Calculating GHG emissions from the Indian thermal power sector - Version 2.0 July 2014Developed by The Energy and Resources Institute (TERI) and the World Resources Institute (WRI) and copyrighted.

User Agreement

By using the Worksheet and associated materials in any manner, the User agrees to the following terms of this agreement.

Copyright: The Worksheets and associated Guidance Document were developed by TERI and WRI, and are copyrighted. The User acknowledges these copyrights.

Acknowledgement: The User agrees to acknowledge TERI and WRI for their role in developing the Worksheets whenever the User authors reports or publications based on whole or part of these Worksheets. Disclaimer: The use of these tools is not a guarantee for an accurate or complete greenhouse gas emissions inventory. To develop a high quality inventory, it is essential to plan an inventory quality system that includes suitable internal and external reviews, and accuracy checks for activity data, emissions factors, and emissions calculations.

Structure of GHG emissions calucation tool for thermal power sector - Table of contents

1 -

2 -

3 -

4 -

5 -

6 -

7 -

8 -

9 -

10

11 - This sheet summarizes the inventory of emissions at facility level

12 - This sheet summarizes the inventory of emissions at company level

13 -

14 -

Important Note:

(usually found in the C:\Program Files\Microsoft Office\Office10 folder)

Introduction (Click here)

Flow sheet (Click here) The flowsheet gives a decision tree that guides the thermal power plants in using the various worksheets that follow in this calculation tool

General plant information (Click here) This sheet provides basic information on the plant and other basic data related to power generation

Direct emissions from stationary combustion - CO2 and SO2 (Click here)This sheet calculates the CO2 and SO2 emissions from the fuel burnt in the boilers as well as in other stationary combustion equipment like turbines, DG sets (for onsite power generation), furnaces, etc

Direct emissions from stationary combustion - CH4 and N2O(Click here)This sheet calculates the CH4 and N2O emissions from the fuel burnt in the stationary combustion equipments like boilers, turbines, DG sets, etc

Direct emissions from fuel combustion from mobile sources(Click here)This sheet calculates CO2 emissions from various company owned vehicles including mining equipment

CH4 emissions from the facility(Click here) This sheet calculates the total CH4 emissions from coal handling and storage in thermal power plants

SF6 emissions from the facility(Click here) This sheet calculates the SF6 emissions from electrical equipment in power plants

HFC emissions from the facility(Click here) This sheet calculates total HFC emissions from refrigeration and air conditioning equipment owned by thermal power plants

Indirect CO2 emissions from the purchased electricity(Click here) This sheet calculates the indirect CO2 emissions accruing from the consumption of electricity purchased from the grid.

Direct emission of CO2 from S02 Scrubbing(Click here) This sheet calculates the CO2 emissions from SO2 scrubbing plant installed in thermal power plants

Summary inventory for facilities(Click here)

Summary inventory for company(Click here)

Default Values(Click here) This sheet provides default values for emissions factors of CO2, CH4 and N2O, NCV of fuels and grid specific emission factors

Conversion factors(Click here) This sheet provides unit conversion factors for mass, volume and energy parameters

In case, "Macro" in the users system is not activated, the user must activate the same before using this tool. For activation, the user should create "Digital Certificate" by using following file path:

In Microsoft Windows Explorer, locate and double-click SelfCert.exe

If the SelfCert.exe file is not on your computer, you might need to install it.

Tool Introduction

Spreadsheets for calculating GHG emissions from Indian power sector - Version 2.0

This customized India specific power sector tool has been developed by The Energy and Resources Institute (TERI), New Delhi through a multi stakeholder consultative process involving interaction with different experts in the field. The tool is based upon the existing corporate GHG Inventory Protocol and tools developed by the World Resources Insitute (WRI), a Washington based NGO and World Buisness Council for Sustainable Development (WBCSD), a Geneva based coalition of international companies under their "Greenhouse Gas Protocol" initiative. The United States Environmental Protection Agency (USEPA) has supported this first version of the customized power sector tool for India. This tool presents a simple approach for inventorising the GHG emissions from a power plant facility, which can then be extended to corporate level. This is an integrated air emissions calculation tool which can be used to calculate both GHG emissions and other air emissions such as SO2 emissions (similar quantification methodologies can be applied to estimate these particular air emissions).

Before using this tool, users are encouraged to refer to the revised edition of "The Greenhouse Gas Protocol" - A Corporate Accounting and Reporting Standard (available at www.ghgprotocol.org), which provides GHG accounting principles, guidelines for setting boundaries, and additional guidance on other aspects of developing GHG inventory. Although the tool has been designed in a simplistic manner that enables the users to directly fill in the information, users should refer to the accompanying Guidance Document concurrently for using this customised tool, which gives the purpose and scope of the customized tool and instructions for filling the different worksheets in this tool.

These worksheets have been adapted from other WRI and WBCSD calculation tools to represent conditions in the Indian Thermal Power Sector. These worksheets enable the user to apply internationally accepted methodological approaches such as the GHG Protocol and IPCC guidelines (incorporating India-specific information where and when appropriate) to more accurately estimate GHG and SO2 emissions.

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The Version 1.0 of the Power Tool was prepared during the year 2007 and field tested in two Indian thermal power plants. It was reviewed by a group of Indian and international experts.TERI and WRI are grateful to the reviewers who had reviewed and provided comments on the tool. A list of reviewers is provided in the India Power Tool Version 1.0 Guidance Document. The tool was revised during the year 2014. The Power Tool Version 2.0 accommodates CO2 emissions from SO2 scrubbing plant. Further, the grid specific emission factors towards generation of electricity was also updated in Version 2.0 of Power Tool.

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(1) Flow chart estimating GHG emissions from Indian thermal power sector

OR

OR

OR

For equipment users who service their own

equipment

For equipment users who have contractors to service their equipment

Based on plant specific information on fuel

properties

Based on default fuel properties

Based on actual fuel consumption

Based on distance travelled

Sales based approach

Life cycle stage approach

Direct emissions from stationary combustion -CO2 (Scope 1) & SO2

Direct emissions from stationary combustion - CH4 & N2O (Scope 1)

Direct emissions from fuel combustion from different mobile sources- CO2

(Scope1) & SO2

CH4 emissions from storage and handling of coal from coal based power

plants (Scope 1)

Quantification of HFC emissions from refrigeration and air-conditioning

equipment (Scope 1)

Indirect CO2 emissions from consumption of purchased electricity (Scope 2)

General plant information

Quantification of SF6 emissions (Scope 1)

Summary of GHG emissions (Scope 1 and Scope 2) and SO2 emissions from

the facility

Summary of inventory for the company

Direct emissions of CO2 from SO2 scrubbing unit (Scope 1)

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(2) General plant information

Color code

Step 1a: Plant name and location of facility

Plant address

Telephone / Fax numbers

Email address

Contact person at plant and designation at plant

Company name

Country

Ownership (State/Private)

Step 1c: Any other additional information

Step 1b: Describe the operational boundries of the facility, e.g., "Facility is owned and controlled by reported company" (See Section 4.0) of the Guidance Document for further information on operational boundary approaches)

User entry

Default values

Auto calculated valueGo to Table of Content (click here)

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Step 2: Inventory Reporting Period

Start report dateEnd report date

Step 3: Operations that are included in the facility boundary for inventorisation Area

MiningCompany owned mining equipment

Company owned refrigeration and air-conditioning equipment

Purchase of power from grid, if any Combustion equipment 1. Boiler 2. Gas turbine 3. Diesel generator 4. Furnace5. Any others (Mention here)

Step 4 : Power generation detailsTotal plant capacity MWGross electricity generation million kWhAuxiliary electricity consumption million kWhNet electricity export million kWhElectricity imported from grid, if any million kWh

Step 5: Broad Specifications of major equipment

Equipment

Boiler Boiler 1Boiler 2Boiler 3Boiler 4Boiler 5Gas Turbine Gas Turbine 1Gas turbine 2Gas turbine 3Gas turbine 4

Reporting period (Type annually/quarterly/monthly)

On-site transportation (including residential colony) with company owned vehicles (cars/buses/jeeps/trucks, etc)

Circuit breakers containing SF6

Gas turbine 5Diesel Generator Diesel Generator 1Diesel Generator 2Diesel Generator 3Diesel Generator 4Diesel Generator 5Steam Turbine Steam Turbine 1Steam turbine 2Steam Turbine 3Steam Turbine 4Steam Turbine 5

SelectYesNo

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Units

TPHTPHTPHTPHTPH

MWMWMWMW

MW

MWMWMWMWMW

MWMWMWMWMW

Reset

Color code

Fuel Type I

Name of fuel Select the fuel

If "Others" fuel, specify the name of the fuel NA

If "Others" fuel, is it fossil fuel?

Fuel consumption

Net calorific value (NCV)

Carbon content %Sulphur content %Carbon oxidized fraction

If "Others" fuel, mention density of the fuel NA

(3) Estimation of direct emissions - CO2 (Scope 1) and SO2 from stationary combustion sources

Mention the number of types of fuels used in the plant for stationary combustion (e.g. diesel, natural gas, coal, rice husk etc.)

PART I : GENERAL DATA

PART II : FUEL PROPERTIES

Is plant specific data on following fuelproperties available?

User entry

Default values

Auto calculated value

Worksheet Introduction

(1) This sheet calculates CO2 and SO2 emissions from different fuels burnt in boilers as well as other stationary combustion equipment like gas turbines, DG sets (for on-site power generation), furnaces, etc.(2) Please add fuel consumption of similar type of fuel from various equipments within the plant and enter the cumulative value in "Fuel Type" column. Repeat the prcedure for other fuels, if required.(3) It is strongly recommended to use only plant specific data for "Fuel Properties". Default values should be used only when plant specific information is not available. (4) Users should use only NCV (Net Calorific Value) of fuel(s) under the "Fuel Properties". If only GCV (Gross Calorific Value) data is available, the user should convert it to NCV using the formula given under in the "Note" provided Table 1 of sheet "13- Default values".(5) For fuels not mentioned in the selection menu, the plant must select "Others" fue. Use only plant specific data for various fuel properties or use of plant specific data is required for Others fuel.(6) Since biomass is considered carbon neutral, CO2 emissions are reported separately in this sheet as "Memo item". They are also reported separately in the overall summary of GHG emissions for this facility that you will generate from using biomass. 7) SO2 emissions reported in the worksheet are not considered under Scope 1 and are reported seperately as "Memo Item" as it is not a controlled substance under Kyoto Protocol. (8) Please use appropriate units as instructed in the worksheet in all the sworksheets.

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PART III : CUSTOMIZED AND DEFAULT EMISSION FACTORS

######Default net calorific value (NCV) NA

###### NA

###### NA

######Default carbon oxidized factor NA

tonne

tonne

tonne

Memo Item

tonne

tonne

PART V: DATA FROM DIRECT MEASUREMENTS FROM THE PLANT

Customized CO2 emission factor kg CO2/GJ

Customized SO2 emission factor kg SO2/GJ

Default CO2 emission factor for the fuel kg CO2/GJ

Default SO2 emission factor for the fuel kg SO2/GJ

PART IV : ESTIMATED CO2 AND SO2 EMISSIONS

CO2 emissions

SO2 emissions

Total CO2 emissions (Scope 1)

Total SO2 emissions

Total CO2 emissions from biomass fuels

Calculate (Total Emissions) Reset

Please provide data from direct measurements of emissions, if available

Is on-line measuring equipment installed?

If "Yes", mention location of these online equipments?Average emissions measured (with appropriate units)

Whether any other method employed to measure actual emissions?

CO2 SO2 NOx and N2O Particular matter (PM)

Please provide data from direct measurements of emissions, if available

Whether any other method employed to measure actual emissions?

If yes, name the method (e.g. flue gas analyser, flue gas extraction/absorption method)

Imported non-coking coalNon-coking coalLigniteDieselNatural gasFurnace oilNaphthaWood, Wood WasteBaggaseMustard stalkRice huskOthers12345kilo LitretonneStd m3YesNo

Please provide data from direct measurements of emissions, if available

Particular matter (PM)

Please provide data from direct measurements of emissions, if available

Color code

PART I: GENERAL DATA

Fuel Type I

Name of the fuel Select the fuelFuel consumption 0

Specify density for liquid fuel NA

Net Calorific Value (NCV) 0.00PART II: DEFAULT EMISSION FACTORS

tonne

tonne

0.00 tonne0.00 tonne

Select the fuelImported non-coking coalIndian non-coking coalLigniteDieselNatural gasFurnace oilNaphthaOther petroleum oilWood, Wood WasteBaggaseMustard stalkRice huskOther biomass fuel12345kilo LitretonneStd m3

(4) Scope 1:Estimation of direct emissions of CH4 and N2O from stationary combustion sources

Default CH4 emissions kg CH4 / GJDefault N2O emissions kg N2O / GJ

PART III: ESTIMATED CH4 AND N2O EMISSIONSCH4 emissions

N2O emissions

Equivalent CO2 emissions from CH4

Equivalent CO2 emissions from N2O

User entry

Default values

Auto calculated value

Worksheet Introduction (1) This sheet calculates the CH4 and N2O emissions from the fuel burnt in the stationary combustion equipment like boilers, gas turbines, DG sets, etc. (2) Since plant specific data is normally not available, only default emission factors are used for estimating CH4 and N2O emissions. The default values are given in Table 2 in Sheet "13-Default values" and are based on IPCC guidelines. For details refer to "GHG Protocol Guidance: Calculation Tool For Direct Emissions from stationary combustion, Version 3.0, July 2005 " developed by WRI/WBCSD, 1996 guidelines and 2000 Good Practice Gudiance.(3) A high degree of uncertainty is associated with the emissions of CH4 and N2O from stationary combustion as these are dependent on various factors like fuel characteristics, type of technology/ equipment, emission controls, etc. However, these emissions are generally quite small as compared to direct CO2 emissions from stationary sources.

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(5) Scope 1: Direct emissions from fuel combustion from mobile sources

Color Code

Companies should estimate direct mobile emissions by either of the following methods

Method 1: Emissions calculated based on actual fuel consumption

Method 2: Emissions calculated based on distance travelled

Method 1: Emission calculated based on actual fuel consumptionType of fuel Quantity of fuel Units Units Units

A B C D E F G H I = C*E*0.99 /1000 J = C * G /1000

Example : Trucks Diesel 750 liter 2.75 kg CO2 / liter 0.031 kg SO2 / liter 2.04 0.02

Select the fuel 0.00 0.00

0.00 0.00

0.00 0.00

0.00 0.00

0.00 0.00

0.00 0.00

0.00 0.00

0.00 0.00

0.00 0.00

0.00 0.00

Total emissions based on actual fuel consumption (tonne) 0.00 0.00Notes for Method 1

1. The fuel consumption in various vehicles should be entered separately as independent entries.

In case plant specific data is available, the same should be preferred.

Method 2: Emission calculated based on distance travelled

A B C D

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.000

Notes for Method 2

504.72899523

1057.2727866

Marine diesel

Bunker oil

Aviation fuel

Gasoline / Petrol

Diesel 36.311039392

Residual fuel oil

LPG

Others

tonne

kilolitre

GJ/tonne

10.056218519

0

18.377499802

Source description (Buses, Trucks, Cars etc.)

CO2 emission factor*

SO2 emission factor*

CO2 emission(tonne)

SO2 emission(tonne)

2. Default emission factors of CO2 & SO2 as provided in Table 1 in the sheet "13-Default Values" have been used.

Type of vehicle (Bus, Trucks, Cars etc.)

Distance travelled (km)

CO2 emission factor

(gm CO2/km)

SO2 emission factor(gm SO2/km)

CO2 emissions(tonne)

SO2 emissions(tonne)

E = B*C/106 F = B*D/106

1. Use only customised CO2 & SO2 emission factor since kg CO2/km varies with vehicle type, age, loading, road conditions, etc.2. For more details on distance based emission, please refer "Calculating CO2 emissions from mobile combustion tool" on www.ghgprotocol.org

m3

Worksheet Introduction (1) This sheet calculates CO2 emissions from various company owned vehicles only.

(2) User should use either Method-1 or Method-2 for estimating emissions from mobile sources, depending on availability of data.

(3) Examples of mobile sources are company owned trucks, cars, buses for transportation of employees, etc.

(4) Emissions from vehicles owned by the contractors but operating for activities concerning the power plant are generally optional and reported under Scope -3, which is however not reported in this power tool.

User entry

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Color Code

Amount of coal purchased tonne

Type of coal mine

Default Methane emission factor 2.50

Total Methane emissions tonne

tonne

(6) Scope 1: Methane (CH4) emissions from storage and handling of coal

std m3 / tonne of coal

Total equivalent CO2 emissions

Worksheet introduction

(1) Handling and storage of coal is a source of fugitive methane (CH4) emissions. For instance, different types of coals desorb methane at different rates, but since coal is usually removed from a mine within hours or days of being mined, some CH4 remains and gets released from the coal during handling operations.

(2) Calculations provided here would help to estimate conservative CH4 emissions associated with coal handling and storage within power plant.

(3) This tool does not account for CH4 emissions from handling of coal used by the power plant in coal mines which is outside (even if the mines are owned by the power plant).

(4) For further details, please refer to "Revised 1996 IPCC Guidelines for National Greenhouse Gas Inventories", Volume 2, Chapter 1.5.

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Color Code

1. Beginning of Year kg

2. End of Year kg Change in Inventory (1 - 2) 0 kg

kg

kg

kg

0 kg

kg

kg

kg

kg

Total Sales/Disbursements (6+7+8+9) 0 kg

D. Change in Nameplate Capacity

10. Total nameplate capacity (proper full charge) of new equipment kg

11. Total nameplate capacity (proper full charge) of retired/sold equipment kg

Change in Capacity (10 - 11) 0 kg

E. Total Annual 0

0.00 kg

CO2 Equivalent emission 0.00 tonne

(7) Scope 1: Quantification of sulphur hexafluoride (SF6) emissions from the power plant

A. Change in Inventory (SF6 contained in cylinders, not electrical equipment)

B. Purchases/Acquisitions of SF6

3. SF6 purchased from producers or distributors in cylinders

4. SF6 provided by equipment manufacturers with/inside equipment

5. SF6 returned to the site after off-site recycling

Total Purchases/Acquisitions of SF6 (3+4+5)

C. Sales/Disbursements of SF6

6. Sales of SF6 to other entities, including gas left in equipment

7. Returns of SF6 to supplier

8. SF6 sent to destruction facilities

9. SF6 sent off-site for recycling

Total SF6 Emissions (A+B-C-D)

Worksheet Introduction

(1) SF6 is mainly used in circuit breakers in a power plant. Fugitive SF6 emissions in a power plant come from normal operations and routine maintenance.

(2) This spreadsheet is based on the "mass-balance" method. The mass balance method works by tracking and systematically accounting for all company uses of SF6 during the reporting period.

(3) The quantity of SF6 that cannot be accounted for is assumed to have been emitted to the atmosphere.

(4) User must fill in sub-calculations A,B,C and D for arriving at the total SF6 emissions.

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(8) Scope 1: Quantification of HFC emissions from refrigeration & airconditioning equipment

Color code

Screeing method : Emission factor based approachName of the equipmen Application Number of unit

A B C

Worksheet Introduction

(1) This worksheet is intended to facilitate the calculation and reporting of hydroflurocarbon (HFC)emissions resulting from servicing and disposal of refrigeration and air conditioning equipment. This does not take into account of ODS (Ozone Depletion Substance) i.e. CFCs, HCFCs etc.

(2) Direct HFC emissions occur from sources that are owned or controlled by the reporting company. These other sources are not calculated in this spreadsheet.

(3) This calculation is based on the material balanced analysis.

(4) The emissions estimated in this sheet are reported under Scope-1.

User entry Default values

Auto calculated value

Total HFC Emissions (tCO2e)

Domestic Refrigeration

Industrial Refrigeration

Chillers

Residential A/C

Mobile Air Conditioners

HFC-23

HFC-32

HFC-125

HFC-134a

HFC-143a

HFC-152a

HFC-236fa

Others

(8) Scope 1: Quantification of HFC emissions from refrigeration & airconditioning equipment

Screeing method : Emission factor based approachNumber of unitType of refrigeran GWP

C D E F G

Refrigerant charge (kg)

Annual leakage factor ( %)

Worksheet Introduction

(1) This worksheet is intended to facilitate the calculation and reporting of hydroflurocarbon (HFC)emissions resulting from servicing and disposal of refrigeration and air conditioning equipment. This does not take into account of ODS (Ozone Depletion Substance) i.e. CFCs, HCFCs etc.

(2) Direct HFC emissions occur from sources that are owned or controlled by the reporting company. These other sources are not calculated in this spreadsheet.

(3) This calculation is based on the material balanced analysis.

(4) The emissions estimated in this sheet are reported under Scope-1.

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Total HFC Emissions (tCO2e)

GWP

G

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

0.00

Tonnes of CO2 equivalent emissions

H = C x E x F x G 10-3

Worksheet Introduction

(1) This worksheet is intended to facilitate the calculation and reporting of hydroflurocarbon (HFC)emissions resulting from servicing and disposal of refrigeration and air conditioning equipment. This does not take into account of ODS (Ozone Depletion Substance) i.e. CFCs, HCFCs etc.

(2) Direct HFC emissions occur from sources that are owned or controlled by the reporting company. These other sources are not calculated in this spreadsheet.

(3) This calculation is based on the material balanced analysis.

(4) The emissions estimated in this sheet are reported under Scope-1.

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Total HFC Emissions (tCO2e) 0.00

Reset

Color Code

Electricity purchased kWh 0MWh

Name of the state

Name of the power grid

0.00 t CO2/ MWh

Click hereFtonne

(9) Scope 2 : Indirect CO2 emissions from the consumption of purchased electricity

Default CO2 emission factor

Total CO2 emissions

Worksheet Introduction

(1) Indirect emissions are consequence of the actions of a reporting entity, but are produced by sources owned or controlled by another entity.

(2) This sheet calculates indirect CO2 emissions assciated with the consumption of electricity purchased by the power plant from the grid (e.g. purchase of electricity from the grid during plant start-up or shut down). (3) The emissions estimated in this sheet are reported under Scope 2.

(4) Grid specific default emission factors are provided in Table 4 of Sheet "13-Default values".

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Color code

Consumption of limestone tonne per year

%

tonne

(10) Estimation of direct emissions - CO2 (Scope 1) from SO2 scrubbing plant

Does your plant have SO2 scrubber unit

Availability of plant specific data on CaCO3 content in limestone

CaCO3 content in limestone

Total CO2 emissions

Worksheet Introduction

(1) This sheet calculates CO2 emissions from SO2 scrubbing unit.

(2) CaCO3 avaialble in limestone reacts with SO2 in flue gases and forms CO2.

(3) The unit is encouraged to use plant specific data for CaCO3 content in limestone . Default value is used if data from plant not available.

(4) The emissions estimated in this sheet are reported under Scope 1.

User entry Default values Auto calculated value

Default values

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Sheet

Yes No

Calculate

tonne per year

(Scope 1) from SO2 scrubbing plant

Worksheet Introduction

(1) This sheet calculates CO2 emissions from SO2 scrubbing unit.

(2) CaCO3 avaialble in limestone reacts with SO2 in flue gases and forms CO2.

(3) The unit is encouraged to use plant specific data for CaCO3 content in limestone . Default value is used if data from plant not available.

(4) The emissions estimated in this sheet are reported under Scope 1.

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(11) Summary of green house gas emissions from the facility

Color Code

Name of the facility 0

Brief description of the inventory limits of the facility 0

Reporting period 0

Start report time 12/30/1899

End report time 12/30/1899

Scope 1: Direct Emissions 1 0.00 tonne

2 0.00 tonne3 0.00 tonne4 0.00 tonne5 0.00 tonne

6 0.00 tonne

7 0.00 tonne

8 0.00 tonne

Total Scope 1 emissions (1 + 2 + 3 + 4 + 5 + 6+7+8) 0.00

Memo item0.00 tonne

0.00 tonne

0.00

0.00

CO2 emissions from direct fossil fuel combustion

Equivalent CO2 emission from CH4 emission from direct fossile fuel combustion

Equivalent CO2 emission from N2O emission from direct fossile fuel combustion

CO2 emissions from direct mobile combustion

Equivalent CO2 emission to CH4 emission from coal handling & storage

Equivalent CO2 emission to SF6 emission from electrical equipment

Equivalent CO2 emission to direct HFC emission from refrigeration equipment

Equivalent CO2 emissions from So2 scrubbing

tCO2 e

Total direct SO2 emissions

Total direct CO2 emissions from biomass fuel

Scope 2: Indirect CO2 emissions

Indirect equivalent CO2 emissions from purchased electricity tCO2 e

Total Emissions (Scope 1 + Scope 2) in tCO2 equivalent tCO2e

Brief Introduction of this sheet

(1) In Scope 1, please enter manually the equivalent values of CO2 emissions for "Direct mobile sources (Serial No.2)" and "Direct HFC emission from refrigeration equipment (Serial No. 5)"

(2) For other emissions, this spread sheet takes automatically from the respective worksheets.

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(12) Summary of greenhouse gas emissions from the company

Color Code

Company name 0

Organisational boundaries chosen 0

Reporting period 0

Start report time 12/30/99

End report time 12/30/99

Facility

A B C D E F G H

Plant 10 or 100% million kWh

Plant 2 Plant 3 Plant 4

Total for company 0 0 0 0 0

Control (%)

Equity Share

(%)

Power generation

Scope1:Direct emissions

(Total equivalent CO2 emissions)

Scope 2:Indirect CO2 emissions

(Indirect emissions from purchased electricity)

Scope 1 for control

Scope 1 for equity

tonnes CO2 tonnes of CO2 Absolute CO2per plant

Absolute CO2per plant

User entry

Worksheet introduction

For each plant, enter the cumulative Scope-1 emissions in column E and Scope 2 emissions in column F

Default values Auto calculated value

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(13) Default values

Fuel Type Net calorific valueGJ/tonne

Solid fossil fuelNon-coking coal 19.63 95.81 0.54Imported non-coking coal 23.53 96.00 3.95Lignite 9.89 106.15 1.01Solid biomass fuelMustard stalk 17.58 93.38 0.01Rice husk 13.39 101.41 0.07Baggase 16.75 32.84 0.01Wood, wood waste 15.22 100.44 (EIA) 0.03

Source:1) Indian non-coking coal and Lignite NCV & emission factors - Ministry of Environment & Forest, GoI, 2004: Report on "India's National communication (NATCOM)

to United Nations Framework Convention on Climate Change", Table no. 2.3, Page no. 372) Mustard stalk and Rice husk NCV and emission factors - PVR Iyer, TR Rao, TD Grover and NP Singh (1997),

Biomass thermo-chemical characterisation, Table 4.2, Proximate analysis and calorific values of difference biomass species, Page no. 41 and 4.2.

Fuel Type Net calorific value Typical densityGJ/tonne GJ/liter x 1000 kg/m3

Liquid fossil fuelAviation gasoline 44.30 0.03 70.09 2.45 0.045 0.002 0.79Bunker oil 40.90 0.04 77.40 3.11 1.959 0.079 0.98Diesel 43.00 0.04 74.13 2.86 0.820 0.032 0.90Furnace oil 40.19 77.40 2.000Gasoline / petrol 44.30 0.03 69.36 2.43 0.045 0.002 0.79LPG 47.30 0.03 63.12 1.62 0.008 0.000 0.54Marine diesel 43.00 0.04 74.10 3.15 0.930 0.040 0.99Naphtha 44.50 73.40 1.333Residual Fuel oil 40.40 0.04 77.44 3.11 1.973 0.079 0.99Source:

3)

4) Diesel & Furnace oil Sulphur emission factor - BIS standards and technical memento - Thermax Pvt. Ltd.5) Furnace oil & Naphtha Calorific value- Greenhouse gas inventory workbook- Revised 1996 IPCCguidelines for national GHG inventories (Vol.2),

Page no. 1.6 Table 1-3 Selected net calorific values.6) Naphtha sulphur content - B I Bhatt S M Vora (1992), "Stochiometry", Second edition, Table no. 7.5, Typical characteristics of liquid fuels (page no. 377).

Fuel Type Net calorific value Typical density

GJ/tonne GJ/literGaseous fossile fuelNatural gas 48.00 56.06 2.19 0.28 0.60

Source:7) Natural gas sulphur content - "Union gas" official website

Note:Conversion of GCV (Gross calorific value) to NCV (Net calorific value)NCV = GCV - 53 x H Where H is the % of hydrogen content in the fuel

Fuel Type Coal 0.001 0.0013Natural gas 0.001 0.0001Petroluem (Oil) 0.003 0.0006Wood and wood waste 0.028 0.0038Other biomass and wastes 0.028 0.0038

Source:Default values are based on Tier 1 Uncontrolled values from the Revised 1996 IPCC Guidelines (Tables 1-7 and 1-8).

Coal mine type

Underground 2.5

Surface 0.1

Source: 2006 IPCC Guidelines for National Greenhouse Gas Inventories, Page 4.12, 4.19

CO2 emission factorSO2 emission factorkg CO2 / GJ kg SO2 / GJ

CO2 emission factor SO2 emission factorkg CO2 / GJ kg CO2 / liter kg SO2 / GJ kg SO2 / liter

Emission factors (kg CO2 /GJ) and Net calorific values are from IPCC, 2006, Volume 2, Energy. Typical densities are from API, 2001. Other values are drived arithmatically except as commented.

CO2 emission factor SO2 emission factor

kg CO2 / GJ kg CO2 / liter kg SO2 / GJ x 1000 kg/m3

0.029 GJ / m3 (std.)

Table 2: Default CH4 and N2O Emission Factors from Stationary Sources

kg CH4 / GJ kg N2O / GJ

Table 3: Average Fugitive CH4 emission factors for coal (post mining)

Emission factor (m3/tonne)

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Table 4: Grid specific emission factors for the different grids

Grid States covered

NEW NE Grid 0.97

Southern Grid 0.99

Source:

CEA Baseline Carbon Dioxide Emission Database Version 10.0 (Emission factor based on Combined Margin in tCO2/MWh incl. Imports)

Table 5. GWPs of Common Greenhouse Gases and RefrigerantsRefrigerants GWP Source Refrigerants GWP Source

1 IPCC AR4, 2007 R-410A 1725

25 IPCC AR4, 2007 R-410B 1832.5

N2O 298 IPCC AR4, 2007 R-411A 15.4

SF6 22800 IPCC AR4, 2007 R-407E 1363

HFC-23 14800 IPCC AR4, 2007 R-408A 1944

HFC-32 675 IPCC AR4, 2007 R-409A 0

HFC-41 92 IPCC AR4, 2007 R-409B 0

HFC-125 3500 IPCC AR4, 2007 R-410A 1725

HFC-134 1100 IPCC AR4, 2007 R-410B 1832.5

HFC-134a 1430 IPCC AR4, 2007 R-411A 15.4

HFC-143 353 IPCC AR4, 2007 R-411B 4.2

HFC-143a 4470 IPCC AR4, 2007 R-412A 350

HFC-152 53 IPCC AR4, 2007 R-413A 1774

HFC-152a 124 IPCC AR4, 2007 R-414A 0

HFC-236fa 9810 IPCC AR4, 2007 R-414B 0

R-401A 18.2 ASHRAE Standard 34 R-415A 25

R-401B 15.4 ASHRAE Standard 34 R-415B 105

R-401C 21 ASHRAE Standard 34 R-416A 767

R-402A 1680 ASHRAE Standard 34 R-417A 1954.8

R-402B 1064 ASHRAE Standard 34 R-418A 3.5

R-403A 1400 ASHRAE Standard 34 R-419A 2403

R-403B 2730 ASHRAE Standard 34 R-420A 1144

R-404A 3260 ASHRAE Standard 34 R-500 36.68

R-406A 0 ASHRAE Standard 34 R-503 4691.7

R-407A 1770 ASHRAE Standard 34 R-504 313.3

R-407B 2285 ASHRAE Standard 34 R-505 0

R-407C 1525.5 ASHRAE Standard 34 R-506 0

R-407D 1428 ASHRAE Standard 34 R-507 or R-507A 3300

R-407E 1363 ASHRAE Standard 34 R-508A 10175

R-408A 1944 ASHRAE Standard 34 R-508B 10350

Table 6. Default Assumptions from IPCC Good Practice Guidelines*Application Charge (kg) Lifetime (years) Emission Factors (% of initial charge/year)

Assembly Recycling Efficiency

Domestic Refrigeration 0.05 - 0.5 12 - 15 0.2 - 1 % 0.1 - 0.5 % 70% of remainder50 - 2000

7 - 10 0.5 - 3 % 10 - 30 % 80 - 90% of remainderTransport Refrigeration 3.0 - 8.0 6 - 9 0.2 - 1 % 15 - 50 % 70 - 80% of remainder

10 - 10000 10 - 20 0.5 - 3 % 7 - 25 % 80 - 90% of remainder

Chillers 10.0 - 2000 10 - 30 0.2 - 1 % 2 - 15 % 80 - 95% of remainderMobile Air Conditioners Not provided 12 0.50% 10 - 20 % 0%

Emission factor(tCO2/MWh)

Haryana, Himachal Pradesh, Punjab, Jammu & Kashmir, Rajasthan, Uttaranchal,Jammu & Kashmir, Rajasthan, Uttaranchal, Uttar Pradesh, Delhi, Gujarat, Madhya Pradesh, Bihar, Orissa, West Bengal, Maharashtra, Goa, Chattisgarh, Jharkhand, Arunacahl Pradesh, Assam, Manipur, Meghalaya, Mizoram, Nagaland, Tripura

Andhra Pradesh, Karnataka, Kereala, Tamil Nadu, Puducherry, Lakshadweep

CO2ASHRAE Standard 34

CH4ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34ASHRAE Standard 34

Annual Leakage Rate

Medium and Large Commercial refrigeration

Industrial Refrigeration including Food Processing and Cold Storage

* These values are from IPCC Good Practice Guidelines and Uncertainty Management in National Greenhouse Gas Inventories (2000).These default values are provided for reference purposes only as their wide range can result in highly variable calculation outcomes. If a value is chosen from within the range, that value should be used consistently from reporting period to reporting period or year to year.They should only be used if entity-specific data are not available, but an inventory that uses these values should be considered preliminary.

(14) Conversion factors

Mass1 pound (lb) 453.6 grams (g)1 kilogram (kg) 2.205 pounds (lb)1 short ton (ton) 2'000 pounds (lb)1 metric ton 2'205 pounds (lb)

Volume7.4805 gallons (gal)28.32 liters (L)

1 gallon (gal) 0.0238 barrel (bbl)1 barrel (bbl) 42 gallons (gal)1 litre (L)

6.2897 barrels (bbl)

Energy1 kilowatt hour (kWh) 3412 Btu (btu)1 megajoule (MJ) 0.001 gigajoules (GJ)1 gigajoule (GJ) 0.9478 million Btu (million btu)1 Btu (btu) 1'055 joules (J)1 million Btu (million btu) 1.055 gigajoules (GJ)1 therm (therm) 100'000 btu 1 kcal 4.186 kJ

Otherkilo 1'000mega 1'000'000giga 1'000'000'000tera 1'000'000'000'0001 psi 0.06895 bar

0.9807 bar1 atmosphere (atm) 1.01325 bar1 mile (statue) 1.609 kilometers

1 metric ton carbon

1 cubic foot (ft3)1 cubic foot (ft3)

0.001 cubic meters (m3)1 cubic meter (m3)

1 kgf / cm3 (tech atm)

1 metric ton CH4 21 metric tons CO2 equivalent1metric ton N2O 310 metric tons CO2 equivalent

3.664 metric tons CO2

(14) Conversion factors

0.4536 kilograms (kg) 0.0004536 metric tons (tonne)

907.2 kilograms (kg)1'000 kilograms (kg) 1.1023 short tons (tons)

0.1781 barrel (bbl)

3.785 liters (L)158.99 liters (L)0.2642 gallons (gal)264.2 gallons (gal) 1'000 liters (L)

3'600 kilojoules (KJ)

277.8 kilowatt hours (kWh) 238891.5 Kcal

293 kilowatt hours (kWh)0.1055 gigajoules (GJ) 29.3 kilowatt hours (kWh)0.000004186 gigajoules (GJ) 0.001162778 kilowatt hours (KWh)

101.325 kilo pascals 14.696 pounds per square inch (psia)

0.02832 cubic meters (m3)0.003785 cubic meters (m3)0.1589 cubic meters (m3)

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