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PROJECT DESIGN DOCUMENT FORM (CDM-SSC-PDD) - Version 03 CDM – Executive Board

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CLEAN DEVELOPMENT MECHANISM PROJECT DESIGN DOCUMENT FORM (CDM-SSC-PDD)

Version 03 - in effect as of: 22 December 2006

CONTENTS A. General description of the small scale project activity B. Application of a baseline and monitoring methodology C. Duration of the project activity / crediting period D. Environmental impacts E. Stakeholders’ comments

Annexes Annex 1: Contact information on participants in the proposed small scale project activity Annex 2: Information regarding public funding Annex 3: Baseline information

Annex 4: Monitoring Information


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Revision history of this document Version Number

Date Description and reason of revision

01 21/01/ 2003 Initial adoption 02 08 /07/2005 • The Board agreed to revise the CDM SSC PDD to reflect

guidance and clarifications provided by the Board since version 01 of this document.

• As a consequence, the guidelines for completing CDM SSC PDD have been revised accordingly to version 2. The latest version can be found at <http://cdm.unfccc.int/Reference/Documents>.

03 22/12/ 2006 • The Board agreed to revise the CDM project design document for small-scale activities (CDM-SSC-PDD), taking into account CDM-PDD and CDM-NM.


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SECTION A. General description of small-scale project activity A.1 Title of the small-scale project activity: >>

Utilization of Biogas and Power Generation on Wastewater from Ethanol Factory in the Kingdom of Thailand

Version 01.2

Date: 04/04/2007

A.2. Description of the small-scale project activity: >> - The purpose of the project activity

At the moment, wastewater discharged from the Pornvilai ethanol factory located on the project site is treated in open lagoon ponds. The project is designed to treat the wastewater in an anaerobic processing system (Digester) so as to restrict the atmospheric emission of methane gas. At the same time, the methane gas is recovered without leak in the atmosphere by means of anaerobic wastewater treatment to utilize for high- efficiency power generation by gas engine. The electricity generated is used to power the factory or grid connection, thus greenhouse gas reduction by fossil fuel consumption reduction for grid power supply equivalency is possible. Additionally, this project makes it possible for greenhouse gases to be reduced through the combustion of surplus methane gas by means of a flare stack, this to be installed in cases of emergency and possible equipment is installed.

- The view of the project participants on the contribution of the project activity to sustainable development The following contribution to the sustainable development through the execution of the project is expected: * The protection of the environmental pollution due to improvement of wastewater quality by the

improvement of the anaerobic wastewater treatment facilities ability. * Combat global warming by the effective utilization of biogas as a renewable energy source. * The protection of the environmental pollution by restraint on peripheral diffusion of emitted odour by

means of the closed structure. * Effective utilization of land by space – saving with a great help from of anaerobic processing method. * Against skyrocketing energy cost such as heavy oil, fossil-fuel consumption required for the power

supply to the grid can energy-saving effect be reduced to the extent that the power generation by the project is supplied to the factory.

* The transfer of technology for the methane fermentation process and biogas power generating equipment.

* The project can disseminate around Southeast Asian countries including Thailand. It becomes clean technology demonstration project, and there is effect of that disseminate.

* The project may also serve as a project for establishing the CDM as an important capability so that the project can demonstrate that it provides funds as new financial machinery to the renewable energy and waste management sectors in the country and the provinces.

* The project will reduce energy import from abroad, thereby providing positive effects to the external payment balance of the country. Diversification of energy by its self-sufficiency and the security of energy supply will be also accelerated.


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* The project will add value (production cost reduction and CER income) to ethanol industries of cassava, a valuable export commodity of Thailand.

* Effective utilization of organic material of waste effluents involving the risk of generation of flammable methane gas.

A.3. Project participants: >> Name of Party involved ((host) indicates a host

Party)

Private and/or public entity(ies) project participants

(as applicable)

Kindly indicate if the Party involved wishes to be considered

as project participant(Yes/No) Thailand (host) Pornvilai International Group Trading

Co., Ltd. (PVL) No

Thailand (host) Bio Natural Energy Company Limited (BNE)

No

Japan Kanematsu Corporation (KG) No Project concerned parties (Host and investing countries)

Investing countries: At the moment, investing countries can not be determined. The consultation among negotiable parties is in progress but an official agreement among them has not been achieved. It will be determined at a later stage.

All of the project concerned parties are private bodies.

(Host country) * Pornvilai International Group Trading Co., Ltd (PVL):

They are the owner of the ethanol factory for producing transport fuel ethanol from molasses (treacle), and they are also the supplier of the project site.

* Bio Natural Energy Company Limited (BNE) SPC (Special Purpose Company), CDM Project Execution Company and the responsible organization for implementation of CDM project.

(Japan) * Kanematsu Corporation (KG):

Preparation of PDD, CDM project management and contacting point of the project For detailed contact address, see Annex 1.


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A.4. Technical description of the small-scale project activity:

At the moment, the wastewater after the production process of transport fuel ethanol from molasses (treacle) is discharged into the existing anaerobic lagoon pond (without the constructed cover). The wastewater from the factory is first discharged into the equalization pond (E1) for smoothing the inlet flow into the treatment process; then it is conveyed by pumps into the anaerobic lagoons (E2 [AN1] ~ E6 [AN5]) for treatment; thereupon, it is treated in the facultative lagoons (E7, 8, 9 [FAC-1, 2]) and the aerobic lagoons (E10, 11 [AL-1, 2]); finally it is treated in the polishing pond (E12, 13 [PL-1, 2]) and then it is released. The residence time is more than 100 days. For reference’s sake, the effluent standard of this factory is BOD < 20 mg/l and COD < 120 mg/l. The general plot plan of the wastewater treatment installation is shown in the Figure 1.

Project object area

Figure 1 General Plot Plan


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The project is designed to apply the anaerobic wastewater treatment unit (Digester) to the existing anaerobic lagoon pond in order that the methane gas emitted in the atmosphere may be recovered and utilized for the gas engine power generator. The project will introduce two important technologies of which transfer is required on different characteristics stages in the region and the world.

1. Alleviation of methane gas emission:

The technology required for alleviation of methane gas emission is a new technology to be transferred. The project calls for the following technology transfer: * Knowledge – bio-engineering expertise mainly on a basis of Canadian technology (ADI Systems

Inc.); * Technology – component part of Digester1 through the technology transfer. Advanced

technological monitoring and management system are required so that the technology transfer will be promoted.

2. Biogas power generation:

It has been characterized and deployed on a global basis; hence the technology may be obtained. A.4.1. Location of the small-scale project activity: >> A.4.1.1. Host Party(ies): >>

Thailand (Host country) A.4.1.2. Region/State/Province etc.: >>

Ayuttaya Province A.4.1.3. City/Town/Community etc: >>

Tuarua District

1 ADI System Inc. has the technology of methane fermentation process under the name of ADI-BVF Digester.


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A.4.1.4. Details of physical location, including information allowing the unique identification of this small-scale project activity : >>

The aforesaid ethanol factory is located in the Ayuttaya Province about 60 km on the north of Bangkok and produces transport fuel ethanol from molasses (treacle). The factory is largely surrounded by rice farms and small neighbourhood consisting of a hundred of houses in the south of the factory. Open space around the factory allows construction of site and its construction will not create such large daily-life disturbance. The whole project limits a negative environmental and daily-life effect by reducing methane gas and odor generated from wastewater in open lagoon. The address is as follows: PORNVILAI INTERNATIONAL GROUP TRADING Co., Ltd (PVL): 55/5 Moo 1 Tharua-Wongdaeng Rd., Tumbon Salaloy, Ampur Tharua, Ayuttaya 13130, Thailand

Ayuttaya Province

Tuarua District

Pornvilai International Group Trading Co.,Ltd.

Figure 2 Location of Project Site

A.4.2. Type and category(ies) and technology/measure of the small-scale project activity: >>

AMS- III.H. Methane Recovery in Wastewater Treatment This category covers the methane recovery component of the project by ‘(vi) introduction of a sequential stage of wastewater treatment with methane recovery and combustion, with or without sludge treatment, to an existing wastewater treatment system without methane recovery’. Measures are limited to those that result in emission reductions less than or equal to 60,000 tCO2e annually.

AMS- I.D. Grid Connected Renewable Electricity Generation This category comprises renewable energy generation units, such as photovoltaics, hydro, tidal/wave, wind, geothermal and renewable biomass, that supply electricity to and/or displace electricity from an electricity distribution system that is or would have been supplied by at least one fossil fuel fired generating unit. The added capacity shall be not exceed 15MW.


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A.4.3 Estimated amount of emission reductions over the chosen crediting period: >>

The crediting period of the project is 7 years and the total emission reduction amounts to 211,652 tCO2

e for the crediting period. Table 1 Total Emission Reduction for Crediting Period

Year Annual estimated of emission reductions (tCO2 e) 2009 30,236 2010 30,236 2011 30,236 2012 30,236 2013 30,236 2014 30,236 2015 30,236 Total estimated reductions (tCO2 e) 211,652 Total number of crediting years 7 Annual average over the crediting period of estimated reductions (tCO2 e)

30,236

A.4.4. Public funding of the small-scale project activity: >>

Public funds will not be invested in this project. A.4.5. Confirmation that the small-scale project activity is not a debundled component of a large scale project activity:

From there not being other CDM project activity within 1km from boundary of this project activity, this project is not debundling.

SECTION B. Application of a baseline and monitoring methodology B.1. Title and reference of the approved baseline and monitoring methodology applied to the small-scale project activity: >>

AMS- III.H. Methane Recovery in Wastewater Treatment (Version 4, Scope 13, 15, dated 23/12/2006)

AMS- I.D. Grid Connected Renewable Electricity Generation (Version 10, Scope 1, dated 23/12/2006)


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B.2 Justification of the choice of the project category: >>

AMS- III.H. Methane Recovery in Wastewater Treatment The applicability criteria for the methodology are as below. 1. This project category comprises measures that recover methane from biogenic organic matter in

wastewaters by means of one of the following options: (i) Substitution of aerobic wastewater or sludge treatment systems with anaerobic systems with

methane recovery and combustion. (ii) Introduction of anaerobic sludge treatment system with methane recovery and combustion to an

existing wastewater treatment plant without sludge treatment. (iii) Introduction of methane recovery and combustion to an existing sludge treatment system. (iv) Introduction of methane recovery and combustion to an existing anaerobic wastewater treatment

system such as anaerobic reactor, lagoon, septic tank or an on site industrial plant. (v) Introduction of anaerobic wastewater treatment with methane recovery and combustion, with or

without anaerobic sludge treatment, to an untreated wastewater stream. (vi) Introduction of a sequential stage of wastewater treatment with methane recovery and

combustion, with or without sludge treatment, to an existing wastewater treatment system without methane recovery (e.g. introduction of treatment in an anaerobic reactor with methane recovery as a sequential treatment step for the wastewater that is presently being treated in an anaerobic lagoon without methane recovery).

2. If the recovered methane is used for heat and or electricity generation that component of the project activity can use a corresponding category under type I.

3. Measures are limited to those that result in emission reductions of less than or equal to 60 kt CO2 equivalent annually.

The proposed CDM project activity deals with the implementation of digester at an existing ethanol manufacturing plant to treat the organic wastewater generated in the production process. Methane produced during the process in the digester is captured using appropriate systems. The captured methane is used to power generation as replace purchased electricity presently used for internal demand in the plant. Thus, the project satisfies Criteria (iv) above.

The recovered methane is combusted in gas engines for electricity generation for the factory, which displaces bought-in grid electricity. Thus component of the project activity can use a category under type I.D..

Section A.4.3. demonstrates that the estimated annual emission reduction of the project activity during the crediting period is 30,236 tCO2e only, which is not exceeding the maximum proposed value of 60 kt CO2e in any year of the crediting period, as proposed by the Type III category of project activity guidelines.

AMS- I.D. Grid Connected Renewable Electricity Generation For the renewable electricity generation component of the project activities, the added generation capacity is less than 15 MW. The power generation capacity added to this project is 600kW, and it is not exceed 15MW.


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B.3. Description of the project boundary: >>

The project boundary for type III.H. (AMS-III.H.) projects is the physical, geographical site of the methane recovery facility. The project boundary for type I.D. (AMS-I.D.) is the physical, geographical site of the renewable generation source. * Substitute power energy / emission level:

The boundary is assumed to be a regional boundary in Thailand as far as the working scope of the grid system is concerned on grounds that the power transmission of hydraulic power generation in the grid system is considered as carbon neutral.

* Imperfect combustion methane emission:

Power generating equipment and a flare stack installation are included in the boundary. * Emission leaked from anaerobic reactor tank and pipelines:

Biogas production in reactor tanks and emission during biogas supply of pipelines are included.

The scope of the project boundary is defined as the plant connecting with the project site and the project related grid system.


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Flare Stackｏ Excess Biogasｏ Emergency flaring

Gene . Setsｏ Biogas electricity production

Fugit ive Methane frompipe l ine , or incomplete

combust ion

BiogasPipe l ine

Gr id Fed Electr ic ity &Emissions displaced by biogas

DigesterｏReceived wastewater flowsｏDelivers biogas

BNE-Pro ject Operat ingCompanyｏManagement of　Digesterｏ Provider of energy services

Ethanol Factory Fac i l i tyｏ Production of ethanol productｏ Production of wastewatersｏ Use of electricity

Equal izat ion Pond（E１）（EQ）

ｏSmoothing of inflow to the treatment process

from ethanolproduct

PondｏReceives waste-water from Digester

：Project boundary

Figure 3 Project Boundary


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B.4. Description of baseline and its development: >>

The baseline study was concluded using relevant methodology AMS-I.D. and AMS-III.H. * The appropriate baseline for project category Type I.D. (AMS-I.D.) is found in paragraphs 7 to 11. * The appropriate baseline for project category Type III.H. (AMS-III.H.) is found in paragraphs 7 and 9.

Details of calculations are as the followings: For AMS-III.H.: In this case, the baseline scenario is continuation of the present open lagoon based treatment of organic wastewater and release of methane into the atmosphere. The above stated condition fits well with paragraphs 6 baseline scenario (iv) of the AMS-III.H. methodology, “The existing anaerobic wastewater treatment system without methane recovery and combustion” as suggested in indicative simplified baseline and monitoring methodologies for selected small-scale CDM project activity categories, III.H., Version 4, Scope 13, 15 dated 23/12/2006.

MEPy,ww,treatment = Qy,ww * CODy,ww,untreated * Bo,ww * MCFww,treatment

Where, Description Variables Value Unit Source

Volume of wastewater per day - 300 m3/day Estimated plant data Operating days - 320 days/yr Estimated plant data Volume of wastewater Qy,ww 96,000 m3 - COD of the wastewater to be treated in the digester

CODy,ww,untreated 134.4 kg/m3 Measured plant data (Refer to Annex 3 BASELINE INFORMATION)

Methane producing capacity of the wastewater

Bo,ww 0.21 kg CH4/kg COD

IPCC default value

Methane correction factor for the wastewater treatment system

MCFww,treatment 0.8 - IPCC default value MCF lower value Anaerobic deep lagoon(depth more than 2 metres)

MEPy,s,treatment = Sy,untreated * DOCy,s,untreated * DOCF * F * 16/12 * MCFs,treatment

Where, Description Variables Value Unit Source

Amount of untreated sludge generated

Sy,untreated 0 tonnes Estimated plant data

Degradable organic content of the untreated sludge generated

DOCy,s,untreated 0.09 - IPCC default value (industrial sludge)

Fraction of DOC dissimilated to biogas

DOCF 0.5 - IPCC default value

Fraction of CH4 in landfill gas F 0.5 - IPCC default value


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Methane correction factor for the sludge treatment system that will be equipped with methane recovery and combustion

MCFs,treatment 0.8 - IPCC default value MCF lower value Anaerobic deep lagoon(depth more than 2 metres)

BEy = MEPy,ww,treatment * GWP_CH4 + MEPy,s,treatment * GWP_CH4

= 2,168 (tonnes/yr) * 21 + 0 (tonnes/yr) * 21 = 45,520 (tCO2e/yr)

For AMS-I.D.: BEgrid baseline electricity generation emissions (tCO2e/year)

BEgrid = EP BIO * CEFgrid = 2,106 (tCO2e/yr) Where,

Description Variables Value Unit Source Electricity produced by the biogas generator unit for grid electricity replacement

EP BIO 4,138 MWh/yr Calculated based on the captured methane volume

Grid emission factor

CEFgrid 0.509 kg CO2e/kWh

Published by Thai DNA http://www.onep.go.th/cdm/0038829_GridEmissions.pdf

Total baseline emission: The total baseline emission is the sum of the two discussed above.

BE = BEy + BEgrid = 45,520 (tCO2e/yr) + 2,106 (tCO2e/yr) = 47,676 (tCO2e/yr)


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B.5. Description of how the anthropogenic emissions of GHG by sources are reduced below those that would have occurred in the absence of the registered small-scale CDM project activity:

The project activity would not have occurred due to at least any one of the following. Alternative baseline scenarios tested. Scenario 1: Scenario of continuity of the current practice (Business-as-usual) Scenario 2: Aerobic treatment of wastewaters (activated sludge or filter bed type treatment) Scenario 3: Proposed project

(The proposed project is designed to recover methane gas through anaerobic processing digester for power generation. The electric power generated is used for own purpose or grid connection, while surplus gas will be burned for diffusion.)

Investment barrier By the Business-as-usual scenario, this technology is already installed and funding is not required any more. A simple alternative to the proposed project activity is a simple aerated lagoon (Perform oxygen supply in a lagoon) operated by mechanical aerators which infuse the oxygen required for the decomposition of the organic matter in to the wastewater. This technology is relatively simpler and low-cost compared to the proposed activity. However aerated lagoons also consume electricity for the aerators. Aerobic treatment (activated sludge or filter bed type treatment) is superior in a processing function. But aerobic treatment uses much electricity for an aeration device, and excess sludge occurring abundantly becomes a problem. In addition, this is higher cost compared to conventional systems. And there is not an income source by introduction. The ADI-Digester has appropriate systems that can control, accelerate and capture the methane emissions arising in the process, but of course at a higher cost compared to conventional systems. Internal rate of return (IRR) of this project is calculated on the condition of the Table 2 and the Table 3

Table 2 Recondition of Internal Rate of Return (IRR) calculation

Items Value Unit Remarks Initial investment 3.32 Million USD - Maintenance cost and utility costs in year 0.14 Million USD

/yr -

Labor cost 0 Million USD /yr

Existing factory worker, will double as the plant worker.

Purchased power price 3.24 Baht/kWh Average 2006 year Generated electric power 600 kW ADI Systems Inc. Total power generation 4,138 MWh/yr - GHG emission reduction 30,236 t CO2e Refer to Section B.6.4 CERs price 11.56 US$/t CO2e - Project operational lifetime and crediting period

14 Years Refer to Section C


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Table 3 Recondition of tax, depreciation etc. Items Value Unit Remarks

Corporation tax 30 % Tax rate of Thailand

Interest, Borrowing period - - Because it will be implemented in the fund on hand completely, it isn't considered for the IRR calculation.

Payment start time 2009 year - Depreciation taxable 3.0 Million USD Equipment cost and design expense Depreciation period 10 years Least 5 years

Depreciation method and rate

fixed installment method, 10%

- Fixed installment method is general in Thailand.

Salvage value 10 % -

Price inflation rate 0 % It isn't considered for the IRR calculation.

Exchange rate (Baht⇔USD) 35.82 Baht/US$ -

The calculation results of the Internal Rate of Return (IRR) of this project in case of without CERs and with CERs are shown in the Table 4.

Table 4 Project IRR (After-tax) without CERs with CERs

Project IRR - 1.7 % 11.2 %

IRR estimates indicate that the rate of return, - 1.7 % is lower value if CERs revenue is not taken into account. These estimates do not take into account the risk associated with the operation of the plant to capture methane. Thus, it is clear that the project’s IRR is not attractive for investment. This adequately demonstrates that the project cannot proceed on a business-as-usual basis. Technology barrier The proposed project activity is the forced extraction of methane and its combustion in the gas engine. Under the business-as-usual scenario, the plant uses anaerobic lagoons to treat the wastewater. This is method of low technology. This type system is widely used in Thailand and other regions. It is considered low-risk technology. The present wastewater treatment facility, open-lagoon system, is able to treat the wastewater and meet the current environmental standards, with 120 mg or less COD per liter of wastewater released into the water bodies. Alternative treatment technologies available for comparison are the BAU condition and the installation of forced aeration systems that can supply the oxygen required for degrading the organic content in the wastewater. Anaerobic lagoons, as prevailing in this case, and aeration systems are the viable technologies available in Thailand for treating high-organic wastewaters. Though several other methods, such as the one to be implemented in this case are available, all these technologies have not diffused into the country.


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Aerobic treatment (activated sludge or filter bed type treatment) is new type installation in Thailand. But it is not almost used on a commercial scale. And it involves potentially lower risks than the ADI-Digester treatment, but it is not regarded as the optimum technology in Thailand. The proposed project activity can be divided into three components. Pretreatment of the wastewater, Methane extraction using a digester, Utilizing the biogas for gas engine All operating parameters for the pretreatment component need to be maintained at the right level for the reactor to receive quality feedstock. In any case, inappropriate maintenance of operating conditions in pretreatment poses significant risks to the successful generation of methane. The ADI-Digester is critical equipment, which forces methane generation. The operating conditions need to be carefully maintained for efficient operation of the reactor. Owing to such inherent risks and non-availability of appropriate technologies adequately addressing all operation and maintenance issues, ADI-Digester have not been the most preferred choice for wastewater treatment in the country. Commonly available, simple, cost-effective technologies using either anaerobic or aerated lagoons have been the adopted ones in several places. Therefore it could be concluded that the ADI-Digester technology reasonably poses significant risks in operation and maintenance in relation to its simple counterparts.

Barrier due to prevailing practice Legal The current practise is a standard case where industrial wastewater involving high-organic load is treated on a basis of ponds in the area as well as Thailand. Direct discharge into water body (inclusive of rivers and lakes) is illegal. Aerobic and anaerobic liquid waste treatment observe it on a current law together and do not take an application of an additional rule. Most of the plants use open lagoon system in Thailand. The possibility of making the existing wastewater discharge standards more stringent is very small and even if such an action is taken, the existing system can be extended by creating more retention ponds to meet stricter norms, for which additional land is readily available. Social The open lagoon systems are presently used and social barrier is almost not found. They are accepted as part of regional circumstances and standard operational practice by commercial entities. Anaerobic and aerobic installations could cause a small number of social barriers to be created through risks (explosion or smells). Although social barriers may be least, there is some possibility for barriers to implementation of new technology.


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Other barriers It is considered that the current pond-based treatment is a standard operational baseline in Thailand and neighbouring areas. They have no positive experience of utilizing aerobic or anaerobic technology in Thailand. It is not assumed that the ordering priority of management for the technology is high. The high-priority issue for most of business people in this sector is the management of wastewater release for keeping easily with local regulations. More ample scale of management resources is required for the capital intensive energy production. Therefore, it is assumed that digesting process is not given their prior attention.

Table 5 Summarized Results of Barrier Analysis Baseline Alternative

Barrier Tested

Scenario 1: Continuity of the current practice

Scenario 2: Aerobic

treatment

Scenario 3: Proposed project

Investment barrier Y Y Y Technology barrier N Y/N Y Barrier due to prevailing practice N Y/N Y/N

Other barriers N Y Y The choice Y means that there are barriers; the choice N means that there is no barrier; the choice NA means that the relevant subject is not applicable. Addtionality Determination – Conclusion Since the project activity that will use the ADI-Digester technology confronts investment, technical, barrier due to prevailing practice and other barriers while the current lagoon system does not, the baseline is confirmed as the continuation of current lagoon system practice and the Project is additional. And this adequately demonstrates that the project activity cannot proceed on a business-as-usual basis.

B.6. Emission reductions:

B.6.1. Explanation of methodological choices: >>

The project follows the AMS-III.H. small scale methodology for Methane Recovery in Wastewater Treatment, Version 4, Scope 13, 15 dated 23/12/2006. In addition, the project follows the AMS-I.D. small scale methodology for Grid Connected Renewable Electricity Generation, Version 10, Scope 1 dated 23/12/2006.

Estimating the Baseline emissions: The baseline emission is calculated as follows: 1) Total Baseline Emission = BEy + BEgrid

2) 3) Where, BEy = Baseline methane emission from an existing wastewater treatment

(AMS-III.H)(Baseline Emission) (tCO2e/yr) BEgrid = Baseline electricity generation emissions (tCO2e/yr)


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2) Baseline methane emission from an existing wastewater treatment (BEy) The baseline emissions from the lagoons are estimated based on the Chemical Oxygen Demand (COD) of the effluent that would enter the lagoon in the absence of the project activity, the maximum methane producing capacity (Bo) and a methane conversion factor (MCF) that expresses what proportion of the effluent would be anaerobically digested in the open lagoons. BEy = MEPy,ww,treatment * GWP_CH4 + MEPy,s,treatment * GWP_CH4

2)-1 2)-2 Where, MEPy,ww,treatment ：Methane emission potential of wastewater treatment plant (tonnes/yr) MEPy,s,treatment ：Methane emission potential of the sludge treatment system (tonnes/yr) GWP_CH4 ：Global Warming Potential for methane (value of 21 is used)

2)-1

MEPy,ww,treatment = Qy,ww * CODy,ww,untreated * Bo,ww * MCFww,treatment

Where, Qy,ww ：Volume of wastewater treated (m3/yr) CODy,ww,untreated ：Chemical oxygen demand of the wastewater entering the anaerobic treatment

reactor/system with methane capture (tonnes/m3) Bo,ww ：Methane producing capacity of the wastewater (IPCC default value for domestic

wastewater of 0.21 kg CH4/kg.COD) MCFww,treatment ：Methane correction factor for the wastewater treatment system that will be

equipped with methane recovery and combustion (MCF lower value in Table III.H.1.)

2)-2

MEPy,s,treatment ：Methane emission potential of the sludge treatment system is considered zero as there is no emission from sludge.

3) Baseline electricity generation emissions (BEgrid)

BEgrid = EP BIO * CEFgrid

Where, EP BIO ：Electricity produced by the biogas generator unit for grid electricity replacement

(MWh/yr) CEFgrid ：Grid emission factor (kg CO2e/kWh)

Estimating the Project emissions: The project activity emission is calculated using the following: Due to the project activity, the emission will be from the electricity used for the project, emission through treated wastewater, emission through the final sludge produced, emission through capture and flare system and emission through dissolved methane in treated wastewater.


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PEy = PEy, power + PEy,ww,treated + PEy,s,final + PEy,fugitive + PEy,dissolved

4) 5) 6) 7) 8) Where, PEy ：Project activity emissions (tCO2e/yr) PEy,power ：Emissions from electricity or diesel consumption (tCO2e/yr) PEy,ww,treated ：Emissions from degradable organic carbon in treated wastewater (tCO2e/yr) PEy,s,final ：Emissions from anaerobic decay of the final sludge produced (tCO2e/yr) PEy,fugitive ：Emissions from methane release in capture and flare systems (tCO2e/yr) PEy,dissolved ：Emissions from dissolved methane in treated wastewater (tCO2e/yr)

4) Emissions from electricity or diesel consumption (PEy,power)

PEy,power = Electricity consumed by the auxiliary equipment (MWh/yr) * Grid emission factor (tCO2/MWh)

5) Emissions from degradable organic carbon in treated wastewater (PEy,ww,treated)

PEy,ww,treated = Qy,ww * CODy,ww,treated * Bo,ww * MCFww,final * GWP_CH4

Where, Qy,ww ：Volume of wastewater treated (m3/yr) CODy,ww,treated ：Chemical oxygen demand of the treated wastewater (tonnes/m3)2

Bo,ww ：Methane producing capacity of the wastewater (IPCC default value for domestic wastewater of 0.21 kg CH4/kg.COD)

MCFww,final ：Methane correction factor based on type of treatment and discharge pathway of the wastewater (fraction) (MCF Higher Value in table III.H.1 for sea, river and lake discharge i.e. 0.2).

6) Emissions from anaerobic decay of the final sludge produced (PEy,s,final)

PEy,s,final = Sy,final * DOCy,s,final * MCFs,final * DOCF * F * 16/12 * GWP_CH4

Where, Sy,final ：Amount of final sludge generated by the wastewater treatment (tonnes/yr) DOCy,s,final ：Degradable organic content of the final sludge generated by the wastewater treatment

(fraction). DOCF ：Fraction of DOC dissimilated to biogas (IPCC default value of 0.5) F ：Fraction of CH4 in landfill gas (IPCC default value of 0.5). MCFs,final ：Methane correction factor of the landfill that receives the final sludge, estimated as

described in category AMS III.G.

2 The IPCC default value of 0.25 kg CH4/kg COD was corrected to take into account the uncertainties. For domestic waste water, a COD based value of Bo,ww can be converted to BOD5 based value by dividing it by 2.4 i.e. a default value of 0.504 kg CH4/kg BOD can be used.


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7) Emissions from methane release in capture and flare systems (PEy,fugitive) PEy,fugitive = PEy,fugitive,ww + PEy,fugitive,s

7)-1 7)-2 Where, PEy,fugitive,ww ：Fugitive emissions through capture and flare inefficiencies in the anaerobic

wastewater treatment (tCO2e/yr) PEy,fugitive,s ：Fugitive emissions through capture and flare inefficiencies in the anaerobic sludge

treatment (tCO2e/yr) 7)-1

PEy,fugitive,ww = (1 - CFEww) * MEPy,ww,treatment * GWP_CH4 7)-1-1

Where, CFEww ：Capture and flare efficiency of the methane recovery and combustion

equipment in the wastewater treatment (a default value of 0.9 shall be used, given no other appropriate value)

MEPy,ww,treatment ：Methane emission potential of wastewater treatment plant (tonnes/yr)

7)-1-1 MEPy,ww,treatment = Qy,ww * CODy,ww,untreated * Bo,ww * MCFww,treatment

Where, Qy,ww ：Volume of wastewater treated (m3/yr) CODy,ww,untreated ：Chemical oxygen demand of the wastewater entering the anaerobic treatment

reactor/system with methane capture (tonnes/m3) Bo,ww ：Methane producing capacity of the wastewater (IPCC default value for domestic

wastewater of 0.21 kg CH4/kg.COD) MCFww, treatment ：Methane correction factor for the wastewater treatment system that will be

equipped with methane recovery and combustion (MCF higher values in table III.H.1)

7)-2

PEy,fugitive,s = (1 - CFEs) * MEPy,s,treatment * GWP_CH4 7)-2-1

Where, CFEs ：Capture and flare efficiency of the methane recovery and combustion equipment

in the sludge treatment (a default value of 0.9 shall be used, given no other appropriate value)

MEPy,s,treatment ：Methane emission potential of the sludge treatment system (tonnes/yr)


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7)-2-1 MEPy,s,treatment = Sy,untreated * DOCy,s,untreated * DOCF * F * 16/12 * MCFs,treatment Where, Sy,untreated ：amount of untreated sludge generated (tonnes) DOCy,s,untreated ：Degradable organic content of the untreated sludge generated (fraction). It shall be

measured by sampling and analysis of the sludge produced, and estimated exante using the IPCC default values of 0.05 for domestic sludge (wet basis, considering a default dry matter content of 10 percent) or 0.09 for industrial sludge (wet basis, assuming dry matter content of 35 percent)

DOCF ：Fraction of DOC dissimilated to biogas (IPCC default value of 0.5) F ：Fraction of CH4 in landfill gas (IPCC default value of 0.5) MCFs,treatment ：methane correction factor for the sludge treatment system that will be equipped

with methane recovery and combustion (MCF Higher value of 1.0 as per table III.H.1).

8) Emissions from dissolved methane in treated wastewater (PEy,dissolved)

PEy,dissolved = Qy,ww * [CH4]y,ww,treated * GWP_CH4

Where, Qy,ww ：Volume of wastewater treated (m3/yr) [CH4]y,ww,treated ：Dissolved methane content in the treated wastewater (tonnes/m3). In aerobic

wastewater treatment default value is zero, in anaerobic treatment it can be measured, or a default value of 10e-4 tonnes/m3 can be used.

Leakage: As per AMS-I.D., paragraph 12 and AMS-III.H., paragraph 8: No leakage calculation is required since the equipment is not being transferred to or from another activity.

Emission Reduction: ERy = Total Baseline emission - (Total PEy + Total Leakagey) ERy = Emission Reduction (tCO2e/yr)


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B.6.2. Data and parameters that are available at validation:

(Copy this table for each data and parameter) Data / Parameter: Operating days per year Data unit: Days/yr Description: This represents the number of days the ethanol plant is operating in a year. Source of data used: Plant owner Value applied: 320 Justification of the choice of data or description of measurement methods and procedures actually applied :

The data is based on the historical recorded data in the plant.

Any comment: N/A Data / Parameter: CEFgrid Data unit: t CO2e/MWh Description: Grid emission factor Source of data used: Thai DNA published on

http://www.onep.go.th/cdm/0038829_GridEmissions.pdf Value applied: 0.509 Justification of the choice of data or description of measurement methods and procedures actually applied :

Data are values mentioned in HP of DNA. The emission factor during this project period uses this value (ex-ante).

Any comment: N/A Data / Parameter: S y,untreated Data unit: tonnes Description: Amount of untreated sludge generated annually Source of data used: Project design Value applied: 0 Justification of the choice of data or description of measurement methods and procedures actually applied :

N/A

Any comment: N/A


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Data / Parameter: Depth of open lagoon Data unit: m (meter) Description: Depth of ponding water (from the water surface to the bottom of the pond) Source of data used: Plant condition Value applied: > 2.7 Justification of the choice of data or description of measurement methods and procedures actually applied :

Based on plant condition

Any comment: Essential to determine if the lagoons capable of anaerobic digestion in baseline. Data / Parameter: MCFww,treatment Data unit: No unit Description: Methane correction factor for the wastewater treatment system that will be

equipped with methane recovery and combustion Source of data used: IPCC default value for anaerobic decay of the untreated wastewater Value applied: 0.8 for Baseline emission calculation

1.0 for Project emission calculation Justification of the choice of data or description of measurement methods and procedures actually applied :

If the depth of the open lagoons is more then 2 m, then the MCF lower value/higher value in table III.H.1 is used.

Any comment: The data is essential to determine the methane emission potential of the wastewater entering the treatment system during baseline and project emission estimations.

Data / Parameter: CFEww Data unit: Percentage Description: Capture and Flare efficiency of the methane recovery and combustion

equipment in the wastewater treatment Source of data used: Default value from UNFCCC methodological tool to determine project

emissions from flaring gases containing methane Value applied: 90 Justification of the choice of data or description of measurement methods and procedures actually applied :

Essential to calculate fugitive emissions through capture & flare inefficiencies in the anaerobic wastewater treatment.

Any comment: Flame is detected on minute basis and flow rate of biogas is monitored continuously to use this default value. Enclosed flare is used.


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Data / Parameter: Bo,ww Data unit: kg CH4/kg .COD Description: Methane producing capacity of the wastewater Source of data used: IPCC default value for domestic wastewater Value applied: 0.21 Justification of the choice of data or description of measurement methods and procedures actually applied :

The earlier default value of IPCC was 0.25. Taking in to account the uncertainty of this estimate and considering the fact that the above furnished value (0.21) has been established as the result of comprehensive discussions among the methodology panel as well as the CDM Executive Board, it is a conservative and transparent approach for the project participant to adopt this value for the methane producing capacity of the wastewater.

Any comment: N/A Data / Parameter: COD influent into the digester Data unit: kg/m3

Description: COD of the wastewater from the ethanol plant before treatment Source of data used: Field measurement Value applied: 134.4 Justification of the choice of data or description of measurement methods and procedures actually applied :

Based on the field measurement

Any comment: N/A


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B.6.3 Ex-ante calculation of emission reductions: >>

Estimating the Baseline emissions: The baseline emission is calculated as follows: 1) Total Baseline Emission = BEy + BEgrid

2) 3) = 45,520 (tCO2e/yr) + 2,106 (tCO2e/yr) = 47,626 (tCO2e/yr)

2) Baseline methane emission from an existing wastewater treatment (BEy)

The baseline emissions from the lagoons are estimated based on the Chemical Oxygen Demand (COD) of the effluent that would enter the lagoon in the absence of the project activity, the maximum methane producing capacity (Bo) and a methane conversion factor (MCF) that expresses what proportion of the effluent would be anaerobically digested in the open lagoons. BEy = MEPy,ww,treatment * GWP_CH4 + MEPy,s,treatment * GWP_CH4

2)-1 2)-2 = 2,168 (tonnes/yr) * 21 + 0 (tonnes/yr) * 21 = 45,520 (tCO2e/yr)

2)-1

MEPy,ww,treatment = Qy,ww * CODy,ww,untreated * Bo,ww * MCFww,treatment = 96,000 (m3/yr) * 0.1344 (tonnes/m3) * 0.21 (kg CH4/kg.COD) * 0.8 = 2,168 (tonnes/yr)

2)-2

MEPy,s,treatment = 0 (tonnes/yr)(Methane emission potential of the sludge treatment system is considered zero as there is no emission from sludge.)

3) Baseline electricity generation emissions (BEgrid)

BEgrid = EP BIO * CEFgrid = 4,138 (MWh/yr) * 0.509 (kg CO2e/kWh) = 2,106 (tCO2e/yr)

Estimating the Project emissions: The project activity emission will be calculated using the following: Due to the project activity, the emission will be from the electricity used for the project, emission through treated wastewater, emission through the final sludge produced, emission through capture and flare system and emission through dissolved methane in treated wastewater.


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PEy = PEy, power + PEy,ww,treated + PEy,s,final + PEy,fugitive + PEy,dissolved

4) 5) 6) 7) 8) = 117 (tCO2e/yr) + 11,380 (tCO2e/yr) + 0 (tCO2e/yr) + 5,691 (tCO2e/yr) + 202 (tCO2e/yr) = 17,390 (tCO2e/yr)

4) Emissions from electricity or diesel consumption (PEy,power)

PEy,power = Electricity consumed by the auxiliary equipment (MWh/yr) * Grid emission factor (t CO2/MWh)

= 230.4 (MWh) * 0.509 (kg CO2e/kWh) = 117 (tCO2e/yr)

5) Emissions from degradable organic carbon in treated wastewater (PEy,ww,treated)

PEy,ww,treated = Qy,ww * CODy,ww,treated * Bo,ww * MCFww,final * GWP_CH4 = 96,000 (m3/yr) * 0.02688 (tonnes/m3) * 0.21 (kg CH4/kg.COD) * 1.0 * 21 = 11,380 (tCO2e/yr)

6) Emissions from anaerobic decay of the final sludge produced (PEy,s,final)

PEy,s,final = Sy,final * DOCy,s,final * MCFs,final * DOCF * F * 16/12 * GWP_CH4 = 0 (tCO2e/yr)

7) Emissions from methane release in capture and flare systems (PEy,fugitive)

PEy,fugitive = PEy,fugitive,ww + PEy,fugitive,s

7)-1 7)-2 = 5,690 (tCO2e/yr) + 0 (tCO2e/yr) = 5,690 (tCO2e/yr)

7)-1

PEy,fugitive,ww = (1 - CFEww) * MEPy,ww,treatment * GWP_CH4 7)-1-1

= (1 - 0.9) * 2,710 (tonnes /yr) * 21 = 5,691 (tCO2e/yr)

7)-1-1

MEPy,ww,treatment = Qy,ww * CODy,ww,untreated * Bo,ww * MCFww,treatment = 96,000 (m3/yr) * 0.1344 (tonnes/m3) * 0.21 (kg CH4 / kg COD) * 1.0 = 2,710 (tonnes/yr)

7)-2

PEy,fugitive,s = (1 - CFEs) * MEPy,s,treatment * GWP_CH4 7)-2-1

= (1 - 0.9) * 0 (tonnes /yr) * 21 = 0 (tCO2e/yr)

7)-2-1

MEPy,s,treatment = Sy,untreated * DOCy,s,untreated * DOCF * F * 16/12 * MCFs,treatment = 0 (tonnes/yr)

8) Emissions from dissolved methane in treated wastewater (PEy,dissolved)


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PEy,dissolved = Qy,ww * [CH4]y,ww,treated * GWP_CH4 = 96,000(m3/yr) * 10－4 (tonnes/m3) * 21 = 202 (tCO2e/yr)

Leakage: As per AMS-I.D., paragraph 12 and AMS-III.H., paragraph 8: No leakage calculation is required since the equipment is not being transferred to or from another activity.

Emission Reduction: ERy = Total Baseline emission - (Total PEy + Total Leakagey)

= 47,626 (tCO2e/yr) - (17,390 (tCO2e/yr) + 0 (tCO2e/yr)) = 30,236 (tCO2e/yr)

B.6.4 Summary of the ex-ante estimation of emission reductions: >>

Year Estimated

emission in the baseline (tCO2 e)

Estimated emission of project

activity (tCO2 e)

Estimated leakage (tCO2 e)

Estimated emission reduction

(tCO2 e)

2009 47,626 17,390 0 30,236 2010 47,626 17,390 0 30,236 2011 47,626 17,390 0 30,236 2012 47,626 17,390 0 30,236 2013 47,626 17,390 0 30,236 2014 47,626 17,390 0 30,236 2015 47,626 17,390 0 30,236 Total (t-CO2 e)

333,382 121,730 0 211,652


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B.7 Application of a monitoring methodology and description of the monitoring plan:

B.7.1 Data and parameters monitored:

Data / Parameter: Qy,ww Data unit: m3/yr Description: Volume of wastewater treated Source of data to be used:

Electronic measurement

Value of data 96,000 Description of measurement methods and procedures to be applied:

The data is measured continuously and the measurements are taken using flow meters electronically.

QA/QC procedures to be applied:

The flow meter undergo maintenance / calibration subject to appropriate industry standards.

Any comment: Used for the project emission and baseline emissions calculation.

Data / Parameter: CODy,ww,untreated Data unit: tonnes/m3

Description: Chemical oxygen demand of the wastewater entering the anaerobic treatment reactor/system with methane capture

Source of data to be used:

On-site sampling/off-site analysis

Value of data 0.1344 Description of measurement methods and procedures to be applied:

Sampling shall be done on-site and analysis is carried out the off -site lab adhering to internationally accepted standards and archived electronically. Monthly average values are used for the estimation of emissions.


The data are cross-checked with samples analyzed by a external accredited laboratories once in 3 months.

Any comment: N/A Data / Parameter: CODy,ww,treated Data unit: tonnes/m3

Description: Chemical oxygen demand of the treated wastewater leaving the new anaerobic digester system

Source of data to be used:

On-site sampling/off-site analysis


Sampling shall be done on-site and analysis is carried out the off -site lab adhering to internationally accepted standards and archived electronically. Monthly average values are used for the estimation of emissions.


The data are cross-checked with samples analyzed by a external accredited laboratories once in 3 months.


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Any comment: N/A Data / Parameter: Auxiliary electricity consumed by the biogas plant Data unit: MWh/yr Description: Electricity consumed by the auxiliary equipment Source of data to be used:

Electricity meter is used.


Electricity is be continuously metered through the use of an electricity meter.


Electricity meters undergo maintenance/calibration according to appropriate industry standards.

Any comment: The data is used to determine the emissions arising from electricity consumption. Data / Parameter: Electricity Data unit: kWh Description: Amount of electricity generated by the Project Source of data to be used:

Electricity meter is used.

Value of data 600 Description of measurement methods and procedures to be applied:

Electricity is be continuously metered through the use of an electricity meter.


The data is used to determine the emissions arising from electricity consumption.

Any comment: N/A Data / Parameter: Biogas generation from the reactor Data unit: Nm3/yr Description: Biogas flow rate at digester outlet Source of data to be used:


Value of data 4,668,684 Description of measurement methods and procedures to be applied:

Electronically measured using flow meter continuously. The flow meter undergo maintenance / calibration subject to appropriate industry standards.


Continuously monitored. The flow meter undergo maintenance / calibration subject to appropriate industry standards.

Any comment: N/A


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Data / Parameter: Biogas flow at power generating unit inlet Data unit: Nm3/yr Description: Biogas flow rate at power generating unit inlet Source of data to be used:


Value of data About 43.6 % of Biogas generated from the reactor Description of measurement methods and procedures to be applied:

On-site metering using electronic flow meters.


Flow meters undergo maintenance/calibration according to appropriate industry standards.

Any comment: Used for project emissions and emissions reduction calculation. Data / Parameter: Biogas flow into flare Data unit: Nm3/yr Description: Volumetric flow rate Source of data to be used:


Value of data About 56.4 % of Biogas generated from the reactor Description of measurement methods and procedures to be applied:

On-site metering using electronic flow meters.


Flow meters undergo maintenance/calibration according to appropriate industry standards.

Any comment: Used for project emissions and emissions reduction calculation. Data / Parameter: Biogas methane concentration Data unit: % Description: Biogas CH4 content Source of data to be used:

Actual measurement

Value of data 65 Description of measurement methods and procedures to be applied:

Electronic on-site sample analysis. At least quarterly Interval to satisfy statistical 95% confidence level.


Sampling is carried out, adhering to internationally recognized procedures. This is being carried out at least quarterly.

Any comment: Used for project emissions and emissions reduction calculation.


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Data / Parameter: Temperature of the exhaust gas in flare Data unit: °C Description: Temperature of the exhaust gas from flare Source of data to be used:


Value of data - Description of measurement methods and procedures to be applied:

Measurement of temperature of the exhaust gas stream in the flare electronically. A temperature of above 500 °C indicates that a significant amount of gases are still being burnt and that the flare is operating.


The flame detectors are kept serviced as per manufacturer’s recommendation as and when required.

Any comment: N/A Data / Parameter: Duration of 500 °C in flare Data unit: Min/hour Description: Duration of sustenance of 500 °C in flare Source of data to be used:



An electronic flame detector will be used to determine the minutes in each hours for which the temperature of 500 °C occurs in a closed flare.


The temperature duration monitors are kept serviced as per manufacturer’s recommendation as and when required.

Any comment: Only applicable in the case of use of a default value. Data / Parameter: Sludge application Data unit: Tonnes /yr Description: Quantity of sludge removed from the treatment system and its application such as

in farms, plantations, etc. Source of data to be used:

Measurement of truck weight and application of the sludge


Sludge removal and its application will be measured whenever the sludge is removed from the biogas reactor and open lagoon system and a record will be maintained in the plant.


Measurement are carried out adhering to internationally recognized procedures.

Any comment: N/A


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B.7.2 Description of the monitoring plan:

>> Existing factory workers will double as the plant worker. An existing factory operator of the ADI-Digester and power generating facility will be trained on equipment operation, data recording, reporting, and operation, maintenance, and emergency procedures. The operator will be in charge of checking for leaks and of the logging of data. The existing facility supervisor will consolidate all of the data Project participants will keep electronic copies and paper copies for backup purposes. Monitoring This plant will be responsible for the execution of the monitoring plan. It will collect and store relevant data in a systematic and reliable way, evaluate them regularly, and ensure the availability of pertinent information for verification. An electronic spreadsheet file will be kept to record and manage all monitored variables and will be regularly presented to the DOE for verification. Quality assurance and quality control Calibration will be carried out according to international standards. This plant will take responsibility for quality assurance and quality control for recording, maintaining and archiving data. This plant will also provide enough staff in charge of data collection and monitoring with necessary training in order to improve the efficiency of their work. Data logging, presentation and storing Daily operation and maintenance log books will be maintained on real time basis by responsible operators. They will be able to provide detailed on-the spot information about the operation of the plant. Any distinguishing event will be reported and recorded as special log.


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B.8 Date of completion of the application of the baseline and monitoring methodology and the name of the responsible person(s)/entity(ies) >>

Date of completion: 13/03/2007 Kanematsu Corporation SEAVANS NORTH, 2-1, Shibaura 1-chome, Minato-ku, Tokyo, Japan Tel: +81-3-5440-8435 Fax: +81-3-5440-6518 E-mail：[email protected] Kanematsu Corporation is the CDM advisor to the Project and is also a project participant listed in Annex 1.

SECTION C. Duration of the project activity / crediting period C.1 Duration of the project activity: C.1.1. Starting date of the project activity: >>

01/04/2007 C.1.2. Expected operational lifetime of the project activity: >>

14 years and 0 month C.2 Choice of the crediting period and related information: C.2.1. Renewable crediting period C.2.1.1. Starting date of the first crediting period: >>

01/04/2009


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C.2.1.2. Length of the first crediting period: >>

7 years and 0 month C.2.2. Fixed crediting period: C.2.2.1. Starting date: >>

Not applicable C.2.2.2. Length: >>

Not applicable SECTION D. Environmental impacts >> D.1. If required by the host Party, documentation on the analysis of the environmental impacts of the project activity: >>

The environment impact analysis for this project is not required in view of the domestic system in Thailand. The analysis, however, was carried out in accordance of EIA check list.

1. Will the construction, operation or termination have a risk of causing physical changes in the

community (topographical changes, land use or changes of lakes and ponds)? Yes, less than one hectare of land which is located in the factory where production activity is under way. (Is the likelihood of being significantly influenced high?) No, the aforesaid land is an empty land in no use.

2. Will the construction or operation of the project use lands, water, substance or energy: among others, deficient natural resources like non-renewable energy? Yes, see the above for the land. And the plant construction includes materials for reactor tanks (Digester), piping materials, power generating unit and other equipment. (Is the likelihood of being significantly influenced high?) No, only limited materials are utilized.

3. Will the project have a risk of use, storage, transport, disposal or production of substance or materials, which are or may be harmful to human health or environments? Yes, there is flammable biogas but a large amount of gas is not stored in the site. (Is the likelihood of being significantly influenced high?) No, the biogas is used for production activity, while its surplus is broken by means of the flare system technology. The biogas is not stored in the site, while its delivery is supported by the system technology of the short pipeline.


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4. Will the project generate solid wastes during the construction, operation or termination of the project? No, it will not generate significant solid wastes except those related to usual construction and operation activities. Those wastes will be safely taken off from the site and they will be cleared out.

5. Will the project release contaminations or dangerous and harmful materials? No, there is mainly carbon dioxide except combustion gas. A large amount of methane gas (greenhouse gas with harmfulness 21 times as much as carbon dioxide) is emitted through a series of ponds, and therefore emission of carbon dioxide will be greatly improved if compared with the current state. (Is the likelihood of being significantly influenced high?) This will provide major favourable impacts to the environment and it is one of aims to commence the project.

6. Will the project generate noise, vibration, light diffusion, thermal energy or electro magnetic radiation? No, the power generating unit and the blower generate a little noise. (Is the likelihood of being significantly influenced high?) The flare system is operated only when the system requires an emergent backup due to the gas explosion or the power generating unit stops. The power generating unit is designed in consideration of atmospheric noise; therefore the noise is negligible. This is the case if in view of the fact that there is no residence in the neighbourhood.

7. Will the project have risks of causing land or water contamination by releasing contaminant from ground surfaces, surface moisture, groundwater, coasts or the sea? No, the wastewater in the reactor tank will not be penetrated into the soil by means of tests by the factory.

8. Will the project have a risk of causing an accident during the construction or operation of the project having exerted an influence on human health or environments? No, there is likely a fire although it is rare. (Is the likelihood of being significantly influenced high?) The pond system is now opened directly to the atmosphere and it generates biogas which is a significant risk for fires; hence the Digester construction will place restrictions on those fire risks.

9. Is there any nearby place or area of which pollution level exceeds the existing legal environmental standards and which has been contaminated or environmentally damaged under the influence of the project? No, the proposed plant will be constructed on site in the existing factory; therefore, it will be subject to all of the related regulations.

D.2. If environmental impacts are considered significant by the project participants or the host Party, please provide conclusions and all references to support documentation of an environmental impact assessment undertaken in accordance with the procedures as required by the host Party: >>

The project makes limited environmental impacts and positive environmental impacts (alleviation of greenhouse gas emission and fuel reduction by the grid electric energy) are more important than negative environmental impacts. Negative environmental impacts from the digester and combustion system are negligible and their influences are not significant. Consequently, the environmental impact analysis is not required.


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SECTION E. Stakeholders’ comments >> E.1. Brief description how comments by local stakeholders have been invited and compiled: >>

Comments of each of stakeholders about the project were received by project implementing persons of the Japanese party at hearings held in August and December, 2006 when they visited Bangkok.

E.2. Summary of the comments received: >>

The specific comments about the project are as follows: * PORNVIRAI INTERNATIONAL GROUP TRADING Co., Ltd (PVL) (the project participant)

- Residents living in the vicinity; they give endorsement to the project because it can be an odor control to their labour environments.

- They open their arms to the project because they can make efficient use of renewable biogas energy.

- They bid welcome to the project because the wastewater treatment is now a major material. * DEDE (Department of Alternative Energy Development and Efficiency)

- They welcome introduction of renewable energy project. - They welcome implementation of the project as CDM project. - They estimate the worth of efficient use of energy by the project so that the project can set a

good example for the wastewater treatments improvement of lots of food factories located in Thailand.

* Surrounding residents - The project achieved their understanding of its odor reduction. - The present situation of releasing directly from generating a large quantity of biogas may pose

them significant fire risks (hazard) and thus a new construction of the project gained a better comprehension of its restriction of these fire risks.

Further hearings hereafter shall be held to receive comments from the following organizations: * ONEP (Office of Natural Resources and Environment Policy and Planning) * Tuarua District (local governmental unit) * PEA (Provincial Electricity Authority) Local power distribution public corporation

E.3. Report on how due account was taken of any comments received: >>

There is now no contrary view or claim to the project. Instead the project seems to be welcomed in expectation of improvement of the environmental issues in the surrounding area and district. The proposed power generating unit shall be designed to be given to the attention to its combustion gas including compliance with the related regulations.


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Annex 1

CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY Organization: Kanematsu Corporation Street/P.O.Box: Shibaura1-2-1 Building: SEVANS NORTH City: Minato-ku State/Region: Tokyo Postfix/ZIP: 105-8005 Country: Japan Telephone: - FAX: - E-Mail: - URL: http://www.kanematsu.co.jp/ Represented by: President Yoshihiro Miwa Title: General Manager Salutation: Mr. Last Name: Gondaira Middle Name: - First Name: Taizo Department: Cable & Power Projects Department Mobile: - Direct FAX: +81-3-5440-6518 Direct tel: +81-3-5440-9080 Personal E-Mail: [email protected]


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CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY Organization: Pornvilai International Group Trading Co.,Ltd. Street/P.O.Box: 310 Charansanitwong Rd., Bangyeekhan, Building: - City: Bangpolad State/Region: Bangkok Postfix/ZIP: 10700 Country: Thailand Telephone: - FAX: - E-Mail: - URL: - Represented by: Executive Director Krittipongse Phatcharapinyopong Title: Executive Director Salutation: Mr. Last Name: Phatcharapinyopong Middle Name: - First Name: Krittipongse Department: - Mobile: - Direct FAX: +66-2-433-1336 Direct tel: +66-2-424-0515 Personal E-Mail: [email protected]


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CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY Organization: Bio Natural Energy Company Limited (BNE) Street/P.O.Box: 159 Sukhumvit 21 North Klongtoey Building: 22nd Floor Serm-Mit Tower City: Wattana State/Region: Bangkok Postfix/ZIP: 10110 Country: Thailand Telephone: - FAX: - E-Mail: - URL: - Represented by: President Mr. Iriya Hironobu Title: President Salutation: Mr. Last Name: Iriya Middle Name: - First Name: Hironobu Department: - Mobile: - Direct FAX: +66-2260-8525-6 Direct tel: +66-2260-8524 Personal E-Mail: [email protected]


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Annex 2

INFORMATION REGARDING PUBLIC FUNDING Public funds are not invested in the project.


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Annex 3

BASELINE INFORMATION Baseline Data A. Lagoon condition

The baseline shall be set. The setting of baseline wastewater and COD concentration is shown in Table 1

Table 1 Setting of Baseline Wastewater and COD Load Month

Item Unit Value Remarks

Wastewater volume m3/d 300 -

COD concentration (Analysis base) mg/l 134,400 Actual measurement

COD load kg COD/day 40,320 ‐ Operation days Days/yr 320 -

Project data A. Operating days, GE specifications, GE operation conditions, Annual power generation

Operating days of this project are shown in Table 2.

Table 2 Project Operating Days

No. Item Value Unit 1 Days of releasing

wastewater of ethanol factory

320 day/yr

2 Hours of releasing wastewater of ethanol factory

24 hour/day

3 Project operating days 320 day/yr 4 Operating hours of

power generating unit 320*24=

7,680hour/yr

5 Flaring operating hours

Surplus and emergent time

hour/yr

The technical specifications of the GE power generating unit for the project are shown in Table 3.

Table 3 Technical Specifications of Power Generating Unit

No Item Value Unit Remarks 1 Power generation output 600 kW Based on the project design 2 Power generation voltage 380 V - 3 Frequency 50 Hz - 4 Generating efficiency 35 % Based on the project design 5 Fuel Consumption 265.3 Nm3 Gas /h -


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The operation conditions of power generating unit for the project are shown in Table 4.

Table 4 Operation Conditions of Power Generating Unit No Item Value Unit Remarks 1 Operating load factor - % - 2 Accident(failure)

factor 5 % 5% of annual operating hours

3 Operation margin 0 % - 4 Loss of auxiliary

machine of power generating unit

5 % Supplementary equipment (pump and cooling installation) to the power generating unit covering power supply source for biogas recovery blower.

5 Transmission loss 0.5 % - 6 Regular maintenance 30 day/yr To be carried out around the same time as the factory

shutdown. B. Biogas attributes, Biogas generation, Digester specifications

The technical specifications of digester are shown in Table 5.

Table 5 Technical Specifications of Digester－Source: ADI Systems Inc.

Item Value Unit Digester capacity 10,000 m3

Average design wastewater volume 300 m3/d Average design inflow COD concentration 134,400 mg/l Organic loading 4.032 kg COD/ m3･d Temperature of reactor 35～38 °C Anaerobic hourly retention time 33 Day Expected outflow COD concentration 26,880 mg/l Expected outflow BOD concentration 3,000～4,000 mg/l Expected COD removal efficiency 80 %


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C. Newly anaerobic wastewater treatment facilities Application process is shown in Fugire 1. This process is composed by anaerobic fermentation reactor (ADI-BVF REACTOR), and it liquefies, and acid formation, acetic acid formation, methane formation progress on it. And, it gets the alkaline collection of the treatment water, effect on planting seed of acid formation fungus by a part of the reactor treatment water being returned. Methane fermentation reactor of lagoon type in the base, the concrete wall is installed in the circumference, and lagoon wall, lagoon slope, the bottom part, and so on are covered and lining with PVC. The top of lagoon is covered with geomembrane cover, and a PVC pipe is installed in the bottom part, and wastewater is made to circulate in it by the pump. The pump, blower are controlled in the gas control room. As for wastewater process and the generated gas, DCS is controlled.

PILOT GAS

EXISTING EFFLUENTHOLDING

POND

INFLUENT WASTE WATER

EQ,POND

(Existing)

INFLUENT PUMPS

(25 m3/h each)

INFLUENT WASTE WATER

EQVALIZED, SCREENED AND

COOLED TO 35-38℃

SAMPLE

RECYCLE PUMP

(100 m3/h)

WASTE SLUDGE

ADI-BVF

REACTOR

(10,0003m)

BIOGAS BLOWER

INTERNAL

DEMAND

STANDARD BIOGAS FLARE

VENT STACK

ELECTRIC

GENERATION

SYSTEM

FLAME TRAP

ASSEMBLY

SEDIMENT

MOISTURE TRAP

BIOGAS BLOWER

MECHANIZED

COOLING SYSTEM

(MCS)

600 kW

Fugire 1 Application process Main equipment ・Influent Pumps ・Mechanized Cooling System (MCS) ・ADI-BVF Unit (Included Circulation pump) ・Biogas Electric Generation Unit ・Biogas Unit (Sediment Moisture Trap, Biogas Blower, Flame Trap, Flare Stack etc.)


44

D. Internal rate of return (IRR) 1) without CERs

2) with CERs

《Cash flow statement》 (Initial investment ： 3.32 Million USD, without CERs)（Unit：Million USD）Profit-and-loss statement Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023Sales Electric generation income 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374

CERs＜Total＞ 0.37 0.37 0.37 0.37 0.37 0.37 0.37 0.37 0.37 0.37 0.37 0.37 0.37 0.37

CostDesulfurization chemical 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02Lubricating oil 0.00 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005NaOH 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07Gas engine maintenance cost 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03Other maintenance cost 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01＜Total＞ 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14

Depreciation 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 - - - - 　Operating income -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 0.2 0.2 0.2 0.2 Nonoperating expense Interest cost 0.0% - - - - - - - - - - - - - - 　Current profits -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 0.2 0.2 0.2 0.2 Corporation tax Corporation tax etc. 30% - - - - - - - - - - 0.1 0.1 0.1 0.1 Current income -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 0.2 0.2 0.2 0.2 Cumulative profits -0.1 -0.1 -0.2 -0.3 -0.3 -0.4 -0.5 -0.6 -0.6 -0.7 -0.5 -0.4 -0.2 -0.0

Cash flow statement Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023Current profits 　 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 -0.1 0.2 0.2 0.2 0.2 Depreciation 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 - - - - Total cash inflows 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 Corporation tax etc. payment - - - - - - - - - - 0.1 0.1 0.1 0.1 Repayment of borrowed money 　 - - - - - - - - - - - - - - Total cash-out flow - - - - - - - - - - 0.1 0.1 0.1 0.1 Cash flow 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

Balance sheet Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023Available assets（Excess funds） 0.2 0.5 0.7 0.9 1.1 1.4 1.6 1.8 2.1 2.3 2.5 2.6 2.8 2.9 Fixed assets(Depreciation assets) 3.3 3.0 2.7 2.4 2.2 2.0 1.8 1.6 1.4 1.3 1.2 1.0 0.9 0.8 0.8 Total assets（Assets section） 3.2 3.1 3.1 3.1 3.1 3.1 3.2 3.3 3.4 3.5 3.5 3.6 3.6 3.7 Borrowed money - - - - - - - - - - - - - - Total liabilities - - - - - - - - - - - - - - Capital 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 Surplus -0.1 -0.2 -0.2 -0.2 -0.2 -0.2 -0.1 -0.1 0.0 0.1 0.2 0.2 0.3 0.4 Total shareholders' equity 3.2 3.1 3.1 3.1 3.1 3.1 3.2 3.3 3.4 3.5 3.5 3.6 3.6 3.7 Total liabilities, shareholders' equity 3.2 3.1 3.1 3.1 3.1 3.1 3.2 3.3 3.4 3.5 3.5 3.6 3.6 3.7

Break-even calculation Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023After-tax cash flow 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2Accumulated after-tax cash flow 0.2 0.5 0.7 0.9 1.1 1.4 1.6 1.8 2.1 2.3 2.5 2.6 2.8 2.9Accumulated after-tax cash flow- Investment capital -3.1 -2.9 -2.6 -2.4 -2.2 -1.9 -1.7 -1.5 -1.2 -1.0 -0.9 -0.7 -0.5 -0.4Internal rate of return [IRR] Excepted interest, after-tax ） #NUM! -6.2% -1.7%（IRR calculation data） -3.3 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2Internal rate of return [IRR] （Excepted interest, before-tax） #NUM! -6.2% -0.4%（IRR calculation data） -3.3 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2

Salvage value 10% Purchased power price 3.24 Baht/kWh = 0.09 US$/kWhInitial investment(Million USD) 3.32 CERs price 11.56 US$/t CO2Depreciation(Million USD) 0.3 Exchange rate 35.82 Baht/US$Depreciation rate 10%

Payout period Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022-3.3 -3.1 -2.9 -2.6 -2.4 -2.2 -1.9 -1.7 -1.5 -1.2 -1.0 -0.9 -0.7 -0.5 -0.4

1 1 1 1 1 1 1 1 1 1 1 1 1 10 0 0 0 0 0 0 0.0 0 0 0 0 0 1 15.0 year

Project income Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022Total power generation MWh 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138GHG emission reduction t CO2

Setting item Setting item

《Cash flow statement》 (Initial investment ： 3.32 Million USD, Crediting period ：14 years, CERs price：11.56US$)（Unit：Million USD）Profit-and-loss statement Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023Sales Electric generation income 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374 0.374

CERs 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35＜Total＞ 0.72 0.72 0.72 0.72 0.72 0.72 0.72 0.72 0.72 0.72 0.72 0.72 0.72 0.72

CostDesulfurization chemical 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02Lubricating oil 0.00 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005 0.005NaOH 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07Gas engine maintenance cost 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03Other maintenance cost 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01＜Total＞ 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14 0.14

Depreciation 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 - - - - 　Operating income 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.6 0.6 0.6 0.6 Nonoperating expense Interest cost 0.0% - - - - - - - - - - - - - - 　Current profits 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.6 0.6 0.6 0.6 Corporation tax Corporation tax etc. 30% 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.2 0.2 0.2 0.2 Current income 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.4 0.4 0.4 0.4 Cumulative profits 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 2.4 2.8 3.2 3.6

Cash flow statement Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023Current profits 　 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.6 0.6 0.6 0.6 Depreciation 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 - - - - Total cash inflows 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 Corporation tax etc. payment 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.2 0.2 0.2 0.2 Repayment of borrowed money 　 - - - - - - - - - - - - - - Total cash-out flow 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.1 0.2 0.2 0.2 0.2 Cash flow 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.4 0.4 0.4 0.4

Balance sheet Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023Available assets（Excess funds） 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.4 5.8 6.2 6.6 Fixed assets(Depreciation assets) 3.3 3.0 2.7 2.4 2.2 2.0 1.8 1.6 1.4 1.3 1.2 1.0 0.9 0.8 0.8 Total assets（Assets section） 3.5 3.7 3.9 4.2 4.4 4.7 5.1 5.4 5.7 6.1 6.4 6.7 7.0 7.3 Borrowed money - - - - - - - - - - - - - - Total liabilities - - - - - - - - - - - - - - Capital 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 3.3 Surplus 0.2 0.4 0.6 0.8 1.1 1.4 1.7 2.1 2.4 2.8 3.1 3.4 3.7 4.0 Total shareholders' equity 3.5 3.7 3.9 4.2 4.4 4.7 5.1 5.4 5.7 6.1 6.4 6.7 7.0 7.3 Total liabilities, shareholders' equity 3.5 3.7 3.9 4.2 4.4 4.7 5.1 5.4 5.7 6.1 6.4 6.7 7.0 7.3

Break-even calculation Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023After-tax cash flow 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.4 0.4 0.4 0.4Accumulated after-tax cash flow 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.4 5.8 6.2 6.6Accumulated after-tax cash flow- Investment capital -2.8 -2.3 -1.8 -1.3 -0.8 -0.3 0.1 0.6 1.1 1.6 2.0 2.4 2.8 3.3Internal rate of return [IRR] Excepted interest, after-tax ） -9.0% 8.0% 11.2%（IRR calculation data） -3.3 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.4 0.4 0.4 0.4Internal rate of return [IRR] （Excepted interest, before-tax） -4.4% 11.7% 15.0%（IRR calculation data） -3.3 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6 0.6

Salvage value 10% Purchased power price 3.24 Baht/kWh = 0.09 US$/kWhInitial investment(Million USD) 3.32 CERs price 11.56 US$/t CO2Depreciation(Million USD) 0.3 Exchange rate 35.82 Baht/US$Depreciation rate 10%

Payout period Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022-3.3 -2.8 -2.3 -1.8 -1.3 -0.8 -0.3 0.1 0.6 1.1 1.6 2.0 2.4 2.8 3.3

1 1 1 1 1 1 0 0 0 0 0 0 0 00 0 0 0 0 0.70191 0 0.0 0 0 0 0 0 0 6.7 year

Project income Fiscal year 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022Total power generation MWh 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138 4,138GHG emission reduction t CO2 30,236 30,236 30,236 30,236 30,236 30,236 30,236 30,236 30,236 30,236 30,236 30,236 30,236 30,236

Setting item Setting item


45

Annex 4

MONITORING INFORMATION Monitoring This plant will be responsible for the execution of the monitoring plan. It will collect and store relevant data in a systematic and reliable way, evaluate them regularly, and ensure the availability of pertinent information for verification. An electronic spreadsheet file will be kept to record and manage all monitored variables and will be regularly presented to the DOE for verification. Quality assurance and quality control Calibration will be carried out according to international standards. This plant will take responsibility for quality assurance and quality control for recording, maintaining and archiving data. This plant will also provide enough staff in charge of data collection and monitoring with necessary training in order to improve the efficiency of their work. Data logging, presentation and storing Daily operation and maintenance log books will be maintained on real time basis by responsible operators. They will be able to provide detailed on-the spot information about the operation of the plant. Any distinguishing event will be reported and recorded as special log.

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CLEAN DEVELOPMENT MECHANISM PROJECT DESIGN … · 2018. 6. 28. · CLEAN DEVELOPMENT MECHANISM...

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