f-cdm-mr: monitoring report form. version 03

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Monitoring report form

(Version 05.1)

MONITORING REPORT

Title of the project activity 20 MW Biomass Power Project at Godawari Power and Ispat Limited, Chhattisgarh

UNFCCC reference number of the project activity NA

Version number of the monitoring report 2.1

Completion date of the monitoring report 04/09/2016

Monitoring period number and duration of this monitoring period

First Monitoring period from 11/08/2013 to 10/08/2015 (both days included)

Project participant(s) Godawari Power and Ispat Limited

Host Party India

Sectoral scope(s) Sectoral Scope: 01- Energy Industries

(renewable / non-renewable sources)

Selected methodology(ies) ACM0018 (Version 03.0) – “Electricity generation from biomass residues in power-only plants”

Selected standardized baseline(s) NA

Estimated amount of GHG emission reductions or net GHG removals by sinks for this monitoring period in the registered PDD

215,018 tCO2e

Total amount of GHG emission reductions or net GHG removals by sinks achieved in this monitoring period

GHG emission reductions or net GHG removals by sinks reported up to 31 December 2012

GHG emission reductions or net GHG removals by sinks reported from 1 January 2013 onwards

NA 179,516 tCO2e

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SECTION A. Description of project activity

A.1. Purpose and general description of project activity

>> Godawari Power and Ispat Limited (GPIL) has installed a 20 MW biomass based power project at Siltara, Raipur. The purpose of the project activity is to generate electricity using renewable biomass residues i.e. rice husk to reduce GHG (CO2) emissions. As biomass is a CO2 neutral fuel, the power produced by the GPIL from renewable biomass will have zero GHG emissions. Also as it is replacing fossil fuel intensive based power generation from NEWNE grid, thereby results in reducing emissions from such fossil fuels. In the project activity, biomass is combusted in the boiler for producing high pressure steam to generate 20 MW electricity. The generation of electricity from project activity during this monitoring period is 260,371.7 MWh. Prior to the start of implementation of project activity, there are four power-only plants at the project site i.e. 11 MW coal/dolo char based power only plant and three waste heat recovery based power only plants (7 MW, 10 MW and 25 MW) located at the project site. Out of the four power only plants at the project site, three power only plants i.e. 11 MW coal/dolochar based power plant, 7 MW waste heat recovery based power plant and 10 MW waste heat recovery based power plant are connected to the proposed project activity through common steam header. Another 25 MW waste heat recovery based power plant is not connected with the steam header of this project activity. However, it is altogether an independent power generation activity with its own boilers and turbogenerator. All the four power only plants continue to operate after the start of this project activity. The primary technology for the project activity is direct combustion of rice husk, and power generation using the Rankine cycle technology. Power generation through this method involves combustion of rice husk directly in the boiler, with generation of steam, which is fed to a steam turbine that drives the generator. The Gold Standard registration date for the project activity is 11/08/2015. The project has obtained the requisite clearances and is commissioned on 01/11/2010. The present monitoring period is the first monitoring period and is from 11/08/2013 to 10/08/2015 through which emission reduction claimed is 179,516 tCO2e. The final PDD, passport and face to face SFR was published in the company website for 60 days open for the comments and did not receive any comment. Also the documents were made available on the GS website. http://godawaripowerispat.com/sustainability/ems/gold-standard-registration/ Vintage wise emission reduction during the entire Monitoring Period.

S. No.

Amount

1 11/08/2013 to 31/12/2013 35126.51 tCO2e

2 01/01/2014 to 31/12/2014 91306.68 tCO2e

3 01/01/2015 to 10/08/2015 53083.46 tCO2e

A.2. Location of project activity

>> Host Party: India State: Chhattisgarh

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District: Raipur Co-ordinates: India Longitude 81°41'5"E Latitude 21°22'24"N

A.3. Parties and project participant(s)

Party involved ((host) indicates a host Party)

Private and/or public entity(ies) project participants (as applicable)

Indicate whether the Party involved wishes to be considered as project participant (yes/no)

India(Host Party) Godawari Power & Ispat Limited (Private entity)

No

A.4. Reference of applied methodology and standardized baseline

>>

ACM0018 (Version 03.0) – “Electricity generation from biomass residues in power-only plants” EB 76, Annex 09 Version 07.0.0 “Tool for the demonstration and assessment of additionality” Version 02 “Tool to calculate project or leakage CO2 emissions from fossil fuel combustion” http://cdm.unfccc.int/methodologies/PAmethodologies/tools/am-tool-03-v2.pdf;

http://cdm.unfccc.int/methodologies/PAmethodologies/tools/am-tool-03-v2.pdf

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Version 06.0.1 “Tool to determine methane emissions avoided from disposal of waste at a solid waste disposal site” Version 01 “Tool to calculate baseline, project and/or leakage emissions from electricity consumption” Version 04.0 “Tool to calculate the emission factor for an electricity system”

A.5. Crediting period of project activity

>> Fixed Crediting Period: 10 years Start date of crediting period: 11/08/2013 Present Monitoring Period: 11/08/2013 to 10/08/2015 (both dates inclusive)

A.6. Contact information of responsible persons/entities

>> Ritesh Agrawal PE Sustainability Solutions Pvt Ltd A subsidiary of PE INTERNATIONAL AG, Germany 421, MIDAS, Sahar Plaza, Andheri Kurla Road, Andheri East, Mumbai, India 400059 Phone: +91 22 42667693 Mobile: +91 99671 06584 E-Mail: [email protected] Internet http://www.thinkstep.com

SECTION B. Implementation of project activity

B.1. Description of implemented registered project activity

>> The primary technology for the project activity is direct combustion of rice husk, and power generation using the Rankine cycle technology. Power generation through this method involves combustion of rice husk directly in the boiler, with generation of steam, which is fed to a steam turbine that drives the generator. The technology used in environmentally safe and sound.

The main elements of the power plant are as follows.

- A new boiler unit which converts the energy available in the fuels into thermal energy; - Refurbished steam turbine units which convert thermal energy into mechanical energy; - Alternator units, which convert mechanical energy into electrical power.

Other equipment, as listed below, also form part of the biomass power plant.

- Fuel and ash handling equipment - System for cooling the exhaust steam - DM Water system and Air Compressor Plant - Electrical systems and Automation system

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The project activity involves installation of new boiler units and refurbishment of existing turbine units for the generation of 20 MW electricity. The technical lifetime of boiler is 20 years. But the residual life of the refurbished turbine is 18 years. Hence the operational lifetime of the project activity is 18 years. The capacity of the turbo generator is 20 MW, which generates electricity at 33/11 kV level. The existing capacity at project site is 28 MW and the forecast capacity is 48 MW after implementation of 20 MW Biomass based project activity.

Table 1: Technical details of the project activity

Equipment: Boiler

Type Semi outdoor, natural circulation, single drum, balance draft, Atmospheric Fluidised Bed (AFB) boiler with convective heat recovery surfaces for super heaters, economizers and tubular air heaters.

Nominal Capacity Adequate to supply steam to the corresponding TG sets.

Pressure Kg/Sq.cm (A) 35

Temperature (oC) 410+/ - 5oC

Steam flow at MCR (T/hr.) 100 T/hr

Steam temperature control range 60 - 100% MCR or better

Feed water temperature at inlet of economizer Deg. C 105

Firing System Fluidized bed combustion system

Ash removal

i. Bottom Ash: Bottom ash discharged in dry form from the furnace will be conveyed to the ash storage silo by pneumatic conveyor system.

ii. Fly Ash: Extracted in dry condition through vacuum and pressurized air conveying system to ash storage silo for the ultimate disposal for backfilling of mined-out areas.

Equipment Name: Turbine 1, 2, 3 and 4

Type Condensing, steam turbine directly coupled to 3000- RPM, 2- pole, 50 Hz, electric power generator.

Normal capacity Refurbished TG 1 (10 MW) and Refurbished TG 2 ( 10 MW), Existing TG 3 (10 MW) and Existing TG 4 (30 MW) respectively

Normal operating frequency range 47.5 to 51.5 Hz

Pressure (kg/sq. cm) 35

Temperature (oC) 410 +/- 5oC

Steam flow at MCR (T/hr.) 100 tonnes/hr.

Exhaust pressure 0.1 kg/cm2 (A)

Type of governing Electro-hydraulic with fire resistant fluid (FRL).

Condensing Equipment Water cooled surface condenser

Regenerative feed heating Heaters of varying capacities for TGS.

Boiler feed pumps 2 x 100% capacity high speed BF pumps.

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Condensate extraction pumps

2 x 100% capacity, electric motor driven vertical pumps of CAN type.

Equipment Name: Generator 1, 2, 3 and 4

Type 3000- RPM, 2- pole, 50 Hz, electric power generator.

Normal capacity Existing Generator 1 (10 MW) and Generator 2 ( 10 MW), Existing Generator 3 (10 MW) and Generator 4 (30 MW) respectively

Normal operating frequency range 47.5 to 51.5 Hz

Training is required to be provided to the operators handling the operation of the critical equipment such as Boiler and Turbine. The company had taken necessary precautions to get the operators of these two equipment trained by the suppliers of their equipment. The company has recruited personnel with relevant experience in the operation of the boiler and turbine. Certified boiler operators are employed for handling boiler operations. Further, suppliers of turbine and boiler provided initial training on the operation of the boiler and turbine.

B.2. Post-registration changes

B.2.1. Temporary deviations from registered monitoring plan, applied methodology or applied standardized baseline

>> Not Applicable

B.2.2. Corrections

>> Not Applicable

B.2.3. Changes to start date of crediting period

>> Not Applicable

B.2.4. Inclusion of a monitoring plan to the registered PDD that was not included at registration

>> Not Applicable

B.2.5. Permanent changes from registered monitoring plan, applied methodology or applied standardized baseline

>> Not Applicable

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B.2.6. Changes to project design of registered project activity

>> Not Applicable

B.2.7. Types of changes specific to afforestation or reforestation project activity

>> Not Applicable

SECTION C. Description of monitoring system

>> GPIL’s Entire Captive Power Plant consists of a 30 TPH Waste Heat Recovery Boiler (WHR), referred as WHRB1, that utilizes waste heat from 350 TPD sponge iron kiln as energy source, a 70 TPH Fluidized Bed Combustion (AFBC-1) Boiler that uses coal rejects (coal char and coal fines) from sponge iron process as fuel, a 54 TPH Waste Heat Recovery Boiler(WHRB2) that utilizes waste heat from another 500 TPD sponge iron kiln as energy source to a common steam header. There are 3 Nos. x 10 MW each and one number 30 MW turbo generator (TG) sets. WHR (WHRB1) was installed by GPIL as a first CDM Project (Waste Heat based 7 MW Captive Power Project having registration No. 0264) to improve the energy efficiency of the production process and AFBC-1 was installed to avoid the pollution problems associated with disposal of coal rejects as required by pollution control norms. The Project Proponent commissioned another Project Activity with its 500 TPD Sponge Iron Kiln along with WHRB2 Waste Heat Recovery Boiler (having 54 TPH Steam Generation capacity) with one 10 MW Turbine and one 30 MW Turbine to generate 10 MW Power from the fresh facility i.e. the New Project Activity, which was registered by CDM-EB as “Waste Heat based 10 MW captive power project “GPIL- WHRB 2” CDM PROJECT ACTIVITY (Registration No. 0772). The project proponent is generating electricity from two locations inside the plant. The power generated from TG1, TG2, TG3 and TG4 are taken to one line and subsequently distributed to the various captive units. The WHR (WHRB1) was commissioned in September 2002 along with the two numbers of 10 MW each TG sets and AFBC-1 boiler was commissioned later in October 2003. The WHRB2 was commissioned on 1/1/2006 along with one number of 10 MW & one number of 30 MW TG Set. The 100TPH Biomass based AFBC-2 boiler was commissioned and started operation on 1st November 2010.

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The methodology requires monitoring the following:

1) The Total electricity generated by TG-1 (EGTG1) is monitored through the independent energy

meters(kWh)


meters


meters


meters

5) The Auxiliary electricity consumed in ECAux1, ECAux2, ECAux5 and ECAux6 are monitored

independently by energy meters.

In order to evaluate the contribution of power to captive consumption from the source independently i.e. project activity, the generation from each source are required to be apportioned which is explained below:

Steam calculation The Steam parameters of pressure and temperature from WHRB1, WHRB2 and AFBC-1 boilers are the same i.e. 35 kg/cm2 and 410 degree C. As working steam parameters of pressure and temperature are identical for the boilers, the only dependent variable for calculation of waste heat power would be the steam flow from respective boilers. However, to maintain transparency in calculating WHR (WHRB1) power following monitoring methodology is used.

1. Vent Steam: To maintain the working pressure (35kg/cm2) in the common header, some

quantity of steam generated is vented (or dumped) out intermittently. Vent position is after the

location of flow meters in the steam mains pipes from boilers to the common header. Since the

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quantity of vent steam is not measured at the site, thus to arrive at a conservative estimate for

project activity purpose it is assumed to be entirely coming from AFBC-2 boiler alone (most

conservative estimate). The total vent steam is calculated as the difference of total steam

generated from WHRB1, WHRB2 AFBC-1 & AFBC-2 and the total steam consumed in the all the

TG sets.

The total vent steam (Svent) is

Svent = (Total steam generated in WHRB1, WHRB2, AFBC-1 and AFBC-2) – (Total Steam Consumed in TG#1, TG#2, TG#3 & net TG#4)

=Sgen - Scons

Also, the total vent steam (Svent) quantity in tonnes per day is subtracted from AFBC-2 steam (i.e. S4) to get the value of Effective AFBC-2 steam (S4Eff ) i.e

S4Eff = S4 - Svent

2. Calculation of Waste Heat Power: The waste heat power generated is calculated

thermodynamically on the basis of Total Enthalpy (steam enthalpy per unit x units of steam flow) of

Effective WHR (WHRB1) steam as a percentage of Total Enthalpy of Steam fed to the common

header from WHRB1 , WHRB2 and AFBC-1.

The calculation is shown as follows: Total heat of Steam from WHR (WHRB1) in kCal (H1)

= (Enthalpy of steam at boiler outlet in kCal/kg) x (WHRB1 steam flow in tonnes per day)

= h1 * S1 *1,000 The enthalpy of steam is calculated based on average temperature and pressure readings for the day and WHR (WHRB1) steam flow.

Similarly Total heat of Steam from AFBC-1 in kCal (H2)

= Enthalpy of steam at boiler outlet in kCal/kg x steam flow in tonnes per day

= h2 * S2*1,000 The enthalpy of steam is calculated based on average temperature and pressure readings for the day and steam flow from the AFBC-1 outlet steam flow meter.

Similarly Total Enthalpy of Steam from WHRB2 in kCal (H3)

= Enthalpy of steam at WHRB2 boiler outlet in kCal/kg x WHRB2 steam flow in tonnes per day

= h3 * S3 *1,000

Similarly Total Enthalpy of Steam from AFBC-2 in kCal (H4)

= Enthalpy of steam at AFBC-2 boiler outlet in kCal/kg x AFBC-2 effective steam flow in tonnes per day

= h4 * S4Eff *1,000

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If EGGEN CPP is the Total Power generated by the all the turbo generators i.e. sum of EGTG1 , EGTG2 , EGTG3 and EGTG4 from TG-1, TG-2, TG-3 and TG-4 per day (in MWh) respectively

i.e. EGGEN CPP = EGTG1 + EGTG2 + EGTG3 + EGTG4

then Power Generated by AFBC-2 Boiler (EGGEN ) would be calculated as

EGGEN (MWh) = EG GEN CPP * (H4)

-------------------------

(H1+H2+H3+H4) ……………………………………...1

Again, if Auxiliary Consumption for power plant per day is EGAUX CPP (in MWh) then it is sum of ECAux1, ECAux2, ECAux5 and ECAux6 from TG-1, TG-2, TG-3 and TG-4 per day (in MWh) respectively

EGAux CPP = ECAux1 + ECAux2+ ECAux5 + ECAux6

Then AFBC2 Auxiliary Consumption (EGAUX ) will also be calculated in the same ratio as

EGAUX (MWh) = EG AUX CPP * (H4) ----------------------------- (H1 + H2+H3+H4) ………………………………………….2

Therefore Net Generation (EGy) from AFBC2 will be

EGy (MWh) = (EGGEN - EGAUX) …………………………………………………..3

Considering the fact that the electricity generated by the project activity is used for internal captive consumption.

Operational and management structure The proposed operational and management structure for the project activity for the purpose of monitoring of emission reductions, leakage effects etc., is shown below (May undergo changes if situation demands):

Board of Directors

Managing Director

General Manager

Plant Incharge

Shift Incharge

Procurement Officer

CSEB

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The responsibilities of various personnel in the organization in implementing the monitoring plan are as follows:

S. No Personnel Responsibility

1 Procurement Officer

Procurement Officer is responsible to assess the suppliers based on the key parameters and submits recommendation to the General Manager for approval. He is also responsible to procure the fuels permitted by the Local statutory authorities and to meet the plant daily requirement without any shortage. Daily procurement report would be sent to the Plant Manager. 2 Shift In charge Shift in charge monitors the plant parameters including the monitoring parameters as described in the PDD. He collects the data recorded in log sheets of respective sections and prepare the consolidated report on electricity generation, export to grid, fuel consumption, plant shut down time, etc. for every shift. These reports would be submitted to the Plant Manager for review.

3 Plant Manager Review of the monitored parameters for correctness, corrective measures in case of minor errors in the monitored data and preparation of a daily summary on project operation and electricity generation to the General Manager on daily basis. 4 General Manager General Manager is responsible for the electricity generation of the project. He would cross check and sign the daily plant operation reports regularly, and report to Managing Director for any abnormality. The periodical tests of the monitoring equipments would be looked after by him as per the monitoring plan. The responsibility of storage and archiving of information in good condition also lies with the General Manager. He would also co-ordinate to obtain audit reports as per the monitoring plan from Internal auditors.

5 Managing Director Managing Director is responsible for the total monitoring plan. The Managing Director examines the reports generated by General Manger w.r.t, the monthly electricity generated; net electricity exported to grid and annual emission reduction calculations as per the monitoring plan. He also examines the internal audit reports prepared by internal auditor/ General manager and in particular takes note of any deviations in data over the norms and monitor that the corrective actions have resulted in adherence to standards. 6 Board of Directors Review of the quarterly reports submitted by Managing Director, guidance for necessary corrective actions to the concerned person and approval of the quarterly reports to then compile as annual report which would be made available to the DOE for verification.

7 Chhattisgarh State Electricity Board (CSEB) Personnel

Metering the electricity export to grid and electricity import from grid.

SECTION D. Data and parameters

D.1. Data and parameters fixed ex ante or at renewal of crediting period

(Copy this table for each piece of data and parameter)

Data/parameter: EFcaptive, y

Unit tCO2/MWh

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Description CO2 emission factor for the electricity displaced in the grid due to the project

activity during the year y in t CO2/MWh

Source of data CEA CO2 baseline database for the Indian Power Sector, Version 09 (Average of Simple operating margin (3 years) and Build margin )

Value(s) applied) 0.9722

Choice of data or measurement methods and procedures

The CEA is the prime authority for Indian power sector for determining the guidelines and norms. The authority publishes all the data relevant to the Indian power sector. The CO2 data base for Indian power sector published by CEA is made available publicly and established in accordance with the guidelines of UNFCCC. Hence, the application of data published by CEA is transparent and conservative.

Purpose of data baseline emission calculations

Additional comments -

Data/parameter: EFCO2, i, y (EFFF,i)

Unit tCO2/TJ

Description CO2 emission factor of each fuel type i

Source of data IPCC default values / India’s Initial National Communication to UNFCCC (INC)

Value(s) applied) Coal : 95.8 tCO2/TJ (Source: NC) Diesel : 74.1 tCO2/TJ (Source: IPCC)


IPCC 2006 values have been used for diesel since no country specific data is available.

Purpose of data project emission calculations


Data/parameter: Biomass residues categories and quantities used for the selection of the baseline scenario selection and assessment of additionality

Unit • Type (i.e. bagasse, rice husks, empty fruit bunches, etc.); • Source (e.g. produced on-site, obtained from an identified biomass residues producer, obtained from a biomass residues market, etc.); • Fate in the absence of the project activity (Scenarios B); • Use in the project scenario (Scenarios P); • Quantity (tonnes on dry-basis)

Description Biomass residues categories and quantities used for the selection of the

baseline scenario selection and assessment of additionality

Source of data Biomass Assessment Report

Value(s) applied) 145,920 tonnes per annum


Value taken from third party Biomass Assessment Report

Purpose of data project emission calculations

Additional comments This parameter is related to the procedure for the selection of the baseline scenario selection and assessment of additionality

Data/parameter: EF km CO2

Unit tCO2 / tkm

Description Average CO2 emission factor for the trucks during year y

Source of data Default CO2 emission factor for freight transportation activity as per EB 63, Annex 10, page 4

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Value(s) applied) For light vehicle 0.000245 For heavy vehicle 0.000129


The default value from the guideline “Default CO2 emission factor for freight transportation activity” EB 63, Annex 10, page 4 have been used in the absence of country specific emission factor.

Purpose of data This value is used for project emission calculation.


D.2. Data and parameters monitored

Data / Parameter: FRf,m

Unit: Tons of dry matter

Description: Total mass of freight transported in freight transportation activity f in monitoring period m (t)

Measured/ Calculated / Default:

Measured On-site measurements

Source of data: On-site measurements maintained in electronic log books

Value(s) of monitored parameter:

(Rice-husk) 336,939.51 (Coal) 37694.09 For the entire monitoring period

Monitoring equipment: Weighbridge The monitoring equipment details along with the calibration details are given in the Annex 3 of the MR.

Measuring/ Reading/ Recording frequency:

Continuous monitoring with monthly recording

Calculation method (if applicable):

The trucks carrying fuel (biomass residues and fossil fuel) are weighted by a calibrated weighbridge twice upon entry and exit to calculate net quantity of fuel procured. The data on quantity of fuel purchased would be collected, recorded and archived separately for all types of fuels. Accuracy: ±2%

QA/QC procedures: Weigh bridge undergoes maintenance and calibration annually. This data would be cross checked against purchase receipts and inventory data.

Purpose of data: Project emission calculation

Additional comment: NA

Data / Parameter: FFproject site,i,y

Unit: Ltrs per year.

Description: Quantity of HSD consumed in DG set or for the preparation or on-site transportation or of the biomass residues during the year, y.


Measured On-site measurements and fuel issuance log book

Source of data: log books –store issues.


0

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Monitoring equipment: NA


Continuous monitoring with monthly recording


NA

QA/QC procedures: The data recorded can be cross checked against the fuel purchase receipts.


Additional comment: -

Data / Parameter: Df,m

Unit: km

Description: Return trip road distance between the origin and destination of freight transportation activity f in monitoring period m


Calculated

Source of data: Biomass accessibility Report


100



As the parameter is not monitored. The maximum one side distance of 50 km has been taken conservatively as according to the latest biomass assessment report, the biomass is available in abundant quantity within 50 km of the project activity. Hence considering 100 km distance travelled in one trip is most conservative.


NA

QA/QC procedures: This can be verified by cross checking the information on distance available from other sources (e.g. web sources)



Data / Parameter: FFd,y

Unit: liters

Description: Quantity of diesel combusted in the DG set of project plant during year y


Measured On-site measurements The total number of operating hours of DG set and the corresponding quantity of diesel consumed for the purpose is recorded in the log book maintained at the DG set room. The operating hours and the quantity of diesel consumption is recorded.

Source of data: Log-book-store issues.


0



Monthly recorded.


NA

QA/QC procedures: The data recorded can be cross checked against the fuel purchase receipts

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Data / Parameter: NCVDiesel

Unit: TJ/Gg

Description: Net calorific value of diesel


Default

Source of data: Page No. 18 of 2006 IPCC Guidelines for National Greenhouse Gas Inventories


43



Once in a monitoring period


NA

QA/QC procedures: NA



Data / Parameter: EFCO2,diesel

Unit: tCO2/TJ

Description: Carbon dioxide emission factor of each fossil fuel type i


Default

Source of data: India’s Initial National Communication to UNFCCC IPCC default values http://www.ipcc-nggip.iges.or.jp/EFDB/find_ef.php


Diesel : 74.10





NA

QA/QC procedures: NA



Data / Parameter: ρi

Unit: kg/Lit

Description: Density of the fossil fuel used for the project site (Diesel)


Default

http://www.ipcc-nggip.iges.or.jp/EFDB/find_ef.php

http://www.ipcc-nggip.iges.or.jp/EFDB/find_ef.php

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Source of data: Society of Indian automobile manufacturers (SIAM) http://www.siamindia.com/scripts/Diesel.aspx The SIAM value is considered as it is publicly available and can be referred as authentic source.


0.82





NA

QA/QC procedures: National level default value is used



Data / Parameter: Sgen

Unit: tonnes per day

Description: Total Steam generated from WHRB1, WHRB2, AFBC-1 and AFBC-2 boiler


Measured (m), Online measurement and calculated This is the sum of steam generation by all the boilers. The individual steam flow of each boiler is monitored using flow meters.

Source of data: Plant log book


4,842 (the value is for 12/08/2013), the complete set of value is included in er sheet

Monitoring Equipment: Refer Annex 3 for the monitoring equipment details along with calibration of individual steam flow meter of each boiler


Continuous monitoring, Daily recording in plant log book


NA

QA/QC procedures: Log book signed by the Shift In-Charge on daily basis. Energy Meters are calibrated annually. In-charge Electrical is responsible for the calibration of the Meters. The data is archived in Electronic/paper form for a crediting period + 2 years or the last issuance of CERs for the project activity whichever occurs later.

Purpose of data: Baseline Calculation


Data / Parameter: Scons

Unit: Tonnes per day

Description: Total Steam Consumed by both TG#1, TG#2, TG#3 and TG#4 turbine


Measured (m), Online measurement and calculated This is the sum of steam consumed by TG#1, TG#2, TG#3 and TG#4 turbine. The individual steam flow to each turbine is monitored using flow meters.



4,694 (The value is for 12/08/2013), the complete set of value is included in ER sheet.

http://www.siamindia.com/scripts/Diesel.aspx

http://www.siamindia.com/scripts/Diesel.aspx

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Monitoring equipment: The individual steam consumption by turbines TG#1, TG#2, TG#3 is monitored by using individual flow meters. For turbine TG#4 there are two meters i.e. main meter and auxiliary steam consumption meter. The steam consumption for TG#4 is calculated by subtracting the auxiliary steam consumption by TG#4 through auxiliary meter from steam consumption by main meter. The monitoring equipment details along with the calibration details are given in the Annex 3 of the MR.


Continuous monitoring , Daily recording in plant log book


Scons = SGTG1+ SGTG1 + SGTG1 +SGTG1

QA/QC procedures: Log book signed by the Shift In-Charge on daily basis. Energy Meters are calibrated annually. In-charge Electrical is responsible for the calibration of the Meters. The data is archived in Electronic/paper form for a crediting period + 2 years or the last issuance of CERs for the project activity whichever occurs later.



Data / Parameter: Svent


Description: Total Steam Vented in the CPP


Calculated



84 (The value is for 12/08/2013), the complete set of value is included in ER sheet.



Daily recording in plant log book


(Total steam generated in WHRB1, WHRB2, AFBC-1 and AFBC-2) – (Total Steam Consumed in TG#1, TG#2, TG#3 & net TG#4)

QA/QC procedures: Calculated on a daily basis. The data is archived in Electronic/paper form for a period a credit + 2 years.



Data / Parameter: S1


Description: Flow of WHRB1 Steam to the common header


Measured, Online Measurement




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Monitoring equipment: Flow meter. The monitoring equipment details along with the calibration details are given in the Annex 3 of the MR.




NA




Data / Parameter: T1

Unit: 0C

Description: Average temperature of WHRB1 steam before common header


Online Measurement




Monitoring equipment: The monitoring equipment details along with the calibration details are given in the Annex 3 of the MR.




NA

QA/QC procedures: The data is monitored from meters at plant and DCS. Manager In-charge is responsible for calibration. The data is archived in Electronic/paper form for a period a credit + 2 years.



Data / Parameter: P1

Unit: Kg/cm2

Description: Avg. pressure of WHRB1 steam before common header


Online Measurement







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NA

QA/QC procedures: The data is monitored from meters at plant and DCS. Manager In-charge is responsible for calibration. The data is archived in Electronic/paper form for a period a credit + 2 years.



Data / Parameter: h1

Unit: KCal/Kg

Description: Enthalpy of WHRB1 steam


Calculated








Calculated from steam tables/ Mollier Diagram

QA/QC procedures: The data is calculated. The data is archived in Electronic/paper form for a period a credit + 2 years.



Data / Parameter: H1

Unit: KCal

Description: Total heat of WHR (WHRB1) steam


Calculated








(h1 x S1*1000) i.e. (Enthalpy of steam at boiler outlet in kCal/kg) x (WHRB1 steam flow in tonnes per day)




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Unit: 0C

Description: Average temperature of AFBC-1 steam before common header


Online Measurement








NA

QA/QC procedures: The data is monitored from meters at plant and DCS. Manager In-charge is responsible for calibration of the meters




Unit: Kg/cm2

Description: Average pressure of AFBC-1 steam before common header


Online Measurement








NA

QA/QC procedures: The data is monitored from meters at plant and DCS. Manager In-charge is responsible for Regular calibration .The data is archived in Electronic/paper form for a period a credit + 2 years.




Unit: kCal/kg

Description: Enthalpy of AFBC-1 steam to common header


Calculated


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Calculated from steam tables/ Mollier Diagram

QA/QC procedures: The data is calculated .The data is archived in Electronic/paper form for a period a credit + 2 years.





Description: Flow of AFBC-1 Steam to Common header


Online measurement








NA

QA/QC procedures: The data is monitored from flow meters at plant and DCS. Manager In-charge is responsible for regular calibration. The data is archived in Electronic/paper form for a period a credit + 2 years.




Unit: Kcal/day

Description: Total Enthalpy of AFBC-1 steam to common header


Calculated








h2 x S2*1000 i.e. Enthalpy of steam at AFBC-1 boiler outlet in kCal/kg x AFBC-1 steam flow in tonnes per day


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Unit: 0C

Description: Avg. Temperature of WHRB2 steam before common header


Online Measurement








NA

QA/QC procedures: The data is monitored from meters at plant and DCS. Manager In-charge is responsible for calibration of the meters. The data is archived in Electronic/paper form for a period a credit + 2 years.




Unit: Kg/cm2

Description: Avg. pressure of WHRB2 steam before common header


Online Measurement








NA

QA/QC procedures: The data is monitored from meters at plant and DCS. Manager In-charge is responsible for Regular calibration. The data is archived in Electronic/paper form for a period a credit + 2 years.




Unit: kCal/kg

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Description: Enthalpy of WHRB2 steam


Calculated








Calculated from steam tables / Mollier Diagram






Description: Flow of WHRB2 Steam to common header


Measured(m), Online Measurement








NA

QA/QC procedures: The data is monitored from meters at plant and DCS. Manager In-charge would be responsible for regular calibration. The data is archived in Electronic/paper form for a period a credit + 2 years.




Unit: KCal

Description: Total Enthalpy of WHRB2 steam


Calculated




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h3 x S3*1000, Calculated from steam tables/ Mollier Diagram. Calculated on a daily basis




Data / Parameter: S4Eff

Unit: Tones per day

Description: Flow of Boiler AFBC-2 Steam to Common header


Calculated






Daily recording


S4- Svent





Unit: 0C

Description: Average temperature of AFBC-2 steam before common header


Online Measurement








NA

QA/QC procedures: The data is monitored from meters at plant and DCS. Manager In-charge is responsible for calibration of the meters


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Unit: Kg/cm2

Description: Average pressure of AFBC-2 steam before common header


Online Measurement








NA

QA/QC procedures: The data is monitored from meters at plant and DCS. Manager In-charge is responsible for Regular calibration .The data is archived in Electronic/paper form for a period a credit + 2 years.




Unit: kCal

Description: Total Heat of AFBC-2 steam


Calculated



785.41 (The value is for 12/08/2013), the complete set of value is included in ER sheet.





h4 x S4Eff*1000, Calculated from steam tables/ Mollier Diagram. Calculated on a daily basis





Unit: kCal/kg

Description: Enthalpy of AFBC-2 steam to common header


Calculated

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Calculated from steam tables / Mollier Diagram






Description: Flow of AFBC-2 Steam to common header


Online measurement








NA

QA/QC procedures: The data is monitored from flow meters at plant and DCS. Manager In-charge is responsible for regular calibration. The data is archived in Electronic/paper form for a period a credit + 2 years.



Data / Parameter: EGGEN CPP

Unit: MWh/ day

Description: Total Electricity Generated by the CPP


Online measurement








EGGEN CPP = EGTG1 + EGTG2 + EGTG3 + EGTG4

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QA/QC procedures: The data is monitored from energy meters at plant and DCS from all the four turbines. Manager In-charge is responsible for calibration of the meters.The data is archived in Electronic/paper form for a period a credit + 2 years.



Data / Parameter: EGAUX CPP

Unit: MWh/ day

Description: Total Auxiliary consumption of the CPP


Online measurement








EGAUX CPP= = ECAux1 + ECAux2+ ECAux5+ ECAux6

QA/QC procedures: The data is monitored from energy meters supplying auxiliary power at plant and DCS. Manager In-charge is responsible for calibration of the meters. The data is archived in Electronic/paper form for a period a credit + 2 years.



Data / Parameter: EGGEN

Unit: MWh/ day

Description: Power generated by AFBC-2 Boiler


Calculated








Calculated based on the ratio of Enthalpy values as (H4* EG GEN CPP )/ (H1+H2+H3+H4)




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Data / Parameter: EGAUX

Unit: MWh/day

Description: AFBC-2 Auxiliary consumption


Calculated








Calculated based on the ratio of Enthalpy values as (H4*EG AUX CPP )/ (H1+H2+H3+H4).




Data / Parameter: EGY

Unit: MWh/ day

Description: Net Generation (EGy) from AFBC-2


Calculated








(Total effective electricity generated by AFBC-2 - Total electricity consumed for the AFBC-2 based generation)




Data / Parameter: GCVcoal

Unit: Kcal/kg

Description: GCV of the coal measured internally


Measured

Source of data: CREDA report


Refer tab “Project Emission” of ER sheet

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Monitoring equipment: Bomb Calorimeter The monitoring equipment details along with the calibration details are given in the Annex 3 of the MR.


Monthly


As per industry standard

QA/QC procedures: -



D.3. Implementation of sampling plan

>> Not Applicable

SECTION E. Calculation of emission reductions or GHG removals by sinks

E.1. Calculation of baseline emissions or baseline net GHG removals by sinks

>>

Baseline emissions due to generation of electricity:

The baseline emission BEEL,y by the project activity during a given year y is net electricity generated by

AFBC-2 multiplied with emission factor. The calculation is shown below.

BEEL,y = EGY (EGPJ,y)* EFcaptive, y

Where EGPJ,y = EGPJ,gross,y – EGPJ,aux,y

= 260,371.70 * 0.9722 tCO2e = 253,133.3

Where

BEEL,y is the Baseline Emissions (tCO2e)

EGY is Net Electricity generated by AFBC-2 i.e. Project Activity EFcaptive, y is the emission factor Baseline emissions due to uncontrolled burning or decay of biomass residues under aerobic conditions: For conservativeness, zero as per the registered PDD.

E.2. Calculation of project emissions or actual net GHG removals by sinks

>> Project emissions are calculated as follows:

Where:

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PEy = Project emissions during year y (tCO2e) PEFFy = Emissions during the year y due to fossil fuel consumption at the project site (tCO2) PEEL,y = Emissions during the year y due to electricity use off-site for the processing of biomass residues (tCO2) PETR,y = Emissions during the year y due to transport of the biomass residues to the project plant (tCO2) PEBR,y = Emissions from the combustion of biomass residues during the year y (tCO2e) PEWW,y = Emissions from wastewater generated from the treatment of biomass residues in year y (tCO2e) Determination of PEFF,y: Emissions from on-site fossil fuel consumption for the generation of electric power. This includes all fossil fuels used at the project site in heat generators (e.g. boilers) for the generation of electric power: = Coal consumption in MT in a month * Average GCV of coal for a month * Emission factor of coal Hence PEFF,y = 65,361.65 tCO2e Determination of PEEL,y: The project activity does not involve off-site processing of biomass residues. Therefore, PEEL,y =0 Determination of PETR,y: Project Emissions: LETR,y = Df,my * FRf,m * EFkm,CO2 Where: LETR,y Leakage emissions from road transportation of freight monitoring period m (t

CO2) Df,my Return trip road distance between the origin and destination of freight

transportation activity f in monitoring period m (km) FRf,m Total mass of freight transported in freight transportation activity f in monitoring

period m (t) EFkm,CO2 Default CO2 emission factor for freight transportation activity f (t CO2 / t km)

Project emissions due to transportation of biomass = 336,939.511*100*0.000245 = 8,255.01 tCO2e

Determination of PEBR,y:

As per the registered PDD (Page 35),

“If project proponents chose to include emissions due to uncontrolled burning or decay of biomass

residues (BEBR,y) in the calculation of baseline emissions, then emissions from the combustion of

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biomass residues have also to be included in the project scenario. Otherwise, this emission source

need not be included.”

As PP has not chosen to include the emissions due to uncontrolled burning or decay of biomass

residues (BEBR,y) in the calculation of baseline emissions,

Hence PEBR,y = 0

Determination of PEww,y:

There is no treatment of biomass residue.

Hence, PEww,y = 0

E.3. Calculation of leakage

>> Leakage: 0 tCO2e. The leakage is taken zero as demonstrated in section B.6.1 and B.6.3 in the registered PDD.

E.4. Summary of calculation of emission reductions or net GHG removals by sinks

Item

Baseline emissions

or baseline net GHG removals by sinks (t CO2e)

Project emissions or actual net GHG removals by sinks (t CO2e)

Leakage (t CO2e)

GHG emission reductions or net GHG removals by sinks

(t CO2e) achieved in the monitoring period

Up to 31/12/2012

From 01/01/2013

Total amount

Total 253,133 73,616 0 NA 179,516 179,516

E.5. Comparison of actual emission reductions or net GHG removals by sinks with estimates in registered PDD

Item Values estimated in ex ante calculation

of registered PDD Actual values achieved during this

monitoring period

Emission reductions or GHG removals by sinks (t CO2e)

215,018 179,516 (round down)

E.6. Remarks on difference from estimated value in registered PDD

>> The emission reduction achieved during the Monitoring Period are lower than estimate.

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Appendix 1. Contact information of project participants and responsible persons/entities

Project participant and/or responsible person/ entity

Project participant

Person/entity responsible for completing the CDM-MR-FORM

Organization name Godawari Power and Ispat Limited

Street/P.O. Box -

Building G-9, Hira Arcade,

City Pandari, Raipur

State/region Chhattisgarh

Postcode 492001

Country India

Telephone 91-771-5057600

Fax 91-771-5057601

E-mail [email protected]

Website http://www.gpilindia.com/

Contact person Mr Lakshman Prasad

Title Advisor

Salutation Mr

Last name Prasad

Middle name -

First name Lakshman

Department Raw Materials

Mobile 09893900103

Direct fax

Direct tel.

Personal e-mail [email protected]

mailto:[email protected]

mailto:[email protected]

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Annex 1

0C Degree Celsius

FBC Atmospheric Fluidized Bed Combustion ABC After Burning Chamber cm Centimetre CPP Captive Power Plant FBB Fluidized Bed Boilers GPIL M/s Godawari Power And Ispat Ltd. kWh Kilowatt hour kCal kilocalorie kg Kilogram MCR Maximum Continuous Rating MWh Megawatt hour PLF Plant Load Factor TPH tonnes per hour TPD tonnes per day TG Turbo Generator WHRB Waste Heat Recovery Boiler

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Annex 2: Sustainability Monitoring plan

No 1

Indicator Air Quality

Mitigation measure N.A.

Chosen parameter Governmental requirements fulfilment

Current situation of parameter Promotion of renewable energy based power generation. Project has received the consent to operate for air for this monitoring period.

Estimation of baseline situation of parameter

The baseline is coal based power generation which would have impacted the environment with CO2 emissions.

Future target for parameter Promotion of renewable energy based power generation.

Way of monitoring How Consent to operate for Air

When Just before expiry of validity for “Consent to Operate”

By who By State Pollution Control Board

No 2

Indicator Quality of employment

Mitigation measure N/A

Chosen parameter Number of trainings provided to unskilled, semi-skilled and skilled people

Current situation of parameter Training records submitted to verification team


NA

Future target for parameter Hiring of skilled and unskilled personnel in the plant and providing specific trainings to them

Way of monitoring How Employment training record

When Continuous

By who GPIL HR & training department

No 3

Indicator Access to affordable & clean energy sources

Mitigation measure N/A

Chosen parameter Net energy generation by power plant

Current situation of parameter The annual net electricity generation during this monitoring period is 130.185 GWh which is higher than the estimated.


The total annual generation of electricity from project activity will be 126.72 GWh.

Future target for parameter The future target for parameter is that the annual net electricity generation will be 126.72 GWh.

Way of monitoring How Interviews with the local inhabitants near the project sites about change in fuel consumption pattern and quality of electricity supplied

When Ongoing, shall be monitored at least annually

By who GPIL personnel

No 4

Indicator Livelihood of the poor

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Mitigation measure NA

Chosen parameter Number of people employed and other employment opportunities created in unskilled jobs.

Current situation of parameter Training records submitted to verification team


NA

Future target for parameter Hiring of skilled and unskilled personnel in the plant and providing them wages as per government norms

Way of monitoring How Employment training records

When Every year

By who GPIL HR & training department

No 5

Indicator Quantitative employment and income generation


Chosen parameter Number of jobs created

Current situation of parameter Record for the employment has been submitted to verification team.

Year unskilled semiskilled skilled Administration Total

2012-13

1023 340 510 127 2000

2013-14

1060 166 666 108 2000

2014-15

1230 487 658 122 2497


NA

Future target for parameter Hiring more skilled and unskilled employees for the project operation at the plant and thus increasing the number of jobs created by the company

Way of monitoring How Employment record

When Every year

By who GPIL HR and admin department

No 6

Indicator Renewable Biomass resources


Chosen parameter Renewable biomass residues usage rate

Current situation of parameter Along with Biomass, some percentage of coal has used during this monitoring period in the 20 MW biomass boiler. The coal use up to 15% is allowed as per the consent to operate for water and air from the government authority i.e. CECB. During this monitoring period, the coal used was less than 15% and acceptable by government authority.

Coal used (T) biomass used (T)

for the monitoring period (11/08/2014 to 10/08/2015)

37694.09 336939.511


0% - i.e. the renewable biomass residue was not used in the baseline.

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Future target for parameter 85% Biomass and 15% Coal (Maximum) as allowed as per CECB government authority

Way of monitoring How Check the type of biomass procured.

When For every biomass residue received

By who

GPIL procurement department

No 7

Indicator Biomass residues surplus


Chosen parameter Surplus rate of biomass residue

Current situation of parameter Surplus rate of biomass residue is above 25%


N/A

Future target for parameter Surplus rate of biomass residue will be checked from biomass assessment survey

Way of monitoring How Interview with local residents. Check the Biomass Resource Collection Report

When Annually

By who GPIL

No 8

Indicator Biomass dust particles


Chosen parameter Exposure to biomass dust/particles

Current situation of parameter Workers exposed to dust particles are provided mask for their faces.


N/A

Future target for parameter Workers exposed to dust particles will be provided mask for their faces.

Way of monitoring How Plant records

When Continuously

By who GPIL

No 9

Indicator Waste Water Discharged


Chosen parameter Waste Water discharged

Current situation of parameter Plant is zero discharge


Waste water will not be discharged without treatment

Future target for parameter Waste water will not be discharged without treatment

Way of monitoring How Check the wastewater treatment facility

When Every Month

By who GPIL

No 10

Indicator Ash generation in the project activity

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Chosen parameter Use of Ash generated

Current situation of parameter Ash generated during the project activity is used for making bricks and in Cement Units


N/A

Future target for parameter Ash generated during the project activity will be used for making bricks and in Cement Units

Way of monitoring How Plant reports

When Every Month

By who GPIL

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Annex 3

Calibration details of Energy Meters

GODAWARI POWER & ISPAT LTD ENERGY METER Calibration in 2015 (Corresponding to monitoring parameters EGGEN CPP, EGAUX CPP)

SR.NO. SERVICE

MAKE SR.NO MODEL TYPE PT RATIO CT RATIO CLASS

M.F. CAL ON CAL DUE

CAL DONE BY

CALIBRATION

FREQUENCY

1. TG # 01 MAIN METER SEMS CSE42875 PREMIE

R ENTITY

E 3M02

1 3P,4W

11KV/√3/110V/√3

—/1A 0.2s 800 01.06.15 31.05.16

VOLTECH ENGG. , RAIPUR

Annual

2. TG # 01 CHECK METER SEMS CSE42876 PREMIE

R ENTITY

E 3M02

1 3P,4W

11KV/√3/110V/√3

—/1A 0.2s 800 01.06.15 31.05.16


R ENTITY

E 3M02

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—/1A 0.2s 800 01.06.15 31.05.16


R ENTITY

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—/1A 0.2s 800 01.06.15 31.05.16


R ENTITY

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—/1A 0.2s 800 04.06.15 03.06.16


R ENTITY

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E 3M02

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—/1A 0.2s 250

0 02.06.15 01.06.16


R ENTITY

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—/1A 0.2s 250

0 02.06.15 01.06.16

9. PP AUX # 01 MAIN METER SEMS CSE42885 PREMIE

R ENTITY

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1 3P,4W

11KV/√3/110V/√3

—/1A 0.2s 200 02.06.15 01.06.16

10. PP AUX # 01 CHECK METER SEMS CSE42886 PREMIE

R ENTITY

E 3M02

1 3P,4W

11KV/√3/110V/√3

—/1A 0.2s 200 02.06.15 01.06.16


R ENTITY

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—/1A 0.2s 200 02.06.15 01.06.16


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—/1A 0.2s 200 02.06.15 01.06.16


R ENTITY

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—/1A 0.2s 200 02.06.15 01.06.16


R ENTITY

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—/1A 0.2s 200 02.06.15 01.06.16


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—/1A 0.2s 200 02.06.15 01.06.16

ENERGY METER Calibration in 2014 (Corresponding to monitoring parameters EGGEN CPP, EGAUX CPP)

SR.NO. SERVICE

MAKE SR.NO MODEL TYPE PT RATIO

CT RATIO CLASS M.F. CAL ON CAL DUE

CAL DONE BY

Calibration

frequency


R ENTITY

E 3M02

1 3P,4W

11KV/√3/110V/√3

—/1A 0.2s 800 03.06.14 02.06.15


Annual


R ENTITY

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—/1A 0.2s 800 03.06.14 02.06.15


R ENTITY

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—/1A 0.2s 800 03.06.14 02.06.15


R ENTITY

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—/1A 0.2s 800 03.06.14 02.06.15


R ENTITY

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—/1A 0.2s 800 19.11.14 18.11.15


R ENTITY

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—/1A 0.2s 800 19.11.14 18.11.15


R ENTITY

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—/1A 0.2s 2500 03.06.14 02.06.15


R ENTITY

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—/1A 0.2s 200 04.06.14 03.06.15


R ENTITY

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—/1A 0.2s 200 04.06.14 03.06.15


R ENTITY

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—/1A 0.2s 200 04.06.14 03.06.15


R ENTITY

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—/1A 0.2s 200 04.06.14 03.06.15


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—/1A 0.2s 200 04.06.14 03.06.15


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—/1A 0.2s 200 04.06.14 03.06.15


R ENTITY

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—/1A 0.2s 200 04.06.14 03.06.15


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—/1A 0.2s 200 04.06.14 03.06.15

ENERGY METER Calibration in 2013 (Corresponding to monitoring parameters EGGEN CPP, EGAUX CPP)

SR.NO SERVICE MAK SR.NO MODEL TYPE PT RATIO CT CLASS M.F. CAL ON CAL DUE CAL DONE Calibratio

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. E RATIO BY n frequency

1. TG # 01 MAIN METER SEMS

CSE42875 PREMIE

R ENTITY

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—/1A 0.2s 800 06.06.13 05.06.14


Annual

2. TG # 01 CHECK METER SEMS

CSE42876 PREMIE

R ENTITY

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11KV/√3/110V/√3

—/1A 0.2s 800 06.06.13 05.06.14


CSE42877 PREMIE

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—/1A 0.2s 800 06.06.13 05.06.14


CSE42878 PREMIE

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—/1A 0.2s 800 06.06.13 05.06.14


CSE42879 PREMIE

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11KV/√3/110V/√3

—/1A 0.2s 800 20.11.13 19.11.14


CSE42880 PREMIE

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11KV/√3/110V/√3

—/1A 0.2s 800 20.11.13 19.11.14


CSE42881 PREMIE

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11KV/√3/110V/√3

—/1A 0.2s 2500 06.06.13 05.06.14


CSE42882 PREMIE

R ENTITY

E 3M02

1 3P,4W

11KV/√3/110V/√3

—/1A 0.2s 2500 06.06.13 05.06.14

9. PP AUX # 01 MAIN METER SEMS

CSE42885 PREMIE

R ENTITY

E 3M02

1 3P,4W

11KV/√3/110V/√3

—/1A 0.2s 200 07.06.13 06.06.14

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10. PP AUX # 01 CHECK METER SEMS

CSE42886 PREMIE

R ENTITY

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1 3P,4W

11KV/√3/110V/√3

—/1A 0.2s 200 07.06.13 06.06.14


CSE42887 PREMIE

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—/1A 0.2s 200 07.06.13 06.06.14


CSE42888 PREMIE

R ENTITY

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—/1A 0.2s 200 07.06.13 06.06.14


CSE42893 PREMIE

R ENTITY

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—/1A 0.2s 200 07.06.13 06.06.14


CSE42894 PREMIE

R ENTITY

E 3M02

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11KV/√3/110V/√3

—/1A 0.2s 200 07.06.13 06.06.14


CSE42895 PREMIE

R ENTITY

E 3M02

1 3P,4W

11KV/√3/110V/√3

—/1A 0.2s 200 07.06.13 06.06.14


CSE42896 PREMIE

R ENTITY

E 3M02

1 3P,4W

11KV/√3/110V/√3

—/1A 0.2s 200 07.06.13 06.06.14

SR. NO.

Monitoring parameter TAG

NO. SERVIC

E MAKE

TX. SR. NO.

TYPE

ACCURACY

CALIBRATED BY

JULY- 2013 OCT- 2013 JAN- 2014

Calibration

frequency

CAL ON

NEXT CAL.D

UE DATE

CAL ON

NEXT CAL.D

UE DATE

CAL ON

NEXT CAL.D

UE DATE

CDM-MR-FORM

Version 04.0 of 51

1

S1

FT-002

WHRB-1 main

steam flow

ABB 1011589 DP ± 0.075 %

of cal.span

Bhilai calibration laboratory

31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

Quarterly

2

P1

PT-003

WHRB-1 main

steam Pressure

ABB 1011607 Pr. ± 0.075 %

of cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

3

T1

TI-006

WHRB-1main steam temp.

ABB 09G221 TT ± 0.1% of cal.span


29/7/2013

28/10/2013

28/10/2013

27/01/2014

27/01/2014

26/04/2014

4

S2

FT-302

AFBC main

steam flow

YOKOGAWA

91L409659-114

DP ± 0.075 %

of cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

5

P2

PT-303

AFBC main

steam Pressure

ABB 1011640 Pr. ± 0.075 %

of cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

6

T2

TI-305

AFBC main

steam temp.



29/7/2013

28/10/2013

28/10/2013

27/01/2014

27/01/2014

26/04/2014

7

S3

FT-727

WHRB-2 main

steam flow

Tata Honeywe

ll 1701713-35 DP

± 0.075 % of

cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

8

P3

PT-726

WHRB-2 main

steam Pressure

Tata Honeywe

ll 1701713-17 Pr.

± 0.075 % of

cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

9

T3

TT-728

WHRB-2 main

steam temp.

Tata Honeywe

ll 29364 TT

± 0.075 % of

cal.span


29/7/2013

28/10/2013

28/10/2013

27/01/2014

27/01/2014

26/04/2014

10 Scons

FT-602 TG-1 inlet

steam flow

ABB 1013370 DP ± 0.075 %

of cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

11 Scons

FT-603 TG-2 inlet

steam flow

ABB 1013369 DP ± 0.075 %

of cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

12

Scons

FT-401 TG-3 inlet

steam flow

Tata Honeywe

ll 1701713-41 DP

± 0.075 % of

cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

CDM-MR-FORM

Version 04.0 of 51

13

FT-001 TG-4 inlet

steam flow

Tata Honeywe

ll 1701713-36 DP

± 0.075 % of

cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

14

Scons

FT-002

TG-4 Auxilary steam flow

Tata Honeywe

ll 1701713-32 DP

± 0.075 % of

cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

15

S4

FT-201

AFBC-2 main

Steam Flow Txr.

Yokogawa

91L409661-114

DP ± 0.075 %

of cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

16

P4

PT-202

Main Steam Press.

Txr.

ABB 09K0162 PT ± 0.075 %

of cal.span


31/7/2013

30/10/2013

29/10/2013

28/01/2014

28/01/2014

27/04/2014

17

T4

TT-203

Main Steam

Temperature. Txr.

ABB 09K188 TT ± 0.1% of cal.span


29/7/2013

28/10/2013

28/10/2013

27/01/2014

27/01/2014

26/04/2014

SR. NO.

Monitoring

parameter TAG

NO. SERVIC

E MAKE

TX. SR. NO.

TYPE

ACCURACY

CALIBRATED BY

APR-2014 JULY-2014 OCT-2014 JAN-2015

Calibration

frequency

CAL ON

NEXT CAL.DUE

DATE

CAL ON

NEXT CAL.DUE

DATE

CAL ON

NEXT CAL.DUE

DATE

CAL ON

NEXT CAL.DUE

DATE

Quarterly

1

S1 FT-002

WHRB-1 main

steam flow

ABB 1011589 DP ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/01/2015

21/1/2015

20/04/2015

2

P1

PT-003

WHRB-1 main

steam Pressur

e

ABB 1011607 Pr. ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/1/2015

21/1/2015

20/4/2015

3

T1

TI-006


ABB 09G221 TT ± 0.1%

of cal.span


26/04/2014

25/07/2014

25/07/2014

24/10/2014

21/10/2014

20/01/2015

20/01/2015

19/04/2015

CDM-MR-FORM

Version 04.0 of 51

4

S2 FT-302

AFBC main

steam flow

YOKOGAWA

91L409659-114

DP ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/01/2015

21/1/2015

20/04/2015

5

P2

PT-303

AFBC main

steam Pressur

e

ABB 1011640 Pr. ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/1/2015

21/1/2015

20/4/2015

6

T2

TI-305

AFBC main

steam temp.

ABB 09G235 TT ± 0.1%

of cal.span


26/04/2014

25/07/2014

25/07/2014

24/10/2014

21/10/2014

20/01/2015

20/01/2015

19/04/2015

7

S3 FT-727

WHRB-2 main

steam flow

Tata Honeyw

ell

1701713-35

DP ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/01/2015

21/01/2015

20/04/2015

8

P3

PT-726

WHRB-2 main

steam Pressur

e

Tata Honeyw

ell

1701713-17

Pr. ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/1/2015

21/1/2015

20/4/2015

9

T3 TT-728

WHRB-2 main

steam temp.

Tata Honeyw

ell 29364 TT

± 0.075 % of

cal.span


26/04/2014

25/07/2014

25/07/2014

24/10/2014

21/10/2014

20/01/2015

20/01/2015

19/04/2015

10

Scons FT-

602

TG-1 inlet

steam flow

ABB 1013370 DP ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/01/2015

21/1/2015

20/04/2015

11

Scons FT-603

TG-2 inlet

steam flow

ABB 1013369 DP ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/01/2015

21/1/2015

20/04/2015

12

Scons FT-401

TG-3 inlet

steam flow

Tata Honeyw

ell

1701713-41

DP ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/01/2015

21/1/2015

20/04/2015

13

FT-001

TG-4 inlet

steam flow

Tata Honeyw

ell

1701713-36

DP ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/01/2015

21/1/2015

20/04/2015

14 Scons FT-

002

TG-4 Auxilary steam

Tata Honeyw

ell

1701713-32

DP ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/01/2015

21/1/2015

20/04/2015

CDM-MR-FORM

Version 04.0 of 51

flow

15

S4

FT-201

AFBC-2 main

Steam Flow Txr.

Yokogawa

91L409661-114

DP ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/01/2015

21/1/2015

20/04/2015

16

P4 PT-202

Main Steam Press.

Txr.

ABB 09K0162 PT ± 0.075

% of cal.span


27/04/2014

26/07/2014

26/07/2014

25/10/2014

22/10/2014

21/1/2015

21/1/2015

20/4/2015

17

T4

TT-203

Main Steam

Temperature. Txr.

ABB 09K188 TT ± 0.1%

of cal.span


26/04/2014

25/07/2014

25/07/2014

24/10/2014

21/10/2014

20/01/2015

20/01/2015

19/04/2015

SR. NO.

Monitoring

Parameter TAG

NO. SERVIC

E MAKE

TX. SR. NO.

TYPE

ACCURACY

CALIBRATED BY

APR-2015 JULY-2015 OCT-2015

Calibration

frequency

CAL ON

NEXT CAL.D

UE DATE

CAL ON

NEXT CAL.D

UE DATE

CAL ON

NEXT CAL.D

UE DATE

1

S1

FT-002

WHRB-1 main

steam flow

ABB 1011589 DP ± 0.075 %

of cal.span


20/04/2015

19/07/2015

18/07/2015

17/10/2015

17/10/2015

16/01/2016

Quarterly

2

P1

PT-003

WHRB-1 main

steam Pressure

ABB 1011607 Pr. ± 0.075 %

of cal.span


20/4/2015

19/7/2015

18/7/2015

17/10/2015

17/10/2015

16/01/2016

3

T1

TI-006




18/04/2015

17/07/2015

17/07/2015

16/10/2015

16/10/2015

15/01/2016

4

S2

FT-302

AFBC main

steam flow

YOKOGAWA

91L409659-114

DP ± 0.075 %

of cal.span


20/04/2015

19/07/2015

18/07/2015

17/10/2015

17/10/2015

16/01/2016

CDM-MR-FORM

Version 04.0 of 51

5

P2

PT-303

AFBC main

steam Pressure

ABB 1011640 Pr. ± 0.075 %

of cal.span


20/4/2015

19/7/2015

18/7/2015

17/10/2

015

17/10/2015

16/01/2016

6

T2

TI-305

AFBC main

steam temp.



18/04/2015

17/07/2015

17/07/2015

16/10/2015

16/10/2015

15/01/2016

7

S3

FT-727

WHRB-2 main

steam flow

Tata Honeywe

ll 1701713-35 DP

± 0.075 % of

cal.span


20/04/2015

19/07/2015

18/07/2015

17/10/2015

17/10/2015

16/01/2016

8

P3

PT-726

WHRB-2 main

steam Pressure

Tata Honeywe

ll 1701713-17 Pr.

± 0.075 % of

cal.span


20/4/2015

19/7/2015

18/7/2015

17/10/2015

17/10/2015

16/01/2016

9

T3

TT-728

WHRB-2 main

steam temp.

Tata Honeywe

ll 29364 TT

± 0.075 % of

cal.span


18/04/2015

17/07/2015

17/07/2015

16/10/2015

16/10/2015

15/01/2016

10 Scons

FT-602 TG-1 inlet

steam flow

ABB 1013370 DP ± 0.075 %

of cal.span


20/04/2015

19/07/2015

18/07/2015

17/10/2015

17/10/2015

16/01/2016

11 Scons

FT-603 TG-2 inlet

steam flow

ABB 1013369 DP ± 0.075 %

of cal.span


20/04/2015

19/07/2015

18/07/2015

17/10/2015

17/10/2015

16/01/2016

12

Scons

FT-401 TG-3 inlet

steam flow

Tata Honeywe

ll 1701713-41 DP

± 0.075 % of

cal.span


20/04/2015

19/07/2015

18/07/2015

17/10/2015

17/10/2015

16/01/2016

13

FT-001 TG-4 inlet

steam flow

Tata Honeywe

ll 1701713-36 DP

± 0.075 % of

cal.span


20/04/2015

19/07/2015

18/07/2015

17/10/2015

17/10/2015

16/01/2016

14

Scons

FT-002

TG-4 Auxilary steam flow

Tata Honeywe

ll 1701713-32 DP

± 0.075 % of

cal.span


20/04/2015

19/07/2015

18/07/2015

17/10/2015

17/10/2015

16/01/2016

15

S4

FT-201

AFBC-2 main

Steam Flow Txr.

Yokogawa

91L409661-114

DP ± 0.075 %

of cal.span


20/04/2015

19/07/2015

18/07/2015

17/10/2015

17/10/2015

16/01/2016

16

P4

PT-202

Main Steam Press.

Txr.

ABB 09K0162 PT ± 0.075 %

of cal.span


20/4/2015

19/7/2015

18/7/2015

17/10/2015

17/10/2015

16/01/2016

CDM-MR-FORM

Version 04.0 of 51

17

T4

TT-203

Main Steam

Temperature. Txr.

ABB 09K188 TT ± 0.1% of cal.span


18/04/2015

17/07/2015

17/07/2015

16/10/2015

16/10/2015

15/01/2016

Weigh Bridge Calibration Matrix Weigh Bridge

No.

Capacity in tones

Location Material weighing

Calibration frequency

Calibration Due date

Calibration done


Calibration done


Calibration done

1 100 Gate 03 Rice husk Annual 08.08.2013 08.08.2013 07.08.2014 20.06.2014 19.06.2015 16.06.2015





Bomb Calorimeter Calibration Matrix Sr. No.

Location Calibration done


Calibration done


Calibration done


Calibrated by

25518514 DM plant lab 03/12/2012 03/12/2013 03/12/2013, 23/12/2013

03/12/2014, 23/12/2014

06/12/2014 06/12/2015 Internally on annual basis

with Calibrated

Instruments

CDM-MR-FORM

Version 04.0 of 51

- - - - -

Document information

Version Date Description

05.1 4 May 2015 Editorial revision to correct version numbering.

05.0 1 April 2015 Revisions to:

Include provisions related to delayed submission of a monitoring plan;

Provisions related to the Host Party;

Remove reference to programme of activities;

Overall editorial improvement.

04.0 25 June 2014 Revisions to:

Include the Attachment: Instructions for filling out the monitoring report form (these instructions supersede the "Guideline: Completing the monitoring report form" (Version 04.0));

Include provisions related to standardized baselines;

Add contact information on a responsible person(s)/ entity(ies) for completing the CDM-MR-FORM in A.6 and Appendix 1;

Change the reference number from F-CDM-MR to CDM-MR-FORM;

Editorial improvement.

03.2 5 November 2013 Editorial revision to correct table in page 1.

03.1 2 January 2013 Editorial revision to correct table in section E.5.

03.0 3 December 2012 Revision required to introduce a provision on reporting actual emission reductions or net GHG removals by sinks for the period up to 31 December 2012 and the period from 1 January 2013 onwards (EB70, Annex 11).

02.0 13 March 2012 Revision required to ensure consistency with the "Guidelines for completing the monitoring report form" (EB 66, Annex 20).

01 28 May 2010 EB 54, Annex 34. Initial adoption.

Decision Class: Regulatory Document Type: Form Business Function: Issuance Keywords: monitoring report

f-cdm-mr: monitoring report form. version 03

Documents