CER MONITORING REPORT

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CER MONITORING REPORT

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Monitoring Report

Ma Steel (old plant) CDQ and waste heat utilization project

UNFCCC Reference Number: 1729

CER Monitoring Period:

Start Date: 04/12/2008 00:00

End Date: 31/08/2009 24:00

Version 1

Date of Report: 12/10/2009


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CONTENTS

A. General Project Activity Information

B. Key Monitoring Activities

C. Quality Assurance and Quality Control Measures

D. Calculation of GHG Emission Reductions


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SECTION A. General Project Activity Information

A.1. Title of the project activity:

Ma Steel (old plant) CDQ and waste heat utilization project

A.2. Project Category

Sectoral Scope 1, Energy Industries

A.3. Geographic Location

The project site is located at 3141 54"N, 11827 17"E, in the coke plant of the old plant

area of Ma Steel. The west side of the proposed project is just adjacent to the No.1~4 coke

ovens and the north side is close to a trunk railway. The old plant is located in Yushan District,

Maanshan City, Anhui Province, PRC. Maanshan City is located in the east of Anhui

Province, on the south bank of the Yangtze River, near the border with Jiangsu Province.The

geographic location of the project is shown below.

Anhui Province


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Figure 1: Location of the project

A.4. Description of the project activity

Ma Steel (old plant) CDQ and waste heat utilization project (below abbreviated as the

proposed project) aims to reduce GHG emissions through installation of two sets of coke dry

quenching (CDQ) systems at the No. 1, 2, 3 and 4 coke ovens in the old plant of Maanshan

Iron & Steel Co., Ltd. (abbreviated as Ma Steel). At present coke wet quenching process

(CWQ) systems have been utilized and a large amount of heat from red-hot cokes emitted into

the atmosphere. The CDQ systems will recover waste heat from red-hot coke produced by

these four coke ovens and utilize the sensible heat for power generation.

The generation capacity of the proposed project is 30 MW. The generated electricity of the

project will be supplied to Ma Steel with an annual net supply of 197.0 GWh, replacing the

equivalent amount of electricity that otherwise would be purchased by Ma Steel from the EastChina Power Grid (ECPG), which is dominated by coal-fired power plants. The expected

emission reductions from the project are estimated at 176,464 tCO2e per year for a fixed

ten-year crediting period.

The project, which recovers waste heat from red-hot coke and then uses the heat for

electricity generation, has significant environmental and social benefits. It contributes to

sustainable development as follows.

The project will reduce the waste of energy resources and promote energyconservation.

Electricity generated by this project will displace coal-fired power generation in theECPG, reducing the environmental pollution generated from burning coal.

Ma Steel


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The project will create employment opportunities for the local community during bothconstruction and operation.

A.5. Project Boundary

The table below illustrates which emission sources and GHG are included in the project

boundary:Table 1: The emission sources and GHG in the project boundary

Source Gas Included? Justification / Explanation

CO2 Yes Main emission source

CH4 No Excluded for simplification

according to ACM0004Baseline

The ECPG power

generation

N2O No Excluded for simplification

according to ACM0004

CO2 Yes The project consumes a small

volume of auxiliary steam supplied

through the common steam header.

The emissions associated with the

production of this steam are taken

into account.

CH4 No Excluded for simplification


Project

Activity

On-site fossil fuel

consumption due

to the project

activity

N2O No Excluded for simplification


The project boundary includes the proposed project activity, No. 1, 2, 3 and 4 coke ovens in

the old plant of Ma Steel and all power plants physically connected to the ECPG, which

includes Jiangsu Province, Anhui Province, Fujian Province, Zhejiang Province and

Shanghai.


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Figure 2: Diagram of the project boundary

A.6. Project Start Date

Starting date of the project activity: 08/01/2007

Crediting period: 04/12/2008 03/12/2018 (Fixed)

A.7. Current Monitoring Period

04/12/2008 0:00 31/08/2009 24:00

A.8. Methodology applied to the project activity for the current period:

A.8.1. Baseline methodology:

Approved consolidated methodology ACM0004 (Consolidated methodology for waste gas

and /or heat and /or pressure for power generation, version 02) and ACM0002 (Consolidated

methodology for grid connected electricity generation from renewable sources, version 06)

are applied to this project activity.

As required by methodology ACM0004, the latest approved (version 03) of the Tool for the

324# Substation

110kV Maanshan City Grid

Steam

common

10kv31# Substation

Liucun Substation

1# CDQ 2# CDQ

Line Line

Line

Line

Line

Line

Steam

common

Project boundary

220kV Anhui Province Grid


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Demonstration and Assessment of Additionality is used to demonstrate the projects

additionality.

A.8.2. Monitoring methodology:

The project has implemented a monitoring methodology developed in compliance with

ACM0004 - Consolidated monitoring methodology for waste gas and/or heat and/or pressurefor power generation for monitoring of CERs. The methodology requires monitoring of the

following:

- Gross electricity generation of the 1# CDQ- Gross electricity generation of the 2# CDQ- Electricity consumption of 1# CDQ- Electricity consumption of 2# CDQ- Steam consumed by the CDQ unit for the de-oxygenizing process- Enthalpy of the steam at certain pressure, saturated temperature

The monitoring meters installation site program is as follows:

Figure 3: Diagram of monitoring points

Net electricity generation and consumption by the project activity;

220kV Anhui Province Grid

324# Substation

110kV Maanshan City Grid

Steam common

header

10kv31# Substation

Liucun Substation

1# CDQ 2# CDQ

A1 A2

Line Line

A

S

Electricity energy meter

Steam flow meter

M Manometer

T Thermometer

A31 A32

Line

Line

Line

Line

Steam common

header


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The power generated by 1# and 2# CDQ will be transmitted outside via line and line , on

which the electricity energy meters A1 and A2 are mounted respectively to monitor the power

generated by each CDQ.The power consumed by No.1 CDQ will be supplied by line and

line , on which electricity energy meter A31 is mounted. The power consumed by No.2 CDQ

will be supplied by line and line , on which electricity energy meter A32 is mounted. A

part of the power consumed by the two sets of CDQ will be changed from 10kV to 380V

through 324# Substation, and the other part power of 10kV will be directly consumed by the

two sets of CDQ. The four electric energy meters monitoring the electricity generated or

consumed by two sets of CDQ systems will be in 31# Substation.

The electric energy is measured continuously, daily and monthly totals are records as part of

the monthly report.

The steam consumed and the enthalpy of CDQ

Steam consumption supplied by the common steam header to the project activity will be

measured by installing standard steam flow / pressure / temperature metering instruments to

ensure that steam used for the de-oxygenizing process. As the steam is vented after use there

is no need to install equipment to monitor the feedback of steam to the steam header.

The steam consumption is measured continuously, daily and monthly totals are records as part

of the monthly report. The enthalpy data is calculated by the pressure and the temperature of

the steam, the pressure and the temperature are measured daily, and the conservative value

will be used in calculation.

A.9. Calculation Methodology

The amount of CERs that is generated is calculated based on the fundamental CDM equation:

Emission reductions (ER) = Baseline Emissions (BE) Project Emissions (PE) Leakage (L)

The project specific elements of the equation are described below.

Project Emissions

The project activity will consume a small volume of steam which is used in thede-oxygenizing process and subsequently vented into the atmosphere after use. The steam is

supplied by common steam header which draws its steam from a number of sources. These

include waste heat recovery units and coal-fired boilers among other sources.

In accordance with the ACM0004 methodology, project emissions due to the firing of

auxiliary fuels are calculated as below:

iii

i

iy OXIDEFNCVQPE =12

44

Where:

yPE : Project emissions in year y (tCO2);


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iQ : Mass or volume unit of fuel i consumed (t or m3);

iNCV : Net calorific value per mass or volume unit of fuel i (TJ/t or m3);

iEF: Carbon emissions factor per unit of energy of the fuel i (tC/TJ);

iOXID : Oxidation factor of the fuel i (%)

Baseline Emissions

According to ACM0004, baseline emissions are calculated as:

yyelectricityyyelectricitEFEGBE ,, =

Where:

#2#1#2#1 AUXAUXGENGENy EEEEEG +=

yEG : Net quantity of electricity supplied to the manufacturing facility by the project during

the year y (MWh),

#1GENE :Gross electricity generation of the 1# CDQ, (MWh),

#2GENE :Gross electricity generation of the 2# CDQ, (MWh),

#1AUXE : Electricity consumption of 1# CDQ, (MWh),

#2AUXE : Electricity consumption of 2# CDQ, (MWh),

yyelectricitEF , : CO2 baseline emission factor for the electricity displaced due to the project

activity during the year y (tCO2/MWh),

Leakage

No leakage is considered, according to ACM0004.

Emission Reduction

The emission reduction ERy by the project activity during a given year y is the difference

between the baseline emissions though substitution of electricity generation with fossil fuels

(BEelectricity,y) and project emissions (PEy), as follows:

yyyelectricity PEBEER = ,

Where:

ERy is the emissions reductions of the project activity during the year y (tCO2);

BEelectricity,y is the baseline emissions due to displacement of electricity during the year y

(tCO2);


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SECTION B. Key monitoring activities according to the monitoring plan for the monitoring period

B.1. Parameters Monitored

Table 2: Parameters Monitored (PDD Version)

ID Number Data TypeMonitoring

MeterData Unit

Measured(m)

Caculated(c)

or

estimated (e)

Recording

Frequency

Proportio

Data to

Monito

EGEN 1#Electricity A1 10

4kwh m Continuously 100%

EGEN 2# Electricity A2 104kwh m Continuously 100%

EAUX 1# Electricity A31 104kwh m Continuously 100%

EAUX 2# Electricity A32 104kwh m Continuously 100%

S Steam S t m Continuously 100%

Ir Enthalpy M&P kJ/kg c Daily


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B.2. Data Collection (accumulated data for the whole monitoring period):

B.2.1. Fixed Values and VariablesTable 3: List of Fixed Default Values

Parameter Description Value Data unit Source of data used

EFyBaseline

Emission Factor0.90465 tCO2 /MWh Calculated (see CDM PDD)

EFCO2

CO2

emission factor

of coal

25.8 TC/TJ IPCC default value

boiler

The heat

efficiency of the

boiler

75 %

According to the design

document, the boilers heatefficiency will be no less

than 75%. To be most

conservative, let boiler=75%

OXIDi Oxidization Rate 100 % IPCC default value

B.2.2. Data concerning GHG emissions by sources of the project activity

From the registration date 04/12/2008 to 31/08/2009, the amount of steam consumed by 1# and

2# CDQ is listed in the table below.

Table 4: Steam consumed by project activity (Unit: t)

Date 1# and 2# CDQ

04/12/2009 00:00 31/12/2009: 24:00 3,368

01/01/2009 00:00 31/01/2009: 24:00 5,12501/02/2009 00:00 28/02/2009: 24:00 4,804

01/03/2009 00:00 31/03/2009: 24:00 5,510

01/04/2009 00:00 30/04/2009: 24:00 4,908

01/05/2009 00:00 31/05/2009: 24:00 4,144

01/06/2009 00:00 30/06/2009: 24:00 4,354

01/07/2009 00:00 31/07/2009: 24:00 4,925

01/08/2009 00:00 31/08/2009: 24:00 5,207

Total 42,345

Ir calculation

The maximum values of the pressure (1.1MPa) and temperature (296 ) are used in the

calculation ofIrfor more conservative.

B.2.3. Data concerning GHG emissions by sources of the baseline:

Table 5: Net quantity of electricity supplied to the manufacturing facility by 1#CDQ (Unit: kWh)

Date Generation Consumption Net Electricity


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EGEN 1# EGEN 2# EAUX 1# EAUX 2#

Generation

(EGy= EGEN

1#+EGEN 2#-EAUX1#-EAUX 2#)

04/12/2009 00:00

31/12/2009: 24:005,445,200 2,975,600 606,480 2,041,600 5,772,720

01/01/2009 00:00

31/01/2009: 24:006,861.600 7,336,000 1,699,080 2,197,280 3,446,502

01/02/2009 00:00

28/02/2009: 24:007,049,600 6,582,400 1,414,080 1,990,560 10,227,360

01/03/2009 00:00

31/03/2009: 24:008,811,200 7,186,800 1,910,280 2,150,400 11,937,320

01/04/2009 00:00

30/04/2009: 24:007,403,200 8,813,200 1,806,600 2,122,240 12,287,560

01/05/2009 00:00

31/05/2009: 24:003,991,200 6,814,400 1,612,560 1,393,440 7,799,600

01/06/2009 00:00

30/06/2009: 24:007,146,000 6,926,800 1,762,200 2,154,880 10,155,720

01/07/2009 00:00

31/07/2009: 24:007,535,200 9,072,800 1,846,440 2,348,480 12,413,080

01/08/2009 00:00

31/08/2009: 24:00 8,206,000 9,605,600 1,915,400 2,358,700 13,537,500

Total 55,594,462 65,313,600 14,573,120 18,757,580 87,577,362

B.2.4. Data concerning leakage

No leakage needs to be considered.

B.2.5. Data processing and archiving

The monitoring data shall be saved for two years after the end of the crediting period or the last

issuance of certified emission reductions.


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SECTION C. Quality assurance and quality control measures

C.1. Allocation of responsibilitiesThe operational and management structure and the responsibilities of the principals are as

follows.

Table 6: Responsibilities for Monitoring Activities

Activity Responsible Division

- Overall Management

- Preparation of External Reports

Energy Department

- On site meter maintenance & calibrations

- Maintaining meter logs

- Training in meter reading & error recognition

- Data aggregation and record keeping

Measure Control Department

- Recording of metered power generation and

consumption

- Original electricity data collection

No.1 Energy Center

- Recording of metered steam consumption

- Recording of metered temperature and

pressure of the steam

- Original steam data collection

Coking Plant

C.2. Meters Calibration

The precision of all the meters used in the monitoring activity meet the national standard, and the

accuracy level of the steam flow meter is 0.5. The accuracy level of the electric energy meter is

0.5. Reading of the meters follows the relevant national rules and standards to ensure the accuracy

of the data.

The electric energy meters measuring the electricity consumed and generated by CDQ must be

checked every year, and the flow meters measuring the steam must be checked every year. The

calibration of instruments for monitoring will be organized by Measure Control Department ofMa Steel. They would be periodically calibrated in accordance with the regulations of the grid

company and internal procedures, by qualified department. Ma Steel has received a management

system certification issued by the government. Ma Steel will be full compliance with check and

verification regulation handbook.

From the registration date 04/12/2008 to 31/08/2009, the calibration information of meters listed

in the tables below.


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Table 7: The calibration information of four electric energy meters

CDQ No. Meters Meters No.Accuracy

level

Calibration

Date

Period of

validity

A1 0678818 22/05/2009 12 month

1#

A31 45462695 13/05/2009 12 month

A2 0678817 21/05/2009 12 month

2#

A32 0678847

0.5

26/05/2009 12 month

Table 8: The calibration information of the steam flow meter

Meter Meter No. Accuracy level Calibration Date Period ofvalidity

S SZZA021249642 0.5 20/05/2009 12 month

Table 9: The calibration information of the manometer

Meter Meter No. Accuracy level Calibration DatePeriod of

validity

M CZZA065890642 0.5 20/05/2009 12 month

Table 10: The calibration information of the temperature sensor

Meter Meter No. Accuracy level Calibration Date Period of validity

T 080955 B 20/05/2009 12 month

C.3. Monitoring Staff Training

Ma Steel has taken the training for the monitoring staff. Internal training has been made available

and followed by monitoring staff to enable them to undertake the tasks. The training shall be

recorded.

C.4. Internal audits and control measures

Internal audits are taken to ensure the veracity and completeness of data. Auditing contents

including:

- the statistical results of monitoring data- the calibration and verification report of the meters- the checkup of monthly-report and daily-report- the training of relative staff- the maintenance and regular running repairs of equipments


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C.5. Troubleshooting procedures:

In case there are errors found in calibration or during the regular checks of meters, the

malfunctioning meter or component is repaired or replaced immediately in accordance with themanufacturers instructions and all data recorded since the last successful check or calibration is

declared void.

The CDM responsible person and specialists are informed of the error and ensure that the

necessary corrective actions are taken to resolve the problem and appropriate steps taken and to

re-calibrate the malfunctioning meter at the earliest opportunity. The error is recorded in the

internal audit forms giving date and time of error discovery, nature of error and corrective action

taken.


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SECTION D. Calculation of GHG emission reductions

D.1. Table providing the formulas used:See section A.9above.

D.2. Description and consideration of measurement uncertainties and error propagation:

Table 11: Consideration of Measurement Uncertainties

Data Uncertainty level of data

(High/Medium/Low)

Comments

S Low These data will be required for the

calculation of project emissions.

Ir Low These data will be required for the

calculation of project emissions.

EGEN 1#, EGENT 2#,

EAUX1#, EAUX 2#,

Low These data will be required for the

calculation of project electricity generation.

D.3. GHG emission reductions:

D.3.1 Project Emission

iii

i

iy OXIDEFNCVQPE =12

44

Fuel Coal

Steam consumption 42,345t

Ir at 1.1MPa, 296 ( kJ/kg) 2,781.21

Calorific value of steam for

de-oxygenizing process (GJ)42,345t*2,781.21kJ/kg/1000 =117,770.34

boiler 75%

Calorific Value of coal to produce

the steam (GJ)121,649.90/75%=157,027.12

EFcoal(TC/TJ) 25.8

CO2:C 44/12

Oxidization Rate 100.00%

CO2 emission (tCO2) 157,027.12*25.8*44/12*100%/1000=14,854.77

D.3.2 Baseline Emission

Electricity Generation (EGEN 1#+EGEN 2#) 120,908,062 kWh

Electricity consumed by auxiliary equipment

(EAUX 1#+EAUX 2#)33,330,700 kWh

Expected net electricity supply

(EGy=EGEN 1#+EGEN2#-EAUX 1#-EAUX 2#)87,577,362 kWh


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Emission Factor (Ex-ante) 0.90465 tCO2e/Mwh

Baseline Emission 79,226.86 tCO2e

D.3.3. Leakage

No leakage needs to be considered (see Section B.2.5.)

D.3.4. Emission Reductions Calculation Table

Reference to

ACM0004Units

From 04/12/2009

to 31/08/2009Sources

Baseline

EmissionBEy tCO2e 79,226.86 See D.3.2

Project emission PEy tCO2e 14,854.77 See D.3.1

Leakage Ly tCO2e 0 Fixed in the PDDTotal emission

reductionstCO2e 64,372.10 Calculated

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