etc.

• Self-contained eye wash near chemical injection

• Life Saving Appliances shall comply with IMO LSA Code and Fire Extinguishers to

be UL/FM listed

• Fire extinguisher distribution shall meet NFPA 1 requirements

Emergency Evacuation

In the event of hydrocarbon leak or fire, personnel on-board will evacuate the platform via

boat landing on to a standby boat. Alternate means of evacuation will be life raft. In the event

of bad weather/storm, when evacuation is not possible, personnel will shelter in temporary

shelter.

88

PPRROOJJEECCTT BBEENNEEFFIITTSS




2. PROJECT BENEFITS

8.1 PROJECT BENEFITS

As per a report published by FICCI, India is the fifth largest energy consumer in the world.

While the world consumes 12000 million tonnes of oil equivalent (mtoe) of energy resources,

India consumes 4.4% of the world total (524.2 mtoe).

Of the total primary energy consumption basket, oil and gas constitute 45% share in the total

energy basket mix. About 78 per cent of India’s petroleum consumption is met from imports

(mostly of crude oil), while about 25% of natural gas (including LNG) consumption comes

from imports. It is estimated that in the coming years, the import dependency for crude oil

alone would reach above 90% level.

Thus, Development of existing oil reserves has become a necessity to bridge the rising

demand-supply gap, reduce import dependency and make ourselves resilient to the external

factors of economic and political disruptions in the sourcing nations.

88

99


CCOOSSTT AANNDD BBEENNEEFFIITT

AANNAALLYYSSIISS




ENVIRONMENTAL COST AND

BENEFIT ANALYSIS

This chapter aims to integrate economic and environmental consideration in decision making.

In general, the cost-benefit aspect of the project is analysed to weigh the costs of proceeding

with proposed development of B-9 cluster to produce natural gas and crude oil against the

benefits that would arise from it.

9.1 PROJECT COST

9.1.1 Economic Cost of Project

The economic cost of the project includes construction and operational cost of the B-9 cluster field

along with the cost for environmental mitigation and monitoring. As already mentioned, the project

will include following activities

• Drilling and completion of 12 Wells out of which 7 wells are in B-9 field, 3 wells in B-7 &

2 wells in BRC fields.

• Installation of two (2) wellhead platforms in B-9 area, and one (1) platform each in B-7 &

BRC areas. Alternately, sub-sea completion wells may also be explored during the design

stage.

• Laying of approximately 80 km sub-sea pipeline (upto 10”) from B-9 field to a nearby

operator’s existing well head platform and hooking-up with the offshore platform facilities.

• Laying of approximately 10 km intra-field sub-sea pipeline (upto 8”) within the B-9 area

and hooking-up with the existing offshore facilities.

• Laying of approximately 30 km sub-sea pipeline (upto 8”) from B-7 platform/area to B-9

platforms /area and hooking-up with the platform facilities.

• Laying of approximately 10 km sub-sea pipeline (upto 6”) from BRC platform/area to B-7

platform /area or B-9 platforms/area and hooking-up with the platform facilities.

The total estimated cost for the development of B-9 cluster is INR 1600 Crores (US$ 250 million).

Further, the cost of EMP implementation during drilling, installation and operation phase is

INR 1,88,00,000(Capital cost and Recurring Cost) and is summarized in Table 10.4 of chapter

10.

9.1.2 Environmental Cost of Project

All development projects are associated with the adverse change in the environment (physical,

biological and social). Likewise, the present project will also have some adverse impact on the

Environment during the installation and operation phase which can be reduced with implementation

of mitigation measures.

• Change in Air Quality: Emission of pollutants from activities such as engines, DG set,

transportation vessels, emergency venting, gas flaring etc.

• Impact on Noise and Vibration: There will be temporary impact on marine fauna due to use of

large machineries and equipment’s and during the operation of wellhead platforms and

9




intermittent movement of helicopters and vessels.

• Impact on Marine Water Quality: Chemical changes in water quality such as decrease in pH

increase in BOD, increase in turbidity etc.

• Impact on Sediment Quality: Temporary suspension of sediments and changes is sea-bed

morphology. Further, the sediment quality may be affected due to accidental spillage of fuels,

chemicals.

• Marine Biology: Physical hinderance to marine organism, habitat loss, destruction of benthic

zone etc.

• Impact on Worker’s Health and Safety: The impact on Worker’s health is mainly from

emissions of pollutants, noise from heavy equipment and truck traffic, hazardous materials and

oil spills, physical injuries etc.

• Impact due to Waste Generation: Improper disposal of waste will have adverse effect on water

and marine biodiversity.

The proper mitigation measures will be applied in both installation and operation phase to reduce the

impact in the environment. The proposed mitigation measures cost is around INR 1,50,00,000. For

effective implementation of the mitigation measures, there will be recurring cost of the project around

INR 38,00,000. The total cost of the mitigation measures and recurring cost is INR 1,88,00,000 (refer

Table 10.4 of Chapter 10)

9.2 PROJECT BENEFIT

India is the fifth largest energy consumer in the world as per report published by FICCI. India

consumes around 4.4% (524.2 mtoe) of the 12000 million tonnes of oil equivalent (mtoe) of

energy resources being consumed by the world.

The oil and gas sector in India constitute 45% share in the total energy basket mix. About 78%

of India’s petroleum consumptions is met from Imports (mostly crude oil) which is expected to

rise to 90% in coming years, while about 25% of natural gas (including LNG) consumptions

comes from imports. The proposed project can provide following benefits

• It will help in bridging the gap between demand and supply of oil and gas sector in India.

• It will reduce India’s dependency on other countries for oil and gas thereby making India

resilient to external factors of economic and political disruptions in the sourcing nations.

1100


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1. ENVIRONMENTAL

MANAGEMENT PLAN

10.1 STRUCTURE OF EMP

Environmental Management Plan (EMP) is the key to ensure a safe and clean environment. The

desired results from the environmental mitigation measures proposed in the project may not be

obtained without a management plan to assure its proper implementation and function. The

EMP envisages the plans for the proper implementation of mitigation measures to reduce the

adverse impacts arising out of the project activities. EMP has been prepared addressing the

issues like:

• Pollution control/mitigation measures for abatement of the undesirable impacts caused

during the drilling and installation and operation stages.

• Details of management plans.

• Post project environmental monitoring programme to be undertaken (Chapter 5).

• Expenditures for environmental protection measures and budget for EMP.

10.2 PROPOSED ENVIRONMENTAL MITIGATION MEASURES

The details of the impacts resulting due to different activities during drilling and operation phases

are given in Chapter 4. Based on these mitigation measures Environmental Management Plan

(EMP) is drafted. The environmental mitigation measures for construction and operation phases

are briefly listed in Table 10.1.

Table 10.1: Proposed Environmental Mitigation Measures

S.

No. Component Impact Mitigation Measures Responsibilities

Drilling and Installation Phase

1. Marine

Water

Quality

• Displacement of sea-bed

sediments may lead to

anoxic intertidal and

offshore mud, leading to

the local chemical

changes in water quality.

• Water quality may be

affected by the

solid/liquid discharge

and accidental spillage

of chemicals.

• The sewage shall be

treated on-board of the

rig according to the

MARPOL Regulations.

Residual chlorine of the

treated sewage shall not

exceed 1mg/L before

disposal.

• Occupier

(Environment)

• Deputy

Management

Representative

(Environment).

2. Marine

Sediment

• Activities like

deployment of rigs and

other sub-sea

infrastructure may

cause local and





10




S.


temporary disturbance

to the sea-bed.


hazards.

3. Marine

Ecology

• Adverse impact on

marine life due to

drilling activity, noise

generation, effluent

discharge.


measures shall be

adopted to minimize

disturbance to the


deployment and


wells.

4. Air

Environment

• NOx, PM₁₀, and SOx

emissions from venting,

flaring and D.G. Sets.

• Good operational

controls and high level

of monitoring shall be

built into the design

operations.

• Regular maintenance of

engines and DG sets

shall be ensured.

• The existing and

proposed DG sets shall

comply with the

applicable emission

norms.

5. Noise

Environment

• Noise and Vibrations

from the heavy

machineries - large

power generation units,

diesel engines, fluid

pumps and mud pumps,

equipment and

transportation vehicles.

• Mobile noise sources

such as rig, and vessels

shall be re-routed to

avoid disturbances.

• Avoid loud, sudden

noises, wherever

possible. Integral noise

shielding shall be used

where practicable and

applicable.

6. Occupational

Health and

Safety

• Respiratory disease due

to inhalation of dust

• Auditory ailment due to

noise



fire hazards, etc.

• The use of personal

protective equipment

like ear muffs and dust

mask shall be made

stringent

• Water sprinkling

system for fugitive dust

generating areas


workers

• Regular health check-

ups for workers/

employees




S.


Operation Phase

1. Marine

Water

• The water quality of the

project site may get

affected due to


chemicals/oil/lubricants

from the routine


• Usage of only low

toxicity chemicals

must be ensured on-

board of the rig and


• Adequate well

management shall be

ensured during well

completion activities to

minimize produced

water production

• Occupier

(Environment)

• Deputy

Management

Representative

(Environment)

2. Marine

Sediment

• Sediment quality is less

likely to be affected due

to operational

discharges and


fuel/chemical/lubricant

during the routine







hazards

3. Marine

Ecology

• Sub-sea infrastructure

shall act as a physical

hindrance to the marine

organisms leading to

direct habitat loss

• The operational

activities are also likely

to have an impact on the

benthos in the benthic

zone


measures shall be

adopted to minimize

disturbance to the


deployment and


wells.

4. Air • Air emissions may

result from gas flaring

activities during the

well testing only (1-2

days).


of the transportation

vessels

• Regular ambient air

quality monitoring

must be carried out.

5. Noise and

Vibration

• Noise is likely to be

generated during the

operation phase due to

the operation of rigs,

generators, etc.

• Rubber padding/noise

isolators shall be

provided at

equipment/machineries


of all equipment and


shall be ensured




S.


6. Occupational

Health and

Safety



fire hazards, etc.

• Strict enforcement of

PPEs on workers/

employees


workers

• Cordoning of

hazardous areas as ‘No

Smoking Zone’

• Bi-annual or annual

health check-up camps

for workers/ employees

10.3 ENVIRONMENTAL MANAGEMENT PLAN

The Environmental Management Plan is prepared to facilitate the field level implementations.

This plan needs to be well implemented during drilling and installation as well as operation

phases of the project. The mitigation management matrix is given in Table 10.2, wherein the

impacts of the project activities are mentioned along with the actions required for effective

environmental management.



Table 10.2: Environmental Management Plan - Mitigation Management Matrix (during Drilling Phase)

Hazards and Effects Proposed Mitigation Required Action

Wastewater and Effluent

Management

• Sewage will be treated on-board the rig. Residual

chlorine of the treated sewage will not exceed 1mg/L

before disposal.

• Drilling, wash water and oily water will be treated to

conform to limits notified as per MARPOL

Regulations, before disposal into sea. The treated

effluent will be monitored regularly.

• WBM or SOBM (to be used in special case only)

will be disposed off as per G.S.R. 546 (E); dated

30/08/05,

• Thoroughly washed the drill cuttings separated from

WBM and unusable portion of WBM having toxicity

of 96 hr LC50 Value> 30,000 mg/L will be

discharged offshore into sea intermittently, at an

average rate of 50 bbl/hr/well from a platform so as

to have proper dilution and dispersion without any

adverse impact on marine environment.

• Unusable portion of SOBM will not be discharged

into sea and shall be bought to onshore for treatment

and disposal in an impervious waste disposal pit.

• Treatment of sewage will be ensured as per

MARPOL regulations.

• It will be ensured that oil content of the effluent

without dilution will not exceed 40 ppm.

• In special case of use of SOBM, low toxicity OBM

should have aromatic content <1 % will be used.

• It will be ensured that the toxicity of the chemical

additive used in WBM/ SOBM is biodegradable

and have toxicity of 96 hr LC50 Value > 30,000

mg/L as per mysid toxicity or toxicity test

conducted on locally available sensitive sea

species.

• It will be ensured that Oil drilling operators record

the daily discharge of drilling fluid, monitor the

effluent quality and submit the compliance report

once in every six months to MoEF.

Fuels, Lubricants and

Chemicals Management

• Oil Spill Contingency Plan (OSCP)-(as given in

section 8.3.2) will be implemented to handle all

major, moderate and minor spills.

• Suitable delivery vessels will be used.

• Oil drip pans will be used wherever there is

significant potential for leakage.

• All spills/leaks will be reported and cleaned up

• Implementation of OSCP will be ensured.

• Casing should be ensured to prevent leakage.

• Delivery vessels will be checked for their

suitability & ensured that they meet safety

requirements.

• Oil drip pans will be made available.




immediately.

Noise • Regular maintenance of all equipment’s and pumps

will be ensured.

• Good working practices will be implemented to

minimize noise.

• Noise mitigation measures such as acoustic

enclosure (rubber padding/noise isolator) will be

provided to operating machines; and engines will be

provided with mufflers.

• Personal protective equipment will be provided to

the workers exposed to prolonged noise levels.

• Equipment log books will be maintained.

• It will be ensured that no machinery is working

when not in use.

• Enclosures will be ensured around the noise

• generating sources where the noise levels exceed

the permissible admissible limits.

• Generator sets will be installed in compliance with

the MoEF norms.

• Installation of acoustic enclosure at drilling site

will be ensured as per the norms notified by

MoEF.

• Sufficient quantity of Personal Protective

Equipment will be made available.

Air Emissions • All equipment’s will be operated within specified

design parameters.

• High efficiency generator sets will be provided

with adequate stack height and modern emission

control equipment’s. Emission can be minimized

further by use of low sulphur diesel (i.e. present

sulphur content of HSD utilized is 50 ppm).

• Regular maintenance of the transportation vessels

to be ensured to minimize level of emission in the

environment.

• Regular ambient air quality monitoring must be

carried out according to the specified norms

• Measures will be taken to minimize emissions

during gas flaring.

• Follow up of preventive and scheduled

maintenance of all the equipments as per the

procedures given by OEM will be ensured.

• It will be ensured that stacks/vents height will be

provided as per CPCB/SPCB norms.

• Efficient flare system designs will be ensured.




Solid Wastes

• Non-Hazardous Wastes

includes organic wastes

from kitchen, scrap metal,

waste oil & surplus

chemicals, sacks, broken

wooden pallets.

• Hazardous waste

including drill cuttings

from drilling activities.

• Proper documentation and manifestation of all

wastes generated will be ensured.

• Litter and debris will not be discarded to sea and will

be segregated before transferring to onshore base for

final disposal.

• Biodegradable waste at the drilling site will be

collected and transferred to onshore base for its

treatment.

• Material such as scrap metal, waste oil & surplus

chemicals will be disposed off in a controlled

manner through authorized waste contractors.

• Drill cuttings generated during drilling operations

will be separated from WBM followed by its

discharge (as per G.S.R. 546 (E), dated 30/08/05).

• Pre-operation inspections will be conducted to

ensure that waste disposal facilities are in place,

• Provision for on-site waste segregation will be

made by providing appropriate bins for different

waste categories.

• Biodegradable waste can be used for composting.

• Arrangements for proper disposal and waste

recycling contractors will be ensured.

• It will be ensured that no drill cuttings (of any

composition) are discharged in sensitive areas as

notified by MoEF.

Non-routine events and

accidental releases (Well

kicks, blow out)

• State of readiness will be maintained for quick

response including plan awareness, training and

regular exercises.

• Risk of loss of well control will be minimized by

▪ Proper well design, which will ensure that the

hydrostatic weight of mud will overcome

formation pressure.

▪ Proper drilling program design to ensure

selection of properly rated blow out preventer

equipment.

▪ Ensuring that the supervision team & Rig

contractor’s relevant operating personnel are

trained to handle well control situations and hold

relevant well control training certificates.

• Records of interaction between the management

and the work force and records of training and

drills will be maintained.

• It will be ensured that all available offset data is

examined for proper design parameters.

• Same as above

• Same as above

• Provisions for well monitoring equipment to

detect influx from reservoir and Pressure detection

service will be ensured.

• It will be ensured that Blowout preventers are

regularly tested as per SOP.

• It will be ensured that spills are reported and

cleared immediately.




▪ Ensuring advanced detection system is in place

and BOP equipment is well maintained.

• Spill Response (for all spills). Spill kits (comprising

adsorbents; approved containers for storage and

transport of spill wastes, disposable bags,

gloves/goggles, etc.) will be made available on the

drill site to handle spills.

Ecological Impacts • Waste management plan will be implemented to

mitigate adverse impacts on the marine

environment.

• Intimation to the Fisheries Department in case of any

unusual phenomenon observed.

• Intimation to the Fisheries Department and/or Forest

Department in case any deceased aquatic species is

observed on the sea surface or any behavioural

change observed in the avi-fauna.

• Formulation and implementation of waste

management plan (as described in section 8.2) will

be ensured.

• Visual observations of the aquatic flora & fauna

will be done through the rig and surveillance

vessels.

• Same as above.

Socio-Economic Impacts • Local people will be provided temporary

employment during the project activities at supply

base.

• Record of nature job/work will be maintained at

supply base office.




10.3.1 WASTE MANAGEMENT PLAN

The waste management plan is framed which will be subject to fine tuning depending on site

conditions related to waste handling and disposal. This Waste management plan is as presented

below in Table 10.3.

Table 10.3: Waste Management Plan

Waste Category Waste Type Proposed Action

Domestic Waste Sewage • Sewage will be treated on-board of the rig

as per MARPOL regulations. Residual

chlorine of the treated sewage will not

exceed 1mg/L before disposal.

Kitchen Waste • Biodegradable waste from kitchen,

laundries and galleys will be collected,

segregated, stored in containers and will be

transported onshore and used for

composting.

Combustible

Waste (Paper,

Rags, Packing

Material).

• Waste will be properly segregated (plastics,

metal, glass) and transported to onshore

base for sale to recycling contractor.

Recyclable Wastes Tin packs, plastic

and glass bottles

and other metallic

materials

• Waste will be properly segregated and

temporarily stored at onshore segregation

pit. The waste will then be delivered to

approved recycling contractor.

Non-Hazardous

Wastes

Drill Cuttings • Cuttings free from WBM will be discharged

offshore (as per G.S.R. 546 (E), dated

30/08/05) into sea intermittently, at an

average rate of 50 bbl/hr/well from a

platform so as to have proper dilution and

dispersion without any adverse impact on

marine environment.

• In case of drill cuttings associated with high

oil content from hydrocarbon bearing

formation, then it should be ensured that

disposal of DC does not have oil content >

10 gm/kg.

Water Based

Drilling Mud

(WBM).

• As per G.S.R. 546 (E), dated 30/08/05,

WBM/SOBM (is used in special case) will

be recycled to the maximum extent.

Unusable portion of WBM/SOBM (toxicity

of 96 hr LC50 Value > 30,000 mg/L) will be

discharged offshore into sea intermittently,

at an average rate of 50 bbl/hr/well from a

platform so as to have proper dilution and




Waste Category Waste Type Proposed Action

dispersion without any adverse impact on

marine environment.

Drilling & Wash

Wastewater

• Drilling and wash water will be treated to

conform to limits notified under

Environment Protection Act, 1986, before

disposal into sea. The treated effluent will

be monitored regularly.

Hazardous Waste Used Oil • Used oil will be collected in the designated

containers. Vessels will be safely

transported to onshore and sent to the

approved recycling contractor for its

disposal as per the norms notified by MoEF.

10.3.2 OIL SPILL CONTINGENCY PLAN (OSCP)

An effective response to oil spill is dependent on the extent of the preparedness of the

organisation and the people involved. The objectives of the plan are:

• To develop appropriate and effective systems for the detection and reporting of spillage of

oil.

• To ensure prompt response to prevent, control, and combat oil pollution.

• To ensure that adequate protection is provided to the public health and welfare, and the

marine environment.

• To ensure that appropriate response techniques are employed to prevent, control, and

combat oil pollution, and dispose off recovered material in an environmentally accepted

manner.

• To ensure that complete and accurate records are maintained of all expenditure to facilitate

cost of recovery.

An effective oil spill contingency plan should comprise four components:

a. Risk Assessment – To determine the risk of spills and expected consequences,

b. Strategic Policy – Defining roles and responsibilities, and providing summary of the

rationale for operations,

c. Operational Procedures – Establishing procedures when spill occurs,

d. Information Directory – Collating support data.

While deciding the plan, it is equally important to take decisions on waste storage and options

for treatment, disposal or reuse of waste, keeping in mind the environmental considerations and

legal requisites. The Plan should include procedures for mobilizing the logistic support

necessary for effective clean up, e.g. distribution of PPE and food for response team, adequate

fuel for machinery and transport facility for labour, equipment and recovered wastes.

The Contingency Plan must also focus on timetable for exercises and training for all levels

including marine and shoreline response teams and other interested parties. This will help in

ensuring that contingency arrangements are in place and personnel have clear understanding of

their responsibilities.




Information that should be included in immediate response strategy includes:

a. Actions required to be undertaken by the observer of an incident/the person that identifies

that an incident has occurred.

b. Process for informing other site personnel (identifying various site roles).

c. Lines of communication and contact information (i.e. contact phone numbers, radio call

protocol, etc.).

d. Steps to identify the most appropriate response strategy/strategies.

The Environmental Officer/Coordinator will be responsible for designing an appropriate post

spill environmental monitoring program.

The Final Oil Spill Report should describe the following:

i. Name, location, organization, and telephone number,

ii. Name and address of the party responsible for the incident; or name of the carrier or

vessel, or other identifying information,

iii. Date and time of the incident,

iv. Location of the incident,

v. Source and cause of the release or spill,

vi. Types of material(s) released or spilled,

vii. Quantity of materials released or spilled,

viii. Medium (e.g. land, water) affected by release or spill,

ix. Danger or threat posed by the release or spill,

x. Number and types of injuries or fatalities (if any),

xi. Weather conditions at the incident location,

xii. Whether an evacuation has occurred,

xiii. Other agencies notified or about to be notified,

xiv. Any other information that may help emergency personnel respond to the incident.

10.4 CAPITAL AND RECURRING COST FOR POLLUTION CONTROL MEASURES

The cost for the EMP implementation during drilling and installation and operation phase is

given in Table 10.4.

Table 10.4: Environmental Budget

S.

No. Pollution Control Measures

Capital Cost

(in INR Lakh)

Recurring Cost

(in INR Lakh)

1 Fuel, Lubricant and Chemical

Management

35,000,000 5,00,000

2 Air emission mitigation

Maintenance of D.G. sets.

3,00,000

3 Noise Mitigation

Acoustic enclosure and Personal

Protective Equipments.

Maintenance cost of equipments.

50,00,000

3,00,000

4 Drilling Waste Management. 65,00,000 10,00,000

5 Environmental Monitoring Plan. 17,00,000

Total Cost 1,50,00,000 38,00,000




10.5 ENVIRONMENTAL AWARENESS TRAINING

Environmental Awareness training will help to ensure that the requirements of the EMP are

clearly understood and followed by all project personnel throughout the project period. The

primary responsibility for providing training as per HSE policy to all project personnel will be

that of the HSE Officer. The HSE policy includes following guidelines:

• We are committed to maintain highest standards of occupational health, safety and

environment protection.

• We will comply with all applicable codes and requirements to promote occupational health,

safety and environment protection.

• We will be always alert, equipped and ready to respond to emergencies.

• We will take all actions necessary to protect the integrity of the system in order to avoid

accidental release of hazardous substances.

• We will enhance awareness and involvement in promotion of Occupational health, safety

and environment protection wherever we work and reside.

10.6 ENVIRONMENT MANAGEMENT CELL

An Environment Management Cell (EMC) will be formed, which will be responsible for

implementation of the aforesaid project monitoring/management plans. The composition of the

Environment Management Cell and responsibilities of its various members are given in Table

10.5.

Table 10.5: Environment Management Cell

S.

No.

Designation Proposed Responsibility

1. Occupier

(Environment)

Policy decisions and overall responsibility with respect

to implementation of the EMP.

2. Deputy Management

Representative

(Environment)

• Responsible for management and implementation of

EMP.

• Day to day monitoring of the implementation of EMP.

1111

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SUMMARY AND

CONCLUSION

11.1 INTRODUCTION

Adani Welspun Exploration Limited (AWEL) has been awarded the Offshore Contract Area

MB/OSDSF/B9/DSF (B-9) Cluster and has signed the Revenue Sharing Contract (RSC) with

the Government of India. AWEL intends to fast-track the project to produce the ‘first-gas’

from the field at the earliest.

The contract area MB/OSDSF/B9/2016 comprises of three (3) Discovered Small Fields (B-9,

B-7 and BRC), located in the Mumbai Offshore Basin. While B-9 & B-7 are Gas Fields, BRC

is an Oil Field. Well-Head platforms are aimed to be minimum facilities platforms which will

be unmanned with periodical visits through helicopter to conduct routine maintenance, well

maintenance and any other related repair work.

11.2 SUMMARY


fields of 183.23 sq.km at Mumbai Offshore Basin. The EIA study for the proposed project

includes establishment of the present environmental scenario in the proposed project area.

EIA report consists of study of the specific activities related to the project and evaluation of

the probable environmental impacts, thus leading to the recommendations of necessary

mitigation measures. The entire EIA study has been carried out on the basis of the applicable

environmental legislation, regulations and guidelines of the MoEF&CC.

In the drilling and installation phase of the project the barges & vessel movement, pipe-laying

works and operating of generators will have maximum impact, especially on air, noise,

vibration and ecological environment. Water quality and geology/soil will be affected due to

the discharge of wastewater (construction and domestic) and leakage of oil etc; from

generators and other equipments. On the other hand, during the operation phase; usage of

maintenance & cleaning chemicals and risk of gas leakages will affect the water, air, noise

and biological environment. With respect to occupational health, impacts are anticipated on

the health of the employees during operation phase. Personnel working near the noise

generating machines, DG sets and handling of chemicals and lubricants are more susceptible

of getting health hazards.

However, all these impacts can be overcome with the mitigation measures proposed in

Chapter 4 and EMP. Overall, this project will bring economic benefits, increase energy

security of the country and generate employment opportunities.

11.3 CONCLUSION

From the Environmental Impact Assessment study, it can be concluded that this project under

consideration will not have any major significant negative impacts with the mitigation

measures are effectively and timely complied to. The measures must be followed by the strict

implementation of Environmental Management Plan and Environmental Monitoring Plan.

1111

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DDIISSCCLLOOSSUURREE OOFF

CCOONNSSUULLTTAANNTTSS




DISCLOSURE OF

CONSULTANTS ENGAGED

12.1 INTRODUCTION

Asian Consulting Engineers Pvt. Ltd. (ACE) is an independent consulting company in the

field of water and environment engineering with its headquarters located in New Delhi, India.

ACE provides consulting services and sustainable solutions for infrastructure projects (roads,

railways, ports, hydropower, water resources and other urban infrastructural plan outs),

industrial projects (refineries, petrochemicals, gas pipelines, offshore and onshore oil & gas

exploration, fertilizers, steel plants, power plants, textiles, hotels, distilleries and tanneries)

and social development projects.

ACE is committed to provide consultancy services of international quality at local costs to

suit its client’s requirements. ACE believes that the key to success is the ability to work

effectively with clients to understand, define, and resolve their environmental concerns. ACE

offers technical talent, specialized expertise, physical resources, and requisite facilities that

are important in responding to water and environmental issues, the world faces today. The

quality of work and timely completion of project are of paramount importance in each

assignment that ACE undertakes.

We, at ACE, know what makes for a successful project. Clients turn to ACE because

• We understand the issue at hand.

• Have the required experience and expertise to develop unique solutions.

• Complete work on time and within budget.

• Work towards client satisfaction as our ultimate goal.

ACE offers this combination of quality and performance through its professionals, managers

and support personnel. Our people are equipped with state-of-the-art technologies and they

are motivated to implement the project to the satisfaction of the client.

12.2 QUALITY OF SERVICES

ACE is committed to providing a high-quality consultancy service. As a recognition of same,

ACE has been awarded ISO 9001:2015 certification by RINA, to provide consultancy

services for Water Supply, Waste Water Treatment, Municipal Solid Waste Management,

Environment and Social Impact Assessment, Environment Impact and Audit, Remote Sensing

and Geographical Information Systems. In addition to this, ACE is also accredited with

Quality Council of India (QCI) (Certificate No.: NABET/EIA/1417/SA030) for preparation of

EIA of Onshore and Offshore Oil and Gas Exploration and Development and Transportation

of Oil and Gas through Pipelines (Category A).

12.3 AREA OF SPECIALIZATION

• Environmental Management,

• Water Resources Engineering,

• Water Supply,

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• Wastewater Management,

• Urban Environment Improvement,

• Social Development,

• GIS and Remote Sensing.

12.4 RESOURCES

Panel of Experts

ACE has experts in the following specialized areas:

• Water supply engineering,

• Water resources engineering,

• Wastewater engineering,

• Solid waste management,

• Public Health and Sanitation,

• Environmental Management,

• Forestry and Wildlife,

• Environmental modeling,

• Fisheries,

• Aquaculture,

• Social development.

Infrastructural Resources

Following facilities are available with ACE:

• Air quality models,

• Noise quality models,

• Water quality models,

• Water distribution analysis software,

• Sewer network analysis software.

Software Availability

• AERMOD,

• CALINE 4,

• ERDAS Imagine,

• Arc GIS,

• AutoCAD,

• Map Info.