Project title: Coal Mine Methane Capture and Utilization ... Periodical Monitoring... · The Second...

The Second Annual Monitoring Report on the reduced emissions

Joint Implementation Mechanism

KWK „Borynia”

Project title:

Coal Mine Methane Capture and Utilization at KWK Borynia Coal Mine, Poland.

Monitoring period: 01.09.2010 – 31.08.2011

Version 4

Date: 6 th February 2012

Coal Mine Capture and Utilization at KWK Borynia Coalmine, Poland – Second Periodical Monitoring Report Version 4

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Contents

1. Joint Implementation Project Information ........... ........................................ 4

1.1. Project title ..............................................................................................................4 1.2. Name, designation of office and address of the project applicant ....................4 1.3. Location of the project activity..............................................................................5

1.3.1. Voivodeship ....................................................................................................................... 5 1.3.2. Community and city ........................................................................................................... 5 1.3.3. Address or parcel identification number ............................................................................ 5

1.4. Type of greenhouse gas, which emission was reduced, avoided or absorbed (please tick the appropriate gas) ........................................................7

1.5. The results of conducted R&D activities..............................................................7 1.6. Reporting period.....................................................................................................7

1.6.1. Crediting period of the project activity and related information ......................................... 7 1.6.2. Registration date of the project activity.............................................................................. 7 1.6.3. Relevant dates for the project activity (e.g. construction, commissioning, continued

operation periods, etc.) ..................................................................................................... 7

2. Monitoring information and data .................... .............................................. 8

2.1. Methodology for calculating the resulting GHG emission reductions or avoided emissions.................................................................................................8

2.1.1. Title, reference and version of the baseline and monitoring methodology applied to the project activity ............................................................................................................. 8

2.1.2. Revision of the monitoring plan ......................................................................................... 9 2.1.3. Request for deviation applied to this monitoring period .................................................... 9 2.1.4. Notification or request of approval of changes .................................................................. 9 2.1.5. Description of the monitoring system ................................................................................ 9

2.2. Sources of greenhouse gas emissions..............................................................18 2.2.1. Purpose of the project activity and the measures taken to reduce greenhouse gas

emissions ........................................................................................................................ 18 2.2.2. Brief description of the installed technology and equipments ......................................... 18 2.2.3. Technical description of the project and sources of greenhouse gas emissions ............ 19

2.3. Additional greenhouse gas emissions caused by the project activity and size of these emissions.......................................................................................20

2.4. Results of the GHG emission reduction or emission avoidance .....................21 2.4.1. Baseline emissions calculation ........................................................................................ 21 2.4.2. Project emissions calculation........................................................................................... 26 2.4.3. Leakage calculation ......................................................................................................... 30

3. Source data used to calculate the size of reduction s or avoided emissions of greenhouse gases...................... ........................................... 30

3.1. Data and parameters used to calculate baseline emissions ............................30 3.2. Data and parameters used to calculate project emissions ..............................33 3.3. Data and parameters used to calculate leakage emissions .............................36 3.4. Other relevant data and parameters ...................................................................36

4. The number of emission reduction units (ERUs) achie ved in the reporting period ................................... ........................................................ 36

4.1. Emission reductions calculation.........................................................................36


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4.2. Comparison of actual emission reductions with estimates in the registered CDM-PDD ...........................................................................................37

4.3. Remarks on difference from estimated value ....................................................37


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List of tables Table 1. Control-measuring equipment registry .....................................................................10

Table 2. Monitoring equipment and adequate monitoring procedures ...................................13

Table 3. Measurement of NMHC content...............................................................................15

Table 4. Electricity meters and adequate monitoring procedures ..........................................16

Table 5. Heat meters and adequate monitoring procedures ..................................................17

Table 6. Description of the trainings done..............................................................................18

Table 7. Project emissions from additional energy required for CMM capture and use.........20

Table 8. Methane consumption by boiler house, indicating thermal demand by maximum monthly consumption in 2002-2007 ...........................................................21

Table 9. The calculation of dmaxk.............................................................................................22

Table 10. Baseline methane destruction emissions ...............................................................24

Table 11. Baseline methane release......................................................................................25

Table 12. Baseline Emission ..................................................................................................25

Table 13. Methane destroyed through power generation.......................................................26

Table 14. Methane destroyed through heat generation .........................................................27

Table 15. Project emissions from methane destroyed ...........................................................28

Table 16. Un-combusted methane from flaring and end uses ...............................................29

Table 17. Project Emissions...................................................................................................29

Table 18. Data and parameters used to calculate baseline emissions ..................................31

Table 19. Data and parameters used to calculate project emissions.....................................33

Table 20. Emission reductions calculation – year 2010 .........................................................36

Table 21. Emission reductions calculation – year 2011 .........................................................36

List of figures

Figure 1. Diagram of the monitoring system ............................................................................9

Figure 2. General organization chart of the service of the monitoring process ......................12

Figure 3. The conceptual scheme of the measurement system.............................................14


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1. Joint Implementation Project Information

1.1. Project title

Coal Mine Methane Capture and Utilization at KWK Borynia Coal Mine, Poland

1.2. Name, designation of office and address of the project applicant

Jastrz ębska Spółka W ęglowa S.A. (Jastrzebie Coal Company) – project owner, and project implementation entity. State treasury sole propriety Company. Company currently manages five coal mines: “Borynia - Zofiówka”, “Budryk", "Jas-Mos”, ”Pniówek”, “Krupiński” and the Material Logistics Plant, which is extracted coking coal and coal for energy purposes. Total mining area - 122 km2; Operational coal deposits - 285.81 million tons; Share capital - PLN 497,620,100; employment - 22.3 thous. workers. According to the decision of the Board JSW from 01/01/2011 KWK “Borynia” and KWK “Zofiówka” operate as a joint entity called KWK “Borynia – Zofiówka”. The change of the name did not affect the validity of agreements and commitments relating to the mine. KWK “Borynia – Zofiówka” Ruch Borynia (The Borynia Coal Mine) – owner of the project site and the entity responsible for the project implementation and management. Coal mining plant, affiliated to the JSW SA. Mining area - 17,4 km2. Operational coal deposits – 34 thous. tones, employment – 3,564 workers. KWK “Borynia – Zofiówka” Ruch Zofiówka (The Zofiówk a Coal Mine) – coal mining plant, affiliated to the JSW SA. Mining area - 16,4 km2. Operational coal deposits – 87 thous. tones, employment – 4,057 workers. Główny Instytut Górnictwa (Central Mining Institute ) – institute employed for JI procedure performance and implementation. Scientific institute directly subordinated to the Minister of Economy, working for the benefit of the mining industry. The Chugoku Electric Power Co., Inc – Japanese Power Company pursuing implementation of the project, participates in preparation of the JI project. The company acquires all ERUs generated in this project. Name of responsible persons / entities: Krzysztof Sta ńczyk Główny Instytut Górnictwa Plac Gwarków 1 40-166 Katowice Tel. +48 32 2592267 Fax. +48 32 2592267 Stefan Łach JSW S.A. – KWK Borynia - Zofiówka ul. Węglowa 4 44-268 Jastrzębie Zdrój +48 32 7561553 +48 32 7561553


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Hideo Yata The Chugoku Electric Power Co., Inc. 4-33, Komachi, Naka-ku, Hiroshima, 730-8701, Japan Tel +81-82-523-6424 Fax +81-82-523-6422 Teruyuki Okada Mizuho Corporate Bank, Ltd. 5-1, Marunouchi 2-chome, Chiyodaku, Tokyo 100-8333, Japan Tel +81-3-5220-7179 Fax +81-3-3201-6582

1.3. Location of the project activity

1.3.1. Voivodeship

Śląskie Voivodeship

1.3.2. Community and city

Community : Jastrzębie Zdrój City : Jastrzębie Zdrój

1.3.3. Address or parcel identification number

Jastrz ębska Spółka W ęglowa S.A. (Jastrzebie Coal Company) Aleja Jana Pawła II 4 44-330 Jastrzębie-Zdrój Kopalnia W ęgla Kamiennego "Borynia-Zofiówka" (The Borynia-Zofi ówka Coal Mine) 44-335 Jastrzębie-Zdrój ul. Rybnicka 6 Geo-coordinates: 49.999444, 18.612778 (49° 59 ′ 58″ N, 18° 36 ′ 46″ E) BORYNIA-ZOFIÓWKA Coal Mine’s Mining Area is located in Upper Silesian Coal Basin (Górnośląskie Zagłębie Węglowe) covering catchments areas of city Jastrzębie Zdrój (95,500 inhabitants, 19,800 employed in industry) and communities: Świerklany, Mszana, and Pawłowice. Total of 33,8 km2 Borynia - Zofiówka mining area is predominately rural with low-density housing, farmlands, meadows, and woodlands. Residential area with high-density housing or medium-density housing in Jastrzębie Szeroka district occupies small part of the mining area. Upper Silesian Coal Basin lies in the historical regions of Upper Silesia in southern Poland and Czech Republic. The basin constitute homogeneous geological and geographical area covering 5,4 thous. km2 and containing the largest coal deposit both in Czech and Poland. Deposit on level 1000 m is estimated at 70 million tones of which around 10-15% have been extracted to date. Except coal zink and lead are mined in the region. Polish part of Upper Silesian Coal Basin is 4.5 thous. km2 being the most industrialized and urbanized part of Poland. There are 50 mines, 17 foundries and steelworks, and 8 smelting plants, numerous


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coking plant, and power plants and other giving the heavies gas and dust pollution not only in Poland, but all over Central Europe.


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1.4. Type of greenhouse gas, which emission was reduced, avoided or absorbed (please tick the appropriate gas)

X CH4 N2O HFCs PFCs SF 6 CO2

1.5. The results of conducted R&D activities

Total emission reductions achieved in the monitoring period 01.09.2010 – 31.08.2011 amounted to 35,673 ERUs.

1.6. Reporting period

This Monitoring Report covers the monitoring period between September 1st 2010 and August 31st 2011 (12 months).

1.6.1. Crediting period of the project activity and related information

Crediting period for the Project was established by Ministry of Environment in the Letter of Approval for: 4 years and 9 months (31 March 2008 – 31 December 2012).

1.6.2. Registration date of the project activity

The project was registered by JISC on 6th May 2011 under identification number: PL1000264.

1.6.3. Relevant dates for the project activity (e.g . construction, commissioning, continued operation periods, etc.)

1. 16 Jan 2006 Meeting of the representatives from GIG and YOHO Sp. z o.o. with the representatives from JSW S.A. and KWK ‘Borynia’ regarding the possibility of implementation of Kyoto Protocol mechanisms inside KWK ‘Borynia’ concerning coal mine methane utilization issue.

2. 24 Feb 2006 Sitting of the energy team of the KWK ‘Borynia’ concerning issues of the coal mine methane utilization including possibility of the Joint Implementation scheme application.

3. 16 May 2006 Establishment of a Project Team to coordinate the implementation of a project called „Construction of a gas engine employed to CHP system powered with CMM for JSW S.A. KWK ‘Borynia’”.

4. 28 June 2006 Conception completion of the proposed CHP system. 5. 07 Sep 2006 Bids invitation to construct CHP system. 6. Sep - Nov 2006 Talks on JI scheme project implementation with SFW Energia Sp. z o.o.

from Gliwice and Carbon – FT B.V. from Venio, the Netherlands. 7. 01 Oct 2006 Bids opening to construct CHP system. 8. 07 Oct 2006 Second phase of the bid to construct CHP system.


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9. 20 Nov 2006 Inquiries on tentative offers to implement JI scheme project sent to GIG in Katowice; SFW Energia Sp. z o.o in Gliwice; Carbon – FT B.V. Venio from the Netherlands and EPA Sp. z o.o. in Szczecin.

10. 20 Dec 2006 Contract signing with INTROL S.A. to construct CHP system. 11. 12 Jan 2007 Decision on the localization of public aim investment for a construction of

CHP system powered with CMM 12. 08 Feb 2007 Bids invitation to implement JI scheme project. 13. 07 March 2007 Bids opening to implement JI scheme project. 14. 19 March 2007 Second phase of the bid to implement JI scheme project. 15. 15 May 2007 Contract signing with GIG to implement JI scheme Project. 16. 04 May 2007 Decision on the localization of public aim investment for construction of

gas pipeline DN 200 to power CHP system. 17. 03 Aug 2007 Endorsement decision for construction of gas pipeline (DN 200) to power

CHP system 18. 02 Aug 2007 Project Idea Note (PIN) submission to the Ministry of the Environment

and the National Fund for Environmental Protection and Water Management.

19. 28 Aug 2007 Endorsement decision for construction of CHP system powered with CMM.

20. 11 Sep 2007 Notice on the planned starting the construction works on day 24 Sep 2007 to the Poviat Clerk of Works for Jastrzębie Zdrój

21. 09 Oct 2008 Starting the construction of the CHP unit. 22. 09-10 Jan 2008 Project validation process began. 23. 31 March 2008 CHP system receipt together with accessories and running of the trial

run. 24. 31 March 2008 Beginning of the first monitoring period 25. 14 May 2008 Notice on the completion of construction works and planned running of

the object (from 24 Sep 2007) to the Poviat Clerk of Works for Jastrzębie Zdrój.

26. 23 Jun 2008 Starting up of the CHP unit. 27. 29 July 2009 Obtaining the Letter of Endorsement from Polish Ministry of

Environment. 28. 06 Aug 2008- Renovation of gas burners in two boilers 1.2 MW 21 Nov 2008 29. 13 Nov 2009 The determination process is completed. 30. 05 Feb 2010 Obtaining the Letter of Approval from Polish Ministry of Environment. 31. 31 Aug 2010 End of the first monitoring period 32. 01 Sep 2010 Start of the second monitoring period 33. 12-22 Apr 2010 Technical overview of the CHP unit 33. 31 Aug 2011 End of the second monitoring period

2. Monitoring information and data

2.1. Methodology for calculating the resulting GHG emission reductions or avoided emissions

2.1.1. Title, reference and version of the baseline and monitoring methodology applied to the project activity

Baseline methodology : The approved consolidated methodology ACM0008/Version 03 “Consolidated baseline methodology for coal bed methane and coal mine methane capture and use for power (electrical or motive) and heat and/or destruction by flaring” has been used to identify the baseline scenario of this JI project.


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Monitoring methodology : The monitoring methodology appropriate to this project is ACM0008 version 03 approved by CDM Executive Board on 22 December 2006. The title of the methodology: “Consolidated monitoring methodology for virgin coal bed methane and coal mine methane capture and use for power (electrical or motive) and heat and/or destruction by flaring”.

2.1.2. Revision of the monitoring plan

There are no changes of the monitoring plan in this monitoring period.

2.1.3. Request for deviation applied to this monito ring period

There is no request for deviation in this monitoring period.

2.1.4. Notification or request of approval of chang es

There is no request for approval of changes in this monitoring period.

2.1.5. Description of the monitoring system

The overall diagram of the monitoring system, together with the location of various measuring devices is presented below.

Figure 1. Diagram of the monitoring system

Methane Recovery Station

C2

Boiler room 2x1.2 MW

F2

CHP

F1

Grid

V1

Q1

V2

Coal mine

Heat supplier

C1

Mining activity

VAM

Q2


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Table 1. Control-measuring equipment registry

Denota-tion

Measured parameter Device type Serial

number Measuring

range The location JI and

ID number

Symbol Period of participation Calibration frequency

Dates of calibration

N08006

September 2008-13/12/2010

22/08/2011 until now

14/11/2008 07/10/2009 30/06/2010 02/08/2011

C1 Methane

concentration in the

captured gas

CH4 continuous concentration analyzer,

using the infrared technique G1/CH4/IR-DP-OS

Nanosens, POLAND N10091

0-100% Gas pipeline

feeding to the CHP

JI-005 P15

PCCH4

13/12/2010 – 22/08/2011

once a year

24/08/2010

C2

Non-methane hydrocarbons

concentration in the captured

gas

Stub pipe for periodic gas sampling required for

chromatographic analysis -

- - Gas pipeline

feeding to the CHP

P16 PCNMHC - -

Sampling dates: 9th Dec 2008

10th Dec 2009 8th Dec 2010

Turbine flow meter CPT-01/COMMON S.A,

POLAND P-41038 80-1600 m3/h June 2008 – 19/12/2008

29/09/2008 26/11/2008

297399

03/02/2009-21/06/2011

22/07/2011 until now

25/09/2009 13/07/2010

07/07/2011

F1 Amount of

methane sent to CHP

Thermal flow meter ST51/FCI, USA

335935

26-1200 m3/h

Gas pipeline feeding to the

CHP

JI-001 P8/B8

MMELEC/ CMMPJ,ELEC,,y

21/06/2011-22/07/2011

once a year

22/12/2010

Turbine flow meter CPT-01/COMMON S.A,

POLAND 27806 80-1200 m3/h

February 2009 – 9/11/2009

-

325634 07/07/2010-04/05/2011

16/06/2011 until now 13/05/2010 02/06/2011 F2

Amount of methane sent to

the gas boiler room

2x1.2MW Thermal flow meter ST51/FCI, USA

335935

26-1200 m3/h

Gas pipeline feeding the boiler room

JI-007 P11/B9

MMHEAT/ CMMPJ,HEAT,,y

04/05/2011-16/06/2011

once a year

22/12/2010


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V1

Additional use of electricity

caused by project activity (CHP)

Electricity meter SEA/Z.E.U.P POZYTON,

POLAND

503-0003278 0-99.999 kWh

Electrical system supply

the CHP

JI-008 P5 CONSELEC.PJ

June 2008 until now 24/11/2009

V2

Amount of electricity

generated during the project

Electricity meter C521/PAFAL, POLAND

13067831 13557836 0-99.999 kWh

Electrical system to receive

electricity from the CHP

JI-009 GENV June 2008 until now

Legalization every 8 years

13/03/2009 25/11/2009

Q1 Amount of heat

generated in the boiler room

2x1.2 MW

Heat meter MULTICAL (POWGAZ) /KAMSTRUP DENMARK

4716831 0.6-3000m3/h

System to receive heat

from the boiler room

JI-011 GENQ, BOIL June 2008 until now November 2009

Q2 Amount of heat

generated in CHP

Heat meter MULTICAL (ULTRAFLOW) /KAMSTRUP DENMARK

225224 0.6-3000m3/h System to

receive heat from the CHP

JI-010 GENQ, CHP June 2008 until now

Legalization every 5 years

December 2009


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Control-measuring equipment for monitoring constitutes part of a supervision system in accordance with the requirements of the PN-EN ISO/IEC 17025:2005 standards as well as provisions included in the Measurement Law. Control-measuring equipment for monitoring is included in the control-measuring equipment registry, which contains denotation and the location of all devices. Each device has its own file, where all important facts regarding ex. repairs, maintenance or shutdowns are stored. All monitoring equipment is a subject to periodical metrological control (calibration). Calibration frequency is defined by each calibration form, which is included in the schedule of the metrological control. To carry out periodic equipment calibrations an external company is used which possesses relevant competences. Detailed information regarding the conduct of the calibration is entered into special calibration forms, which become an annex to the monitoring procedures. Calibration forms are stored in the equipment files. Some equipment – auxiliary equipment, such as sacks to collect gas samples, which have no direct impact on the measured results are not subjects to the metrological control, but only to technical supervision. The organisation chart of the Monitoring team is presented in the following picture.

Figure 2. General organization chart of the service of the monitor ing process

Technical staff service of installation

Direct readings and recording of

the monitoring parameters (CH4, electricity, heat)

Accredited laboratory Central Mining Institute

Analyses of NMHC

Project Technical Manager Chief Power Engineering

KWK „Borynia” Managing the monitoring process at site;

Monitoring data collection and storage;

Cooperation with Project Coordinator.

Project Coordinator Central Mining Institute

Supervision of the monitoring process; Periodical calculations of GHG emission reductions and reporting activities.


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� Monitoring of gaseous components

Measurements of CMM destruction For the purpose of monitoring the emission reduction the following parameters are to be measured:

1. CMM consumed at the CHP unit (MMELEC/CMMPJ,ELEC,,y), 2. CMM supplied to the boiler house 2 x 1,2 MW (MMHEAT/CMMPJ,HEAT,,y).

The amounts of consumed methane are calculated on the basis of the coal gas volumes supplied and the average CH4 concentrations. The total volumes of coal methane gas consumed by the CHP unit and the boiler house are measured directly at each module by flow meters. Methane concentration is measured in one point (at gas engine inlet) and data obtained are used both for the CHP and the boiler house methane consumption calculations. In the table below the methane metering equipment and adequate monitoring procedures were presented.

Table 2. Monitoring equipment and adequate monitoring procedures

Measured parameter Figure

reference Data variable Measuring instrument

Uncertainty level

Monitoring procedure

Volume of coal methane gas supplied to the CHP unit

F1 VELEC/VPJ,ELEC,,y Thermal flow meter ST51FCI

1.5% Procedure

PM-1

Volume of coal methane gas supplied to the boiler house 2 x 1.2 MW

F2 VHEAT/VPJ,HEAT,,y Thermal flow meter ST51FCI

1.5% Procedure

PM-2

Methane concentration

C1 PCCH4 Infra red gas analyzer: G1/CH4/IR-DP-OS Manufacturer: Nanosens

1.0% Procedure

PM-1/ PM-2

The conceptual scheme of the measurement system used for the monitoring of CMM consumed by the CHP (MMELEC/CMMPJ,ELEC,,y) is presented in the following picture:


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Figure 3. The conceptual scheme of the measurement system

This automatic measurement system consists of three main elements:

1. Thermal flow meter ST51FCI (JI-001) 2. Infra red gas analyzer G1/CH4/IR-DP-OS Nanosens (JI-005) 3. Flowmeter monitor FP-2001D with mathematic functions and registration (JI-006)

During the gas engine operation, the flow monitor FP-2001D is receiving signals from the flowmeter ST51FCI and from the gas analyzer G1/CH4/IR-DP-OS. For each 10-min time periods the flow monitor is calculating amount of pure methane destroyed in CHP by multiplying amount of gas consumed (m3) and average CH4 concentration (%). The obtained values for the 10-min time intervals are recorded in the internal memory of the flow monitor FP-2001D. Every 1 hour the flow monitor sends information about the amount of CMM consumed to the central computer located in the CHP control room. The value recorded in the central computer is an average calculated from six measurements performed within one hour by the flow monitor FP-2001D. The same measurement system is also used for the monitoring of amounts of CMM destroyed by the boiler room 2x1.2 MW (MMHEAT/CMMPJ,HEAT,,y). However the volume of gas supplied to boiler room is monitored by other meter of ST51FCI type (JI-007) installed on the supply pipeline. For both parameters (MMELEC/CMMPJ,ELEC,,y and MMHEAT/CMMPJ,HEAT,,y) the CMM reduction data are also recorded manually on the appropriate monitoring forms (FMs). The obtained values taken from the central computer located in the CHP control room are recorded manually in the FMs once a day. The responsibility for the readings and manual records belongs to the EKOP Sp. z o. o. company. By the end of each calendar month the EKOP Sp. z o. o. hands over the filled in monitoring forms to the Project Technical Manager. The collected data are stored and archived in a central data base (office of the Project Technical Manager). The Project Technical Manager is responsible for correctness of the logged data and administration of the data base. He regularly verifies the recorded data and checks the


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stored data plausibility, errors and deviations. All inconsistencies are discussed with the service and the operation teams. Data transfer and protection: Electronic data concerning CMM destruction in CHP and in boiler room 2x1.2 MW is transferred automatically from the flowmeter monitor FP-2001D to the central computer located in the CHP control room every 1 hour. The data is recorded automatically in the memory of the computer in a separate database. The access to the database is allowed only for authorized users, i.e. Project Technical Manager and selected workers of the CHP service (EKOP Sp. z o. o.). Electronic data manipulation risk is therefore negligible small. The monitoring forms FM-1 and FM-2 being filled in manually once a day are passed on to the Project Technical Manager every month. The Project Technical Manager keeps the monitoring forms in his office and hands over their copies to the Central Mining Institute (GIG). Basing on the data from the monitoring forms GIG performs calculations of the GHG emission reduction and it prepares the periodical monitoring report (MR). Measurements of NMHC content Apart from measurements of the CMM destruction, amount of non-methane hydrocarbons (NMHC) is to be monitored. The NMHC analysis frequency is once a year. The measurement characteristics are presented in the table below:

Table 3. Measurement of NMHC content

Measured parameter

Figure reference

Data variable Measuring technique

Uncertainty level


Concentration of non-methane hydrocarbons

C2 PCNMHC

Direct sampling at pipeline and chromatographic determination.

Uncertainty level is calculated

individually for each component and it is given in analyses report (see attached)

Procedure PM-3

The CMM is sampled on the supply pipeline in the CHP room. Gas is sampled to Tedlar bag and subsequently it is sent to accredited laboratory in order to determine its composition. The scope of analysis: ethane, ethylene, propene, prophylene, acetylene. The entity responsible for the analyses is GIG. Data transfer and protection: Analysis reports are collected by Project Technical Manager and stored in his office. Results of analyses are additionally recorded manually in the monitoring form FM-3.

� Electrical measurements

For the purpose of monitoring the emission reduction the following parameters are to be measured:

1. Net electricity consumption of the CHP unit (CONSELEC,PJ), 2. Net electricity generation of the CHP unit (GENV).


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In the table below the applied electricity meters and corresponding monitoring procedures were presented:

Table 4. Electricity meters and adequate monitoring procedures

Measured parameter

Figure reference

Data variable Measuring instrument

Uncertainty level


Electricity consumed by the CHP unit

V1 CONSELEC,PJ SEA Manufacturer: Z.E.U.P POZYTON

1% Procedure

PM-4

Electricity generated in the CHP unit

V2 GENV C52 adg Manufacturer: Pafal, Poland

1% Procedure

PM-4

The both electricity meters have continuous monitoring frequency (cumulative type). Information about current indication of meters is sent every 15 minutes to a central computer located in the office of Project Technical Manager. Electricity consumption and production data is stored electronically in the memory of the central computer. Additionally for both parameters (CONSELEC,PJ and GENV), the data are recorded manually on the appropriate monitoring forms, i.e. FM-4/1 and FM-4/2 respectively. The manual recording frequency on the FMs is once a day. The responsibility for the readings and manual records belongs to the EKOP Sp. z o. o. company. By the end of each calendar month the EKOP Sp. z o. o. hands over the filled in monitoring forms to the Project Technical Manager. The collected data are stored and archived in a central data base (office of the Project Technical Manager). The Project Technical Manager is responsible for correctness of the logged data and administration of the data base. He regularly verifies the recorded data and checks the stored data plausibility, errors and deviations. All inconsistencies are discussed with the service and the operation teams. Data transfer and protection: Electronic data concerning electricity consumed and produced by CHP is transferred automatically from the appropriate meters to the central computer located in the office of Project Technical Manager. The data is recorded automatically in the memory of the computer in a separate database. The access to the database is allowed only for authorized users, i.e. Project Technical Manager and selected workers of Energy Department team of Borynia Coalmine. Electronic data manipulation risk on the level of the Energy Department is therefore negligible small. Independently of the central computer of the Energy Department, the electronic data on electricity are stored on a central server disc of the Borynia Mine (data back up). The emergency copies of all data stored in the central server disc are performed daily. The monitoring forms FM-4/1 and FM-4/2 being filled in manually once a day are passed on to the Project Technical Manager every month. The Project Technical Manager keeps the monitoring forms in his office and hands over their copies to the Central Mining Institute (GIG). Basing on the data from the monitoring forms GIG performs calculations of the GHG emission reduction and it prepares the periodical monitoring report (MR).

� C.3. Heat measurements

For the purpose of monitoring the emission reduction the following parameters are to be monitored:

1. Heat generated by the boiler house 2 x 1.2 MW (GENHEAT, boil) 2. Heat generated by the CHP unit (GENHEAT, CHP)


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In the table below the applied heat meters and corresponding monitoring procedures were presented:

Table 5. Heat meters and adequate monitoring procedures

Measured parameter

Figure reference

Data variable Measuring instrument Uncertainty

level Monitoring procedure

Heat generated by boilers 2x1.2 MW

Q1 GENHEAT, boil Multical KAMSTRUP coupled with flow meter POWGAZ

±(0.5 + ∆Θmin/∆Θ)%

Procedure PM-5

Heat generated by CHP unit

Q2 GENHEAT, CHP Multical 601 KAMSTRUP coupled with flow meter Ultraflow

±(0.5 + ∆Θmin/∆Θ)%

Procedure PM-6

The heat meters have continuous monitoring frequency (cumulative type). Information about current indication of meters is sent continuously to the central computer located in the office of Project Technical Manager. The transferred data are recorded every 1 hour. Heat production data is stored electronically in the memory of the central computer. Additionally for both parameters (GENHEAT, boil and GENHEAT, CHP), the data are recorded manually on the appropriate monitoring forms, i.e. FM-5 and FM-6 respectively. The manual recording frequency on the FMs is once a day. The responsibility for the readings and manual records belongs to the EKOP Sp. z o. o. company. By the end of each calendar month the EKOP Sp. z o. o. hands over the filled in monitoring forms to the Project Technical Manager. The collected data are stored and archived in a central data base (office of the Project Technical Manager). The Project Technical Manager is responsible for correctness of the logged data and administration of the data base. He regularly verifies the recorded data and checks the stored data plausibility, errors and deviations. All inconsistencies are discussed with the service and the operation teams. Data transfer and protection: Electronic data concerning heat produced by CHP and boiler room 2x1.2 MW is transferred automatically from the appropriate meters to the central computer located in the office of Project Technical Manager. The data is recorded automatically in the memory of the computer in a separate database. The access to the database is allowed only for authorized users, i.e. Project Technical Manager and selected workers of Energy Department team of Borynia Coalmine. Electronic data manipulation risk is therefore negligible small. The monitoring forms FM-5 and FM-6 being filled in manually once a day are passed on to the Project Technical Manager every month. The Project Technical Manager keeps the monitoring forms in his office and hands over their copies to the Central Mining Institute (GIG). Basing on the data from the monitoring forms GIG performs calculations of the GHG emission reduction and it prepares the periodical monitoring report (MR).

� C.4. Additional information.

All meters installed in the proposed project are accorded with national standards. All elements of the monitoring system are included in an equipment register which contains labelling and meter location. Each apparatus has its own card file, in which all important events concerning reparations, maintenance and excluding from the operation are noted. All the equipment used are maintained and serviced in accordance with the original manufactures instructions. Technical conditions of the particular elements of the monitoring system undergo periodical technical survey according to established plan of surveys.


18

All responsibilities related to the project monitoring plan realization belong to the Project Technical Manager (Borynia Coalmine Chief Power Engineering). He appoints the personnel in charge of monitoring tasks and supervises its work. The Project Technical Manager is also responsible for the organization of the staff trainings. General description of the staff trainings done so far is presented in Table 7.

Table 6. Description of the trainings done

No. Training scope Training date Lecturer Number of participants

1 13th March

2011 8

30th April 2011 10

• A reminder of general information about the Joint Implementation mechanism and details of the JI Project at Borynia Mine

• Quality assurance procedures and functioning of the project at Borynia Mine

20th April 2011

Project Technical Manager

Stefan Łach

2

2.2. Sources of greenhouse gas emissions

2.2.1. Purpose of the project activity and the meas ures taken to reduce greenhouse gas emissions

The project involves utilization of mine gas (methane) captured through the mine methane recovery structures, used for heat and power generation in CHP. Overview on measures taken to reduce greenhouse gas emissions:

- On-site fuel consumption due to the project activity, including transport of the gas; - Emissions from methane destruction; - Emissions from NMHC destruction; - Fugitive emissions of unburned methane.

2.2.2. Brief description of the installed technolog y and equipments

The gas engine. The core of the CHP is a gas engine, GE Jenbacher J 612 GS-E71 with the following technical features:

- Electric power: 1,819 kW; - Thermal power: 1,877 kW; - Ampere-hour efficiency: 41.3%; - Thermal efficiency: 42.7%; - Applied Power: 4,401 kW;


19

- Max. consumption of gas mixture 734 m3N/h, for pure CH4 440 m3

N/h;

The boilers. System consists of 2 boilers type HVTO100 equipped with gas burners with continuous regulation adapted to burn a mixture of varying composition. Technical parameters are as follows:

- Power burners up to 1,200 kW each; - Consumption of gas mixture 240 - 600 m3/h, including the amount of CH4 120 - 240

m3/h; - CH4 content of 40 - 60% by volume mixture; - The amount of CH4 required for proper operation of boiler is 75 m3/h.

2.2.3. Technical description of the project and sou rces of greenhouse gas emissions

The recovered methane shall be utilized in a newly constructed CHP located in BORYNIA-ZOFIÓWKA Coal Mine site. System will consist of gas engine, cooling system, control system and heat recovery unit. Extracted CMM will power the Jenbacher gas engine (J 612 GS) of 4401 kW of power input, and 1819 kW and 1877 kW of electrical and thermal output respectively. Electrical efficiency is anticipated at 41.3%, and thermal efficiency at 42.7% giving a figure of 84.0% of total system efficiency. CHP location is planned on the coal mine area approx. 800 m distance away from methane recovery station. Thus the pipeline connection needs to be constructed. Connections to switching station and to the pipeline are already provided. The Methane Recovery Station is already installed, however, it needs to be renovated as it becomes aging and probably causes several problems, especially gas engine failure as a result of leaking compressor oil into CMM pipeline. CMM is captured by methane recovery station in volume of 20 m3/min per pure CH4. The methane content in recovered CMM ranges from 30% to 70%. Proposed Jenbacher gas engine is designed to run on unprocessed CMM. Jenbacher gas engine is one of the best available gas engine in the world which can be run with low concentration of methane. A schematic for the CMM extraction and utilization is shown below:

At BORYNIA-ZOFIÓWKA Coal Mine, CMM is productively used in little degree for captive heat generation by two CMM-fired boilers (1.2 MW x 2) and the rest is released to the atmosphere. The proposed project is aimed at use of captured methane for energy production instead venting to the air. CMM will power newly constructed Jenbacher J 612 GS gas engine employed to Combined Heat and Power System (CHP) to produce 1819 kW of electrical and 1877 kW of thermal power. As the result 2,179 tonnes of CH4 will be destroyed. Additionally further emission reduction will be achieved through replacement of import fossil grid energy heat and power to date used in the BORYNIA-ZOFIÓWKA Coal Mine with in-

Methane Recovery Station

CHP

On-site demand in

Borynia Coal Mine

Gas Boiler

Room 2 x 1.2 MW

pipeline Ø 200 (800 m) Electricity 1819 kWe

Heat 1877 kWth

~7.5 m3 CH4/min

Heat


20

plant power generation. The rest of CMM continues to be released to the atmosphere as well. All electricity and heat generated by this project will be consumed within Borynia-Zofiówka Coal Mine. In addition, Borynia-Zofiówka Coal Mine will continue to purchase electricity from the Grid because net electricity generation in this project (planned value: 11,787 [MWh/yr]) is far below total demand of electricity in Borynia-Zofiówka Coalmine.

2.3. Additional greenhouse gas emissions caused by the project activity and size of these emissions

Project emissions from additional energy required f or CMM capture and use:

PEME = CONSELEC,PJ *CEFELEC Where:

PEME - Project emissions from energy use to capture and use methane (tCO2e)

CEFELEC - Carbon emissions factor of electricity used by coal mine (tCO2e/MWh) CONSELEC, PJ - Additional electricity consumption for capture and use of methane, if

any (MWh) Where:

CONSELEC, PJ = (REnd – RBeginning) * 40 40 - Electricity transformation factor specific for the measuring instrument: 200 [Amper] / 5 [Amper] = 40

Table 7. Project emissions from additional energy required for CMM capture and use

Date Amount of electricity use to capture and use methane (Data from form FM-4/1)

Carbon emissions factor of

electricity used by coal mine

Project emissions from energy use to

capture and use methane

[Month-Year]

Reading - beginning of

month RBeginning

Reading - end of month

REnd

Amount of electricity CONSELEC

[kWh]

CEFELEC [tCO 2e/MWh] PEME [tCO 2e]

09-2010 21,447.18 22,467.38 40,808.000 0.770 31.422 10-2010 22,467.38 23,402.38 37,400.000 0.770 28.798 11-2010 23,402.38 24,278.33 35,038.000 0.770 26.979 12-2010 24,278.33 25,010.56 29,289.200 0.770 22.553

TOTAL - 2010 - - 142,535 - 110 01-2011 25,010.56 25,741.40 29,233.600 0.770 22.510 02-2011 25,741.40 26,399.98 26,343.200 0.770 20.284 03-2011 26,399.98 27,220.21 32,809.200 0.770 25.263 04-2011 27,220.21 27,815.82 23,824.400 0.770 18.345 05-2011 27,815.82 28,809.68 39,754.400 0.770 30.611 06-2011 28,809.68 29,867.83 42,326.000 0.770 32.591 07-2011 29,867.83 30,657.88 31,602.000 0.770 24.334 08-2011 30,657.88 31,201.50 21,744.800 0.770 16.743

TOTAL - 2011 - - 247,638 - 191 TOTAL - - 390,173 - 300


21

2.4. Results of the GHG emission reduction or emission avoidance

2.4.1. Baseline emissions calculation

In the table below monthly volume of captured methane (in nm3 CH4) by Methane Recovery Station in 2002-2007 were presented:

Table 8. Methane consumption by boiler house, indicating thermal dem and by maximum monthly consumption in 2002-2007

Methane consumption by boiler house (in nm 3 CH4), indicating thermal demand by maximum monthly consumption in 2002-2007 Month/Year

2002 2003 2004 2005 2006 2007 January 31,200 0 113,503 144,629 120,672 125,280 February 28,900 0 110,304 132,884 83,808 110,736

March 72,700 0 123,615 141,644 117,792 113,184 April 144,800 0 53,634 98,131 102,096 116,640 May 118,500 0 112,054 71,721 122,544 108,576 June 86,600 45,600 112,667 60,333 97,488 81,792 July 41,300 85,771 81,797 66,719 55,584 84,096

August 0 72,308 35,819 104,976 85,536 82,800 September 0 68,698 28,432 84,960 100,947 -

October 18,100 140,490 119,085 106,848 130,032 - November 22,600 102,801 140,040 125,856 115,200 - December 0 109,563 166,514 102,672 122,976 -

Total 564,700 625,231 1,197,464 1,241,373 1,254,675 - In the table below the calculation of dmax was presented:


22

Table 9. The calculation of d maxk

Projection of methane consumption by the existing b oilers [m 3 CH4] Period IX X XI XII I II III IV V VI VII VIII TOTAL

Sep. 2006 - Aug. 2007 100,947 130,032 115,200 122,976 125,280 110,736 113,184 116,640 108,576 81,792 84,096 82,800 1,292,259

Sep. 2005 - Aug. 2006 84,960 106,848 125,856 102,672 120,672 83,808 117,792 102,096 122,544 97,488 55,584 85,536 1,205,856

Sep. 2004 - Aug. 2005 28,432 119,085 140,040 166,514 144,629 132,884 141,644 98,131 71,721 60,333 66,719 104,976 1,275,108

Sep. 2003 - Aug. 2004 68,698 140,490 102,801 109,563 113,503 110,304 123,615 53,634 112,054 112,667 81,797 35,819 1,164,945

Sep. 2002 - Aug. 2003 0 18,100 22,600 0 0 0 0 0 0 45,600 85,771 72,308 244,379

Average [m 3/year] 1,036,509

Average [m 3/month] 86,376

dk IX X XI XII I II III IV V VI VII VIII TOTAL Sep. 2006 - Aug. 2007 0.9374 1.2075 1.0698 1.1420 1.1634 1.0283 1.0510 1.0831 1.0082 0.7595 0.7809 0.7689 12

Sep. 2005 - Aug. 2006 0.8455 1.0633 1.2524 1.0217 1.2009 0.8340 1.1722 1.0160 1.2195 0.9701 0.5531 0.8512 12

Sep. 2004 - Aug. 2005 0.2676 1.1207 1.3179 1.5671 1.3611 1.2506 1.3330 0.9235 0.6750 0.5678 0.6279 0.9879 12

Sep. 2003 - Aug. 2004 0.7077 1.4472 1.0589 1.1286 1.1692 1.1362 1.2733 0.5525 1.1543 1.1606 0.8426 0.3690 12

Sep. 2002 - Aug. 2003 0.0000 0.8888 1.1098 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 2.2391 4.2117 3.5506 12

dmaxk 0.9374 1.4472 1.3179 1.5671 1.3611 1.2506 1.3330 1.0831 1.2195 2.2391 4.2117 3.5506 22


23

Baseline methane destruction emissions: 12

BEMD,y = (CEFCH4 + r * CEFNMHC) * ∑(THBL,y/12*1)dmaxk

k=1

Where: BEMD, y - Baseline emissions from destruction of methane in the baseline

scenario in year y (tCO2e) THBL, y - Projected annual baseline thermal demand for year y (tCH4) dk - Scalar adjustment factor for day k to reflect seasonal variations, such

that Σdk=12 dmax

k - Maximum scalar adjustment factor for day k over the 5 years prior to the start of the project activity (i.e. Σdmax

k>12) CEFCH4 - Carbon emission factor for combusted methane (2.75 tCO2e/tCH4) CEFNMHC - Carbon emission factor for combusted non methane hydrocarbons

(various. To be obtained through periodical analysis of captured methane) (tCO2eq/tNMHC)

r - Relative proportion of NMHC compared to methane With:

r = PCNMHC / PCCH4

PCCH4 - Concentration (in mass) of methane in extracted gas (%) PCNMHC - NMHC concentration (in mass) in extracted gas (%)

According to measurements performed in 2010, concentrations of NMHCs in the CMM from Borynia Mine were as follows:

No. Compound Concentration, ppm

Error, ± ppm Conc.+ Error, ppm

1 Ethan 419 205,308 624,308 2 Ethylene 0,03 0,007 0,037 3 Propane 31,5 15,432 46,932 4 Propylene 0,03 0,011 0,041 5 Acetylene 0,002 0,001 0,003

TOTAL 671,321 ppm (~0,07%) Because the total content of NMHCs in CMM did not exceed 1% by volume (taking into account the upper error limits), emissions from the NMHCs destruction was omitted in the further calculations.

*1 The use of monthly data is admitted by the methodology: “Consolidated monitoring methodology for virgin coal bed methane and coal mine methane capture and use for power (electrical or motive) and heat and/or destruction by flaring”


24

Table 10. Baseline methane destruction emissions

Date

Baseline - average monthly

consumption of methane

(from Table 9)

Maximum scalar

adjustment factor for

month k over the 5 years prior to the start of the

project (from Table 9)

Heat demand projection with d max

k

Methane used to serve

estimated thermal energy demand in the

baseline for month

Projected annual

baseline thermal

demand for month with

dmaxk

Baseline emissions

from destruction of methane

in the baseline

scenario in month / year

[Month-Year] [m 3 CH4] dmax

k [m 3 CH4] THBL [tCH 4] THBL*dmax

k [tCH 4]

BEMD [tCO 2]

09-2010 86,376 0.9374 80 968,7 57.9 54.2 149.185 10-2010 86,376 1.4472 125 000,9 57.9 83.8 230.314 11-2010 86,376 1.3179 113 835,7 57.9 76.3 209.742 12-2010 86,376 1.5671 135 355,8 57.9 90.7 249.393

TOTAL - 2010 345,503 - 455 161 - 305 839

01-2011 86,376 1.3611 117 566,0 57.9 78.8 216.615 02-2011 86,376 1.2506 108 018,7 57.9 72.4 199.024 03-2011 86,376 1.3330 115 139,5 57.9 77.1 212.145 04-2011 86,376 1.0831 93 555,9 57.9 62.7 172.377 05-2011 86,376 1.2195 105 334,3 57.9 70.6 194.078 06-2011 86,376 2.2391 193 407,9 57.9 129.6 356.354 07-2011 86,376 4.2117 363 789,2 57.9 243.7 670.282 08-2011 86,376 3.5506 306 687,2 57.9 205.5 565.071

TOTAL - 2011 691,006 - 1 403 499 - 940 2,586

TOTAL 1 036 509 - 1 858 660 - 1,245 3,425 Baseline methane release:

12

BEMRy = GWPCH4*[(CMMPJ,ELEC,,y+ CMMPJ,HEAT,,y ) -∑(THBL,y/12)dmaxk]

k=1

Where:

BEMR, y - Baseline emissions from release of methane into the atmosphere in year y that is avoided by the project activity (tCO2e)

THBL, y - Projected annual baseline thermal demand for year y (tCH4) dk - Scalar adjustment factor for day k to reflect seasonal variations, such that Σdk=12 dmax

k - Maximum scalar adjustment factor for day k over the 5 years prior to the start of the project activity (i.e. Σdmax

k >12) CMMELEC, y -CMM that would have been captured, used and destroyed by use

Generation in the baseline scenario in year y

CMMHEAT, y -CMM that would have been captured, used and destroyed by use heat Generation in the baseline scenario in year y

GWPCH4 - Global warming potential of methane (tCO2e/tCH4 = 21)


25

Table 11. Baseline methane release

Date

Global warming

potential of methane

Methane measured sent to

power plant (CHP) and heat

plant (gas boiler)

Projected annual baseline thermal demand for month with

dmaxk

Baseline emissions from release of methane into

the atmosphere in month that is avoided by the

project activity

[Month-Year] GWPCH4

[tCO 2e/tCH4]

TOTAL: MMELEC + MMHEAT

[tCH 4]

THBL*dmaxk

[tCH 4] [tCH 4] BEMR [tCO 2]

09-2010 21.0 298.5 54.2 244.3 5,129.334 10-2010 21.0 351.3 83.8 267.6 5,619.083 11-2010 21.0 363.1 76.3 286.8 6,023.747 12-2010 21.0 314.7 90.7 224.0 4,704.516

TOTAL - 2010 - 1,328 305 - - 01-2011 21.0 307.0 78.8 228.3 4,793.603 02-2011 21.0 267.3 72.4 195.0 4,094.464 03-2011 21.0 310.4 77.1 233.2 4,897.694 04-2011 21.0 165.2 62.7 102.5 2,153.078 05-2011 21.0 203.2 70.6 132.6 2,785.188 06-2011 21.0 198.1 129.6 68.5 1,438.053 07-2011 21.0 131.0 243.7 -112.7 -2,367.535 08-2011 21.0 99.6 205.5 -105.9 -2,223.259

TOTAL - 2011 - 1,682 940 - - TOTAL - 3,009 1,245 - -

Baseline Emission:

BEy = BEMD,y + BEMR,y

Where:

BEy - Baseline emissions in year y (tCO2e) BEMD,y - Baseline emissions from destruction of methane in the baseline scenario in

year y (tCO2e) BEMR,y - Baseline emissions from release of methane into the atmosphere in year y

that is avoided by the project activity (tCO2e)

Table 12. Baseline Emission

Date

Baseline emissions from destruction of

methane in the baseline scenario in month / year

Baseline emissions from release of methane into the atmosphere

in month / year that is avoided by the project activity

Baseline emissions in month /

year [Month-Year] BE MD [tCO 2] BEMR [tCO 2] BE [tCO 2]

09-2010 149.185 5,129.334 5,278.519 10-2010 230.314 5,619.083 5,849.397 11-2010 209.742 6,023.747 6,233.489 12-2010 249.393 4,704.516 4,953.909

TOTAL - 2010 839 - - 01-2011 216.615 4,793.603 5,010.218 02-2011 199.024 4,094.464 4,293.488 03-2011 212.145 4,897.694 5,109.839 04-2011 172.377 2,153.078 2,325.455 05-2011 194.078 2,785.188 2,979.266 06-2011 356.354 1,438.053 1,794.407 07-2011 670.282 -2,367.535 -1,697.253 08-2011 565.071 -2,223.259 -1,658.188

TOTAL - 2011 2,586 - - TOTAL 3,425 - -


26

2.4.2. Project emissions calculation

Methane destroyed through power generation

MDELEC = MMELEC * EffELEC Where:

MDELEC - Methane destroyed through power generation (tCH4) MMELEC - Methane measured sent to power plant (tCH4) EffELEC - Efficiency of methane destruction/oxidation in power plant (99.5% from IPCC)

Table 13. Methane destroyed through power generatio n

Date Amount of methane sent to power plant (CHP): Data from form FM-1

Specific gravity of methane

Methane measured sent to power plant (CHP)

Efficiency of methane

destruction/oxidation in power

plant

Methane destroyed through power

generation

[Month-Year]

Reading - beginning of month [Nm 3CH4]


[Nm 3CH4]

Amount of methane [Nm 3CH4]

dCH4 [t/m3]

Turbine flowmeter:

MMELEC [tCH 4]

Emergency procedure

FM-4/2: MMELEC [tCH 4]

TOTAL: MMELEC

[tCH 4] EffELEC [%] MDELEC

[tCH 4]

09-2010 3,567,104.00 3,881,246.00 314,142.00 0.00067 210.475 0.000 210.475 99.50% 209.423 10-2010 3,881,246.00 4,238,454.00 357,208.00 0.00067 239.329 0.000 239.329 99.50% 238.132 11-2010 4,238,454.00 4,596,991.00 358,537.00 0.00067 240.220 0.000 240.220 99.50% 239.019 12-2010 4,596,991.00 4,929,989.00 332,998.00 0.00067 223.109 0.000 223.109 99.50% 221.993

TOTAL - 2010 - - 1,362,885 - 913 0 913 - 909 01-2011 4,929,989.00 5,249,958.00 319,969.00 0.00067 214.379 0.000 214.379 99.50% 213.307 02-2011 5,249,958.00 5,523,892.00 273,934.00 0.00067 183.536 0.000 183.536 99.50% 182.618 03-2011 5,523,892.00 5,846,455.00 322,563.00 0.00067 216.117 0.000 216.117 99.50% 215.036 04-2011 5,846,455.00 6,010,065.00 163,610.00 0.00067 109.619 0.000 109.619 99.50% 109.071 05-2011 6,010,065.00 6,243,136.00 233,071.00 0.00067 156.158 0.000 156.158 99.50% 155.377 06-2011 6,243,136.00 6,517,104.00 273,968.00 0.00067 183.559 0.000 183.559 99.50% 182.641 07-2011 6,517,104.00 6,695,617.00 178,513.00 0.00067 119.604 0.000 119.604 99.50% 119.006 08-2011 6,695,617.00 6,799,239.00 103,622.00 0.00067 69.427 0.000 69.427 99.50% 69.080

TOTAL - 2011 - - 1,869,250 - 1,252 0 1,252 - 1,246 TOTAL - - 3,232,135 - 2,166 0 2,166 - 2,155


27

Methane destroyed through heat generation

MDHEAT = MMHEAT * EffHEAT Where:

MDHEAT - Methane destroyed through heat generation (tCH4) MMHEAT - Methane measured sent to heat plant (tCH4) EffHEAT - Efficiency of methane destruction/oxidation in heat plant (taken as 99.5% from IPCC)

Table 14. Methane destroyed through heat generation

Date Amount of methane sent to the heat

plant (gas boiler room): Data from form FM-2

Specific gravity of methane

Methane measured sent to heat plant (gas boiler)


destruction/oxidation in heat plant (boiler

house)

Methane destroyed

through heat generation

[Month-Year]

Reading - beginning of

month [Nm 3CH4]


[Nm 3CH4]

Amount of methane [Nm 3CH4]

dCH4 [t/m3]

Turbine flowmeter:

MMHEAT [tCH4]

Emergency procedure

FM-6: MMHEAT [tCH 4]

TOTAL: MMHEAT [tCH 4]

EffHEAT [%] MDHEAT [tCH 4]

09-2010 695,724.00 827,109.00 131,385.00 0.00067 88.028 0.000 88.028 99.50% 87.588 10-2010 827,109.00 994,269.00 167,160.00 0.00067 111.997 0.000 111.997 99.50% 111.437 11-2010 994,269.00 1,177,694.00 183,425.00 0.00067 122.895 0.000 122.895 99.50% 122.281 12-2010 1,177,694.00 1,314,417.00 136,723.00 0.00067 91.604 0.000 91.604 99.50% 91.146

TOTAL - 2010 - - 618,693 - 415 0 415 - 412 01-2011 1,314,417.00 1,452,711.00 138,294.00 0.00067 92.657 0.000 92.657 99.50% 92.194 02-2011 1,452,711.00 1,577,802.00 125,091.00 0.00067 83.811 0.000 83.811 99.50% 83.392 03-2011 1,577,802.00 1,718,474.00 140,672.00 0.00067 94.250 0.000 94.250 99.50% 93.779 04-2011 1,718,474.00 1,801,445.00 82,971.00 0.00067 55.591 0.000 55.591 99.50% 55.313 05-2011 1,801,445.00 1,871,660.00 70,215.00 0.00067 47.044 0.000 47.044 99.50% 46.809 06-2011 1,871,660.00 1,893,307.00 21,647.00 0.00067 14.503 0.000 14.503 99.50% 14.430 07-2011 1,893,307.00 1,910,315.00 17,008.00 0.00067 11.395 0.000 11.395 99.50% 11.338 08-2011 1,910,315.00 1,955,366.00 45,051.00 0.00067 30.184 0.000 30.184 99.50% 30.033

TOTAL - 2011 - - 640,949 - 429 0 429 - 427 TOTAL - - 1,259,642 - 844 0 844 - 840


28

Project emissions from methane destroyed:

PEMD = (MDELEC + MDHEAT)*(CEFCH4 +r*CEFNMHC)

With: r = PCNMHC / PCCH4

Where: PEMD - Project emissions from CMM/destroyed (tCO2e) MDELEC - Methane destroyed through power generation (tCH4) MDHEAT - Methane destroyed through heat generation (tCH4) CEFCH4 - Carbon emission factor for combusted methane (2.75 tCO2e/tCH4) CEFNMHC - Carbon emission factor for combusted non methane hydrocarbons

(the concentration varies and, therefore, to be obtained through periodical analysis of captured methane) (tCO2eq/tNMHC)

r - Relative proportion of NMHC compared to methane PCCH4 - Concentration (in mass) of methane in extracted gas (%) PCNMHC - NMHC concentration (in mass) in extracted gas (%)

Because NMHC not exceeds 1% by volume of extracted CMM, emissions from NMHC destruction was skipped.

Table 15. Project emissions from methane destroyed

Date

Methane destroyed

through power generation

Methane destroyed

through heat generation

Carbon emission factor for

combusted methane

Carbon emission factor for

combusted non methane hydrocarbons

Project emissions from CMM/destroyed

[Month-Year] MD ELEC [tCH 4] MDHEAT [tCH 4] CEFCH4

[tCO 2e/tCH4] CEFNMHC

[tCO 2e/tNMHC] PEMD [tCO 2e]

09-2010 209.423 87.588 2.75 2.93 816.780 10-2010 238.132 111.437 2.75 2.93 961.315 11-2010 239.019 122.281 2.75 2.93 993.575 12-2010 221.993 91.146 2.75 2.93 861.132

TOTAL - 2010 909 412 - - 3,633 01-2011 213.307 92.194 2.75 2.93 840.128 02-2011 182.618 83.392 2.75 2.93 731.528 03-2011 215.036 93.779 2.75 2.93 849.241 04-2011 109.071 55.313 2.75 2.93 452.056 05-2011 155.377 46.809 2.75 2.93 556.012 06-2011 182.641 14.430 2.75 2.93 541.945 07-2011 119.006 11.338 2.75 2.93 358.446 08-2011 69.080 30.033 2.75 2.93 272.561

TOTAL - 2011 1,246 427 - - 4,602 TOTAL 2,155 840 - - 8,235

Un-combusted methane from flaring and end uses:

PEUM= GWPCH4 * [ MMELEC*(1-EffELEC)+ MMHEAT * (1-EffHEAT)] Where:

PEUM - Project emissions from un-combusted methane (tCO2e) GWPCH4 - Global warming potential of methane (21 tCO2e/tCH4)


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MMELEC - Methane measured sent to power plant (tCH4) EffELEC - Efficiency of methane destruction/oxidation in CHP (taken as 99.5%

from IPCC) MMHEAT - Methane measured sent to heat plant (tCH4) EffHEAT - Efficiency of methane destruction/oxidation in heat plant (taken as

99.5% from IPCC)

Table 16. Un-combusted methane from flaring and end uses

Date

Methane measured

sent to power plant

(CHP)


destruction/ oxidation in power plant

Methane measured sent

to heat plant (gas boiler)


destruction/ oxidation in heat plant

(boiler house)

Global warming


Project emissions from un-

combusted methane

[Month-Year] TOTAL: MMELEC [tCH 4]

EffELEC [%] TOTAL: MMHEAT [tCH4]

EffHEAT [%] GWPCH4

[tCO 2e/tCH4] PEUM

[tCO 2e] 09-2010 210.475 99.50% 88.028 99.50% 21.0 31.343 10-2010 239.329 99.50% 111.997 99.50% 21.0 36.889 11-2010 240.220 99.50% 122.895 99.50% 21.0 38.127 12-2010 223.109 99.50% 91.604 99.50% 21.0 33.045

TOTAL - 2010 913 - 415 - - 139 01-2011 214.379 99.50% 92.657 99.50% 21.0 32.239 02-2011 183.536 99.50% 83.811 99.50% 21.0 28.071 03-2011 216.117 99.50% 94.250 99.50% 21.0 32.589 04-2011 109.619 99.50% 55.591 99.50% 21.0 17.347 05-2011 156.158 99.50% 47.044 99.50% 21.0 21.336 06-2011 183.559 99.50% 14.503 99.50% 21.0 20.797 07-2011 119.604 99.50% 11.395 99.50% 21.0 13.755 08-2011 69.427 99.50% 30.184 99.50% 21.0 10.459

TOTAL - 2011 1,252 - 429 - - 177 TOTAL 2,166 - 844 - - 316

Project Emissions:

PEy = PEME + PEMD+PEMU Where:

PEy - Project emissions in year y (tCO2e) PEME - Project emissions from energy use to capture and use methane (tCO2e) PEMD - Project emissions from methane destroyed (tCO2e) PEUM - Project emissions from un-combusted methane (tCO2e)

Table 17. Project Emissions

Date Project emissions

from CMM/destroyed

Project emissions from un-combusted

methane



Estimated project

emissions

[Month-Year] PE MD [tCO 2e] PEUM [tCO 2e] PEME [tCO 2e] PE [tCO 2e] 09-2010 816.780 31.343 31.422 879.545 10-2010 961.315 36.889 28.798 1,027.002 11-2010 993.575 38.127 26.979 1,058.681 12-2010 861.132 33.045 22.553 916.730

TOTAL - 2010 3,633 139 110 3,882 01-2011 840.128 32.239 22.510 894.877 02-2011 731.528 28.071 20.284 779.883 03-2011 849.241 32.589 25.263 907.093


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Date Project emissions

from CMM/destroyed


methane



Estimated project

emissions

[Month-Year] PE MD [tCO 2e] PEUM [tCO 2e] PEME [tCO 2e] PE [tCO 2e] 04-2011 452.056 17.347 18.345 487.748 05-2011 556.012 21.336 30.611 607.959 06-2011 541.945 20.797 32.591 595.333 07-2011 358.446 13.755 24.334 396.535 08-2011 272.561 10.459 16.743 299.763

TOTAL - 2011 4,602 177 191 4,969 TOTAL 8,235 316 300 8,851

2.4.3. Leakage calculation

No leakage effects need to be accounted for under this proposed project.

3. Source data used to calculate the size of reduct ions or avoided emissions of greenhouse gases

3.1. Data and parameters used to calculate baseline emissions

Relevant data necessary for determining the baseline of anthropogenic emissions of greenhouse gases by sources within the project boundary, and how such data will be collected and archived:


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Table 18. Data and parameters used to calculate bas eline emissions

ID number Data variable Source of data Data unit

Measured (m),

calculated (c),

estimated (e)

Recording frequency

Proportion of data to be monitored

How will the data be

archived? (electronic/

paper)

Comment

Overall

Bl BEy

Baseline emissions in year y

tCO2 c yearly 100% electronic

(Archived data to be kept for

Crediting period +2 yrs)

B2 BEMD,y

Baseline emissions from destruction of

methane in the baseline scenario in

year y

tCO2 e Estimated ex-

ante 100% electronic (Crediting period

+2 yrs)

B3 BEMR,y

Baseline emissions from release of

methane into the atmosphere in year y that is avoided by the project activity

tCO2 c yearly 100% electronic (Crediting period

+2 yrs)

Methane destruction due to thermal demand in baseli ne

B4 CMMBli,y

CMM that would have been

captured, used and destroyed by

thermal demand in the baseline

scenario in year y

tCH4 e Estimated ex-ante at start of

project 100% electronic

(Archived data to be kept for


B5 THBL,ｙ

Projected annual baseline

CMM demand for

thermal energy uses

tCH4 e Ex ante 100% electronic

Estimated by procedure

defined in the corresponding

baseline methodology

(Crediting period +2 yrs)


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Measured (m),

calculated (c),

estimated (e)

Recording frequency




paper)

Comment

B6 CEFCH4

Carbon emission

factor for methane tCO2e/tCH4 tCO2e/tCH4 =2.75

B7 dk

max

Scalar adjustment factor for

month k, based on the seasonal load shape

(Σ dkmax > 12)

c Ex ante 100% electronic (Crediting period

+2 yrs)

Baseline emissions from methane released into the a tmosphere

B8 CMMPJ,ELEC,,y

Pre-mining CMM captured, sent to and destroyed by

use power Generation in the project activity in

year y

tCH4 m Hourly 100% electronic (Crediting period +2 yrs)

B9 CMMPJ,HEAT,,y

Pre-mining CMM captured, sent to and destroyed by

use Heat Generation in the project activity in

year y

tCH4 m Hourly 100% electronic (Crediting period +2 yrs)

B10 GWPCH4

Global warming


tCO2e/tCH4 e Ex ante 21 tCO2e/tCH4

B11 CEFCH4

Carbon emission factor for combusted

methane tCO2e/tCH4 e Ex ante 2.75 tCO2e/tCH4


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3.2. Data and parameters used to calculate project emissions

Data to be collected in order to monitor emissions from the project, and how these data will be archived:

Table 19. Data and parameters used to calculate pro ject emissions


Measured (m), calculated (c), estimated (e)

Recording frequency




paper)

Comment

Overall

P1 PEy

Project emissions in yearly y tCO2e c monthly 100% electronic (Archived data to be kept for


P2 PEME



tCO2e c monthly 100% electronic (Crediting period +2 yrs)

P3 PEMD

Project emissions from methane

destroyed tCO2e c monthly 100% electronic (Crediting period +2 yrs)

P4 PEUM


methane tCO2e c monthly 100% electronic (Crediting period +2 yrs)

Combustion emissions from additional energy require d for CMM capture and use

P5 CONSELEC.PJ Additional electricity

consumption by project

MWh m Hourly 100% electronic

The sources of additional electricity consumption

include CHP and Methane Recovery Station

(Archived data to be kept for Crediting period +2 yrs)

P6 CEFELEC PJ Carbon emission

factor of CONSELEC

PJ tCO2/ MWh c Ex ante 100% electronic

The calculation is described in Annex 2

(Crediting period +2 yrs) CEFELEC = 0.770 t CO2e/MWh


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Recording frequency




paper)

Comment

Combustion emissions from use of captured methane

P7 MDELEC Methane destroyed

by CHP tCH4 c Calculated monthly 100% electronic (Crediting period +2 yrs)

P8 MMELEC Methane sent to

CHP tCH4 m Continuous 100% electronic

Flow meters will record gas volumes, pressure and temperature. Density of methane under normal

conditions of temperature and pressure is 0.67kg/m3(2006

IPCC Guideline) (Crediting period +2 yrs)

P9 EffELEC


destruction/oxidation in CHP

e Ex ante Set at 99.5% (IPCC)

P10 MDHEAT Methane destroyed by heat generation tCH4 c

Calculated monthly 100% electronic (Crediting period +2 yrs)

P11 MMHEAT Methane sent to the existing boiler tCH4 m Continuous 100% electronic

Flow meters will record gas volumes, pressure and temperature. Density of methane under normal

conditions of temperature and pressure is 0.67kg/m3 (2006 IPCC Guideline)

(Crediting period +2 yrs)

P12 EffHEAT


destruction/oxidation in heat plant

- e Ex ant Set at 99.5%(IPCC)

P13 CEFCH4 Carbon emission

factor for CH4 Constant value:

tCO2e / tCH4= 2.75

P14 CEFNMHC

Carbon emission factor for combusted

non methane hydrocarbons

(various)

To be obtained through periodical analysis of the fractional composition of

captured


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Recording frequency




paper)

Comment

P15 PCCH4

Concentration methane in

extracted gas

%

m (concentration, optical and

calorific) Hourly 100% electronic

Average of 6 measurements during one hour (Crediting

period +2 yrs)

P16 PCNMHC NMHC

concentration in coal mine gas

% m (concentration,

optical and calorific)

Annually 100%

Used to check if more than 1% of emission and to

calculater (Crediting period +2 yrs)

To be analysed under the responsibility of the GIG

P17 r Relative proportion of NMHC compared

to methane % c Annually 100% To be analysed under the

responsibility of the GIG

Un-combusted methane from end uses

P18 GWPcH4 Global warming

potential of methane e Ex ante

Set at 21

P19 MMELEC Methane sent to

CHP tCH4 m Hourly 100% electronic

Flow meters will record gas volumes, pressure and

temperature (Archived data to be kept for


P20 EffELEC


destruction/oxidation in CHP

e Ex ante Set at 99.5% (IPCC)

P21 MMHEAT Methane sent to the existing boilers tCH4 m

Hourly 100% electronic

Flow meters will record gas volumes, pressure and

temperature. (Crediting period +2 yrs)

P22 EffHEAT


destruction/oxidation in heat plant

- e Ex ante Set at 99.5%(IPCC)


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3.3. Data and parameters used to calculate leakage emissions

There are no calculated leakage emissions.

3.4. Other relevant data and parameters

Does not refer.

4. The number of emission reduction units (ERUs) achieved in the reporting period

4.1. Emission reductions calculation

The emission reduction ERy by the project activity during a given year y is the difference between the baseline emissions (BEy) and project emissions (PEy), as follows:

ER y = BE y - PE y Where:

ERy - Emissions reductions of the project activity during the year y (tCO2e) BE,y - Baseline emissions during the year y (tCO2e) PEy - Project emissions during the year y (tCO2e)

Table 20. Emission reductions calculation – year 2010

Date Estimated project emissions

Baseline emissions in month

Emission reduction units

[Day-Month-Year] PE [tCO 2e] BE [tCO 2] ER [tCO 2e] 09-2010 879.545 5,278.519 4,398.974

10-2010 1,027.002 5,849.397 4,822.395

11-2010 1,058.681 6,233.489 5,174.808

12-2010 916.730 4,953.909 4,037.179

TOTAL 2010: (01.09. ÷ 31.12.2010) 3,882 - 18,433

Table 21. Emission reductions calculation – year 2011

Date Estimated project emissions

Baseline emissions in month

Emission reduction units

[Day-Month-Year] PE [tCO2e] BE [tCO2] ER [tCO2e]

01-2011 894.877 5,010.218 4,115.341

02-2011 779.883 4,293.488 3,513.605

03-2011 907.093 5,109.839 4,202.746

04-2011 487.748 2,325.455 1,837.707

05-2011 607.959 2,979.266 2,371.307

06-2011 595.333 1,794.407 1,199.074


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07-2011 396.535 -1,697.253 0.000

08-2011 299.763 -1,658.188 0.000

TOTAL 2011 (01.01 ÷ 31.08.2011) 4,969 - 17,240

4.2. Comparison of actual emission reductions with estimates in the registered CDM-PDD

Emission reduction units [tCO 2e] Year

Calculated in PDD Registered Monitoring Period

2008 33,971 8,105 (31.03÷31.12)

2009 45,294 13,619

21,645 (01.01÷31.08)

First Monitoring

Period

2010 45,294 18,433 (01.09÷31.12)

2011 45,294 17,240 (01.01÷31.08)

Second Monitoring

Period (Current)

4.3. Remarks on difference from estimated value

The differences between the estimated values and the really measured emission reductions resulted from the following reasons:

• Releasing of methane form the coal seams was much lesser from the forecasted amounts due to a significant decrease in coal production by Borynia-Zofiówka coalmine.

• In April 2011 maintenance works were carried out at the CHP unit (11 days out of operation)

Project title: Coal Mine Methane Capture and Utilization ... Periodical Monitoring... · The Second...

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