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
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SECTION A. General description of project activity
A.1
Title of the project activity:
NRL -Captive power generation by recovery and utilization of the waste energy (thermal and
pressure) of HP steam
Version-01
Date : 31/01/2007.
A.2.
Description of the project activity:
Purpose
The objective of the project is to reduce GHG emissions through installation of one 12 mega-watt (MW)
Steam Turbine Generator (STG) for captive power generation utilizing the waste pressure energy across
the steam pressure reduction valve as well as the waste thermal /heat energy of surplus high pressure
(HP) steam generated from various processes. This project activity would enable parallel operation of the
STG (12MW) along with one naphtha/natural gas based Gas Turbine Generator (GTG) of 30MW to meet
the power demand of the refinery complex. In absence of the project activity the project proponent
would have to operate the GTG at higher generation load consuming additional fossil fuel
(naphtha/natural gas) to meet the entire power demand for the refinery complex.
Therefore, the project activity will result in a reduction of fossil fuel consumption at the GTG end which
would lead to GHG emission reductions from the Captive Power Plant (CPP) of the refinery.
Salient Features
Present steam and power generation system in the refinery
In the present scenario (i.e. in the before project scenario) there are 2 GTGs with Heat Recovery Steam
Generators (HRSGs) each having rated capacity of 30 MW. One GTG is kept as standby and the other
one generates 25 MW of power which is the present power requirement of the refinery at 100% load
along with the marketing terminal and township. High Pressure (HP) steam (40.2 kg/cm2, 4300C)
generated from the HRSG and also the HP steam generated from Hydrogen Unit (H2U), Coke
Calcination Unit (CCU) and Utility Boiler (UB) of the CPP are fed to the main HP steam header of the
refinery.
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Around 52 MT/hr of HP steam is passed through Pressure Reducing and De-superheating Station1(PRDS) for letting down to medium pressure (MP) level. MP steam generated from process units and
MP steam generated through PRDS-1 by HP steam let down join the main MP steam header. A part of
the MP steam (around 17 MT/hr) from MP header is again fed to PRDS-2 for letting down to Low
Pressure (LP) level. Excess HP steam if generated from other process areas is vented. The present HP
steam balance of the refinery is given below:
HP steam balance
HP steam generation
Sources
HP steam consumption
Quantity
Sources
(MT/hr)
Total HP steam consumption in
From process unit waste heat recovery
boilers, HRSG and Utility Boiler
Total HP steam production
the process including losses
186.00
Quantity
(MT/hr)
107.00
HP steam to PRDS-1 (HP to MP)
52.00
Total HP steam consumption
159.00
186.00
Therefore, according to the HP steam balance (186.00-159.00) =27 MT/hr of surplus HP steam is
available in the refinery steam network. Presently this surplus steam is vented and as a result the heat
content of this surplus HP steam is wasted to atmosphere.
Power recovery potential in the existing steam distribution network:
This surplus 27MT/hr of HP steam has been estimated to have a generation capacity of 5.5 MW power
through a STG with vacuum condenser.
80% of the energy which is wasted (as waste pressure energy) during throttling process in PRDS 1&2
can be recovered and used for power generation with power recovery potential is 2.8 MW.
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PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03.1
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Therefore, total quantum of power recovery to be achieved by passing the entire surplus HP steam (27
MT/hr) and PRDS HP steam (52MT/hr) through a STG is (5.5+2.8)= 8.3 MW.
Project activity for energy efficiency improvement:
The project activity consists of investment for installation of a STG of rated capacity 12 MW which will
run along with the GTG utilizing HP steam going to PRDS and the surplus HP steam from process which
is presently being vented. MP steam and LP steam extractions from the 12 MW STG will be utilized in
various process units of the refinery.
In absence of the project activity 8.3 MW of power, which is the power recovery potential in the existing
steam distribution network, would be generated from the GTG only and additional process steam
requirement at MP and LP level would be met by HP and MP steam let down in PRDS 1&2 respectively.
The parallel operation of the proposed STG along with the existing GTG will therefore result in
reduction of fossil fuel (naphtha/natural gas) consumption in the GTG thereby contributing to the
reduced GHG emissions from the refinery.
Project’s Contribution to Sustainable Development
The project activity’s contribution to “Sustainable Development of India” is discussed under the three
pillars of sustainable development:
Social well-being: By creating a demand for some skilled jobs for the construction of the unit as well as
operation and the maintenance of the installed equipments, the project activity has the potential to
generate both direct and indirect employment in the locality. The project activity may also help to create
a business opportunity for local stakeholders such as bankers / consultants, suppliers / manufacturers,
contractors etc.
Economic well-being: Through lower fossil fuel consumption for the process, the project activity will
contribute to the conservation of non-renewable natural resources– thereby making the same available for
other industrial applications.
Environmental well-being: The project activity will ultimately result in the reduction of fossil fuel
consumption for power generation in CPP. Thus emissions of CO2 and other pollutants like NOx , SOx
etc associated with the combustion of fossil fuel will be greatly reduced.
Technological well-being: The project activity has contributed to the development of an innovative
technological modification by which the project proponent will reduce fossil fuel consumption for power
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generation. A vital part of the project activity will be to impart proper technical and managerial training
to the managerial and operational staffs of the refinery for proper functioning of the system. An intensive
in-house knowledge base should be developed to build up scientific and technical expertise for running
the process. Adoption of this novel technological measure will also help in capacity building of
employees for efficient resource utilization in petroleum refining industry. Moreover, this technology can
be replicated to other petroleum refineries and process chemical industries in India.
A.3.
Project participants:
Name of the Party involved Private
and/or
public Kindly indicate if
((host) indicates a host entity(ies)
the Party involved
party)
Project
participants
(as wishes to be
applicable)
considered as
project participant
(Yes/No)
Ministry of Environment and
Numaligarh Refinery Limited –
Forests (MoEF), Government
A public sector company
No
of India
A.4.
Technical description of the project activity:
A.4.1. Location of the project activity:
A.4.1.1.
Host Party(ies):
India
A.4.1.2.
Region/State/Province etc.:
Assam
A.4.1.3.
City/Town/Community etc:
Golaghat District
A.4.1.4.
Detail of physical location, including information allowing the
unique identification of this project activity (maximum one page):
NRL is one of the north-eastern refineries in the country. The plant site is located in Golaghat district of
Assam. The refinery site and the associated township is well connected by rail, road and air transport.
The nearest airport is Jorhat 70 km from NRL. The nearest railway station is Furkating Junction 35 km
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from NRL. The other communication and infrastructure facilities are also available to the refinery
complex of NRL.
A.4.2. Category(ies) of project activity:
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As per the sectoral scopes related to approved methodologies and DOEs, the recommended sectoral
scopes of the project activity is
(1) Energy industries (renewable-/ non-renewable sources)
A.4.3. Technology to be employed by the project activity:
The STG to be installed under the proposed project activity will have two extractions (MP& LP) with
one condensing stage. Governor will control pre set (i) extraction flows to MP and LP steam header from
this turbine (ii) RPM of the turbine (iii) load of power generator by adjusting the inlet HP steam flow to
HP chest, steam flow to MP chest and steam flow to LP chest i.e. condensing stage. Existing PRDS valve
will control MP and LP steam header pressure. Steam flow through MP and LP extraction line will be
pre set to meet the requirement of MP and LP steam headers, keeping the steam vents closed. Thus under
normal running condition PRDS 1&2 will remain just closed, however ready to open whenever steam
demand of the respective downstream steam header increases and header pressure starts falling. Similarly
excess pressure of different steam headers will be controlled by steam vents like HP steam vent and
combustion control. MP steam header pressure increase will be controlled by a proposed new steam vent
on the MP steam header and by auto shifting and adjustment of set points for flow control of steam
through MP extraction line by cascading with pressure signal of MP steam header. In the similar fashion
the increase in pressure in the LP steam header can also be controlled. Indication with Low/High alarm
for temperature and pressure signal for each steam header will be provided in the central control room for
timely action by the operators. Two turbine-extraction by-pass control valves will be provided, which
will open within 5 seconds on turbine tripping and maintain the same flow of steam, which was going
through MP and LP extraction line before tripping of turbine. After this opening, these control valves at
turbine extraction bypass will changeover to pressure controller of respective steam headers.
Electronic type (with Distributed Control System) instrumentation will be provided for this new 12 MW
STG with proper integration with the existing system for efficient and safe operation.
Various input requirement for operating the 12 MW STG will be HP steam, cooling water, electrical
system, instrument air, control oil circuit and lube oil circuit along with lube oil pumps, lube oil storage
etc.
Control Philosophy of the Project Activity:
Operational and control philosophy for the proposed STG is developed to fulfil the following three
objectives:
-
Keeping both PRDS-1 & PRDS-2 closed
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-
Keeping all the steam vents closed
-
Minimizing the flow of steam to its condenser to ensure the optimum use of refinery
steam system
According to this philosophy the governor will control pre-set extraction flows to MP and LP steam
header from the turbine, RPM of the turbine and power output from the generator by adjusting inlet HP
steam flow to HP chest, steam flow to MP chest and steam flow to LP chest. Steam flow through the MP
extraction line as well as LP extraction line will be pre-set to meet the requirement of MP and LP steam
headers by keeping all the steam vents closed. Thus under the normal running condition PRDS 1 &
PRDS 2 will be on stand-by mode but start operating whenever demand of the downstream steam header
increases and pressure starts falling. Excess pressure of the various steam headers will immediately
control the respective vents but ultimately the same will be taken over by either combustion control of
the utility boiler or the respective extraction control to stop the vents. Combustion control of utility boiler
will take care of HP vent control as well as the falling pressure in the HP header. MP steam header
pressure increase will be initially controlled by its vent and afterward by gradual auto shifting and
adjustment of the set points for flow control of steam through MP steam extraction line by cascading
with pressure signal of MP steam header. In case of LP steam header exactly the similar control system
will work.
There will be three numbers of governor control valves placed on each of the steam inlet line to HP, MP
and LP chest respectively. Governor control along with the whole interlock tripping system will be
operated by oil hydraulic and electronic signals.
Since, the GTG operates on fossil fuel ; the project activity would reduce the consumption of high carbon
fossil fuel – naphtha/ natural gas. Moreover, this shift in fuel use in refinery is also expected to reduce air
borne pollutants and improve air quality in and around the refinery complex.
A.4.4
Estimated amount of emission reductions over the chosen crediting period:
Years
Apr 2007- Mar 2008
Apr 2008- Mar 2009
Apr 2009- Mar 2010
Apr 2010- Mar 2011
Annual estimation of emission reductions
in tonnes of CO2e
36239
36239
36239
36239
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Apr 2011- Mar 2012
Apr 2012- Mar 2013
Apr 2013- Mar 2014
Apr 2014- Mar 2015
Apr 2015- Mar 2016
Apr 2016- Mar 2017
Total estimated reductions (tonnes of CO2 e)
Total number of crediting years
36239
36239
36239
36239
36239
36239
362390
Annual average over the crediting period of
estimated reductions ((tonnes of CO2 e)
36239
10
A.4.5. Public funding of the project activity:
No public funding is available for the project activity
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:
Title:
Consolidated baseline methodology for waste gas and/or heat and/or pressure for power
generation.
Reference: Revised approved consolidated baseline methodology ACM0004/ Version 02, Sectoral
Scope: 01, 03 March 20061.
B.2
Justification of the choice of the methodology and why it is applicable to the project
activity:
As stated in the “Consolidated baseline methodology for waste gas and/or heat and/or pressure for power
generation”,
“This methodology applies to project activities that generate electricity from waste heat or the
combustion of waste gases in industrial facilities”
- The project activity of NRL will involve an energy efficiency measure whereby the surplus HP steam of
the process as well as the PRDS HP steam is passed through an STG for power generation. The waste
1
Refer - http://cdm.unfccc.int/EB/Meetings/023/eb23_repan8.pdf
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heat of the surplus HP steam as well as the pressure energy which is wasted across the PRDS will be
recovered and utilized for power generation.
Apart from this key applicability criterion, the project activity is required to meet the following
conditions in order to apply the baseline methodology“The methodology applies to electricity generation project activities:”
1. “that displace electricity generation with fossil fuels in the electricity grid or displace captive
electricity generation from fossil fuel”
- The electricity generated in STG utilizing the surplus HP steam from the process as well as the PRDS
HP steam would reduce generation load of the existing GTG thereby reducing fossil fuel consumption at
the GTG end of the CPP.
2. “Where no fuel switch is done in the process, where the waste heat or pressure or the waste gas is
produced, after the implementation of the project activity”
-The surplus HP steam as well as the HP steam which is let down through PRDS comes from the main
HP steam header. HP steam generated from the process Waste Heat Recovery Boilers (WHRBs), fuel oil
fired Utility Boiler (UB) and Heat Recovery Steam Generator (HRSG) in the downstream of GTG join
the main HP steam header of the refinery. No fuel switch is planned in the crediting period at the
generation points of the HP steam joining the main HP steam header. The project activity thus meets both
the applicability criteria of the methodology.
Furthermore,
“The methodology covers both new and existing facilities”
- The project activity will be undertaken in the existing petroleum refinery of NRL.
As stated above, the project activity under consideration meets all the applicability conditions of the
baseline methodology. This justifies the appropriateness of the choice of methodology in view of the
project activity and its certainty in leading to a transparent and conservative estimate of the emission
reductions directly attributed to the project activity.
B.3.
Description of the sources and gases included in the project boundary
As per the methodology,
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“The spatial extent of the project boundary comprises the waste heat or gas sources, captive power
generating equipment, any equipment used to provide auxiliary heat to the waste heat recovery process,
and the power plants connected physically to the electricity grid that the proposed project activity will
affect”.
Based on the definition as per the proposed methodology, the project boundary covers the captive power
generation system of the refinery.
The following components of the CPP would be covered in project boundary:

Gas Turbine Generators with HRSG in downstream

12 MW Steam Turbine Generator including HP steam inlet line and MP, LP extractions and the
vacuum condenser

PRDS 1&2

All the auxiliary electrical loads for the project activity
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PROJECT BOUNDARY
Naphtha
Gas
Turbine
HRSG
PROCESS
GENERATION
Utility
Boiler
VENT
LOSS
H2U
ELECTRICITY
CV
-1
HP HEADER
PROCESS
LOAD
H2U
~
12 MW
STG
BFW
~
CW
~
PROCESS
GENERATOR
HCU/DCU/SRB
LOSS
CW
MP HEADER
CW
CV
-2
CONDENSOR
BFW
PROCESS
LOAD
H2U/HCU/CDU/
VDU/DCU/SRB
PROCESS
GENERATOR
HCU/CDU/VDU/D
CU/SRB
~
~
LOSS
LP HEADER
PROCESS LOAD
H2U/HCU/CDU/VDU
/DCU/SRB/OFF
SITE/NRMT
POWER GRID OF
THE REFINERY
UTILITY
CGP (D/A) + ETP
PRDS
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RGC Gland
RGC turbine
ejector
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Abbreviations:
PRDS
Pressure Reducing and De-super heater
BFW
Boiler Feed Water
CW
Cooling Water
CV
Control Valve
ETP
Effluent Treatment Plant
HRSG Heat Recovery Steam Generator
H2U
Hydrogen Unit
HCU
Hydrocracker Unit
UB
Utility Boiler
SRB
Sulfur Recovery Block
In accordance with the methodology, the following emission sources are considered for the purpose of
determination of baseline emissions and project emissions.
Project Activity
Baseline
Table B-1: Sources and types of pollution included in the project boundary
2
Table B-1: Overview on emission sources included in or excluded from the project boundary
Source
Gas
Included
Justification/ Explanation
CO2
Included
Main emission source
Grid
electricity CH4
Excluded
Excluded
for
simplification.
This
is
generation
conservative.
N2O Excluded
Excluded for simplification
CO2
Excluded
This is not applicable as the baseline scenario
Captive
electricity CH4
for the project activity is not captive electricity
generation
generation (please refer to Section B.4 of this
N2O
PDD).
CO2
Included
May be an important emission source. There is
no fossil fuel consumption in the project
activity. However the same will be monitored
On-site fossil fuel
during the proposed crediting period and
consumption due to
emissions from the same, if found to be
the project activity
significant2, will be deducted.
CH4
Excluded
Excluded for simplification.
N2O Excluded
Excluded for simplification.
Combustion of waste CO2
Excluded
It is assumed that the DRI kiln gas would also
gas for electricity
have been combusted in the baseline scenario as
generation
per the statutory requirements.
Say, 1% of total emission reductions resulting from the project activity.
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CH4
N2O
Excluded
Excluded
Excluded for simplification.
Excluded for simplification.
B.4.
Description of how the baseline scenario is identified and description of the identified
baseline scenario:
The project activity involves utilization of the surplus HP steam as well as the PRDS HP steam in the
STG whereby the waste heat of the surplus HP steam and the pressure energy of the HP steam which is
wasted across the PRDS during throttling is recovered and utilized for power generation in the STG. The
methodology is applied in the context of the project activity as follows:
Identification of Alternative Baseline scenarios and selection of appropriate baseline scenario:
As per the methodology, the project proponent should include all possible options that provide or
produce electricity (for in-house consumption and/or export) as baseline scenario alternatives. These
alternatives are to be verified for legal and regulatory compliance requirements and also for their
dependence on key resources such as fuels, materials or technology that are not available at the project
site. Further, among those alternatives that do not face any prohibitive barriers, the most economically
attractive alternative is to be considered as the baseline scenario.
Two plausible alternative scenarios were available with the project proponent that was contemplated
during project inception stage:
Alternative 1: No project option – Continuation of the existing practice of captive power
generation
This is the continuation of existing practice. In this scenario PRDS 1&2 will be operated for letting down
HP steam to MP and LP level with corresponding loss of pressure energy due to throttling process.
Surplus HP steam in the steam distribution network will be vented and the heat content of the HP steam
will be wasted. The entire power demand of the refinery complex will be met by operating the GTG, as a
result equivalent amount of CO2 will be released. This alternative is in compliance with all applicable
legal as well as regulatory requirements and can be a baseline option.
Alternative 2: Implementation of the Project Activity without CDM benefit
This option involves installation of 12 MW STG which will utilize the PRDS HP steam and surplus HP
steam of the steam distribution network to generate power. MP and LP extraction steam from STG will
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be used to meet process steam requirement of the refinery. This alternative is in compliance with all
applicable legal and regulatory requirements and this option would result in reduction in CO 2 emissions.
However, for this option, the project proponent would face a number of regulatory, investment and
technological barriers (as detailed in Section B5 below) making it predictably prohibitive. Hence this
option is not a part of baseline scenario.
Evaluation of the alternatives on economic attractiveness:
Continuation of the existing practice i.e. captive power generation through GTG and letting down HP
steam through PRDS for producing MP and LP steam does not require any additional investment.
However, the project activity involves capital investment for purchase, installation, commissioning and
operation of the STG and other auxiliaries.
Since only two alternatives are possible for the project activity no separate evaluation has been
performed for calculating economic attractiveness of the identified alternatives.
Thus in view of the above discussion, the Baseline Alternative 1: ‘The continuation of the current
situation’ is the most likely baseline scenario and has been considered as business as usual scenario for
the baseline emission calculations. Further, the fact that this is a common practice being followed by the
other similar industries in the similar sector of industries (business-as-usual-scenario) corroborates that
Alternative 1 represents the most appropriate baseline scenario. Among the other petroleum refining
industries in the country the project activity has achieved less penetration due to perceived technical and
operational risks associated with the project activity (as elaborated in section B.5).
Establishing the additionality for the project activity
This step is based on “Tool for the demonstration and assessment of additionality – Version 2” as
provided in Annex 8 to the ‘EB–22 meeting report’ of the twenty second meeting of CDM Executive
Board. Information/data related to preliminary screening, identifying alternatives, common industry
practice and other financial, regulatory and technology related barriers were used to establish the
additionality. Details of establishing additionality are explained in section B5.
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): >>
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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 absence of the
registered CDM project activity.
The proposed project activity is energy efficiency improvement activity and results into net reduction in
CO2 emissions of facility.
Following steps of additionality test are followed with respect to the project activity of NRL for
demonstration of additionality
Step 0. Preliminary screening of projects started after 1 January 2000 and prior to 31 December
2005
The project will be commissioned in July 2007. The CDM fund was seriously being considered before
starting the planning of project. There are sufficient evidences available in the form of documentation
that shows that the CDM incentive played an important role in the decision-making.
Step 1: Identification of alternatives to the project activity consistent with current laws and regulations
Define realistic and credible alternative scenarios to the CDM project activity that can be (part of) the
baseline scenario through the following sub-steps:
Sub-step 1a. Define alternatives to the project activity:
The alternatives to the proposed project activity are ‘Continuation of the existing practice for captive
power generation (Alternative 1)’ and ‘Implementation of the project activity without CDM benefit
(Alternative 2)’. The detail of these alternatives to the project activity are presented in section B.3
Sub-step 1b. Enforcement with applicable laws and regulations:
For the energy efficiency projects in petroleum refinery, there is no legal mandate applicable for the
project proponent. But the project complies with all good and safe engineering practices.
Step 2. Investment Analysis
The project proponent does not follow this step to demonstrate additionality, but follows step-3 for
barrier analysis.
Step 3. Barrier Analysis
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If this step is used, determine whether the proposed project activity faces barriers that:
(a) Prevent the implementation of this type of proposed project activity and
(b) Do not prevent implementation of at least one of the alternatives.
Use the following sub-steps:
Sub-step 3a. Identify barriers that would prevent a wide spread implementation of the proposed project
activity:
Following are the barriers that would prevent the proposed project activity from being carried out if the
project was not registered as a CDM activity.
Barrier due to prevailing practice:
The project is not the prevailing practice in the petroleum refining industry in India. Therefore, the
project proponent lacks the familiarity with such project.
The project is the “first of a kind”:
The project activity is the ‘first of its own kind’ in the Indian petroleum refining industry of India. In
large scale industries like petroleum refinery accurate control of steam flow at various pressure and
temperature level is of critical importance. Such control of steam flow at various pressure levels is
usually controlled by PRDS which operates reliably without any risk of failure. Therefore, in Indian
petroleum refineries use of PRDS is a common practice for controlling the steam flow and meeting the
additional MP and LP steam demand. However, the project proponent has decided to keep the PRDS as
stand-by and utilize the entire PRDS HP steam as well as the surplus HP steam from the process in the 12
MW extractions cum condensing type STG thereby entirely controlling the steam flow to the process
from MP and LP extractions by the governor control system of the STG itself. This technological
modification bears technical and operational risks as elaborated in the section ‘Technological Barrier’.
Although the reliability of this technical modification in the utility system has not yet been established in
Indian petroleum refining industry the project proponent has decided to cross the associated barriers and
go ahead with the CDM project activity. If the project activity is successful it has good replication
potential across the petroleum refining industry. Therefore it would ensure that greater amount of CO 2
reduction will take place across the industry wherein this technology would be successfully applied.
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The high risk of new technology therefore prevents widespread implementation of the project activity.
Technological barriers
Since the implementation of this energy efficiency measure is entirely new in Indian refinery sector, the
operational difficulties associated with the unforeseen circumstances are not yet fully experienced. The
technical people of NRL are not trained in handling the operational risks. Some of the potential risks
identified by the project proponent are as follows:
With the implementation of the project activity all the three steam headers as well as the power system of
the refinery will become dependent on this 12 MW extractions cum condensing type STG as it will take
the inlet steam from HP header and control the header pressure of both the MP and LP steam headers and
feed power to the tune of 8.3 MW to the refinery grid. During the project activity implementation the
existing GTG has to be synchronized accurately with the STG. Major risks of the project activity arises
out of the tripping or malfunctioning of the STG which may lead to the following operational problems
in the refinery complex:
Problem of frequency synchronization:
Since, the GTG would be synchronized with the STG, tripping of STG may create sudden load
fluctuation in the GTG thereby leading to tripping of the GTG also. As a result the entire power
system of the refinery would collapse leading to black-out situation.
Impact of steam supply fluctuation on the refinery process:
Steam sensitivity of the process: In many refinery processes supply of steam at specific
temperature and pressure level is of critical importance.
A case in point is the Hydrogen Unit (H2U) which produces hydrogen through steam reforming
of naphtha using HP steam. ‘Steam:carbon’ ratio (which is the ratio of steam to hydrocarbon) is a
critical process parameter which needs to be maintained at an optimum level for both the Prereformer as well as the Reformer of H2U.
If the steam:carbon ratio falls below the optimized value then H2U catalyst will be spoilt due to
coke deposition on the catalyst and as a result the H2U will trip immediately and has to remain
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under shutdown. Shutdown of H2U will cause de-activation of the catalyst and start-up of the
unit will take more than six months because the fresh catalyst is supplied by the vendor Haldor
Topse. Tripping of H2U will lead to subsequent tripping of the Hydrocracker Unit (HCU) since
HCU requires hydrogen as feed. Emergency tripping of HCU bears the spoiling and deactivation
risk of the expensive HCU catalyst. As a consequence, the entire refinery would go under
shutdown for more than six months. This situation if occurs has serious financial implication for
the refinery since both H2U catalyst as well as HCU catalyst are very costly (H2U catalyst~INR
20 crore; HCU catalyst ~INR 30 crore) and both the catalysts are supplied by the foreign
vendors. Furthermore, shutdown of the entire refinery for more than six months will result in
huge production losses during the shutdown, start-up and intermediate periods. For a stand-alone
refinery like NRL production loss for such a long period of time would result in financial loss of
very high magnitude and adversely impact the company’s bottom-line.
Similarly, MP and LP steam are extensively used in the main distillation columns as well as in
the strippers, re-boilers etc. of various process units. These units will also be affected in case of
disruption or fluctuation of MP and LP steam supply from the CPP due to tripping of STG and
result in deterioration of product quality from these units.
Operational problems affecting steam supply to the process: The project activity is the
passage of both the PRDS HP steam as well as the surplus HP steam through the newly installed
STG thereby keeping both the PRDS 1&2 as stand by. As per the standard operating procedure
(SOP) of the refinery in case of fault or tripping of the turbine the PRDS valves should open and
maintain the un-inhibited supply of steam to the process at MP and LP level. However, the
following operational problems are envisaged
Two-phase flow in PRDS steam line: If steam flow is not maintained continuously then gradual
deposition of condensate takes place in the steam line. Usually, a very low steam flow is
maintained to remove this condensate; however, this practice is often proved technically
infeasible since it is difficult to completely remove the condensate deposited in the steam line
maintaining a lower amount of steam flow through-out. As a result during the tripping of turbine
when suddenly the steam by-pass line of PRDS 1&2 is opened there is considerable chance of the
occurrence of two phase flow (steam and condensate) in the steam line which can result in
thermal as well as mechanical shock (hammering) and resultant damage of the steam line.
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Furthermore, problems due to the following abnormal situations are also envisaged:
Operational problems
Resultant effects
-Delay or slow opening
 Pressure build-up in the HP steam distribution line. During sudden
of any or both the
increase in the steam pressure the relief valves will blow, however, in
turbine bypass steam
most of the cases the relief valves do not get re-set and as a result the
valves
steam pressure will once again come down below the required level.
-Any
or
both
the
turbine by pass steam
valves do not open at
all

Sudden drop down of MP and LP steam flow to the process
 Disturbance of the optimum steam flow to Pre-reformer and Reformer
of H2U
 Disturbance of steam flow to distillation columns, strippers, reboilers, turbines and other units
Other Barriers:
Barriers due to lack of awareness about available technologies, products; limited dissemination of
information on operation know how; limited managerial resources; organizational capacity:
Since, the project activity does not have any precedence in other petroleum refineries of India NRL
personnel at various levels lacked relevant managerial background for project activity implementation,
operation and maintenance. They are also not well-equipped to handle the situation in case the refinery
processes are disturbed due to above mentioned technical as well as operational risk factors associated
with the project activity. They have to be trained in the proper manner to ensure smooth operation.
In-spite of all these barriers NRL would implement the project activity considering the GHG emission
reduction potential of the proposed project activity.
Sub-step 3 b. Show that the identified barriers would not prevent a wide spread implementation of at
least one of the alternatives (except the proposed project activity already considered in step 3a):
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The alternative to the project activity (i.e. power generation through GTG and continuing MP and LP
steam generation through PRDS 1&2) is relatively more familiar practice, more reliable and less risky, as
it is proven across the petroleum refining industry, however, this alternative does not contribute to GHG
emission reductions. The implementation of the project activity would involve several technological,
operational and common practice barriers. In-spite of all the associated barriers NRL has decided to
implement the project activity considering its GHG emission reduction potential.
Step 4. Common Practice Analysis
Sub-step 4a. Analyse other activities similar to the proposed project:
There is no activity similar to the proposed project activity in India.
Sub-step 4b. Discuss any similar options that are occurring:
Not applicable
Step 5. Impact of CDM Registration
As stated earlier, during the conceptualization of the proposed CDM project activity the potential CDM
revenue that would flow to the project activity had been seriously considered. Following impacts of
CDM fund are identified from the point of view of mitigation of risks and barriers discussed above.

CDM fund will provide additional coverage to the risks associated with the project activity and help
in mitigating the other technical risk factors as mentioned above.

CDM funds will provide the training support to NRL employees in understanding operational
accuracies and troubleshooting measures during operational problems.
The fund will stimulate R&D efforts in NRL to find methods of mitigating risks and enhance replication
of such energy efficiency projects or process improvement schemes in petroleum refining industry, to
promote GHG abatement.
B.6.
Emission reductions:
B.6.1. Explanation of methodological choices:
In the project scenario, the waste energy (heat and pressure) of the HP steam would be utilized to
generate power in the STG; MP and LP steam extraction from STG will be used in the process. In the
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baseline scenario the same amount of power would have been met by the fossil fuel based GTG and
producing MP and LP steam for process by HP steam let down through PRDS.
Algorithm for calculation of emission reduction is as follows:
The Captive Power Plant (CPP) of NRL will consist of Gas Turbine Generator (GTG) and Steam Turbine
Generator (STG) which would be installed under the project activity to operate through surplus HP steam
as well as the PRDS HP steam. Power generation from STG would reduce the same quantum of power
generation from GTG through combustion of fossil fuel thereby reducing equivalent amount of CO 2
emissions from the CPP. In the baseline scenario the same amount of CO2 would be emitted.
CO2 generation from combusting fossil fuel in the GTG in the baseline scenario:
1. Total power generation from the STG (in MWh/annum) = PSTG =EGGEN
2. Auxiliary consumption consists of the power consumption for the auxiliary electrical loads
required to be operated for the project activity
Total auxiliary consumption (in MWh/annum) = EG AUX
(to be conservative EGAUX will be taken as the sum of the rated capacity of the auxiliary
electrical loads)
3. Net power generation from the project activity EGy (in MWh/annum) = EGGEN - EGAUX
4.
Emission factor for displaced electricity:
EFcaptive,y = (EFCO2, i / Eff captive)* 44/12 *( 3.6 TJ/ 1000 MWh)
Where,
EFcaptive,y : Emission factor for captive power generation (tCO2/MWh)
EFCO2, i: weighted average CO2 emissions factor of the fuels used in captive power generation (tC/TJ)
Effcaptive: Efficiency of captive power generation (nameplate efficiency of GTG)
44/12: Carbon dioxide conversion factor
3.6/1000: TJ to MWh conversion factor
Boiler efficiency has been assumed as 100% for a conservative estimation
5. CO2 emissions that would have been resulted from CPP in absence of the project activity:
BEy = CO2,baseline
CPP
= Net power generation from the project activity * Emission factor for
displaced electricity
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= EGy (in MWh/annum) * EFcaptive, y (tCO2/MWh)
BE: Baseline CO2 emissions per annum
6. Project Emission (PEy) = 0
7. Emission Reduction from the project activity (ERy) = BEy – PEy
B.6.2. Data and parameters that are available at validation:
The following parameters, required for the computation of baseline emissions and project emissions (and
hence emission reductions resulting from the project activity), are standard parameters which will not be
monitored throughout the crediting period and will remain fixed for the entire crediting period. The same
will be produced to the Validator during validation of the project activity.
Data / Parameter:
Data unit:
Description:
Source of data used:
Value applied:
Justification of the
choice of data or
description of
measurement methods
and procedures
actually applied :
Any comment:
NCVNG
Kcal/kg
Data / Parameter:
Data unit:
Description:
Source of data used:
Value applied:
Justification of the
choice of data or
description of
measurement methods
and procedures
actually applied :
Any comment:
EFNG
tC/TJ
Emission factor of Natural gas used as fuel
IPCC 2006 default value
17.2 tC/TJ
This parameter is important for baseline calculation.
Net Calorific Value of the natural gas
Laboratory Analysis
11000kcal/kg
This parameter is important for baseline calculation.
The data will be measured once in a month.
This data will be tested by the accredited laboratory.
Computation with data published by international standard/ authorised
government agency and statistics available in the public domain will ensure the
reliability of the parameter. Furthermore, conservative approach has been
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followed for the computation.
Data / Parameter:
Data unit:
Description:
Source of data used:
Value applied:
Justification of the
choice of data or
description of
measurement methods
and procedures
actually applied :
Any comment:
NCVHSD
kcal/kg
Net Calorific Value of HSD used
Laboratory Analysis
9800 kcal/kg
This data is important for baseline emission calculation.
This data will be measured on monthly basis.
Data / Parameter:
Data unit:
Description:
Source of data used:
Value applied:
Justification of the
choice of data or
description of
measurement methods
and procedures
actually applied :
Any comment:
EFHSD
tC/TJ
Total Carbon Content of HSD used in GTG
IPCC 2006 default value
20.99 tC/TJ
This data is important for baseline emission calculation
Data / Parameter:
Data unit:
Effcaptive
Description:
Source of data used:
Value applied:
Justification of the
choice of data or
description of
measurement methods
and procedures
actually applied :
Any comment:
Emission Factor for the Captive Power Plant
Name plate efficiency of the GTG
40%
As per the Baseline Methodology of ACM 0004, the nameplate efficiency of
the GTG based CPP will be taken into consideration.
This data will be tested by the accredited laboratory.
Computation with data published by international standard/ authorised
government agency and statistics available in the public domain will ensure the
reliability of the parameter. Furthermore, conservative approach has been
followed for the computation.
%
Since, in absence of the project activity the entire power will be generated by
GTG only the efficiency of the CPP with GTG in operation will be used for
emission reduction calculations.
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Fixed parameter for the computation of Project Emissions
As mentioned above in Section B.6.1 of the PDD, no auxiliary fuel firing for generation start up
or for emergency situations will be will be required for the project activity. The project emission, under
such circumstance will be zero.
B.6.3 Ex-ante calculation of emission reductions:
Ex-ante estimation of Baseline Emissions
The ex-ante computation of baseline emission for the project activity (please refer to ‘Annex-3: Baseline
Information’ for detail computation) is tabulated below:
Sl.
Operating
No.
Year
Emission Factor
for
captive
power
generation, EFy
(tCO2/MWh)
Baseline Emission
(tonnes of CO2 e)
1.
Aug 2007- Jul 2008
0.57
2.
Aug 2008- Jul 2009
0.57
36239
36239
3.
Aug 2009- Jul 2010
0.57
36239
4.
Aug 2010- Jul 2011
0.57
36239
5.
Aug 2011- Jul 2012
0.57
36239
6.
Aug 2012- Jul 2013
0.57
36239
0.57
36239
7.
Aug 2013- Jul 2014
0.57
36239
8.
Aug 2014- Jul 2015
0.57
36239
9.
Aug 2015- Jul 2016
0.57
36239
10.
Aug 2016- Jul 2017
Total
362390
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Ex-ante estimation of Project Emissions
As per ACM 0004 the Project Emissions are applicable only if auxiliary fuels are fired for generation
startup, in emergencies, or to provide additional heat gain before the HP steam enters the STG for power
generation. Since in the project case of NRL, no auxiliary fuels are fired, no project emission is
considered. Therefore,
PEy = 0
where,
PEy = Project Emissions in the year y (tCO2)
Ex-ante estimation of Leakage Emissions
The methodology does not require the project proponent to consider any leakage emissions. Therefore,
Ly = 0
where,
Ly = Leakage Emissions in the year y (tCO2)
Ex-ante estimation of Emission Reductions
The ex-ante computation of emission reductions resulting from the project activity (please refer to
‘Annex-3: Baseline Information’ for detail computation) is tabulated as below:
Sl.
Operating
Emission Reductions
No.
Year
(tonnes of CO2 e)
1.
Aug 2007- Jul 2008
2.
Aug 2008- Jul 2009
36239
36239
3.
Aug 2009- Jul 2010
36239
4.
Aug 2010- Jul 2011
36239
5.
Aug 2011- Jul 2012
36239
6.
Aug 2012- Jul 2013
36239
7.
Aug 2013- Jul 2014
36239
8.
Aug 2014- Jul 2015
36239
9.
Aug 2015- Jul 2016
36239
10.
Aug 2016- Jul 2017
36239
Total
362390
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B.6.4
Summary of the ex-ante estimation of emission reductions:
Aug 2007- Jul 2008
Estimation of
Project activity
Emission
reductions
(tonnes of CO2
e)
0
Aug 2008- Jul 2009
0
36239
36239
Aug 2009- Jul 2010
0
Aug 2010- Jul 2011
Year
Estimation of
baseline
Emissions
reductions
(tonnes
of CO2 e)
Estimation of
leakage
(tonnes
of CO2 e)
0
Estimation of
emission
reductions
(tonnes of
CO2 e)
0
36239
36239
36239
0
36239
0
36239
0
36239
Aug 2011- Jul 2012
0
36239
0
36239
Aug 2012- Jul 2013
0
36239
0
36239
Aug 2013- Jul 2014
0
36239
0
36239
Aug 2014- Jul 2015
0
36239
0
36239
Aug 2015- Jul 2016
0
36239
0
36239
Aug 2016- Jul 2017
0
36239
0
36239
Total (tonnes of
CO2 e)
0
0
362390
B.7
362390
Application of the monitoring methodology and description of the monitoring plan:
Title: Consolidated monitoring methodology for waste gas and/or heat and /or pressure for power
generation.
Reference: Revised approved consolidated monitoring methodology ACM0004/ Version 02, Sectoral
Scope: 01, 03 March 2006
The approved consolidated monitoring methodology is designed to be used in conjunction with the
approved consolidated baseline methodology. The applicability conditions of the monitoring
methodology are identical with those with the baseline methodology. The project activity under
consideration meets all the applicability conditions of the approved consolidated baseline methodology
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(please refer to Section B.2 of the PDD for details). Hence it is justified to adopt the approved
consolidated monitoring methodology for the project activity.
Description of Monitoring Methodology
The methodology ACM0004 requires monitoring of the following:
 Net Electricity Generation from Project Activity (MWh / year) – The project activity accrues credits
for generating power in STG through recovery and utilization of waste heat of the surplus steam and
waste pressure energy of the steam across PRDS thereby reducing equivalent amount of power
generation through GTG. The power generation from STG as well as GTG will be directly monitored
by energy meters installed at the STG and GTG respectively. The auxiliary consumption for the
project activity will also be monitored. The project activity has employed state of the art monitoring
and control equipments that will measure, record, report and control the key parameters like total
power generated from STG, power generated from GTG and power used for auxiliary consumption.
The monitoring and controls is part of the Distributed Control System (DCS) of the entire plant. All
instruments are calibrated and marked at regular interval to ensure accuracy.
 Data needed to calculate carbon dioxide emission factor of the CPP – To compute the CO2 emission
factor (tCO2/MWh) for the CPP of the refinery the following will be required:
-
IPCC default value of CO2 emission factor of natural gas and HSD (auxiliary fuel) in
terms of (tC/TJ)
-
Efficiency (%) of the CPP
The efficiency of the CPP has been computed as per the following methodological steps:
“Use the highest value among the following three values as a conservative approach:
1. Measured efficiency prior to project implementation;
2. Measured efficiency during monitoring;
3. Manufacturer nameplate data for efficiency of the existing boilers”
Among the above three options available, the nameplate efficiency of the GTG has been taken into
consideration for calculation of the efficiency of the CPP since in the baseline scenario the entire power
demand will be supplied by the GTG only.
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B.7.1
Data and parameters monitored:
The approved consolidated monitoring methodology requires the project proponent to monitor the
following parameters for the computation of baseline emissions, project emissions and hence emission
reductions. The parameters and the monitoring procedures are detailed below:
Data / Parameter:
Data unit:
Description:
Source of data to be
used:
Value of data applied
for the purpose of
calculating expected
emission reductions in
section B.5
Description of
measurement methods
and procedures to be
applied:
QA/QC procedures to
be applied:
Any comment:
Data / Parameter:
Data unit:
Description:
Source of data to be
used:
Value of data applied
for the purpose of
calculating expected
emission reductions in
section B.5
Description of
measurement methods
and procedures to be
applied:
QA/QC procedures to
be applied:
EGGEN
MWh/year
Total electricity generated in the project activity in the year y
Plant Log Book/DCS
8.01 MW
The data will be recorded on hourly basis.
This data will be measured at the output of STG to the best accuracy with the
help of a kWh meter and will be monitored continuously in DCS. The same data
will be recorded shift-wise in the log book and the daily report will be archived
for 10+2 years.
Yes
The instrument for measurement of the data will be calibrated at regular interval
EGAUX
MWh/year
Auxiliary electricity (i.e. electricity consumption of the auxiliary loads) in the
year y
Rated Capacities
This data will be calculated one-time. In case there is any addition of the
auxiliary load in the crediting period the same will be added accordingly.
The auxiliary consumption is calculated as the sum of the rated capacity of the
individual auxiliary electrical loads.
Yes
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Any comment:
The rated capacities are taken for a conservative estimate
Data / Parameter:
Data unit:
Description:
EGy
MWh/year
Net electricity generated in the project activity (and hence substituted from the
grid) in the year y
Plant Log Book
Source of data to be
used:
Value of data applied
for the purpose of
calculating expected
emission reductions in
section B.5
Description of
measurement methods
and procedures to be
applied:
QA/QC procedures to
be applied:
Any comment:
B.7.2
The parameter will be calculated from EGGEN and EGAUX
Yes
Description of the monitoring plan:
Please refer to ‘Annex-4: Monitoring Plan’ of the PDD for detail description of the Monitoring Plan.
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:
January 2005
Name of person/entity determining the baseline:
NRL is the project participant.
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SECTION C. Duration of the project activity / crediting period
C.1
Duration of the project activity:
C.1.1. Starting date of the project activity:
01/05/2006
C.1.2. Expected operational lifetime of the project activity:
20y 0m
C.2
Choice of the crediting period and related information:
C.2.1. Renewable crediting period
C.2.1.1.
Starting date of the first crediting period:
Not Applicable
C.2.1.2.
Length of the first crediting period:
Not Applicable
C.2.2. Fixed crediting period:
C.2.2.1.
Starting date:
01/08/2007
C.2.2.2.
Length:
10 y 0 m
SECTION D. Environmental impacts
>>
D.1.
Documentation on the analysis of the environmental impacts, including transboundary
impacts:
The only environmental impacts from this work are positive-reductions in fossil fuel use and associated
pollution. There are no negative environmental impacts from the installation of this project activity. The
technologies are easily transportable and installation does not require any major construction equipment.
This project does not require an environmental impact assessment (EIA) under Indian law.
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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:
Not Applicable
SECTION E. Stakeholders’ comments
E.1.
Brief description how comments by local stakeholders have been invited and compiled:
Identification of stakeholders:
NRL will be implementing a project activity of utilization of waste heat and waste pressure energy of HP
steam of the refinery. The project leads to zero net GHG on-site emissions. Some of the key stakeholders
identified for the project are as under:
 Representatives of the District Authority - Golaghat
 Assam Pollution Control Board (APCB)
 Employees of NRL
NRL has applied/communicated to the relevant stakeholders to get the clearances as per statutory
requirement. NRL has also received comments from some of the relevant stakeholders.
The project would receive public comments while on the UNFCC website, which has been addressed in
the process of methodology approval. Further, as part of registration process, public comments will be
invited by appointed DOE.
E.2.
Summary of the comments received:
The project initiative has also been formally appreciated by some of the key stakeholders who are in
regular communication with NRL.
E.3.
Report on how due account was taken of any comments received:
The relevant comments and important clauses mentioned in the project documents/clearances like Project
Viability Report, environmental clearances, local clearance etc. were considered while preparation of
CDM project design document. The NRL representatives met with the various stakeholders for appraisal
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page 33
and support. They were commended for their voluntary action toward environmental development and
energy efficient measures undertaken in this project activity.
As per UNFCCC requirement this Project Design Document (PDD) will be published at the validator’s
web site for public comments.
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Annex 1
CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY
Organization:
Numaligarh Refinery Limited
Street/P.O.Box:
Building:
-
City:
Numaligarh
State/Region:
Assam
Postfix/ZIP:
785699
Country:
India
Telephone:
91-03776-265737
FAX:
91-03776-265578
E-Mail:
ajit.k.maiti@nrl.co.in
URL:
www.nrl.co.in
Represented by:
Mr. A.K.Maiti
Title:
Senior Manager, Technical Services
Salutation:
Mr.
Last Name:
Maiti
Middle Name:
Kumar
First Name:
Ajit
Department:
Mobile:
-
Direct FAX:
-
Direct tel:
-
Personal E-Mail:
-
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Annex 2
INFORMATION REGARDING PUBLIC FUNDING
No public funding for this project
Annex 3
BASELINE INFORMATION
Baseline for the project activity is continuation of existing practice i.e. generation of captive power from
GTG.
Sl. No.
Parameter/data type
1
Baseline power generation
from GTG
2
Emission factor for natural
gas used in GTG
3
Emission factor for HSD
used in GTG
4
Weighted average emission
factor for fuels used in
GTG
5
Nameplate efficiency of the
CPP (this is the nameplate
efficiency of the GTG)
6
Baseline CO2 emission
factor for CPP
7
No. of operating hours per
annum
8
Baseline emissions from
CPP
Unit
Data
Source
MW
8.01
NRL source
tC/TJ
16.09
NRL source
tC/TJ
20.99
NRL source
tC/TJ
16.27
NRL source
%
40
NRL source
tCO2/MWh
0.54
NRL source
Days
330
NRL source
tCO2/annum
34070
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PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03.1.
CDM – Executive Board
page 36
Annex 4
MONITORING INFORMATION
The Monitoring and Verification (M&V) procedures define a project-specific standard (baseline of
historical emissions) against which the project's performance (i.e. GHG reductions) and conformance
with all relevant criteria will be monitored and verified. It includes developing suitable data collection
methods and data interpretation techniques for monitoring and verification of GHG emissions with
specific focus on specific energy consumption parameters. It also allows scope for review, scrutinize and
benchmark all this information against reports pertaining to M & V protocols.
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.
The project employs latest state of art monitoring and control equipment that measure, control and record
various key parameters.
Parameters monitored will be as follows:
1. The monitoring of power output from GTG and STG
2. Monitoring auxiliary consumption in the project activity
3. Monitoring of NCV value of natural gas and HSD used as fuel in the GTG
4. Monitoring of C% in natural gas and HSD
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.
GHG SOURCES
Direct On-Site Emissions
Direct on-site emissions after implementation of the CDM project arise from the following sources.
Net emissions due to increased load for auxiliary consumption.
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PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03.1.
CDM – Executive Board
page 37
As discussed above, these emissions are monitored and taken into account while estimating net emission
reductions of project.
Direct Off-Site Emissions
There is no off-site emission due to the project.
Indirect On-Site Emissions
There is no indirect on-site emission due to the project.
Indirect Off-Site Emissions
No indirect off-site emissions could occur due to CDM project.
Project Parameters affecting Emission Reduction
Monitoring Approach
The general monitoring principles are based on:
 Frequency
 Reliability
 Registration and reporting
As the emission reductions from the project activity are determined by the reduction in the fossil fuel
consumption due to reduced electricity generation load on the GTG it is important to discuss the
monitoring principles in the context of monitoring these parameters.
Frequency of monitoring
The project developer has installed all metering facilities within the plant premises. The measurement is,
monitored and controlled through DCS on continuous basis and recorded shift-wise (8-hours shift) in log
sheets by operator, 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 of 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
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PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03.1.
CDM – Executive Board
page 38
indicate the date of calibration and the date of next calibration. Therefore it ensures the monitoring
system is highly reliable.
Registration and reporting
Registration is done on the basis of shift-wise data logging in computer. Daily, weekly and monthly
reports are prepared stating the steam reduction and electrical consumption.
The following reports will be generated for monitoring and controlling emissions.
The daily report of hourly data of power generation from STG and power output from GTG will be
prepared. The daily report of hourly data of reduction in power generation from GTG compared to the
baseline scenario would be kept on record. The power output from STG i.e. the electricity which is
generated through recovery and utilization of the waste heat of the surplus HP steam and waste pressure
energy of the PRDS HP steam will be multiplied with the baseline emission factor of the CPP to arrive at
the baseline emission factor.
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 two hourly basis. Fully functional management information is built,
which is generated through DCS in pre-decided daily reports formats so that accessing and verification of
actual data are possible at any point of time. A computerised MIS can be 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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