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PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03.1.

CDM – Executive Board page 1

CLEAN DEVELOPMENT MECHANISM

PROJECT DESIGN DOCUMENT FORM (CDM-PDD)

Version 03 - in effect as of: 28 July 2006

CONTENTS

A. General description of project activity

B. Application of a baseline and monitoring methodology

C. Duration of the project activity / crediting period

D. Environmental impacts

E. Stakeholders’ comments

Annexes

Annex 1: Contact information on participants in the project activity

Annex 2: Information regarding public funding

Annex 3: Baseline information

Annex 4: Monitoring plan





SECTION A. General description of project activity

A.1 Title of the project activity:

Waste gas utilisation for steam and power generation at RIL Jamnagar refinery

Version : 03Date : 19/10/2006

A.2. Description of the project activity:

>>

Reliance Industries Limited - Jamnagar is a fully integrated manufacturing complex comprising of a

petroleum refinery complex, a petrochemical complex, a power generation complex, and a port &

terminal complex along with the associated pipeline network. The refinery, of Crude is the world’s largest

grass root refinery. The design of the refinery as well as various process units within the complex is by

world’s leading technology suppliers viz. UOP & Linde etc.

RIL-Jamnagar is consciously working in the field of energy conservation and management to reduce

Green House Gas emission. In recognition of its effort, contribution and success, RIL-Jamnagar is

recipient of National Energy Conservation Awards by Ministry of Power, Government of India,

Confederation of Indian Industries, Petroleum Conservation Research Association etc.

The project activity involves efforts to reduce GHG emission through recovery of waste gases flared in

the refinery. Thus the aim of project activity was to systematically study the flare system, identify the

potential to reduce flaring and implement the schemes to reduce the flared gases.

The study involved stepwise analysis of all major streams joining the flare header. It consisted of

following steps :

• Review the conditions in Process Equipment to minimize flare control valve openings

• Identify leaky valves continuously and fix them

• Consider a flare gas recovery system.

Having worked on first two methods and minimizing the flare loss, it became apparent that further

reduction of flare loss is possible by going for a suitable and well designed flare gas recovery system. The

flare gas recovery System is known to be operative in some refineries internationally, while not working

properly at some other places. A detailed technical study and hydrocarbon balance with the help of

simulations resulted into proposals to management for four projects for flare gas recovery. Due to the lack

of experience and risk involved, the project proposals were not approved for a long period of time. Only





when the incentive of CDM revenue along with other intangible benefits was taken into consideration, the

project proposals were approved. Various systems installed for flare gas recovery are explained below :

Measure I : Main Flare Gas Recovery

The Flare Gas Recovery System (FGRS) is a skid-mounted package consisting mainly of two

compressors which take suction from the flare gas header upstream of the Liquid Seal Drum, compresses

the gas and cools it for reuse in the Refinery Fuel Gas system.

FGRS is located downstream of knockout drums as all flare gases from various units in the refinery is

available at this single point. It is located just upstream of the seal drums as pressure control at the

suction to compressor will be maintained precisely, by keeping increased height of water column in the

drum.

The flare gas enters the compressors at 1.1 bara and 380°C. A continuous recirculating flow of process

water enters the compressors for compression, sealing and cooling of gas. After leaving the compressors

the gas, water and hydrocarbons mixture runs into the horizontal Gas/Liquid separator where the

compressed gas is separated from the water and condensed hydrocarbons by gravity due to lower gas

speed. The separated flare gas runs through demister before leaving the G/L separator in order to have

minimum water and condensed hydrocarbons content in the outlet gas stream and leaves from the top.

Measure II : Low Low Pressure (LLP) Flare gas Recovery

Delayed Coker at Reliance is the worlds largest coker operating at ultra low recycle and low drum

pressures aimed at maximizing distillate potential and reduced coke make for a given feed. Coking

operation is a semi batch process, which involves various sequential activities between coking and





decoking cycle. One such activity is steaming of hydrocarbons from the coke drum to the blowdown

drum. This low-pressure coker operation forces the lighter fractions (non condensable) of hydrocarbons

from the blowdown system to be flared (LLP Flare). Several ideas were brainstormed to recover the

blowdown gases into the gas plant and ultimately an ejector system was commissioned to recover these

flare gases and make the worlds largest coker as a zero flaring coker.

A flare gas recovery system (FGRS) was designed and installed. This system recovers almost 43 Tonnes

per day of flare gases from coker. This also helped achieve a 95% reduction in Sox levels from flare.

The LLP Flare gas recovery system is as shown in the schematic (figure1). The flare gas from the

blowdown system is collected at the common flare knock out drum from where the gases are recovered

with the help of ejectors. The ejector system is a combination of four ejectors of equal capacity in

parallel. Medium pressure steam is used as a motive fluid and the flare gas are compressed to 0.9 Kg/cm2

(g) and is routed to the main fractionator overhead condenser receiver vessel after cooling. A water seal

pot is designed to create a system backpressure of 0.25 Kg/cm2 (g) at 70% level. This system has been

functional effectively with its unique control philosophy to minimize steam consumption. The ejector

motive steam is automatically switched on and off to control the suction pressure of the blowdown gases

at the ejector based on the requirement. The control philosophy takes care of inherent fluctuations in

coker automatically and needs no manual intervention at any point of time.

Flare gas seal

pot

Gas

KO A B C D

Close drain

A B

LLP

Close

Drain

FGBack-up PV

A33A

PVA34

PVA33B

XV061

XV062

XV06 3 XV06

4

XV065

XV066

XV06 7 XV06

8

PTA34

PSV A39

CWR Recovered gas to main

fractionator overhead

receiver vessel

A33

MP Motive steam

B/D settling

FractionatorO/H Receiver

Outlet of

Main ovhd

condensers

To

Compressor

Gas from B/D

O/H condenser

Gas from B/D O/H

PT 796

Flare gas

condenser

B/D settling

Outlet of

Main ovhd

condensers

CWS

Figure 1





The trends (Figure 2) analyses the period with and with out FGRS system in coker. These trends indicate

the quantity of gases generated from blowdown system and the impact of FGRS on the quantity of

hydrocarbon being flared.

Sustainable development :Reliance Group is a socially responsible company and has taken following initiatives:

• Educational Initiatives.

o Dhirubhai Ambani Institute of Information and Communication Technology (DA-IICT),

Gandhinagar, India

o Dhirubhai Ambani International School, Mumbai

o Dhirubhai Ambani Foundation Rewards and scholarships

• Healthcare Initiatives

o Sir Hurkisondas Nurrotumdas Hospital and Research Centre (HNHRC), Mumbai and

Dhirubhai Ambani Hospital, Lodhivali, Raigad

• Harmony, an initiative of the Dhirubhai Ambani Memorial Trust, is dedicated to the cause of a

growing population of Senior Citizens

Some of the initiatives taken at RIL- Jamnagar:

• Cattle feed supply to cowsheds; organisation of community meals programmes, safety awareness

programmes; mobile medical van service to surrounding villages, multidiagnostic medical camps and

a village medical center

• Repairing of village roads, supply of drinking water through water tankers on need basis during the

year.

0

10000

20000

30000

40000

50000

60000

70000

80000

9/5/2004 9/10 /2004 9/15 /2004 9/20 /2004 9/25 /2004 9/30 /2004 10/5 /2004 10/10/2004 10/15 /2004 10/20 /2004 10/25 /2004

K g /

d a y

B efore F GR S A fte r F GR S

B l o w d o w n G a s

q u a n t i t y

Ne t Ga s F l a r e d





• Support Jamnagar Municipal Corporation and citizens in various community celebrations and

activities.

The four criteria for sustainable development as defined by Host Government are addressed as follows :

Environmental impact : As the project activity reduces the quantity of fuel burnt in the boiler, the

emissions in the form of NOx, SOx and CO2 are reduced. This contributes to the sustainable development

of environment.

Social impact : Direct & Indirect employment has been generated in the plant for the project

implementation & management. Also the simulation studies and interaction with international experts

enhanced the skill sets of manpower.

Economical impact : The project activity reduces fuel consumption in the boilers, thus reducing the

variable cost of production. Though the quantum of savings are negligible as compared to total turnover

of the refinery, directionally the project contributes to economical development.

Technological impact : The project activity is the result of rigorous studies by the project proponent. The

outcome of the studies is the most energy efficient way of operating the unit in which project is

implemented. The project activity was vetted by leading refiner, M/s Shell and the same is now

incorporated in their design. This proves that the project activity is based on sound technology. The

modification detailed in this project can now be implemented in Saturated Gas Concentration Units of

other Crude Distillation Units. Hence, the benefit towards environmental development is anticipated

worldwide through this modification.

A.3. Project participants:

>>

Name of Party involved ((host)

indicates a host Party)

Private and/or public

entity(ies) project participants

(as applicable)

Kindly indicate if the Party

involved wishes to be

considered as project

participant (Yes/No)

India [ (Ministry of Environment

and Forest (MoEF)(Host party)]

Reliance Industries Limited

(Private entity)

No

A.4. Technical description of the project activity:

A.4.1. Location of the project activity:

>>

Reliance Industries Limited

Refinery complex

Jamnagar

A.4.1.1. Host Party(ies):

>>India





A.4.1.2. Region/State/Province etc.:

>>

Gujarat state

A.4.1.3. City/Town/Community etc:

>>

Motikhavdi, Taluka Lalpar,P.O. Digvijaygram





A.4.1.4. Detail of physical location, including information allowing the

unique identification of this project activity (maximum one page):

>>

N Buildin

Road Rail

CPP

PP

The site is located at latitude 22° 22' N,

longitude 69° 51' E adjacent to the town

of Jamnagar in Gujarat State alongside

the Gulf of Kutch approximately 480

km north of Bombay on India's West

Coast. The refinery site is located just

to the south of the State Highway No.25

to Jamnagar. Total area of this complex

is 7500 acres. Nearest Railway station is

Jamnagar Railway Station & Nearest

Airport is Jamnagar Airport





A.4.2. Category(ies) of project activity:

>>

Project activity falls under “Categoty III : Energy Demand” as per Sectoral scopes related approved

methodologies and DOEs.

A.4.3. Technology to be employed by the project activity:

>>

The flare gas recovery system has been developed in house by the engineers of project proponents after

rigorous studies and accurate and systematic monitoring of various process parameters. The is an

excellent example of in-house tailor-made engineering solution for energy conservation. It is based on

good engineering practices. All proven tools of engineering viz, simulations, six sigma approach,

discussions with experts in the field of technology etc. The technology reduces not only the GHG

emission but also other pollutants i.e. SOx, NOx. The heat and gases released through flare normally

causes nuisance for the people staying in vicinity. Recovery of gases has thus contributed towards

environmental and social sustainability.

The modifications carried out in the plant for installation of the systems are explained below :

Measure II : Main Flare Gas Recovery :

The major modifications carried out in the field are:

1) The proposed Flare Gas Recovery system is a skid mounted package involving (All wetted parts shall

be of SS316L-the material should comply with NACE MR 0175 which is suitable for H2S, chlorine

and organic sulphur):

♦ A 20” tap off from the Main Flare header of 84” at downstream of knockout drums and

upstream of liquid seal drums for the suction of Flare gas recovery compressors.

♦ A set of two Liquid ring compressors to compress the flare gas from 1.1 bara to 8.0 bara with

mechanical seal flushing system. A bypass line for 100% recirculation is provided. To meet

the suction pressure requirements of these Compressors, flare gas header pressure needed to

be increased. This necessitated redesigning the water seal drums of the flare system &

revalidating the safety release system of all the operating plants connected with this system.

♦ A shell and tube water condenser to cool the liquid ring (water).

2) A Flare Gas Amine Absorber (distillation unit )





Measure-1 LLP flare gas recovery :

Coking operation is a semi batch process, which involves various sequential activities between cokingand decoking cycle. One such activity involves steaming of hydrocarbons from the coke drum to the

blowdown drum for 1.5 hours. The lighter fractions (non condensable) of hydrocarbons are flared (LLP

Flare). In the project activity, The flare gas from the blowdown system is collected at the common flare

knock out drum from where the gases are recovered with the help of ejectors. The ejector system is a

combination of four ejectors of equal capacity in parallel. Medium pressure steam is used as a motive

fluid and the flare gas are compressed to 0.9 Kg/cm2 (g) and is routed to the main fractionator overhead

condenser receiver vessel after cooling. A water seal pot is designed to create a system backpressure of

0.25 Kg/cm2

(g) at 70% level. This system has been functional effectively with its unique control

philosophy to minimize steam consumption. The ejector motive steam is automatically switched on and

off to control the suction pressure of the blowdown gases at the ejector based on the requirement. The

control philosophy takes care of inherent fluctuations in coker automatically and needs no manual

intervention at any point of time.

A.4.4 Estimated amount of emission reductions over the chosen crediting period:

>>

Average Emission reduction is estimated to be 71227 tonnes CO2 e /year. Thus over a crediting period of

ten years, estimated CERs amount to 712270 tonnes CO2 e.

Years Annual estimation of emission reduction

tonnes CO2 e

Nov’2003 – Oct’2004 34642

Nov’2004 – Oct’2005 75292

Nov’2005 – Oct’2006 75292

Nov’2006 – Oct’2007 75292

Nov’2007 – Oct’2008 75292

Nov’2008 – Oct’2009 75292

Nov’2009 – Oct’2010 75292

Nov’2010 – Oct’2011 75292

Nov’2011 – Oct’2012 75292

Nov’2012 – Oct’2013 75292

Total estimated reductions

( tonnes CO2 e )

712270

Total Number of crediting years 10 years

Annual Average over the crediting

period of estimated reductions ( tonnes of

CO2 e )

71227





A.4.5. Public funding of the project activity:

>>

No public funding has been sought for the project activity and the project proponent made entire

investment.

SECTION B. Application of a baseline and monitoring methodology

B.1. Title and reference of the approved baseline and monitoring methodology applied to the

project activity:

>>

There are no approved methodologies for energy efficiency improvements. A new baseline methodology

(NM0155) titled ‘Baseline and monitoring methodology for waste gas and / or heat utilization’ is used forestimation of emission reduction.

Version : 03

B.2 Justification of the choice of the methodology and why it is applicable to the project

activity:

>>

The methodology applies to project activities where no fuel switch is done in the process where the waste

heat or the waste gas is produced after the implementation of the project activity.





The methodology covers both new and existing facilities.

Criteria Project activity fulfils the criteria

Make use of waste heat or the combustion ofwaste gases in industrial facilities for Electricity

generation, Steam generation, and / or Process

heating

The Project activity involves recovery of the wastegas, which was being flared. The gas is made use

of for power and steam generation in captive

power plant.

that do not involve setting up of new cogeneration

facility to make use of waste gas

The project activity uses waste gas in the existing

equipments and there is no new cogeneration

installation to make use of waste gas

No fuel switch is done in the process where the

waste heat or the waste gas is produced after the

implementation of the project activity

Only that gas which was being flared is used in the

project activity for steam and power generation

and there is no fuel switch in the process where it

is generated.

The methodology covers both new and existing

facilities.

In the project, methodology is applied to the

existing capacity and as mentioned in the

methodology, the capacity enhancement will be

treated as new facility.

The project proponent should be able to demonstrate

that the quantity of waste gas as measured by the

flowmeter is completely utilised for electricity /

steam / process heating application

The project proponent through P&IDs and actual

plant set up can demonstrate that all the waste gas

after flowmeter is utilised for electricity / steam

Thus the methodology is applicable to the project activity.





B.3. Description of the sources and gases included in the project boundary

>>

Source Gas Included? Justification / Explanation

CO2 Included Main emission source

CH4 ExcludedCaptive electricity /

steam generation N2O Excluded

Excluded for simplification. This is conservative.

CO2 Included Main emission source

CH4 IncludedWaste gas

N2O Excluded

Excluded for simplification. This is conservative.

CO2 Included May be a main emission source

CH4 ExcludedOnsite fossil fuel

consumption due to

project activity N2O Excluded

Excluded for simplification.

CO2 Included Exception: If waste gas is burned in baseline case and not

vented, the source is excluded.

CH4 Excluded

Combustion of waste

gas for electricity /

steam generation or

process heating

applications N2O Excluded


CO2 Included Increase in electricity consumption, if any will result in

additional CO2 emission at power plant.

CH4 Excluded

P r o j e c t A c t i v i t y

Combustion of fuel in

CPP/grid for additional

energy required in

project activity N2O Excluded


Project boundary

Waste gas generation unit

(Coker plant / Hydrogen

plant)

Captive Power plant(Boilers and Gas tubines)

Flare





B.4. Description of how the baseline scenario is identified and description of the identified

baseline scenario:

>>

The methodology requires that the alternative baseline scenarios to the CDM project activity are to include

various other sources for power (P), steam (S) and possible use of waste gas (W)

The possible alternatives scenarios in absence of the CDM project activity for electricity are identified as

follows:

Scenario designation Description

P1 Proposed project activity not undertaken as CDM project activity.

P2 Existing captive power generation / cogeneration from other energy source than

waste heat/ gas including renewable energy

P3 New captive power generation / cogeneration using other energy source(s) than

waste heat / gas including renewable energy

P4 Import of power from grid

P5 Continuation of existing practice

The possible alternatives scenarios in absence of the CDM project activity for steam are identified as follows:


S1 Proposed project activity not undertaken as CDM project activity.

S2 Existing captive boiler / cogeneration from other energy source than waste heat/

gas including renewable energy

S3 New captive boiler / cogeneration using other energy source(s) than waste heat /

gas including renewable energy

S4 Use of steam, which is vented in the manufacturing unit, say through heat pump.

S5 Reduction in steam demand by use of other heating medium like electricity

S6 Continuation of existing practice, if not already included in options above





The possible alternatives scenarios in absence of the CDM project activity for use of waste gas are identified

as follows:


W1 Waste gas vented without combustion

W2 Waste gas released to atmosphere after combustion

W3 Waste gas sold as product / energy source

W4 Continuation of existing practice, if not already included in options above

Baseline options that do not comply with legal and regulatory requirements and depend on key resources

such as fuels, materials or technology that are not available at the project site are excluded.

P1, S1 : As explained in justification of additionality of the project activity in the section B.3. of this

PDD, project is not possible without CDM.

P2, S2 : Existing CPP can be run with using other fuels than the waste gas, fuel oil, naphtha etc. There is

no prohibitive barrier to use other fuels and flare the waste gas.

P3, S3 : The project activity does not increase the installed capacity of captive power plant but reduced

the steam – power generation from fossil fuels. The CPP is equipped with all the latest technology

machines and the operation of CPP is very reliable. The flexibility and economics due to use of internally

generated fuels favour the generation of steam, power and all other utilities captively rather than

purchasing from outside. The power failure of grid is very common in India and loss of production due to

power disturbances are not affordable for such a large complex. Hence, though there is provision for

using grid power, the complex remains islanded all the time, and imports power only in case of

emergencies. Hence there exist substantial barriers for this alternative and it is hence eliminated

P4, S4, S5 : As explained for P1 & S1, the capacity of the power – steam generation system is not

limiting. The project activity does not increase the capacity as such and hence reduction in power demand

or steam demand through some means can not be the alternative to the project activity.

W1 : waste gas cannot be vented due to safety and environmental concerns.





W3 : The waste gas mainly contains hydrogen and hydrocarbons, which are left over after recovering all

the refinery products. Hence there is no possibility to economically extract any product from this gas. The

project proponent has the economics of recovery of hydrogen from waste gas and the same may be

produced to validator.

P5, S6, W4 : The only alternative to the project activity which does not have any prohibitive barrier was

to continue with existing practice i.e. flaring of waste gas and use of other fossil fuels in captive power

plant.

The parameters, data required to establish baseline scenario are given in following table along with source

:

SN Key information / data Data source

aWaste gas low (Flare loss) before

project implementationIP-21 trends

b Net calorific value of waste gasCalculated from composition

of waste gas

c Reliability of grid power supply State grid failure data

Note : IP-21 is the software which fetches data directly from Distributed Control System (DCS) and stores for a

longer period of time than DCS. The data can be analysed in Microsoft Excel through IP-21.

Baseline study completed along with PDD on 17/12/2005.

Name of entity determining baseline : M/s Reliance Industries Limited, who is project proponent. The

contact information is furnished in Annex I





B.5. Description of how the anthropogenic emissions of GHG by sources are reduced below

those that would have occurred in the absence of the registered CDM project activity (assessment

and demonstration of additionality): >>

(a) Description of the baseline scenario determined by applying the methodology :

As discussed in Section B.2., the baseline scenario is determined as continuation of existing practice.

In this case, the plant would have consumed more carbon intensive fuel in CPP and continued to burn

the waste gas in flare.

(b) Description of the project activity scenario

In the project activity scenario, the waste gas is recovered and replaces the other fuel consumption in

boilers / Gas turbines of CPP.

(c) Analysis showing why the emissions in the baseline scenario would likely exceed emissions in the

project activity scenario.

The comparison of CO2 emission from various sources within project boundary are shown in the

following diagram. The reduction in green house gas emission is in flare and in the boilers and gas

turbines in CPP in terms of CO2, CH4 and N2O. However, for calculation purpose, only CO2 is

considered for simplicity. This is conservative approach.

As per the decision 17/cp.7 para 43, a CDM project activity is additional if anthropogenic

emissions of greenhouse gases by sources are reduced below those that would have occurred in

Reduced

CO2

Flare

Gas Turbine

in CPP

CO2

CO2

Fossil fuel

(Naphtha)

Boilers in

CPP

Fossil fuel

(Fuel oil)

CO2

Waste gas

(H2 & CH4 rich)

Flare

Gas Turbinein CPP

No CO2 by

waste gas used

in ro ect

Fossil fuel

(Naphtha)

Boilers in

CPP

Fossil fuel

(Fuel oil)

Reduced

CO2

Waste gas

(H2 & CH4 rich)

CO2

CO2

Baseline Project activity





the absence of the registered CDM project activity. Following steps of additionality test are

followed for demonstration of additionality:

Steps Additionality Requirements Status of

Additionality Check

Step 0: Preliminary

screening based on

the starting date of

the project activity

The proposals for the two measures in project were

submitted for management approval on 02/12/2002 and

08.01.2000. However, considering the risk and

uncertainties involved in the project implementation, the

decision to implement the project was delayed. Both the

projects were approved in Mar’03 when revised

proposal giving due consideration to monetary as well asintangible benefits of CDM were addressed.

The projects were implemented in November 2003 and

October 2004 respectively.

The additionality check

has crossed Step 0, and

may proceed to Step 1.

Step 1: Identification of alternatives to the project activity consistent with

current laws and regulations

Status of

Additionality Check

Sub-step (1a):

Define Alternatives

to the project

activity

Following alternatives are identified :

1. The proposed project activity is not undertaken

as a CDM project activity.

2. Without project activity the additional energy

Import for electricity could be achieved from the

grid

3. Existing or new captive power, steam, process

heat generation on-site, using other energy

sources than waste heat and/or gas, such as coal,

diesel, natural gas, hydro, wind, etc;

4. Other uses of the waste gas which depending on

the quality & quantity of the waste gas and the

technology suitability considering the

operational parameter. But in case of the project

proponent the only alternative was the project,

hence the waste gas would have been continuing

to flare if not recovered.

5. The continuation of the current situation



may proceed to either

Step 2 (Investment

Analysis) followed by

Step 3 (Barrier

Analysis), or directly to

Step 3.

In this PDD, Step 3 has

been used for

additionality check.






Additionality Check

Sub-step (1b):

Enforcement of

applicable laws and

regulations

There is no mandatory requirement for Reliance

Industries limited, Jamnagar, under all applicable laws

to implement the energy efficiency project such as this

project activity.

Step 3. Barrier analysis

Sub-step 3a. Identify

barriers that would

prevent the

implementation of

type of the proposed

project activity

Sub-step 3b. Show

that the identified

barriers would not

prevent the

implementation of at

least one of the

alternatives (except

the proposed project

activity)

Reliance Industries Limited is actively participating in

efforts towards Green House Gases emission reduction.

The company has contributed to sustainable

development initiatives of the country through various

boards, advisory committees. The backup papers can be

furnished to the validator, if so desired.

The project activity overcomes “technological barriers”

as well as “barriers due to prevailing practice”, as

described below.

• Technological Barriers:

Flare gas recovery can be described as the sewage

system of a refinery or gas recovery at a production

sight. It is normally considered waste gas due to the

composition of the gas. Since these are undesirable

gases of different composition pressure, quality,

quantity, etc, these gases are generally sent to flare to be

burned off as it is a very complex to identify each and

every outlet further study and recovery. The commonly

identified Imbalance of flare gas due to :

1. Reduced demand

2. Reduced load of one / more units









Additionality Check

3. Sudden shutdown of one / more units4. Relief valve malfunction

5. Intermittent minor venting from:

Sight glasses

Compressor bottles

Sampling systems

Pump or compressor vents

The flare is an essential safety system, used for safe

disposal of flows from pressure safety valves and

depressurization of processing equipment. The flare gas

recovery system must not compromise this capability

The system must be able to open quickly, before the

pressure rises and reaches a predetermined level.

The reliability must satisfy the security standards of

the project.

The gas recovery system must be simple and reliable.

The project proponent has sourced technology form the

world’s leading technology provider, and by design

itself, the refinery is energy efficient. To carry out

something for further improvement in energy efficiency

requires conscious and innovative efforts. The project

proponent is always putting in such effort to reduce

Green House Gas emissions and contribute to

environmental sustainability. Systematic monitoring and

study has resulted into the identification of the project

activity.

The project proponent had identified following methods

to reduce flare loss.

1. Review the conditions in process equipments to

minimize flare control valve openings.

2. Identify leaky valves continuously and fix them

3. Install a flare gas recovery system.






Additionality Check

Project proponent, having worked on first two methodsand minimizing the flare loss, it became apparent that

further reduction of flare loss is only possible by going

for a suitable and well-designed flare gas recovery

system. The flare gas recovery system is known to be

operative in some refineries internationally, while not

working properly at some other places.

Following potential risks due to implementation of

project activity are identified :

• The successful recovery of flare depend on accurate

flare load estimation any error or technical

inaccuracy will may the investment worthless. The

flare system is a key safety system, unique in that it

cannot be accessed for maintenance at any time

other than complete shutdown and degassing of the

entire process facility. Failure of components within

the flare system will at best cause safety concern,

and at worst ensure an unexpected facility

shutdown. If uncorrected, damage to the flare

system can impact operational integrity of the

process facility. The major cause of component

failure on the flare system is low flow rate flaring

when the flame wafts about in the breeze impinging

directly on the flare tip itself, the pilots and any

other equipment on the flare deck. The cost of

retrofit on existing facilities often draws into

question the benefit of full zero flare solutions. The

technological risk was mitigated by deputing an

international consultant to review the technical

aspects of the projects and with proper engineering

and simulations. This explains the major risk of non-

operability of the project in case of faulty design.






Additionality Check

The risk involved in use of waste gas in CPP was

significant. The performance of the gas turbines with

waste gas as fuel was prime concern. There was no

previous experience with project proponent of using

hydrogen rich gas in gas turbines. The risk was

mitigated by consultation with the machine suppliers.

• Safety risks are risk of project not synchronising

with the prevailing process during the time of

commissioning of the project. Risk in future due to

malfunctioning of modified system under abnormal

conditions or malfunctioning of the equipments

installed within the modification for which the

system is not tested before.

• The material of construction is for equipments &

piping is designed to resist wet H2S service which

will mitigate risk of material decay.

Measure I : Main Flare Gas Recovery

Main Flare System at Jamnagar Refinery Complex,

consisting of High Pressure (HP) and Low Pressure (LP)

flare headers, is a very large network consisting of all

the process units and offsite areas. Approximately 2000

points are connected to Main Flare System. Moreover, at

present all process units are running at their peak

capacityThe system comprises for installation of Liquid ring

Compressor, Amine Absorber, Flare header,

modifications in seal drum and control Instruments

The identified operational risks of the project activity

are :

• Liquid ring Compressor is the heart of the flaring

system failure will stop the complete project. This






Additionality Check

compressor needs special maintenance unlike othervacuum pumps, troubleshooting them is critical to

their continued operation and maintenance. As a

result, it is important that only qualified personnel,

using proper equipment, be authorized to perform

testing, possibility of leakage in tubes of the liquid

ring cooler of the liquid ring compressor due to

corrosion is expected. Malfunction of the vacuum

system could be due to utility or process conditions,

or both, or the equipment, and it is important to

determine the cause. A malfunction due to external

influences can be determined as follows:

- Reduced capacity of pump due to Seal water

temperature higher than design or Low seal water

flow rate

- Excessive noise due to Excessive or insufficient

seal liquid to pump or Coupling misalignment.

- High power consumption due to Excessive seal

liquid Coupling, misalignment, Excessive

discharge pressure, Defective bearing, Gland ring

too tight, Improperly mounted pump.

- Vibration due to Coupling misalignment, Pump or

motor not properly anchored, Rotor imbalance,

Improperly mounted pump.

- Pump shaft is seized and will not turn due to Scale

from hard water, Foreign object in pump,

Improperly mounted pump.

• In case of failure of Amine Absorber output H2S will

directly go into the fuel gas network as the flare gas

is high H2S content, and the network is not designed

for the same. This will have adverse effect on the life

of the network system and reduce the life.






Additionality Check

• In case of failure in the Flare Gas Header controlsystem there is possibility of explosion, for safe

operation of FGRS it is mandatory to eliminate the

possibility of air being sucked into the flare gas

system, since the composition is not only of

hydrocarbons and hydrogen sulphide but also of

hydrogen, which when mixed with air can be highly

explosive.

• The Seal Drum modification was carried out

necessary to have a bandwidth for pressure control of

the flare gas recovery system which was a difficult

task because of ongoing operation.

In case of failure in the purging system there is a

possibility of fire hence to avoid a major hazard with an

elevated flare (i.e., possible flash back of the flame into

the stack) modifications were carried out as stack be

continuously purged with fuel gas or inert gas (N2) to

prevent ingress of air. There may be a back flow of

purge gas, if purging is done from the original location.

Since there is a proposal for seal height increase, the

flow may not be able to break the seal height and hence,

would go back to KOD. Therefore, flare stack starves of

required purge, which is unsafe. Therefore, it is now

proposed to change the purging location from upstream

of the seal drum to downstream.

Over and above the control system is the key success to

the project as approximately 2000 points are connected

to Main Flare System incase of any change in process

parameters or the malfunction of the control system will






Additionality Check

be down, Hence project proponent has deployed skilledmanpower and sufficient inventory to mitigate the same

risk.

Measure II : Low Low Pressure (LLP) Flare gas

Recovery

The process is to recover vapors from the Coker Blow

down Settling Drums and recycle back to fractionators

overhead overhead drum. Presently, the vapor generated

from the Coker blow down settling drums is routed to

LLP flare header and flared.

The system comprises for installation of Blow down

Vent gas Single stage ejectors, Surface condensers,

knock out drum and control Instruments

The identified operational risks of the project activity

are :

1. The main problem an ejector is likely to experience

during operation is reduced capacity because of

worn parts. The sources of wear are the moving

fluids including:

• Motive fluid which enters the nozzle

• Suction fluid which is entrained in the suction

head

• Discharge fluid which is a mixture of the motive

fluid and the suction fluids

Steam is the fluid of choice for most vacuum

applications. Any moisture in the motive steam will

eventually affect the performance of the jet. The

high velocity wet steam will erode the metal in a

process known as wiredrawing.






Additionality Check

2. In case of failure in the condenser, there is possibilityof entry of hydrocarbons in cooling water. This was

the perceived safety concern. There is possibility of

leaking of the tubes due to under deposit corrosion

problem at the dead zone / low velocity zone of the

ejector after condenser. This will result in ingress of

cooloing water in sour water due to this the soar

water quantity will increase and high amount of Cl

in sour water may disturb the Crude unit operation /

may increase corrosion in Crude unit as this water is

treated in Sour water stripping unit and then used as

desalter make up water. Further if there is leakage in

the tube the H2S will mix with cooling water which

goes to cooling tower the piping and the equipments

is not design to handle H2S this may reduce life of

the Cooling water system.

3. There is a wide variation in the molecular weight and

density of the gas to be recovered which has being

mitigated by complicated control Instruments any

malfunctioning of the same may impact the success

of the project.

4. Integration and control of a flare gas recovery unit is

of critical importance. For example, care must be

exercised in the design of the recovery system to prevent application of a vacuum to the vapor header

that might draw in air and create a flammable

mixture in either the flare header or the fuel gas

system.

From the above it could be observed that Reliance

being in the Indian scenario has achieved a

appreciable goal of being third larges refinery of the

world. This itself is a remarkable achievement for a






Additionality Check

privet company in a developing country. Projectproponent has taken substantial effort and risk to

develop and implement the project activity compared

to Indian industries and expertise to develop and

modify a renowned technology at own cost & risk .

Following problem was overcome to complete the

CDM project.

• Unavailability of skill set required to identify / design

/ implement the potential energy saving opportunity

in the process plant.

• Skilled and/or properly trained labour to operate and

maintain the technology is not available, leading to

financial losses due to failure of equipment and

process control

• Inadequate information sharing within the industries

thus managers are not aware of the energy efficiency

measures implemented at similar facilities within the

country.

• Technology transfer barriers, such as lack of modern

equipment on local markets.

• Perceived technical and financial risks to enterprises

in adopting innovative energy saving technologies

(fears that a new technology may not work, couldinterrupt production, take time to perfect, or will not

actually result in financial savings, which inhibit

enterprise management from adopting new energy-

saving technologies).

• Barriers due to prevailing practice, e.g.:Developers

lack familiarity with state-of-the-art technologies and

are reluctant to use them;

• The project is the “first of a kind” and hence the






Additionality Check

project proponent does not have any past experienceof operation of the project and risks involved in

implementation of the project.

• Barriers due to prevailing practice:

In India, as per the prevailing practice, any major

modification in process, is undertaken only on the

recommendation of technology supplier/licensor. It

is also not a common practice in Indian industries to

carry out such major modifications in the process on

ground of energy conservation alone. Reliance

Industries Limited has been participating in the

National Energy Conservation Awards competition

constituted by Ministry of Power, Government of

India and has received the award every year. The

performance of the company in the area of energy

conservation has been appreciated by various

agencies in India including Confederation of Indian

Industries (CII), Bureau of Energy Efficiency etc

from time to time.

It is learnt through interaction, at different forums,

with representatives from leading companies in the

country and also with the experts in the field of

energy conservation that flare gas recovery is not a

common practice in India.

The Shell Benchmarking study of CE&L shows that

Reliance Refinery is the most energy efficient of all

leading refiners across world. Major contributor to

Energy and loss in refinery is the flaring. Hence

lowest CE&L index is because of near zero flaring






Additionality Check

of Jamnagar Refinery. Also the Energy IntensityIndex for our refinery in Soloman Benchmarking is

the lowest in the class.

The barriers in use of technology and its non-prevalence

as identified above, do not exist for the alternative i.e.

continuing with existing scenario

Step 4. Common practice analysis

Sub-step 4a. Analyze

other activities

similar to the

proposed project

activity.

Sub-step 4b. Discuss

any similar options

that are occurring.

As mentioned above under Step 3, it is not a

common practice in refineries in India to take

initiatives in big way towards energy conservation.

The innovativeness of the project is appreciable and

extraordinary. Huge flare is a common feature of

refineries in India. The flare loss in Jamnagar

refinery is less than one tenth of the normal flare loss

in refineries in India. Hence it is not a common

practice to undertake in Indian industries. Lack of

awareness and adequate knowledge form the prime

barriers to this.




Step 5. Impact of

CDM registration

The approval and registration of the project activity as a

CDM activity would result inter alias in the following

benefits:

Reduction in GHG emissions ;

Encourage other refinery industries in India and

abroad to initiate such measures for energy

conservation;

Since Step 5 is

satisfied, the project

activity is not a

baseline scenario, and

hence is additional.






Additionality Check

Publicity of the efforts taken by the project

proponent towards energy efficiency and hence

sustainable development; and

The social status of the company would be enhanced





B.6. Emission reductions:

B.6.1. Explanation of methodological choices:

>>

This methodology applies to project activities that make use of waste heat or the combustion of waste

gases in industrial facilities for either or all of following applications :

• Electricity generation, thus reducing fossil fuel consumption in captive or grid power generation

• Steam generation, thus reducing fossil fuel consumption in the boiler(s)

• Process heating, thus reducing fossil fuel consumption either in process furnaces or in boilers

owing to reduced steam consumption for process heating


heat or the waste gas is produced after the implementation of the project activity

The project activity involves use of waste gas which otherwise would have flared, for generation of

power and steam. There is no fuel switch over done in the process where waste has is produced, i.e. coker

and hydrogen units of refinery.

The project reduces fossil fuel consumption, namely naphtha for electricity generation and fuel oil for

steam generation in boilers. Thus the relevant sections of the methodology is applied to the project

activity.





B.6.2. Data and parameters that are available at validation:

(Copy this table for each data and parameter)

PROJECT CONSTANTSMeasure I :

ID Number PC-1

Parameter NCVi

Data unit TJ/1000t

Description Net Calorific value of fuels for power

Source of data IPCC default

Value applied 45.01

Justification of the choice of data or

description of measurement methods

and procedures actually applied

IPCC default factor of naphtha is used.

Any comment --

ID Number PC-2

Parameter OXIDi

Data unit Fraction

Description Oxidation factor of naphtha

Source of data 1996 Revised IPCC Guidelines (p. 1.29)

Value applied 0.99




NA

Any comment --

Measure II :

ID Number PC-1

Parameter NCVi

Data unit TJ/1000t

Description Net Calorific value of fuels for steam generation

Source of data IPCC default

Value applied 40.19


description of measurement methodsand procedures actually applied

IPCC default factor for fuel oil s used

Any comment --

ID Number PC-2

Parameter OXIDi

Data unit %

Description Oxidation factor of fuel oil

Source of data 1996 Revised IPCC Guidelines (p. 1.29)

Value applied 0.99


description of measurement methodsand procedures actually applied

NA





Any comment --

ID Number PC-3Parameter Hs

Data unit TJ/t

Description Enthalpy of steam

Source of data To be calculated from the steam temperature and pressure,

which are available in DCS

Value applied 0.0027




NA

Any comment Data to be archived for crediting period + 2 yrs

Constants for Baseline monitoring

Measure I :

ID Number BC-1

Parameter NCVwE

Data unit Kcal/kg

Description Net Calorific Value of waste gases used for electricity

generation

Source of data Determined from laboratory analysis of gas

Value applied 9750


description of measurement methods and

procedures actually applied

Daily composition is available and average is used.

Any comment --

Measure II :

ID Number BC-2

Parameter NCVws

Data unit Kcal/kg

Description Net calorific value of waste gas used for steam generation

Source of data Determined from laboratory analysis of waste gas

Value applied 11209Justification of the choice of data or

description of measurement methods and

procedures actually applied

Daily analysis of the gas is available and average is used.

Any comment --





B.6.3 Ex-ante calculation of emission reductions:

>>

a. Emission due to auxiliary fuels : Not applicable

b. Due to additional power or steam load due to project activity

For Measure I :

PE1y = E p x x (EFEcaptive)

= 3110 x x 72

= 806

For Measure II :

Efficiency of boiler is estimated by direct method.

PE1y = S p x x EFs

= 30240 x (0.0027 / 0.92) x 75.4

= 16428

PE1y Project emission due to increased electrical load in Measure I (t CO2/TJ)

PE2y Project emission due to increased steam load in Measure II (t CO2/TJ)

EP Additional electricity consumption due to project activity (MWh/year)Sp Additional steam consumption due to project activity (t/hr)

Hs Enthalpy of steam (TJ/t)

η b Boiler efficiency (Fraction).

EFsteam Weighted average Emission factor for fuels used in boiler (tCO2/TJ)

EFEcaptive Weighted average emission factor for captive power (tCO2/TJ)

Total project emission PE = PEEy + PEsy

= 17234

Energy equivalent of waste gas used for power generation (TJ/year)

Baseline emission for electricity generated at CPP

BE1 = x (η1project / η1baseline)

= 11287 x 0.041 x 76.6 x 1

= 35448

Where

BE1 Baseline emission for electricity generated at captive power plant (t CO2/year)

Qw1 Waste gas used for measure I (t or m3/year)

Hs

η b

3.6

1000

Qw1 x NCVw1 x EF1

3.6

1000





NCVw1 Net Calorific Value of waste gas used for Measure I. Weighted average value is

considered if multiple waste gases are utilised (TJ/t or TJ/m3)

EF1 Emission factor for fuel displaced by waste gas in Measure I (t CO2/TJ)

η1project Energy efficiency of electricity generation in project case for Measure I (fraction)η1baseline Energy efficiency of electricity generation in baseline case for Measure I(fraction)

Baseline emission for Measure II :

BE2 = Qw2 x NCVw2 x EFs x (η2project / η2baseline)

= 15896 x 0.047 x 75.4 x 1

= 57078

Where

BE2 Baseline emission for Measure II (t CO2/year)

Qw2 Quantity of waste gas utilised for Measure II (t or m3 per year)

NCVws Net calorific value of waste gas used for Measure II. Weighted average value is taken

in case of multiple waste gases (TJ/t or m3)

EF2 Emission factor for the fuel displaced by waste gas for Measure II (t CO2/TJ)

η2project Energy efficiency of boiler in project case in Measure II(fraction)

η2baseline Energy efficiency of boiler in baseline case for Measure II (fraction)

Total Baseline emission BE = BE1 + BE2

= 92526

ER y = BEy - PEy

= 75292

ER y emissions reductions of the project activity during the year t in tons of CO2

BEy baseline emissions due to displacement of electricity during the year y in tons of CO2

PEy project emissions during the year y in tons of CO2





B.6.4 Summary of the ex-ante estimation of emission reductions:

>>

Measure I :

Year

Estimation of Project

activity emission

(tonnes CO2 e)

Estimation of baseline

emissions

(tonnes CO2 e)

Estimation of

leakage

(tonnes CO2 e)

Estimation of

emission reduction

(tonnes CO2 e)

Nov’03 – Oct’04 806 35448 0 34642

Nov’04 – Oct’05 806 35448 0 34642

Nov’05 – Oct’06 806 35448 0 34642

Nov’06 – Oct’07 806 35448 0 34642

Nov’07 – Oct’08 806 35448 0 34642

Nov’08 – Oct’09 806 35448 0 34642

Nov’09 – Oct’10 806 35448 0 34642

Nov’10 – Oct’11 806 35448 0 34642

Nov’11 – Oct’12 806 35448 0 34642

Nov’12 – Oct’13 806 35448 0 34642

Total(tonnes of CO2 e)

8060 354480 0 346420

Measure II :

Year

Estimation of Project

activity emission(tonnes CO2 e)

Estimation of baseline

emissions(tonnes CO2 e)

Estimation of

leakage(tonnes CO2 e)

Estimation of

emission reduction(tonnes CO2 e)

Nov’03 – Oct’04 57078 57078 0 0

Nov’04 – Oct’05 16428 57078 0 40650

Nov’05 – Oct’06 16428 57078 0 40650

Nov’06 – Oct’07 16428 57078 0 40650

Nov’07 – Oct’08 16428 57078 0 40650

Nov’08 – Oct’09 16428 57078 0 40650

Nov’09 – Oct’10 16428 57078 0 40650

Nov’10 – Oct’11 16428 57078 0 40650

Nov’11 – Oct’12 16428 57078 0 40650

Nov’12 – Oct’13 16428 57078 0 40650


204930 570780 0 365850





For complete project :

YearEstimation of Project

activity emission

(tonnes CO2 e)

Estimation of baselineemissions

(tonnes CO2 e)

Estimation ofleakage

(tonnes CO2 e)

Estimation ofemission reduction

(tonnes CO2 e)

Nov’03 – Oct’04 57884 92526 0 34642

Nov’04 – Oct’05 17234 92526 0 75292

Nov’05 – Oct’06 17234 92526 0 75292

Nov’06 – Oct’07 17234 92526 0 75292

Nov’07 – Oct’08 17234 92526 0 75292

Nov’08 – Oct’09 17234 92526 0 75292

Nov’09 – Oct’10 17234 92526 0 75292

Nov’10 – Oct’11 17234 92526 0 75292

Nov’11 – Oct’12 17234 92526 0 75292

Nov’12 – Oct’13 17234 92526 0 75292


212990 925260 0 712270

B.7 Application of the monitoring methodology and description of the monitoring plan:

Proposed New Monitoring methodology for waste gas and/or heat utilization

This methodology applies to project activities that make use of waste heat or the combustion of waste

gases in industrial facilities for either or all of following applications :

• Electricity generation, thus reducing fossil fuel consumption in captive or grid power generation

• Steam generation, thus reducing fossil fuel consumption in the boiler(s)

• Process heating, thus reducing fossil fuel consumption either in process furnaces or in boilers

owing to reduced steam consumption for process heating


heat or the waste gas is produced after the implementation of the project activity

The project activity involves use of waste gas which otherwise would have flared, for generation of

power and steam. There is no fuel switch over fone in the process where waste has is produced, i.e. coker

and hydrogen units of refinery.

Proposed baseline methodology “Baseline methodology for waste gas and / or heat utilisation is

applicable to the project activity as discussed in Section B.1.1 of PDD, hence this monitoring

methodology can to be used.





B.7.1 Data and parameters monitored:

(Copy this table for each data and parameter)

Project monitoring :

(a) Project activity emissions parameters

Data/Parameter Qi

Data unit t or m3 per hour

Description Quantity of auxiliary fuel

Source of data Flowmeter / design values

Measurement

procedures (if any)

Will be monitored in flowmeter and DCS or from equipment specifications

Monitoring

frequency

Continuously

QA/QC procedures Data to be archived for 2 years following the end of the crediting period.

Any comment --

Data/Parameter EFi

Data unit TJ/1000t

Description Emission factor for auxiliary fuel

Source of data IPCC default or calculated based on composition.

Measurement

procedures (if any)

If EF is calculated, composition to be determined with calibrated instruments

based on international standard.

Monitoring

frequency

Once for IPCC default. If calculated based on composition, the composition to be

monitored on monthly basis and EF to be calculated annually.QA/QC procedures Data to be archived for 2 years following the end of the crediting period.

Any comment --

Data/Parameter E py

Data unit MWh/yr

Description Additional electricity consumption due to project activity

Source of data DCS / handheld meter / equipment specifications

Measurement

procedures (if any)

Measured by energy meter or by handheld meter.

Monitoring

frequency

Online if DCS / measured monthly / Once if specifications are used.

QA/QC procedures Data to be archived for crediting period + 2 yrs. Source of data is Specification

sheets, hence no QA/QC procedure required.

Any comment --





Data/Parameter S py

Data unit tDescription Additional steam consumption due to project activity

Source of data DCS / equipment specifications

Measurement

procedures (if any)

Measured by energy meter or by handheld meter.

Monitoring

frequency

Online if DCS / measured monthly / Once if specifications are used.

QA/QC procedures Data to be archived for crediting period + 2 yrs. Source of data is Specification

sheets, hence no QA/QC procedure required.

Any comment --

Data/Parameter EFsteam Data unit t CO2/TJ

Description Weighted average emission factor for fuels used in boiler

Source of data IPCC default or calculated based on composition

Measurement

procedures (if any)



Monitoring

frequency


monitored on monthly basis and EF to be calculated annually

QA/QC procedures Default factors. No QA/QC procedure required. If calculated, data to be archived

for crediting period + 2 yrs

Any comment --

Data/Parameter EFEcaptive

Data unit T CO2/ MWh

Description Weighted average emission factor for captive power

Source of data IPCC default or calculated based on composition

Measurement

procedures (if any)



Monitoring

frequency


monitored on monthly basis and EF to be calculated annually

QA/QC procedures Data to be archived for crediting period + 2 yrs.

Any comment Weighted average value to be taken in case of multiple fuels

(b) Baseline emissions parameters

Data/Parameter Qw1

Data unit T or m3

Description Waste gas used for Measure I

Source of data Flowmeter

Measurement

procedures (if any)

DCS / local flowmeter indication

Monitoring

frequency

Online / daily

QA/QC procedures DCS data. Measuring instruments being calibrated and maintained as per ISO

procedures. QA/QC procedures included in ISO documentation and audited





regularly. Data to be archived for 2 years following the end of the crediting period.

Any comment --

Data/Parameter EF1

Data unit t CO2/ TJ

Description Emission factor for fuel displaced by use of waste gas for Measure I

Source of data IPCC default value may be taken if available. Else to be calculated based on

composition of fuel. according to Equation 1.

Measurement

procedures (if any)

Fuel composition to be monitored in latter case.

Monitoring

frequency

Once (IPCC default) or monthly analysis of composition and annual calculation of

emission factor.

QA/QC procedures Default factors. No QA/QC procedure required. Data to be archived for crediting

period + 2 yrs.

Any comment Weighted average value to be taken in case of multiple fuels

Data/Parameter η1project

Data unit Fraction

Description Energy efficiency for Measure I in project case

Source of data Specific fuel energy consumption to be calculated

Measurement

procedures (if any)

Fuel consumption for electricity generation and total power generated to be

monitored on monthly basis in DCS.

Monitoring

frequency

Monthly

QA/QC procedures Data to be archived for crediting period + 2 yrs.Any comment Load-wise energy efficiency to be determined.

Data/Parameter η1baseline

Data unit Fraction

Description Energy efficiency of electricity generation in baseline case

Source of data Specific fuel energy consumption to be estimated from fuel consumption and

power generated for baseline period I.e. six months befor project implementation

Measurement

procedures (if any)

Fuel consumption and power generation at various loads to be monitored for

baseline period.

Monitoring

frequency

Monthly for six months before project implementation.


Any comment Load-wise energy efficiency to be established.

Data/Parameter Qw2

Data unit T or m3

Description Quantity of fossil fuel equivalent to waste gas being utilised for Measure II

Source of data DCS

Measurement

procedures (if any)

--

Monitoring Online





frequency

QA/QC procedures DCS data. Measuring instruments being calibrated and maintained as per ISO

procedures. QA/QC procedures included in ISO documentation and audited

regularly. Data to be archived for 2 years following the end of the crediting period.Any comment --

Data/Parameter EF2

Data unit T CO2/ TJ

Description Emission factor for fuel displaced by waste gas for Measure II

Source of data IPCC default value may be taken if available.

Measurement

procedures (if any)

Fuel composition to be monitored in latter case.

Monitoring

frequency

Once (IPCC default) or monthly composition to calculate the emission factor

annually.

QA/QC procedures Default factors. No QA/QC procedure required. Composition to be analysed based

on international standards and analysers.

Any comment Weighted average to be taken for multiple fuels.

Data/Parameter η2project

Data unit fraction

Description Energy Efficiency of boiler in project case

Source of data Estimated from fuel energy consumption and steam generation.

Measurement

procedures (if any)

Consumption of fuel and steam generation to be monitored in DCS.

Monitoringfrequency Monthly

QA/QC procedures Data to be archived for crediting period + 2 yrs. Instruments to be calibrated

periodically.

Any comment --

Data/Parameter η2baseline

Data unit Fraction

Description Energy Efficiency of boiler in baseline case

Source of data Estimated from fuel energy consumption and steam generation.

Measurement

procedures (if any)

Consumption of fuel and steam generation to be monitored in DCS

Monitoring

frequency

Monthly for six months prior to implementation of project.


Any comment --





B.7.2 Description of the monitoring plan:

>>

The process monitoring and control system at the Gandhar Complex is fully automated. All the

parameters covered under monitoring plan are monitored online through IP-21 based system that is

connected with Distributed Digital Control System (DCS). The data is archived electronically on IP-21

server.

Central Technical Services (CTS) department monitors the data on monthly basis in the form of monthly

reports. CTS Engineer will monitor and document the data on regular basis as per the monitoring plan

outlined in the GHG Emission Reduction Management System.

Report on emission reductions will be maintained on a monthly basis and will be available with CTS

department.

Project proponent have established a project specific GHG Emission Reduction Management System

RIL/CDM/MS/PDD/0607/009 which has made the project system driven and not person specific this

document gives detailed responsibility matrix, emergency preparedness, calibration / measuring/

monitoring and reporting parameters, control of records, internal audits, performance review, corrective

action for sustaining the CDM project.





The project proponent already has well-established monitoring system. The Central Technical Services

(CTS) department has main responsibility of monitoring the plant parameters on regular basis. The

parameters related to emission reduction are being monitored by the engineer of energy cell of CTS.

ORGANOGRAM

B.8 Date of completion of the application of the baseline study and monitoring methodology and

the name of the responsible person(s)/entity(ies)

>>

Date of completing the final draft of this baseline section: 17/12/2005

Name of person/entity determining the baseline:

Name of entity : Reliance Industries Limited

Contact details are given in Annexure 1.

CTS Engineer

( monitors the parameters

related to GHG Emission

reduction)

Central Environmental CellCTS Sectional Head

CTS Head

Site President

Plant Operation Head







SECTION D. Environmental impacts

>>

D.1. Documentation on the analysis of the environmental impacts, including transboundary

impacts:

>>

As per the guidelines for conducting the EIA, the project activity does not fall into any of the two

categories, hence EIA is not required to be done as per the guidelines. However, the project proponent has

carried out environment impact analysis as a good engineering practice.

Detailed Environmental Impact Assessment of the project was carried out before its implementation. The

filled checklist used for EIA is available with the project proponent.

As the project leads to reduced fossil fuel consumption, it contributes to betterment of environment and

there is no negative effect in terms of land, water, air or noise pollution. The socio-economic and cultural

environment is also not affected in any way due to implementation of the project.

There are no legal clearances required for implementation of the project activity

D.2. If environmental impacts are considered significant by the project participants or the host

Party, please provide conclusions and all references to support documentation of an environmental

impact assessment undertaken in accordance with the procedures as required by the host Party:

>>

There are no negative environmental impacts envisaged due to implementation of project, in fact it

contributes to sustainable development of environment.





SECTION E. Stakeholders’ comments

>>

E.1. Brief description how comments by local stakeholders have been invited and compiled:

>>

The project activity involves modifications within the existing operational plant. There are well-

established procedures within the company for involving technical as well as operating staff in the

decision making for implementation of any project. Field Change Order (FCO) is circulated through all

key departments within the plant concerned with the area of project activity. Comments from the

department chief are available in FCO.

There are no negative impacts of the project in any way on any stakeholder. In fact they appreciated the

efforts of project proponent towards energy conservation and the environmental benefits that the project

activity has resulted into.

All the local stakeholders of RIL Jamnagar are mapped and interviewed during a recent exhaustive

Corporate Social Responsibility (CSR) study. The report of their feedback is available with the project

proponent and may be made available to the validator is so desired.

E.2. Summary of the comments received:

>>

The stakeholders who were interviewed include panel superintendent, field engineer, Technical services

engineer and plant production manager. After providing all the details of project activity, the questions

were asked to evaluate what the stakeholder thinks about impact of project activity on following :

1. Air pollution

2. Water pollution

3. Water availability

4. Water allocation

5. Natural drainage pattern

6. Drainage in general

7. Solid waste generation and disposal

8. Land use / landscape

9. Plant life

10. Agriculture / horticulture

11. Habitat fragmentation





12. Employment

13. Vocational opportunities

14. Income levels

15. Stress on infrastructure

The stakeholders have indicated that there is no significant impact of the project activity in terms of any

of the above parameters.

E.3. Report on how due account was taken of any comments received:

>>

Stakeholders have appraised the project as an environment friendly project and have expressed their

satisfaction on the fact that it reduces emissions and contributes to well-being of society. There are no

negative comments received that require the project proponent to take any corrective action





Annex 1

CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY

Organization: Reliance Industries Limited

Street/P.O.Box: Thane-Belapur Road, Koparkhairane

Building: 2nd

Floor, B Wing, PHQ, Dhirubhai Ambani Knowledge City (DAKC)

City: Navi Mumbai

State/Region: Maharashtra

Postfix/ZIP: 400709

Country: India

Telephone: + 91 22 67270585

FAX: + 91 22 67270699

E-Mail: [email protected]

URL: www.ril.com

Represented by:

Title: General Manager

Salutation: Mr

Last Name: Mukherjee

Middle Name: K

First Name: Kisor

Department: Projects

Mobile: + 91 9322645078

Direct FAX: + 91 22 67270699

Direct tel: + 91 22 67270585

Personal E-Mail: [email protected]





Annex 2

INFORMATION REGARDING PUBLIC FUNDING

No Public Funding is sought for the project activity

Annex 3

BASELINE INFORMATION

Measure I:

Parameter Units Value

Energy equivalent of waste gas

used for power and steam

generation

TJ/year 458

Baseline emission T CO2/year 35448

Measure II :

Parameter Units Value

Energy equivalent of waste gas

used for power and steamgeneration

TJ/year 737

Baseline emission T CO2/year 57078





Annex 4

MONITORING INFORMATION

The parameters for monitoring performance and estimating emission reduction by the project activity will

be monitored as per the monitoring plan given in Section D of this PDD. Monitoring and verification

protocol is developed as part of ‘GHG emission reduction management system’. The M&V protocol

provides a range of data measurement, estimation and collection options/techniques in each case

indicating preferred options consistent with good practices to allow project managers and operational

staff, auditors, and verifiers to apply the most practical and cost-effective measurement approaches to the

project. The aim is to enable this project have a clear, credible, and accurate set of monitoring, evaluation

and verification procedures. The purpose of these procedures would be to direct and support continuous

monitoring of project performance/key project indicators to determine project outcomes, greenhouse gas

(GHG) emission reductions.

Major Parameters monitored will be as follows.

1. Waste gas flow for steam and power generation

2. Fuels consumption and steam generation in boiler for boiler efficiency calculations

3. Boiler Steam pressure and temperature for enthalpy estimation

The instrumentation system installed for the project is Distributed Control System (DCS) of reputed

make, with shift-wise recording and feedback facility with desired level of accuracy. All instruments will

be calibrated and marked at regular intervals so that the accuracy of measurement can be ensured all the

time.

Monitoring Approach

The general monitoring principles are based on:

• Frequency

• Reliability

• Registration and reporting





As the emission reduction units from the project are determined by the reduction in steam quantity and

subsequent reduction in consumption of fuel in service boiler, it is important to discuss the monitoring

principles in context of monitoring these parameters.

Frequency of monitoring

The project developer has installed all metering facilities within the plant premises. The measurements are

monitored and controlled through DCS on continuous basis, recorded day-wise in log sheets by operator

and duly authenticated by head of plant.

Reliability

The amount of emission reduction units is proportional to the net energy reduction due to project. Thus

the steam meter reading is of crucial value. All measurement devices will be digital type meters with on-

line DCS (Distributed Control System) having best accuracy and will be procured from reputed

manufacturers. Since the reliability of the monitoring system is governed by the accuracy of the

measurement system and the quality of the equipment for reproducibility, all instruments must be

calibrated once a year for ensuring reliability of the system. All instruments carry tag plates, which

indicate the date of calibration and the date of next calibration. Therefore it ensures that the monitoring

system is highly reliable.

Registration and reporting

Registration is done on the basis of daywise data logging in computer. Daily and monthly reports are

prepared stating the steam consumption and strippers output.

A daily report will be generated showing day-wise data on steam used in strippers in CDU-I and II, day-

wise calculated steam consumption per ton of stripper output and net reduction in steam consumption

calculated by multiplying difference in specific steam consumption and total production.

Verification

The reduction in steam consumption leads to the CO2 emission reductions. The project control system

comprises sophisticated monitoring system like on-line display meters and Distributed Control Systems

(DCS) which measures, collects the information about various process parameters, monitors and controls

on a continuous basis and records on daily basis. Fully functional management information generated

through DCS in pre-decided daily reports formats are built, so that access to and verification of actual





data are possible at any point of time. A computerised MIS can is generated and distributed among

decision makers of the project. The major activities to be verified are as under

• Verification of various measurement and monitoring methods

• Verification of instrument calibration methods

• Verification of data generated through on-line meters and DCS

• Verification of measurement accuracy

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Documents

PDD Waste Gas RIL JN Version3