Monitoring report form
(Version 0 3. 2)

| Title of the project activity | Afam Combined Cycle Gas Turbine Power Project |
| --- | --- |
| Reference number of the project activity | 5645 |
| Version number of the monitoring report | 01 |
| Completion date of the monitoring report | 16/07/2014 |
| Registration date of the project activity | 29/10/2012 |
| Monitoring period number and duration of this monitoring period | 01/11/2012-31/10/2013 |
| Project participant(s) | Nigerian National Petroleum Corporation(NNPC) |
| Shell Nigeria(a subsidiary of Royal Dutch/Shell plc) |  |
| Elf Petroleum Nigeria Limited(EPNL,a subsidiary of TOTAL S A) |  |
| Agip(a subsidiary of ENI SpA) |  |
| Host Party(ies) | Federal Republic of Nigeria |
| Sectoral scope(s)和 applied methodology(ies) | Sectoral Scope 1AM0029 / Version 03“Baseline Methodology for Grid Connected Electricity Generation Plants using Natural Gas”. |
| Estimated amount of GHG emission reductions or net anthropogenic GHG removals by sinks for this monitoring period in the registered PDD | 550,234 tCO2e |
| Actual GHG emission reductions or net anthropogenic GHG removals by sinks achieved in this monitoring period | 671,550 tCO2e |
| Actual GHG emission reductions or net anthropogenic GHG removals by sinks achieved during the period up to 31 December 2012(if applicable) | 131,292 tCO2e |
| Actual GHG emission reductions or net anthropogenic GHG removals by sinks achieved during the period from 1 January 2013 onwards (if applicable). | 540,257 tCO2e |

* * *

| Date (s) | Activities |
| --- | --- |
| 29/10/2012 | Registration of the project activity under the CDM by the UNFCCC Secretariat |
| 01/11/2012 | Starting date for crediting |

* * *

o o
The physical location for the project is at geographical coordinates: 04 47’56”N and 07 00’07”E

04^{\\circ}4756{\\mathsf{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 if the Party involved wishes to be considered as project participant (Yes/No) |
| --- | --- | --- |
| Federal Republic of Nigeria (host) | Nigerian National Petroleum Corporation(NNPC) |  |
| Shell Nigeria(a subsidiary of Royal Dutch/Shell plc) |  |  |
| Elf Petroleum Nigeria Limited(EPNL,a subsidiary of TOTAL S A) |  |  |
| Agip(a subsidiary of ENI SpA) | No |  |

A.4. Reference of applied methodology

Approved methodology:

The methodology applied for this project activity is AM0029 “Baseline Methodology for Grid Connected
Electricity Generation Plants using Natural Gas” (Version 03). Please see Section B.6.1 of the registered
PDD for further explanation of how the baseline and monitoring methodology AM0029 (Version 03) shall be
applied for monitoring of the CDM project activity.

Tools:

As per the applied methodology, the following specific tools have been applied:

• Tool to calculate the emission factor for an electricity system (version 2.2.1)

A.5. Crediting period of project activity

• Tool for the demonstration and assessment of additionality (version 6.0)

The crediting period is fixed type at ten years (120 months) from the beginning of project operations The
start date is 01 November 2012. The length of the crediting period is 01/11/2012 – 31/10/2022.

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# F-CDM-MR

**SECTION B. Implementation of project activity**

**B.1. Description of implemented registered project activity** **>>** **Description of the installed technology, technical processes and equipment:** The combustor is fired with natural gas and produces hot, high pressure, low NOx gases, which expand in the gas turbine. The gas turbine drives the generators, the thermal energy contained in the high temperature exit gases of the gas turbine is recovered in the heat recovery steam generator (HRSG), which is designed to maximize the heat recovery of gases and allows a minimum stack temperature of the exhaust gases. The steam generated from the HRSG is introduced in the steam turbine and then expands to drive the generator.
_**Figure 1: Afam VI Facility Schematic Design also showing the monitoring points**_

## (Source: Registered PDD)

# Version 03.2 Page 4 of 15

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B.2. Post registration changes

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

B.2.2. Corrections

No corrections to project information or parameters fixed at validation have been submitted with this
monitoring report.

No changes to the project design of the project activity have been submitted with this monitoring report.

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B.2.6. Types of changes specific to afforestation or reforestation project activity

Not applicable

SECTION C. Description of monitoring system

Schematic of the CDM monitoring points

The monitoring plan applied for the CDM project activity is as described in Section B.7 and Annex 4 of the
registered PDD, as available on the UNFCCC website. As part of the CDM monitoring preparations, the
monitoring procedures presented in the PDD have been developed in more detail to reflect the physical
infrastructure installed – however, all the monitoring points’ variables are similar to that in the PDD.
Monitoring procedures are maintained in the SPDC Plant Procedures manual which is updated periodically
and maintained at the site. It will be made available to the DOE.

Parameters monitored:
The monitoring methodology requires the following parameters to be monitored during the crediting period:

The monitoring methodology requires the following parameters to be monitored during the crediting period:
For project emissions:

2. Net Calorific Value(s) of the fuel used in the project activity;

3. Annual fuel(s) consumption in project activity;


Baseline emissions will be monitored as per the “Tool to calculate emission factor for an electricity system”,
as applicable. Therefore, according to Option 3 used in the choice of baseline emissions factor, EFBL,
parameters EGPJ,yand COEFBLare been monitored.

E F\_{B L}

3. Fuel emission factors for fuel used in the project activity.

4. Fuel emission factors for fuel used in the project activity.


\ E E F\_{B L}

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The key roles and CDM related responsibilities of staff at the Afam VI power plant are the following:

a) Collection of data, QA, reporting and storage of all primary data
b) Periodic maintenance, inspection and calibration of all measurement equipment, including control of

b) Periodic maintenance, inspection and calibration of all measurement equipment, including control of
meter accuracy and software configurations (e.g. flow computers)

In essence, the key CDM roles of each of three organizational units are:

• Gas Volumes: Responsible for all primary monitoring data related to volumes and assuring that all
equipment is maintained within the criteria in the PDD monitoring plan and the procedure’s manual.

• Gas Composition: Ensuring gas compositions comply with the standards required by the plant and

• Gas Composition: Ensuring gas compositions comply with the standards required by the plant and
also meeting the CDM monitoring requirements. Also ensuring that the Gas chromatograph is
calibrated at the required frequency and standards
• Electricity Generated: Responsible for all primary monitoring data related to electricity generation and

All data will be recorded in a purpose built MS Excel spreadsheet. Data will be stored on SPDCs’ computer
server and backed up regularly. This is achieved periodically in a secure and reliable storage for up to two
years after the end of the crediting period. Hard copies are kept for a one year period or until electronic
copies are available. For data assurance and quality control of primary data, procedures and all relevant
CDM information are maintained in a specified site in the gas plant administration building in the office of the
CDM Focal Point. The information is kept in structured folders and includes: procedures, manuals and
standards for the meters, certifications, and other relevant information. This serves as the documental control
point.

• Electricity Generated: Responsible for all primary monitoring data related to electricity generation and
assuring that all equipment is maintained within the criteria in the PDD monitoring plan and the
procedure’s manual.

SECTION D. Data and parameters

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* * *

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: | OXIDf |
| --- | --- |
| Unit: | - |
| Description: | Oxidation factor of natural gas used in the calculation of project emission |
| Source of data: | 2006 IPCC Guidelines for National Greenhouse Gas Inventories default factor for stationary combustion sources. |
| Value(s) applied: | 1 |
| Purpose of data: | Used for calculating CO2 emission coefficient for PE |
| Additional comment: | None |

\\mathsf{O X l l\_{t}}

\\mathrm{C O\_{2}}

| Data/Parameter: | EFBLCO2,y |
| --- | --- |
| Unit: | tCO2/MWh |
| Description: | Baseline CO2 emissions factor |
| Source of data: | Calculated based on the fuel coefficient and the energy efficiency of the technology,as estimated in the baseline scenario analysis. |
| Value(s) applied): | 0.511(see section B.6.1) |
| Purpose of data: | Calculation of baseline emissions. |
| Additional comment: | None |

\ {sf E E}\_{\\tt B L,C O2,v}

t C O\_{2}/M N N

\\mathrm{C O\_{2}}

| Data/Parameter: | $\\Pi\_{BL}$ |
| --- | --- |
| Unit: | % |
| Description: | Energy efficiency of the technology |
| Source of data: | Conservative default efficiency factor for new gas-fired OCGT units built after 2000, as contained in Annex I of the “Tool to calculate the emission factor of electricity system” v2.2.1 |
| Value(s) applied: | 39.5 |
| Purpose of data: | For calculating baseline CO2 emission factor for baseline emissions |
| Additional comment: | None |

%

| Data/Parameter: | COEFBL |
| --- | --- |
| Unit: | tCO2e/GJ |
| Description: | Fuel emission coefficient |
| Source of data: | IPCC default emission factor for natural gas. |
| Value(s) applied: | 0.0561 |
| Purpose of data: | For calculating baseline emission |
| Additional comment: | None |

{\\mathrm O\_{2}}

\\mathsf{C O E F}\_{\\mathsf{B L}}

| Data/Parameter: | FCf,y |
| --- | --- |
| Unit: | m3 |

|  |
| --- |

m^{3}

Version 03.2

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| Description: | Annual quantity of fuel (natural gas) consumed in project activity |
| --- | --- |
| Measured/Calculated/Default: | Continuous metering of gas supply both at supplier (Okoloma gas plant)和 project end for cross verification and measured in standard cubic meters(m3) |
| Source of data: | Fuel(natural gas)flow meter reading at Afam plan gas reception facilities. |
| Value(s)of monitored parameter: | 643,488,591 |
| Monitoring equipment: | Elster Instromet2000 |
| Measuring/Reading/Recording frequency: | Continuous |
| Calculation method(if applicable): | Not applicable |
| QA/QC procedures: | Natural gas supply metering(Elster Instromet2000)to the project will be subject to regular(in accordance with stipulation of the meter supplier)maintenance and testing to ensure accuracy. |
| Purpose of data: | For calculating project emission |
| Additional comment: | None |
|  |  |
| Data/Parameter: | FCf1,2,y |
| Unit: | m3 |
| Description: | Annual quantity of fuel(natural gas)consumed in gas turbine#11 |
| Measured/Calculated/Default: | Daily meter reading |
| Source of data: | Fuel(natural gas)flow meter reading at turbine#13inlet(SM R1-X-KG1600 Elster Instromet meter located at point4infigureA4.1) |
| Value(s)of monitored parameter: | 221,783,455 |
| Monitoring equipment: | SMR1-X-KG1600 Elster Instromet meter. |
| Measuring/Reading/Recording frequency: | Daily |
| Calculation method(if applicable): | Not applicable |
| QA/QC procedures: | Used to corroborate gas consumption data collected at point1 |
| Purpose of data: | For calculating project emission. |
| Additional comment: | None |
|  |  |
| Data/Parameter: | FCf1,3,y |

(\\mathfrak{m}^{3})

\\mathsf{F C}\_{\\mathsf{f},2,\\mathsf{y}}

\\overline{{^{{}}{m^{{}}}}}

| Data/Parameter: | FCf,3,y |
| --- | --- |
| Unit: | m3 |
| Description: | Annual quantity of fuel(natural gas) consumed in gas turbine #12 |
| Measured/Calculated/Default: | Daily meter reading |
| Source of data: | Fuel(natural gas)flow meter reading at turbine #12inlet(SM R1-X-KG1600 Elster Instromet meter located at point 3 in figure A4.1) |
| Value(s) of monitored parameter: | 172,372,951 |
| Monitoring equipment: | SM R1-X-K G1600 Elster Instromet meter. |

\\mathsf{F C}\_{\\mathsf{f},3,\\mathsf{y}}

\\overline{{{^}m^{3}}}

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| Measuring/Reading/Recording frequency: | Daily |
| --- | --- |
| Calculation method(if applicable): | Not applicable |
| QA/QC procedures: | Used to corroborate gas consumption data collected at point 1 |
| Purpose of data: | For calculating project emissions. |
| Additional comment: | None |

| Data/Parameter: | FCf4,y |
| --- | --- |
| Unit: | m3 |
| Description: | Annually quantity of fuel(natural gas) consumed in gas turbine #13 |
| Measured/Calculated/Default: | Daily meter reading |
| Source of data: | Fuel(natural gas)flow meter reading at turbine #11 inlet(SM R1-X-KG1600 Elster Instromet meter located at point2 in figure A4.1) |
| Value(s) of monitored parameter: | 249,332,185 |
| Monitoring equipment: | SM R1-X-K G1600 Elster Instromet |
| Measuring/Reading/Recording frequency: | Daily |
| Calculation method(if applicable): | Not applicable |
| QA/QC procedures: | Used to corroborate gas consumption data collected at point1 |
| Purpose of data: | For calculating project emissions. |
| Additional comment: | None |

\\mathsf{F C}\_{\\mathsf{f},4,\\mathsf{y}}

\\overline{{m^{3}}}

| Data/Parameter: | NCVf,y |
| --- | --- |
| Unit: | GJ/m3 |
| Description: | The net calorific value(energy content)per volume unit of natural gas used in the calculation of project emissions. |
| Measured/Calculated/Default: | Gas samples collected using SPDC standard gas sampling protocol and analysed using standard gas chromatography techniques in on-site laboratory. |
| Source of data: | Based on a fortnightly sampling at the Afam gas custody point |
| Value(s) of monitored parameter: | 0.04654 |
| Monitoring equipment: | On site GC laboratory |
| Measuring/Reading/Recording frequency: | Fortnightly |
| Calculation method(if applicable): | Not applicable |
| QA/QC procedures: | The calorific value of the gas will recorded by the project participant and cross checked against measurements made,and provided,by the gas supplier |
| Purpose of data: | For calculating CO2 emission coefficient for project emission. |
| Additional comment: | None |

\\mathsf{N C V\_{\\mathsf{f},y}}

G l/m^{3}

Version 03.2

\\mathrm{C O\_{2}}

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| Data/Parameter: | EFCO2Fy |
| --- | --- |
| Unit: | tCO2/GJ |
| Description: | CO2 emission factor per unit of energy of natural gas used in the calculation of project emission. |
| Measured/Calculated/Default: | Gas samples collected using SPDC standard gas sampling protocol and analysed using standard gas chromatograph techniques in on-site laboratory |
| Source of data: | Based on a fortnightly sampling at the Afam gas custody point |
| Value(s) of monitored parameter: | 0.03340 |
| Monitoring equipment: | On-site Gas Chromatograph |
| Measuring/Reading/Recording frequency: | Fortnightly |
| Calculation method(if applicable): | None |
| QA/QC procedures: | The CO2 content of the gas will be recorded by the project participant and cross-checked against measurements made, and provided, by the gas supplier. |
| Purpose of data: | For calculating CO2 emission coefficient for project emission. |
| Additional comment: | None |
|  |  |
| Data/Parameter: | EGPJ56y |
| Unit: | MWh |
| Description: | Electricity produced by gas and steam turbines. |
| Measured/Calculated/Default: | Continuous metering of electricity supplied by the gas and steam turbines to the bus-bar of the Afam plant. |
| Source of data: | Electricity meters installed in the plant power export to bus-bar (meter type EDMI MK6E with accuracy class 0.2S.IEC62052-11/62053-22 and meter type EDMI MK6E with accuracy class 0.2S/0.55.IEC62052-11/62053-22) for both the gas and steam turbine. |
| Value(s) of monitored parameter: | 3,269,378 |
| Monitoring equipment: | EDMI MK6E |
| Measuring/Reading/Recording frequency: | Continuous metering of electricity supplied by the gas and steam turbine to the bus-bar of the Afam plant. |
| Calculation method(if applicable): | Not applicable |
| QA/QC procedures: | Metered export of electricity to be checked against data on power received by the grid operator(PHCN) at the Afam plant-grid interface points.Accuracy of the meters are to be tested every 180 days as outlined in section 7.3 of the PPA and the calibration of meters needs to be undertaken if electrical energy measured by the system differs by over half a percent(0.5%) from any back-up system. |
| Purpose of data: | For calculating baseline emission. |
| Additional comment: | None |

\\mathsf{E G}\_{\\mathsf{P J,56,y}}

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# F-CDM-MR

| D.3. Implementation of sampling plan >> Section D.2 above. | Only 2 parameters have been determined from analysis of samples of physical fluid characteristics of the inlet gas stream. Details descriptions of the sampling design, the amount of collected data, the analysis of collected data and the compliance with relevant requirements are provided for each relevant parameter in |  |
| --- | --- | --- |
| >\> BE = EG .EF y PJ, y BL,CO2, y plant (EG PJ,y to use for EF BL,CO2,y system” using a 50/50 OM/BM weight; and technology are as follows: æ COEF ö BL EF = çç BL,CO2, y h BL è ø Where: COEF BL η BL electricity system” v2.2.1) was applied The resulting value for EF emissions are: | 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 are calculated in accordance to Equation 2 in the registered PDD and methodology: (Equation 2) AM0029 requires that baseline emissions are calculated by multiplying the electricity generated in the project ) with a baseline CO2 emission factor (EF BL,CO2,y the lowest emission factor among the following three options: Option 1 – The build margin (BM) as per the “Tool to calculate the emission factor for an electricity system”; Option 2 – The combined margin (CM) as per the “Tool to calculate the emission factor for an electricity Option 3 – The emission factor of the technology (and fuel). As stated in the PDD, the most likely technology that would be used instead of CCGT is OCGT plant and this has therefore been chosen for the calculation of Option 3. As per equation (3) the input parameters for this (Equation 3) ÷÷ \*3.6GJ / MWh = the fuel emission coefficient (tCO2e/GJ), (IPCC default emission factor for natural gas) was used. = the energy efficiency of the technology, 39.5% (conservative default efficiency factor for new gas-fired OCGT units built after 2000, as contained in Annex I of the “Tool to calculate the emission factor of an is calculated to be 0.511 tCO2/MWh BL,CO2 Amount of electricity generated during the monitoring period is determined as 3,269, 378 MWh For the monitoring period in consideration, the relevant parameter values and the resulting baseline Parameter: Unit: Value: EG (MWh) 3,269,378 PJ,56, y h () 0.395 BL (tCO2e/GJ) 0.0561 COEF BL | ). The methodology requires project participants |

# Version 03.2 Page 12 of 15

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B L\_{y}

| Parameter: | Unit: | Value: |
| --- | --- | --- |
| Oxidf | (-) | 1 |
| EFCO2,f,y | (tCO2/GJ) | 0.03340 |
| NCVf,y | (GJ/m³) | 0.04654 |
| COEFf,y | (tCO2w/GJ) | 0.0016 |
| FCf,y | (m³) | 643 X 10⁶ |
| PEy | (tCO2) | 1,000,055 |

(t O\_{2})

(P E y)

F C\_{t,V}=

(mathfrak m{{}^^{{3}}}

C O E F\_{t,\\gamma}\\mathrm{{=}}\ H e C O\_{2}

(\\dagger{\\sf C}022)^{3}

C O E F\_{ _{f,y}}=\\sum{N C V_{ _{f,y}}}\*{E E_{C\_{O2,f,y}}}\*{O X I D\_{f}}

\\mathrm{C O\_{2}}

{x i d}\_{f}

Emathit{F F}\_{c o2,f,y}

(t C O\_{2}/G y)

(G J/m^{3})

\\mathrm{C H}\_{4}

L E c H4,y

L E\_{L N N,C O,y}

\ O{E F F}\_{f,y}

(t C O\_{2e}/G J)

\ C\_{f,y}

(t O\_{2})

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F-CDM-MR

| Item | Baseline emissions or baseline net GHG removals by sinks (tCO2e) | Project emissions or actual net GHG removals by sinks (tCO2e) | Leakage(tCO2e) | Emission reductions or net anthropogenic GHG removals by sinks(tCO2e) |
| --- | --- | --- | --- | --- |
| Total | 1671604 | 1000055 | 0 | 671550 |

(\\up O\_{2}e)

(\\mathrm{t o}\_{2})

(\\mathtt{t O}\_{2}\\mathtt{e})

(t C O\_{2}e)

E.5. Comparison of actual emission reductions or net anthropogenic 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) | 550,234 | 671,550 |

\\mathbf{c o}\_{2}\\mathbf{e})

During the monitoring period in consideration, the actual emission reductions achieved are 18% higher than
the estimated emission reduction over the same period (i.e. a period of 365 days in 2012/2013) presented in
the registered PDD.

The difference between the estimated and actual operations is largely related to the gas composition and
emission factor of fuel used in the PDD calculations which were estimated based on use of literature (for the
NCV) and IPCC default value (emission factor of the natural gas fuel). The monitored values are based on
the actual gas analysis on the fuel composition carried out in the laboratory.

E.7. Actual emission reductions or net anthropogenic GHG removals by sinks during the first
commitment period and the period from 1 January 2013 onwards

| Item | Actual values achieved up to 31 December 2012 | Actual values achieved from 1 January 2013 onwards |
| --- | --- | --- |
| Emission reductions or GHG removals by sinks (tCO2e) | 131,292 | 540,257 |

Version 03.2

\\mathbf{c o}\_{2}\\mathbf{e})

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Document information

| Version | Date | Description |
| --- | --- | --- |
| 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 anthropogenic 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" (EB66, Annex 20). |
| 01 | 28 May 2010 | EB54, Annex34. Initial adoption. |
| Decision Class: Regulatory Document Type: Form Business Function: issuance Keywords: monitoring report, performance monitoring |  |  |