CLEAN DEVELOPMENT MECHANISM PROJECT DESIGN DOCUMENT · PDF fileproject design document form (cdm-ssc-pdd) - version 03 cdm – executive board 1 clean development mechanism project

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

CDM – Executive Board

1

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



2

Revision history of this document

Version Number

Date Description and reason of revision

01 21 January

2003

Initial adoption

02 8 July 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 December

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.

http://cdm.unfccc.int/Reference/Documents



3

SECTION A. General description of small-scale project activity

A.1 Title of the small-scale project activity:

>>

Project title: Henan Suixian Longyuan Methane Recovery Project

Version of document: 01

Date of the document: 31/07/2011

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

>>

The Henan Suixian Longyuan Methane Recovery Project (hereinafter referred as the “Project”) developed

by Henan Suixian Longyuan Paper Co., Ltd. (hereinafter referred as the “Project owner”) is a wastewater

methane recovery and heat generation project located at north industry cluster area of Sui county,

Shangqiu city, Henan province, China.

The Project is to recover biogas generated from anaerobic treatment of waste water from paper production

and utilize it as co-fuel in a dual fuelled boiler to generate thermal energy (steam) for paper production

process. The paper production line generates about 16,000m3 of wastewater per day and the COD is

around 3,000mg/l.

In the absence of the proposed project activity, waste water from the paper production line is treated in

anaerobic lagoons where methane-rich biogas is generated and emitted to the atmosphere directly; and

steam is supplied by onsite coal fired boilers. The project constructs efficient anaerobic reactor (Internal

Circulation Reactor), biogas recovery and purification system and dual fuel (coal and biogas) boiler

system. Therefore, the Project will reduce greenhouse gas (GHG) emissions through avoidance of

methane emissions to the atmosphere from wastewater treatment and reduction of coal consumption for

steam generation. It is estimated that the proposed project activity will reduce 65,191 tCO2e of GHG

annually, in combining methane emission avoidance of 48,800 tCO2e and biogas based heat generation of

16,391 tCO2e.

The baseline scenario of the project is anaerobic lagoon system without methane recovery for waste water

treatment component and coal fired boiler for steam generation component.

The Project will contribute to sustainable development of the host country by:

Reducing health damage and danger from biogas diffusion, such as odor and danger of

explosion of methane;

Reducing air pollution by SOx and PM from coal combustion, and reducing coal ash waste

generation; and

Increase the local employment;

In general, this project will contribute to the sustainable development of the local area.

A.3. Project participants:

>>



4

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)

People’s Republic of China

(host) Suixian Longyuan Paper Co., Ltd. No

Switzerland Bunge Emissions Holdings S.A.R.L. No

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

A.4.1. Location of the small-scale project activity:

>>

A.4.1.1. Host Party(ies):

>>

People’s Republic of China

A.4.1.2. Region/State/Province etc.:

>>

Henan Province

A.4.1.3. City/Town/Community etc:

>>

Sui county, Shangqiu city

A.4.1.4. Details of physical location, including information allowing the unique

identification of this small-scale project activity(ies):

>>

The proposed project locates at north industry cluster area of Suixian, Shangqiu city, Henan province,

China. The geographic site is at longitude 115°4′17″E and at latitude 34°28′5″N. The location of the

project is shown in the map of Figure1.



5

Figure 1 Location of the project



6

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

>>

Type and category

According to Appendix B to the simplified modalities and procedures for small-scale CDM project

activities, the project type, category and sectoral scope are determined as follows:

Methane recovery component:

Type III: Other project activities

Category III.H: Methane Recovery in Wastewater Treatment

Sectoral Scope 13: Waste handling and disposal

Biogas heat generation component:

Type I: Renewable energy projects

Category I.C: Thermal energy for the users with or without electricity

Sectoral Scope 1: Energy industries (renewable /non-renewable sources)

Technology of the project

The project introduces efficient Internal Circulation Reactor (IC reactor) instead of anaerobic lagoons to

recover biogas, the recovered biogas, after desulfuration, will be utilized as co-fuel in a dual fuelled boiler

to generate steam for paper production process. In case the boiler is not operating, biogas will be

bypassed to the emergency flare to be combusted. The system is shown in figure 2.

Figure 2 Wastewater treatment technology and methane recovery/utilization system

Key technical features of the project are showed in the table:

Table 1 Key technical factors of the equipments

No. Name Key technical factors Number

1 IC reactor Æ4.1x6.0m 2

Wastewater

Settlin pond

Aeration basin

Discharge

Sand leach

Settling pond

IC reactor

Pre-acid

Cycling pot

Dual fuel boiler

Biogas

Water

Steam

Paper production

Flare



7

2 Washing tower Æ1.0x10.3m 1

3 Water circulating pump P=0.35MPa 2

4 Sulfur separator Æ1.2x6.0m 1

5 Roots fan Q=19000～21000m3/h 4

6 Air compressor P=0.35MPa 1

7 Hold-up vessel 1

8 Chemical adding pump Q=170 ltr/h； P=0.7MPa 2

9 Nutrition adding pump Q=1.6 ltr/h； P=0.76MPa 2

10 Flare - 1

11 Pipeline, valve and

support -

All technologies involved in this project are from China, it does not involve international technology

transfer.

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

>>

The project will apply a 10-year fixed crediting period which means the fixed crediting period will be

from 01/01/2012 to 31/12/2021 and will generate an estimated totally 651,910tCO2e during the credit

period.

Years

Annual estimation of emission

reductions

in tonnes of CO2e

2012 65,191

2013 65,191

2014 65,191

2015 65,191

2016 65,191

2017 65,191

2018 65,191

2019 65,191

2020 65,191

2021 65,191

Total estimated reductions

(tonnes of CO2e)

651,910

Total number of crediting years 10

Annual average over the crediting

period of estimated reductions (tonnes

of CO2e)

65,191

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

>>

No public funding from parties included in Annex I is available to the project activity.



8

A.4.5. Confirmation that the small-scale project activity is not a debundled component of a

large scale project activity:

>>

According to paragraph 2 of Appendix C “the simplified modalities and procedures for small-scale CDM

project activities”, a small-scale project is considered a debundled component of a large project activity if

there is a registered small-scale activity or an application to register another small-scale activity:

With the same project participants;

In the same project category and technology;

Registered within the previous two years; and

Whose project boundary is within 1 km of the project boundary of the proposed small-scale activity.

The project participants confirm that none of the above mentioned conditions is applicable to this project

activity. The project proponents further confirm that they have not registered any small-scale CDM

activity or applied to register another small-scale CDM project activity within 1 km of the project

boundary, neither in the same project category and technology/measure, nor registered within the

previous two years.

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:

>>

The following approved baseline and monitoring methodologies and relevant tools are applied to the

proposed CDM project activity.

Methane Recovery component:

The approved small-scale CDM baseline and monitoring methodology AMS III.H. “Methane Recovery in

Wastewater Treatment” (Version 16.0) is applied to the methane recovery component of the project

activity. The methodology is obtained from:

http://cdm.unfccc.int/methodologies/DB/4ND00PCGC7WXR3L0LOJTS6SVZP4NSU

Biogas heat generation component:

The approved small-scale CDM baseline and monitoring methodology AMS I.C “Thermal energy for

user with or without electricity” (Version 19.0) is applied to the heat generation component of the project

activity. The methodology is obtained from:

http://cdm.unfccc.int/methodologies/DB/H2PMYUBPE9H1DP9S0WB470N5EKU1NP

Tools:

Approved methodological tool “Tool for the demonstration and assessment of additionality (version

05.2)” http://cdm.unfccc.int/methodologies/PAmethodologies/tools/am-tool-01-v5.2.pdf

“Tool to calculate the emission factor for an electricity system (Version 02.2)”.


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

>>

AMS-III.H (Version 16.0) is applicable to the methane recovery component of the project activities

http://cdm.unfccc.int/methodologies/DB/4ND00PCGC7WXR3L0LOJTS6SVZP4NSU


http://cdm.unfccc.int/methodologies/PAmethodologies/tools/am-tool-01-v5.2.pdf




9

because:

No. Technology/measure In the case of the project Applicability

1 This methodology comprises measures that

recover biogas from biogenic organic matter in

wastewater by means of one, or a combination,

of the following options:

(a) Substitution of aerobic wastewater or sludge

treatment systems with anaerobic systems with

biogas recovery and combustion;

(b) Introduction of anaerobic sludge treatment

system with biogas recovery and

combustion to a wastewater treatment plant

without sludge treatment;

(c) Introduction of biogas recovery and

combustion to a sludge treatment system;

(d) Introduction of biogas recovery and

combustion to an anaerobic wastewater treatment

system such as anaerobic reactor, lagoon, septic

tank or an on site industrial plant;1

(e) Introduction of anaerobic wastewater

treatment with biogas recovery and combustion,

with or without anaerobic sludge treatment, to an

untreated wastewater stream;

(f) Introduction of a sequential stage of

wastewater treatment with biogas recovery and

combustion, with or without sludge treatment, to

an anaerobic wastewater treatment system

without biogas recovery (e.g. introduction of

treatment in an anaerobic reactor with biogas

recovery as a sequential treatment step for the

wastewater that is presently being treated in an

anaerobic lagoon without methane recovery).

The project introduces

anaerobic IC reactor with

biogas recovery and

combustion as a sequential

treatment step for

wastewater that is presently

being treated in anaerobic

lagoons without biogas

recovery.

Thus the Project falls into

option (f)

Applicable

2 In cases where baseline system is anaerobic

lagoon the methodology is applicable if:

(a) The lagoons are ponds with a depth greater

than two meters, without aeration. The value for

depth is obtained from engineering design

documents, or through direct measurement, or by

dividing the surface area by the total volume. If

the lagoon filling level varies seasonally, the

average of the highest and lowest levels may be

taken;

(b) Ambient temperature above 15°C, at least

during part of the year, on a monthly average

basis;

(c) The minimum interval between two

consecutive sludge removal events shall be 30

days.

The baseline system is

anaerobic lagoon, where:

(a) the depth of the lagoons

is greater than 2 meters,

without aeration.

(b) Monthly average

ambient temperature of

the project site is higher

than 15 oC.

(c) The interval between

two consecutive sludge

removal events is

greater than 30 days

Applicable



10


3 The recovered biogas from the above measures

may also be utilised for the following

applications instead of combustion/flaring:

(a) Thermal or mechanical,2 electrical energy

generation directly;

(b) Thermal or mechanical, electrical energy

generation after bottling of upgraded biogas, in

this case additional guidance provided in Annex

1 shall be followed; or

(c) Thermal or mechanical, electrical energy

generation after upgrading and distribution, in

this case additional guidance provided in Annex

1 shall be followed:

(i) Upgrading and injection of biogas into a

natural gas distribution grid with no significant

transmission constraints;

(ii) Upgrading and transportation of biogas via a

dedicated piped network to a group of end users;

or

(iii) Upgrading and transportation of biogas (e.g.

by trucks) to distribution points for end users.

(d) Hydrogen production;

(e) Use as fuel in transportation applications after

upgrading.

The recovered methane is

utilized in a dual fuelled

boiler for thermal energy

generation directly, thus the

project is covered in 3(a).

Applicable

4 If the recovered biogas is used for project

activities covered under paragraph 3 (a), that

component of the project activity can use a

corresponding methodology under Type I.

The approved baseline and

monitoring methodology

AMS I.C. is used for the

heat utilization component

of the project activity

Applicable

5 For project activities covered under paragraph 3

(b), if bottles with upgraded biogas are sold

outside the project boundary, the end-use of the

biogas shall be ensured via a contract between

the bottled biogas vendor and the end-user. No

emission reductions may be claimed from the

displacement of fuels from the end use of bottled

biogas in such situations. If however the end use

of the bottled biogas is included in the project

boundary and is monitored during the crediting

period CO2 emissions avoided by the

displacement of fossil fuel can be claimed under

the corresponding Type I methodology, e.g.

AMS-I.C .Thermal energy production with or

without electricity..

The project is not covered

under paragraph 3 (b).

N/A


(c) (i), emission reductions from the

displacement of the use of natural gas are eligible

under this methodology, provided the


under paragraph 3 (c i).

N/A



11


geographical extent of the natural gas

distribution grid is within the host country

boundaries.


(c) (ii), emission reductions for the displacement

of the use of fuels can be claimed following the

provision in the corresponding Type I

methodology, e.g. AMS-I.C.


under paragraph 3 (c ii).

N/A

8 In particular, for the case of 3 (b) and (c) (iii), the

physical leakage during storage and

transportation of upgraded biogas, as well as the

emissions from fossil fuel consumed by vehicles

for transporting biogas shall be considered.

Relevant procedures in paragraph 11 of Annex 1

of AMS-III.H .Methane recovery in wastewater

treatment. shall be followed in this regard.


under paragraph 3 (c iii).

N/A


(b) and (c), this methodology is applicable if the

upgraded methane content of the biogas is in

accordance with relevant national regulations

(where these exist) or, in the absence of national

regulations, a minimum of 96% (by volume).


under paragraph 3（b）or 3

（c）

N/A

10 If the recovered biogas is utilized for the

production of hydrogen (project activities

covered under paragraph 3 (d)), that component

of the project activity shall use the corresponding

methodology AMS-III.O .Hydrogen production

using methane extracted from biogas.


under paragraph 3 (d).

N/A

11 If the recovered biogas is used for project

activities covered under paragraph 3 (e), that

component of the project activity shall use

corresponding methodology AMS-

III.AQ .Introduction of Bio-CNG in road

transportation..


under paragraph 3 (e).

N/A

12 New facilities (Greenfield projects) and project

activities involving a change of equipment

resulting in a capacity addition of the wastewater

or sludge treatment system compared to the

designed capacity of the baseline treatment

system are only eligible to apply this

methodology if they comply with the relevant

requirements in the .General guidelines to SSC

CDM methodologies.. In addition the

requirements for demonstrating the remaining

lifetime of the equipment replaced, as described

in the general guidelines shall be followed.

The Project is neither a

Greenfield project nor does

it involve any capacity

addition of the wastewater

treatment system.

N/A

13 The location of the wastewater treatment plant as

well as the source generating the wastewater

The location of the

wastewater treatment plant

Applicable



12


shall be uniquely defined and described in the

PDD.

as well as the source

generating the wastewater is

uniquely defined and is

described in the PDD.

14 Measures are limited to those that result in

aggregate emissions reductions of less than or

equal to 60 kt CO2 equivalent annually from all

Type III components of the project activity.

Annual emission reductions

achieved by the methane

recovery component of the

project is estimated to be

48.80 ktCO2e, which is less

than 60 ktCO2e.

Applicable

AMS I.C (Version 19.0) is applicable to the heat generation component of the project activity because:


1 This category comprises renewable energy

technologies that supply users1 with thermal energy

that displaces fossil fuel use. These units include

technologies such as solar thermal water heaters and

dryers, solar cookers, energy derived from

renewable biomass and other technologies that

provide thermal energy that displaces fossil fuel.

The project will generate

thermal energy (steam)

from biogas captured

through wastewater

treatment process and

displace steam that would

have been supplied by a

coal fired boiler.

Applicable

2 Biomass-based cogeneration systems consisting of

steam generator(s) and steam turbine(s) are included

in this category. For the purpose of this

methodology .cogeneration. shall mean the

simultaneous generation of thermal energy and

electrical energy in one process. Project activities

that produce heat and power in separate element

processes (for example, heat from a boiler and

electricity from biogas engine) do not fit under the

definition of cogeneration project.

This project does not

introduce any co-

generating system.

N/A

3 Emission reductions from a biomass cogeneration

system can accrue from one of the following

activities:

(a) Electricity supply to a grid;

(b) Electricity and/or thermal energy (steam or heat)

production for on-site consumption or for

consumption by other facilities;

(c) Combination of (a) and (b).


introduce any co-

generating system.

N/A

4 The total installed/rated thermal energy generation

capacity of the project equipment is equal to or less

than 45 MW thermal2 (see paragraph 6 for the

applicable limits for cogeneration project activities).

The aggregated installed

capacity of the dual-fuel

fired boiler is equivalent

to 18MWth, which is less

than 45MWth.

Applicable



13


5 For co-fired systems, the total installed thermal

energy generation capacity of the project

equipment, when using both fossil and renewable

fuel shall not exceed 45 MW thermal (see paragraph

6 for the applicable limits for cogeneration project

activities).




to 18MWth, which is less

than 45MWth.

Applicable

6 The following capacity limits apply for biomass

cogeneration units:

(a) If the project activity includes emission

reductions from both the thermal and electrical

energy components, the total installed energy

generation capacity (thermal and electrical) of the

project equipment shall not exceed 45 MW thermal.

For the purpose of calculating this capacity limit the

conversion factor of 1:3 shall be used for converting

electrical energy to thermal energy (i.e. for

renewable project activities, the maximal limit of 15

MW(e) is equivalent to 45 MW thermal output of

the equipment or the plant);

(b) If the emission reductions of the cogeneration

project activity are solely on account of thermal

energy production (i.e. no emission reductions

accrue from electricity component), the total

installed thermal energy production capacity of the

project equipment of the cogeneration unit shall not

exceed 45 MW thermal;

(c) If the emission reductions of the cogeneration

project activity are solely on account of electrical

energy production (i.e. no emission reductions

accrue from thermal energy component), the total

installed electrical energy generation capacity of the

project equipment of the cogeneration unit shall not

exceed 15 MW.


introduce any co-

generating system.

N/A

7 In case electricity and/or steam/heat produced by

the project activity is delivered to another facility or

facilities within the project boundary, a contract

between the supplier and consumer(s) of the energy

will have to be entered into specifying that only the

facility generating the energy can claim emission

reductions from the energy displaced.

The steam produced by

the Project is utilized

within the same plant.

N/A

8 Project activities that seek to retrofit or modify an

existing facility for renewable energy generation are

included in this category.

A dual-fuelled boiler is

being retrofitted for

renewable energy

generation.

Applicable

9 The capacity limits specified in the above

paragraphs apply to both new facilities and retrofit

projects. In the case of project activities that involve

the addition of renewable energy units at an existing

There is not renewable

energy units.

N/A



14


renewable energy facility, the total capacity of the

units added by the project should comply with

capacity limits in paragraphs 4 to 6 and should be

physically distinct4 from the existing units.

10 The capacity limits specified in the above

paragraphs apply to both new facilities and retrofit

projects. In the case of project activities that involve

the addition of renewable energy units at an existing

renewable energy facility, the total capacity of the

units added by the project should comply with

capacity limits in paragraphs 4 to 6 and should be

physically distinct4 from the existing units. factor

values from peer reviewed literature or from a

registered CDM project activity can be used,

provided that it can be demonstrated that the

parameters from these are comparable e.g. source of

biomass, characteristics of biomass such as

moisture, carbon content, type of kiln, operating

conditions such as ambient temperature.




to 18MWth,which is less

than 45MWth.

N/A

11 If solid biomass fuel (e.g. briquette) is used, it shall

be demonstrated that it has been produced using

solely renewable biomass and all project or leakage

emissions associated with its production shall be

taken into account in emissions reduction

calculation.

There is no solid biomass

fuel used.

N/A

12 If electricity and/or steam/heat produced by the

project activity is delivered to a third party i.e.

another facility or facilities within the project

boundary, a contract between the supplier and

consumer(s) of the energy will have to be entered

into that ensures there is no double-counting of

emission reductions.

The project activity

doesn’t deliver

electricity or heat to a

third party within the

project boundary. Heat

produced will only be

used by the project owner

itself; hence the starch

factory cannot be

considered a third party.

N/A

13 If the project activity recovers and utilizes biogas

for power/heat production and applies this

methodology on a stand alone basis i.e. without

using a Type III component of a SSC methodology,

any incremental emissions occurring due to the

implementation of the project activity (e.g. physical

leakage of the anaerobic digester, emissions due to

inefficiency of the flaring), shall be taken into

account either as project or leakage emissions.

The project activity also

involves a Type III

component of a SSC

methodology, as the

introduction of a

wastewater treatment with

biogas recovery of the

project activity is

applicable under the

methodology AMS

III.H.

N/A

14 Charcoal based biomass energy generation project This is no applicable to N/A



15


activities are eligible to apply the methodology only

if the charcoal is produced from renewable biomass

sources provided:

(a) Charcoal is produced in kilns equipped with

methane recovery and destruction facility; or

(b) If charcoal is produced in kilns not equipped

with a methane recovery and destruction facility,

methane emission from the production of charcoal

shall be considered. These emissions shall be

calculated as per the procedures defined in the

approved methodology AMS III.K.

Alternatively, conservative emission factor values

from peer reviews literature or from a registered

CDM project activity can be used, provided that it

can be demonstrated that the parameters from these

are comparable e.g. source of biomass,

characteristics of biomass such as moisture, carbon

content, type of kiln, operating conditions such as

ambient temperature.

the project activity since

there is no use of charcoal

in the project activity.

B.3. Description of the project boundary:

>>

As per AMS-III.H (Version 16.0), the project boundary is the physical, geographical site where the

wastewater and sludge treatment takes place. The project boundary for AMS-I.C (Version 19.0) is the

physical, geographical site of the renewable energy generation. As shown in figure 4, wastewater

treatment facilities and heat generation facilities of the project owner are included in the project boundary.



16

Wastewater treatment Methane recovery and biogas heat generation

Figure 4 Project Boundary

B.4. Description of baseline and its development:

>>

This section discusses the plausible baseline scenarios, and selects the baseline scenario on the basis of a

barrier analysis. More information can be found in section B.5

Step 1: Identification of alternative scenarios

This Step serves to identify all alternative scenarios to the proposed CDM project activity that can be the

baseline scenario through the following Sub-steps:

Step 1a Baseline scenario for wastewater treatment

According to methodology AMS III.H. baseline scenarios for wastewater treatment are shown in table 5:

Table 5 Baseline scenario for wastewater treatment

Scenario Alternatives Baseline scenario or not and the reason

W1

The untreated wastewater being discharged

into sea, river, lake, stagnant sewer or

flowing sewer

Environmental Protection Law of China

prohibits discharge of untreated industrial

wastewater, thus this scenario is excluded.

W2 The existing anaerobic lagoon system

without methane recovery It will be analysed in the following step 2.

Wastewater

Defoaming pot

Stabilivolt tank

Sulfur separator

Boiler

Biogas

Steam

Discharge

Roots fan

Washing tower

Adjust pond

Cycling pot

IC reactor

Settling pond

Aeration basin

Flare



17


W3

Anaerobic reactor with methane recovery

and utilization for heat generation (the

proposed project activity undertaken without

being registered as a CDM project activity)

It is applicable. It is in conformity with

Chinese laws.

Conclusion: We conclude that alternative W2, W3 are the possible baseline alternatives for wastewater

treatment.

Step 1b Baseline scenario for heat generation

According to methodology AMS I.C. baseline scenarios for heat generation are shown in table 6:

Table 6 Baseline scenario for heat generation


H1 Heat generation using coal in a boiler Heat generation using onsite coal-fired boiler .

It is the possible alternative scenario.

H2 Heat generation using existing /new

renewable energy There is no existing /new renewable energy

nearby. It is not possible alternative scenario.

H3

The proposed project activity

undertaken without being registered as a

CDM project activity

It is applicable.

Conclusion: We conclude that alternatives H1and H3 are the possible baseline alternative for heat

generation.

Step 2: Identify the baseline scenario taking into account the national and/or sectoral policies as

applicable.

From step 1 and 2 the realistic combinations of the scenario alternatives are (1) W2 + H1, (2) W3 + H3.

Step 3: Step 2 and/or step 3 of the latest approved version of the “Tool for the demonstration and

assessment of additionality” shall be used to identify the most plausible baseline scenarios by

eliminating non-feasible options (e.g. alternatives where barriers are prohibitive or which are clearly

economically unattractive).

From the above steps the realistic combinations of the scenario alternatives are(1) W2 + H1, (2) W3 +

H3. According to “Tool for the demonstration and assessment of additionality”, scenario alternative (1)

corresponds to the current situation is the baseline scenario of the project. Scenario alternative (2) is not

financially attractive. This can be evidenced by the investment analysis of the project activity in Section

B.5of the PDD. So scenario alternative W4 and H1 is not the baseline scenario of the project.

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:

>>

CDM consideration



18

CDM was seriously considered during the development of the Project, the timeline of the Project

implementation is shown in the following table 7.

Table 7. Timeline of the Project Implementation

Time Milestones

07/2010 Project Feasibility Study Report (FSR) is completed

20/08/2010 FSR is approved

08/2010 EIA Environmental Impact Assessment (EIA) is completed

25/08/2010 EIA is approved

05/09/2010 Decision on CDM development was made in the board meeting

of Project Owner

20/09/2010 CDM Consulting Agreement signed

20/09/2010 CDM notification in EB and NDRC finished

25/09/2010 The project start date (Construction Contract is signed)

03/2011 ERPA is signed

2619/1007/20102011 Equipment Purchase Contract is signed

03/2011 ERPA is signed

Due to the following barrier, the project can not be implemented without the support of the CDM fund:

Investment Barriers:

Investment analysis

Sub-Step a Determine appropriate analysis method

Because the Project generates financial and economic benefits other than CDM income, thus the simple

cost analysis (Option I) is not applicable. Option II is based on the comparison of returns of the project

investment with the investment required for an alternative to the project. As the alternative baseline

scenario of the proposed project is that the baseline scenario does not require investment, the investment

comparison analysis (Option II) is not suitable for this project. To determine the project shall be

implemented or not, , benchmark analysis (Option III) has been selected.

Sub-step b Benchmark Analysis Method (Option III)

A project will be financially acceptable when the financial Internal Return Rate (IRR) is better than the

sectoral benchmark IRR.

According to the “Economic evaluation measurements and parameters of constructive projects

(version.3)”, issued by NDRC & Ministry of Construction of the People’s Republic of China, the

benchmark IRR of Total Investment IRR (before tax) for manufacturers of paper and pulp in China is

13%. As the main business of the project owner is producing paper product, the benchmark IRR of the

paper production industry in China can be applied to this project.

Thus, this shall be applied for assessing financial attractiveness of the project. Accordingly, if the total

investment IRR (before tax) of the project is lower than 13%, then the project is not financial attractive

and the project is financial additional.

Sub-step c Calculation and comparison of financial indicators

Based on the feasibility study report of the project, basic parameters for calculation of financial indicators

are as follows:

Table 8. Basic parameters for calculation of financial indicators



19

Key Parameters Unit Value

Expected saving of

standard coal

T 3500

Total Investment 104 RMB 1700

Coal Price (with VAT) RMB/t 800

Value Added Tax(VAT) % 17

Tax for City Construction

and Maintenance

% 5

Tax for Education % 3

Income Tax % 25

Lifetime of Plants Year 14

Operating costs 104 RMB/year 61

Depreciation cost 104 RMB/year 161.5

Residual value % 5

CERs price EUR/tCO2e 8

Comparison of financial indicator

Table 9. Financial indicators of this project

Project IRR of total investment after tax

Without CDM 5.67%

With CDM revenue 28.27%

In accordance with benchmark analysis (Option III), if the financial indicators of the proposed project,

such as the project IRR, are lower than the benchmark values, the proposed project is not considered as

financially attractive. The project IRR without CDM revenue is 5.67%, lower than the benchmark rate of

13%. With the CDM revenue, the project IRR of 28.27% is significantly improved and exceeds the

benchmark. Therefore, with the CDM revenue the proposed project becomes financially viable to the

investors.

Sub-step d. Sensitivity analysis

The objective of sensitivity analysis is to show whether the conclusion regarding the financial

attractiveness is robust to reasonable variations in the critical assumptions. The investment analysis

provides a valid argument in favour of additionality only if it consistently supports (for a realistic range of

assumptions) the conclusion that the project activity is unlikely to be the most financially attractive or is

unlikely to be financially attractive.

For the project, the following financial parameters were taken as uncertain factors for sensitive analysis of

financial attractiveness:

-Fixed Asset Investment

-O&M cost

-Income of saving coal

-Annual operation hours

The range of ±10% is appropriate for Fixed Asset Investment, O&M cost, Income of saving coal and

Annual operation hours considering inflation in past several years.



20

The impacts of the four factors on project IRR have been analyzed. Its corresponding project IRR of the

proposed project changed at different extent. Details are shown in table 9 and figure 5.

Table 9. IRR sensitivity to different financial factors of the proposed project

(Total project investment, without CDM)

-10% -5% 0 5% 10%

Fixed Asset Investment 7.87% 6.72% 5.67% 4.68% 3.76%

O&M cost 6.27% 5.97% 5.67% 5.36% 5.06%

Income of saving coal 3.65% 4.63% 5.67% 6.67% 7.65%

Annual operation hours 3.65% 4.63% 5.67% 6.67% 7.65%

Benchmark 13.00% 13.00% 13.00% 13.00% 13.00%

Figure 5 IRR sensitivity to different financial factors of the proposed project

(Total project investment, without CDM)

When the above four financial factors fluctuate within the range of -10% to +10%, the IRR on total

investment of the proposed project without CDM revenue varies to different extent, as shown in table 9

and figure 5. It shows that the IRR doesn’t exceed 13% when the four factors fluctuate within the range of

-10% to +10%. The analysis above demonstrates that IRR remains low Therefore, the only alternative

that achieves the benchmark IRR is the CDM project with the increment of the CERs revenue.

Conclusion

The barrier analysis established that the project would not occur without its registration as a CDM project.

The Project therefore is both additional and reduces anthropogenic emissions of GHG below the levels

that would have occurred in the absence of the registered CDM project activity.



21

The benefits and incentives expected due to approval and registration of the project activity as a CDM

activity would certainly improve the sustainability of the project activity and would help to overcome the

identified barriers.

B.6. Emission reductions:

B.6.1. Explanation of methodological choices:

>>

The emission reductions related to methane that would be emitted to the atmosphere is estimated

according to the AMS III.H. (Version 16.0). The emission reduction achieved by biogas heat generation

is estimated according to the AMS I.C. (Version 19.0).

Estimate the Baseline Emission (BEy)

Baseline emissions for the year y are calculated as:

BEy=BEbio,y+BEthermal,y （1）

Where

BEy : Baseline emissions(tCO2e/yr)

BEbio,y : Baseline emissions from methane recovery component(tCO2e/yr)

BEthermal,y : Baseline emissions from biogas heat generation component(tCO2e/yr)

The following section shows the process of calculation for BEbio,y and BEthermal,y, separately.

Baseline Emissions - Methane Recovery Component (BEbio,y) According to paragraph of AMS III.H., the baseline emissions are calculated as:

BEbio,y=BEpower,y+BEww,treatment,y+BEs,treatment,y+BEww,discharge,y+BEs,final,y (1)

Where,

BEpower,y Baseline emissions in year y (tCO2e). It is not applied, as the existing water treatment

system, which is the anaerobic lagoon, does not use any electricity.

BEww,treatment,y Baseline emissions from waste water treatment in year y (tCO2e)

BEs,treatment,y Baseline emissions of the sludge treatment systems affected by the project activity in

year y (tCO2e). It is not applied for sludge.

BEww,discharge,y Baseline methane emissions from degradable organic carbon in treated wastewater

discharged into sea/river/lake in year y (tCO2e).

BEs,final,y

Baseline methane emissions from anaerobic decay of the final sludge produced in year

y (tCO2e). If the sludge is controlled combusted, disposed in a landfill with biogas

recovery, or used for soil application in the baseline scenario, this term shall be

neglected.

Therefore, the baseline equation shall become:

BEbio,y=BEww,treatment,y+BEww,discharge,y (2)

4,,,,,,,,inf,,,, )( CHBLwwoiBLtreatmentwwiBLCODyilow

i

yiwwytreatmentww GWPUFBMCFCODQBE (3)

Where:

Qww,i,y: Volume of wastewater treated in baseline wastewater treatment system i in year y (m3).

CODinf low,i,y: Chemical oxygen demand of the wastewater inflow to the baseline treatment system i in

year y (t/m3)



22

ηCOD,BL,i: COD removal efficiency of the baseline treatment system i

MCFww,treatment,BL,i: Methane correction factor for baseline wastewater treatment systems i

Bo,ww: Methane producing capacity of the wastewater (IPCC value of 0.25 kg CH4/kg COD)

UFBL: Model correction factor to account for model uncertainties (0.89)

GWPCH4: Global Warming Potential for methane (value of 21)

BEww,discharge,y=Qww,y×GWPCH4×Bo,ww×UFBL×CODww,discharge,BL,y×MCFww,BL,discharge （4）

Where,

Qww,y Volume of treated wastewater discharged in the year y（m3）

CODww,discharge,BL,y Chemical oxygen demand of the final treated wastewater discharged into river in the

year y (tonnes/m3) (Taken from the historical recorded data)（t/m3）

UFBL Model correction factor to account for model uncertainties (0.89)

MCFww,BL,dishcharge

Methane correction factor based on discharge pathway in the baseline situation (e.g.

into sea, river or lake) of the wastewater (fraction) (MCF values as per Table III.H.1

0.0).

Baseline Emissions - Biogas Heat Generation Component (BEthermal,y)

According to AMS I.C. (Version 19.0) paragraph 40, the baseline emission for the case of co-fired plants,

shall be calculated as follows:

BL

BLmeasuredyjPJ

k

ykbiomasskbiomass

ycofireythermal EFSEC

NCVFC

BEBE

,,,

,,,

,,

)(

(5)

Where,

BEcofire,y Baseline emissions during the year y (tCO2)

FCbiomass,k Quantity of biomass type k combusted during the year y (volume or mass unit)

NCVbiomass,k,y Average net calorific value of biomass type k combusted during the year y (TJ per unit

volume or mass unit)

EFBL CO2 emission factor of the fossil fuel that would have been used in the baseline co-fired

plant established using three years average historical data (tCO2/MWh)

η BL Energy efficiency of the equipment that would have been used in the baseline

SECPJ,j,y,measured Specific energy consumption of fuel type j of the project activity in year y (TJ/MWh)

yPJ

j

yjyPJj

measuredyPJjEG

NCVFC

SEC,

,,,

,,,

)(

(6)

Where,

FCj,PJ,y Quantity of fuel type j combusted in the project activity during the year y (volume or mass unit)

NCVj,y Average net calorific value of fuel type j combusted during the year y (TJ per unit volume or

mass unit)

EGPJ,y Energy generation in year y (MWh)

Estimate the Project Emission (PEy) Project emissions for the year y are calculated as:

PEy= PEbio,y + PEthermal,y (7)



23

Where:

PEy : Project emissions

PEbio,y : Project emissions from methane recovery component

PEthermal,y : Project emissions from biogas heat generation component

The following section shows the process of calculation for PEbio,y and PEthermal,y, separately.

Project Emissions - Methane Recovery Component (PEbio,y)

According to the methodology AMS III.H (Version 16.0), the project activity emissions are calculated as

follows:

PEbio,y=PEpower,y+PEww,treatment,y+PEs,treatment,y+PEww,discharge,y+PEs,final,y+PEfugitive,y+PEbiomass,y+PEflaring,y (8)

Where,

PEpower,y Emissions from electricity or fuel consumption in the year y (tCO2e).

PEww,treatment,y Methane emissions from wastewater treatment systems affected by the project activity,

and not equipped with biogas recovery, in year y (tCO2e). As the treatment system is equipped with

biogas recovery, this term is neglected.

PEs,treatment,y Methane emissions from sludge treatment systems affected by the project activity, and

not equipped with biogas recovery, in year y (tCO2e). As the treatment system is equipped with biogas

recovery, this term is neglected.

PEww,discharge,y Methane emissions from degradable organic carbon in treated wastewater in year y

(tCO2e).

PEs,final,y Methane emissions from anaerobic decay of the final sludge produced in year y (tCO2e).

The sludge from the Project is controlled combusted in the conversed boiler, thus this term can be

neglected.

PEfugitive,y Methane emissions from biogas release in capture systems in year y. It can be neglected.

PEbiomass,y Methane emissions from biomass stored under anaerobic conditions. The recovered

methane from the Project is not stored thus this term can be neglected.

PEflaring,y Methane emissions due to incomplete flaring in year y (tCO2e). Since the recovered

methane is combusted in the conversed boiler, and not in an enclosed or open flare, this term is neglected.

Also, because the methane capture through combustion in the emergency flare is not to be claimed for

conservativeness, this term is not considered.

Therefore, the formula used to calculate project emissions is simplified to be:

PEbio,y=PEpower,y+ PEww,discharge,y+ PEfugitive,y (9)

1) Calculation of PEpower,y

PEpower,y=ECy×EFgrid,CM,y (10)

Where,

ECy: Electricity consumption of the project facility in the year y (MWh)

EFgrid,CM,y: Emission coefficient of the grid (combined margin emission factor of the Central China

Power Grid) in the year y (tCO2e/MWh).

Determine Baseline Emission Factor (EF grid,CM,y)

According to“Tool to calculate the emission factor for an electricity system”, the detailed steps on

calculating Emission Factor (EFy, hereafter EFy is used to substitute EFgrid,CM,y for calculation simple) are

enumerated as following:



24

Step 1. Identify the relevant electric power system

The relevant electric power system of the project is Central China Power Grid which contains Henan,

Hubei, Hunan, Jiangxi, Sichuan and Chongqing region.

EFgrid,import,y will be considered in following steps. Detail information seen in annex 3.

Step 2. Select an operating margin (OM) method

The calculation of the operating margin emission factor (EFgrid,OM,y ) is based on one of the following

methods:

(a) Simple OM;

(b) Simple adjusted OM;

(c) Dispatch Data Analysis OM;

(d) Average OM.

The Simple OM method (a) can only be used where low operating cost/must-run power plants produce

less than 50% of total grid generation. Among the total electricity generations of the Central China Power

Grid which the Project is connected into, the average amount of low-cost/must run resources is less than

50% of total grid electricity generation. Therefore, the option (a) of Simple Operation Margin Emission

Factor could be employed in calculating the project’s Operation Margin Emission (EFOM,y).

For the simple OM, the emission factor will be calculated as the ex-ante option: a 3-year generation-

weighted average based on the most recent data available at the time of submission of the CDM-PDD to

the DOE for validation, without requirement to monitor and recalculate the emission factor during the

crediting period.

Step 3. Calculate the operating margin emission factor according to the selected method

The simple OM emission factor is calculated as the generation-weighted average CO2 emissions per unit

net electricity generation (tCO2/MWh) of all generating power plants serving the system, not including

low-cost / must-run power plants / units. It may be calculated:

Based on data on fuel consumption and net electricity generation of each power plant / unit (Option

A), or

Based on data on net electricity generation, the average efficiency of each power unit and

the fuel type(s) used in each power unit (Option B), or

Based on data on the total net electricity generation of all power plants serving the system and the

fuel types and total fuel consumption of the project electricity system(Option C)

In China, all power grids and power plants keep their specific net electricity generation and the fuel

consumption data as business secrets, so they would not publicly release these data, thus option (A) and

option (B) are not applicable and only option (C) is feasible.

m

ym

yiCO

i

yiymi

yOMsimplegridEG

EFNCVFC

EF,

,,,,,

,,

2

(11)

Where,

EF grid,OMsimple,y Simple operating margin CO2 emission factor in year y (tCO2/MWh).

FC i,y Amount of fossil fuel type i consumed in the project electricity system in year y (mass or

volume unit).

NCV i, y Net calorific value (energy content) of fossil fuel type i in year y (GJ / mass or volume

unit).

EF co2,i,y CO2 emission factor of fossil fuel type i in year y (tCO2/GJ).



25

EG y Net electricity generated and delivered to the grid by all power sources serving the system,

not including low-cost / must-run power plants / units, in year y (MWh).

i All fossil fuel types combusted in power sources in the project electricity system in year y.

m Power units included in the build margin.

y Either the three most recent years for which data is available at the time of submission of

the CDM-PDD to the DOE for validation (ex ante option) or the applicable year during

monitoring (ex-post option).

Data of net electricity generation is from the China Electric Power Yearbook 2006 ~2008.

Data on different fuel consumptions for power generation and the net caloric values of the fuels are from

the China Energy Statistical Yearbook from 2006~2008.

The emission factors for each kind of fuel are from the 2006 IPCC Guidelines for National Greenhouse

Gas Inventories.

According to the calculation of DNA of China the operating margin emission factor of East China Power

Grid is 1.0871tCO2/MWh, published on Dec 20th 2010.

Step 4. Identify the cohort of power units to be included in the build margin

The sample group of power units m used to calculate the build margin consists of either:

(a) The set of five power units that have been built most recently, or

(b) The set of power capacity additions in the electricity system that comprise 20% of the system

generation (in MWh) and that have been built most recently.

A direct application of this approach is difficult in China. The Executive Board (EB) has provided

guidance on this matter with respect to the application of the AMS-Ⅰ.D. and AM0005 methodologies for

projects in China on 07/10/2005 in response to a request for clarification by DNV on this matter. The EB

accepted the use of capacity additions to identify the share of thermal power plants in additions to the grid

instead of using power generation. The relevance of this EB guidance extends to the “Tool to calculate

the emission factor for an electricity system”. The calculation in step 5 and the calculation of the

published BM Emission Factor are based on this approach and are described below.

In terms of vintage of data, we choose the options 1 as below:

For the first crediting period, calculate the build margin emission factor ex-ante based on the most recent

information available on units already built for sample group m at the time of CDM-PDD submission to

the DOE for validation. For the second crediting period, the build margin emission factor should be

updated based on the most recent information available on units already built at the time of submission of

the request for renewal of the crediting period to the DOE. For the third crediting period, the build margin

emission factor calculated for the second crediting period should be used. This option does not require

monitoring the emission factor during the crediting period.

Step 5. Calculate the build margin emission factor

The build margin emissions factor is the generation-weighted average emission factor (tCO2/MWh) of all

power units m during the most recent year y for which power generation data is available, calculated as

follows:

m

ym

m

ymELym

yBMgridEG

EFEG

EF,

,,,

,, (12)

Where,

EF grid,BM,y Build margin CO2 emission factor in year y (tCO2/MWh).

EG m,y Net quantity of electricity generated and delivered to the grid by power unit m in year

y(MWh).



26

EF EL,m,y CO2 emission factor of power unit m in year y (tCO2/MWh).

m Power units included in the build margin.

y Most recent historical year for which power generation data is available.

In the current circumstance in China the data of sampling power units group m are not available. We

apply an indirect approach based on the EB decision mentioned in step 4.

Because the generation capacities of coal, oil and gas fueled power cannot be separated from the current

statistic data, the following steps are adopted in the calculation: firstly the PDD make use of the latest

energy balance data to calculate all sorts of emission scale in total emission from coal, oil and gas fueled

power; then based on the emission factor under the level of best commercialized technical efficiency,

calculate the fuelled power emission factor of the grid; last multiply the fuelled power emission factor and

fuelled power proportion of the total power, then comes the resulting BM of the grid.

The detailed procedure and formula are as follows:

1. Calculate the specific proportions of CO2 emission induced by solid, liquid and gaseous fuels in local

grid with the following formulas:

, , ,

,

, , ,

,

i j y i j

i COAL j

Coal

i j y i j

i j

F COEF

F COEF

(13)

, , ,

,

, , ,

,

i j y i j

i OIL j

Oil

i j y i j

i j

F COEF

F COEF

(14)

, , ,

,

, , ,

,

i j y i j

i GAS j

Gas

i j y i j

i j

F COEF

F COEF

(15)

Where,

Fi,j,y is the amount of fuel i consumed by province j in year(s) y;

COEFi,j is the emission factor of fuel i as calculated from the carbon content and the percent oxidation of

the fuel i consumed in the year (s) y;

Coal, Oil and Gas refer to the solid, liquid and gaseous fuel.

2. Calculated the emission factor of fossil fuel plants

, , ,Thermal Coal Coal Adv Oil Oil Adv Gas Gas AdvEF EF EF EF (16)

Where,

,Coal AdvEF , ,Oil AdvEF and ,Gas AdvEF refers to the emission factor of the efficiency level of the best

technology commercially by utilizing coal, oil and gas to generate electricity.

3. Calculate the EFBM,y of the grid

,Thermal

BM y Thermal

Total

CAPEF EF

CAP (17)

Where CAPTotal is the total installed capacity addition and CAPThermal is the installed capacity addition of

fossil fuel.

According to the calculation of DNA of China the build margin emission factor of East China Power Grid

is 0.4543tCO2/MWh, published on Dec 20th 2010.

Step 6. Calculate the combined emissions factor

The combined margin emissions factor is calculated as follows:



27

EFgrid,CM,y = EFgrid,OM,y×wOM + EFgrid,BM,y×w BM (18)

Where,

EFgrid,OM,y Operating margin CO2 emission factor in year y (tCO2/MWh).

EFgrid,BM,y Build margin CO2 emission factor in year y (tCO2/MWh).

wOM Weighting of operating margin emissions factor (%).

wBM Weighting of build margin emissions factor (%).

The weighting w OM and the weighting w BM are both taken 0.5 as default for the first crediting period.

For the second and third crediting period, w OM = 0.25 and w BM = 0.75.

According to the formula, the baseline emission factor of ECPG is obtained as:

EFy ＝ EFgrid,CM,y = 0.5×1.0871＋0.5×0.4543＝0.7707 t CO2e /MWh.

2) Calculation of PEww,discharge,y

PEww,discharge,y=Qww,y*GWPCH4*Bo,ww*UFPJ*CODww,discharge,PJ,y*MCFww,PJ,discharge (19)

Where,

Qww,y ： Volume of wastewater treated in the year y (m3)

UFPJ ： Model correction factor to account for model uncertainties (1.12)

CODww,discharge,PJ,y：Chemical oxygen demand of the treated wastewater discharged into the sea, river or

lake in the project scenario in year y (t/m3)

MCFww,PJ,discharge： Methane correction factor based on the discharge pathway of the wastewater in the

project scenario (e.g. into sea, river or lake) (MCF values as per Table III.H.1. 0.1)

3) Calculation of PEfugitive,y

PEfugitive,y=PEfugitive,ww,y+PEfugitive,s,y （20）

Where,

PEfugitive,ww,y Fugitive emissions through capture inefficiencies in the anaerobic wastewater

treatment in the year y (tCO2e)

PEfugitive,s,y

Fugitive emissions through capture inefficiencies in the anaerobic sludge treatment

in the year y (tCO2e). In this Project, the sludge shall be control combusted,

therefore the value is zero.

Thus,

PEfugitive,y=PEfugitive,ww,y （21）

PEfugitive,ww,y=(1-CFEww)×MEPww,treatment,y×GWPCH4 （22）

Where,

CFEww Capture efficiency of the biogas recovery equipment in the wastewater treatment

systems (a default value of 0.9 shall be used)

MEPww,treatment,y Methane emission potential of wastewater treatment systems equipped with biogas

recovery system in year y (t)

MEPww,treatment,y=Qww,y×Bo,ww×UFPJ×CODremoved,PJ,y×MCFww,treatment,PJ （23）

Where,

CODremoved,PJ,y The chemical oxygen demand removed10 by the treatment system k of the project

activity equipped with biogas recovery in the year y (t/m3)

MCFww,treatment,PJ Methane correction factor for the project wastewater treatment system k equipped

with biogas recovery equipment (MCF values as per Table III.H.1 0.8)



28

Project Emissions - Biogas Heat Generation Component (PEthermal,y)

According to AMS I.C (Version 19.0), anthropogenic emissions due to the heat supply component of the

project activity are zero as this project is utilizing biogas with biogenic origins. Therefore, PEthermal,y = 0

Estimate the leakage (LEy)

The equipment for the Project is not transferred from another facility and the existing equipment will not

be transferred to another activity, thus leakage effects are not considered as per AMS-III.H and AMS I.C.

Therefore, LEy=0.

Emission reductions

For all scenarios in paragraph 1, i.e. 1 (a) to 1 (f), emission reductions shall be estimated ex ante in the

PDD using the equations provided in the baseline, project and leakage emissions sections above.

Emission reductions shall be estimated ex ante as follows:

ERy,ex ante=BEy,ex ante-(PEy,ex ante+LEy,ex ante) （24）

Where,

ERy,ex ante Ex ante emission reduction in year y (tCO2e)

BEy,ex ante Ex ante baseline emissions in year y（tCO2e）

PEy,ex ante Ex ante project emissions in year y（tCO2e）

LEy,ex ante Ex ante leakage emissions in year y (tCO2e)

The project belongs to 1 (a). Thus According to paragraph 36, emission reductions due to the project

activity during the year y are calculated as follow:

ERy =BEy,ex post-(PEy,ex post+LEy,ex post) (25)

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

>>

Data / Parameter: GWPCH4

Data unit: tCO2e/tCH4

Description: Global Warming Potential for methane

Source of data used: 2006 IPCC Guidelines for National Greenhouse Gas Inventories

Value applied: 21

Justification of the

choice of data or

description of

measurement methods

and procedures actually

applied :

IPCC Default Value

Any comment: -

Data / Parameter: Bo,ww

Data unit: kgCH4/kgCOD

Description: Methane producing capacity of the wastewater

Source of data used: IPCC Guidelines for National Greenhouse Gas Inventories

Value applied: 0.25

Justification of the IPCC default value corrected to take into account uncertainties for AMS. III.H



29

choice of data or

description of

measurement methods


applied :

(Version 16.0)

Any comment: -

Data / Parameter: MCFww,treatment,BL,i

Data unit: -

Description: Methane correction factor for baseline wastewater treatment systems i

Source of data used: Table III.H.1 in AMS-III.H. (Version 16.0)

Value applied: 0.8


choice of data or

description of

measurement methods


applied :

Value stipulated in the applicable approved methodology

Any comment: -

Data / Parameter: CODinf low,i,y

Data unit: t/m3

Description: Chemical oxygen demand in the baseline situation in the year y to which the

sequential anaerobic treatment step is being introduced

Source of data used: Plant data

Value applied: 0.0030


choice of data or

description of

measurement methods


applied :

FSR

Any comment: -

Data / Parameter: η COD,BL,i

Data unit: %

Description: COD removal efficiency of the baseline treatment system i

Source of data used: FSR

Value applied: 90


choice of data or

description of

measurement methods


applied :

FSR

Any comment: -

Data / Parameter: EFBL



30

Data unit: kg/TJ

Description: Emission factor of raw coal

Source of data used: IPCC

Value applied: 87300


choice of data or

description of

measurement methods


applied :

From IPCC

Any comment: -

Data / Parameter: NCVcoal

Data unit: MJ/t

Description: Net calorie value of raw coal

Source of data used: State standard

Value applied: 20908


choice of data or

description of

measurement methods


applied :

This is the standard set by State.

Any comment: -

Data / Parameter: NCVCH4,y (=NCVCH4,PJ,y)

Data unit: MJ/m3

Description: Average net calorific value of biomass type j (methane) for SEC calculation,

and type k (methane) for BE cofire,y calculation, combusted during the year y in

GJ per unit volume or mass unit

Source of data used: The fundamentals and technology of furnace”, Chemical Industry Press.

Value applied: 35.865


choice of data or

description of

measurement methods


applied :

Official statistical data

Any comment: Used for ex-post calculation of BEthermal,y

Data / Parameter: Qww,i,y

Data unit: m3

Description: the flow of wastewater

Source of data used: FSR

Value applied: 5.60*106


choice of data or

description of

From FSR



31

measurement methods


applied :

Any comment: Used for ex-ante calculation of BEww,treatment,y

Data / Parameter: η BL

Data unit: %

Description: Energy efficiency of the equipment that would have been used in the baseline

Source of data used: Paragraph 26 (c), AMS I.C (Version 19.0)

Value applied: 100


choice of data or

description of

measurement methods


applied :

Efficiency of the baseline units (excluding cogeneration plants) shall be

determined by

adopting one of the following criteria (in a preferential order):

(a) Highest measured operational efficiency over the full range of operating

conditions of a unit with similar specifications, using baseline fuel. The

efficiency tests shall be conducted following the guidance provided in relevant

national/international standards;

(b) Highest of the efficiency values provided by two or more manufacturers for

units with similar specifications, using the baseline fuel;

(c) Default efficiency of 100%.

Any comment: Used for ex-post calculation of BEthermal,y

Data / Parameter: BC

Data unit: MWth

Description: Boiler rated capacity


Value applied: 18


choice of data or

description of

measurement methods


applied :

FSR

Any comment: -

Data / Parameter: ECy

Data unit: MWh

Description: Electricity consumption of the project facility in the year y


Value applied: 1900


choice of data or

description of

measurement methods


applied :

FSR

Any comment:



32

Data / Parameter: MCFww,PJ,discharge

Data unit: -

Description: Methane correction factor based on the discharge pathway of the wastewater in

the project scenario (e.g. into sea, river or lake)

Source of data used: Table III.H.1 in AMS-III.H. (Version 16.0)

Value applied: 0.1


choice of data or

description of

measurement methods


applied :

Value stipulated in the applicable approved methodology

Any comment:

B.6.3 Ex-ante calculation of emission reductions:

>>

As described in section B.6.1, emission reductions will be calculated as follows:

Estimate the Baseline Emission (BEy)

Baseline Emissions - Methane Recovery Component (BEbio,y)

4,,,,,,,,inf,,, )( CHBLwwoiBLtreatmentwwiBLCODyilow

i

yiwwybio GWPUFBMCFCODQBE

Table 11 Calculation of baseline emissions of methane recovery component

Description Parameter Data unit Value applied

Volume of wastewater treated in

baseline wastewater treatment system

i in year y

Qww,y m3 5.60×10

6

Chemical oxygen demand of the

wastewater inflow to the baseline

treatment system i in year y

CODinf low,y t/m3 0.0030

COD removal efficiency of the

baseline treatment system i η COD,BL % 90

Methane correction factor for baseline

wastewater treatment systems i

MCFww,treatment,BL - 0.8

Methane producing capacity of the

wastewater

Bo,ww kgCH4/

kgCOD

0.25

Model correction factor to account for

model uncertainties

UFBL - 0.89

Global Warming Potential for

methane

GWPCH4 tCO2e/tCH4 21

Baseline emissions of methane

recovery component

BEbio,y tCO2e 56,159

Baseline Emissions - Biogas Heat Generation Component (BEthermal,y)

BL

BLmeasuredyjPJ

k

ykbiomasskbiomass

ycofireythermal EFSEC

NCVFC

BEBE

,,,

,,,

,,

)(



33

yPJ

j

yjyPJj

measuredyPJjEG

NCVFC

SEC,

,,,

,,,

)(

EGPJ,y = BC* OpD * OpH

Table 12 Calculation of baseline emissions of biogas heat generation component


Quantity of standard coal combusted

in the project activity

FCcoal,PJ,y t 23,100

Average net calorific value of

standard coal combusted

NCVcoal MJ/t 20,908

Boiler rated capacity BC MWth 18

Number of Operational Days OpD day 350

Daily operational hours OpH hour 24

Energy generation in year y EGPJ,y MWh 147,000

Specific energy consumption of

standard coal

SECPJ,j,y,measured MJ/MWh 3,286

Quantity of biomass CH4 combusted FCCH4,y m3 5,100,000

Average net calorific value of

biomass CH4 combusted

NCVCH4,y MJ/m3 35.865

Energy Conversion Factor ECF TJ/MWh 0.0036

CO2 emission factor of the standard

coal

EFBL tCO2e/MWh 0.314

Energy efficiency of the equipment

that would have been used in the

baseline

η BL % 100%

Baseline emissions BEthermal,y tCO2e 17,496

Therefore, total baseline emissions are:

BEy=BEbio,y+BEthermal,y=56,159+17,496=74,015 tCO2e

Estimate the Project Emission (PEy)

Project Emissions - Methane Recovery Component (PEbio,y)

PEbio,y=PEpower,y+ PEww,discharge,y + PEfugitive,y

Table 13 Calculation of PEpower,y of project emissions


Electricity consumption of the project

facility in the year y

ECy MWh 1,900

Emission coefficient of the grid (combined

margin emission factor of the Central

China Power Grid) in the year y

EFgrid,CM,y tCO2e/MWh 0.7707

Emissions from electricity or fuel

consumption in the year y

PEpower,y tCO2e 1,464

Table 14 Calculation of PEww,discharge,y of project emissions



34


Volume of wastewater treated in the year y Qww,y m3 5.60×10

6

Model correction factor to account for

model uncertainties

UFPJ - 1.12

Chemical oxygen demand of the treated

wastewater discharged into the sea, river

or lake in the project scenario in year y

CODww,discharge,PJ,y t/m3 0.000075

Methane correction factor based on the

discharge pathway of the wastewater in the

project scenario

MCFww,PJ,discharge - 0.1

Methane producing capacity of the

wastewater

Bo,ww kgCH4/

kgCOD

0.25

Global Warming Potential for methane GWPCH4 tCO2e/tCH4 21

Methane emissions from degradable

organic carbon in treated wastewater in

year y

PEww,discharge,y tCO2e 247

Table 14 Calculation of PEfugitive,y of project emissions

Description Parameter Data unit Value

applied

Capture efficiency of the biogas recovery equipment in

the wastewater treatment systems CFEww

- 0.9

Volume of wastewater treated in baseline wastewater

treatment system i in year y

Qww,y m3 5.60×10

6

Methane producing capacity of the wastewater Bo,ww kgCH4/

kgCOD

0.25

Model correction factor to account for model

uncertainties

UFPJ - 1.12

The chemical oxygen demand removed10 by the

treatment system k of the project activity equipped with

biogas recovery in the year y CODremoved,PJ,y

t/m3 0.0027

Methane correction factor for the project wastewater

treatment system k equipped with biogas recovery

equipment MCFww,treatment,PJ

- 0.8

Methane emission potential of wastewater treatment

systems equipped with biogas recovery system in year y MEPww,treatment,y t 3386.9

Global Warming Potential for methane GWPCH4 tCO2e/tCH4 21

Methane emissions from biogas release in capture

systems in year y

PEww,discharge,y tCO2e 7,112

Therefore, the project emissions of methane recovery component are:

PEbio,y=PEpower,y+ PEww,discharge,y =1464+247+7,112=8,824 tCO2e

Project Emissions - Biogas Heat Generation Component (PEthermal,y)

PEthermal,y = 0



35

Therefore, the project emissions are:

PEy= PEbio,y+PEthermal,y=8,824+0=8,824 tCO2e

Calculate Emissions Reductions

ERy= BEy-PEy=74,015-8,824=65,191 tCO2e

Emission reductions from biogas recovery component is BEbio,y - PEbio,y = 56,159-7,359=48,800tCO2e/yr.

It is lower than the upper limit of 60ktCO2e/yr of AMS III.H. and thus the project is eligible to use the

methodology.

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

>>

The net emission reduction induced by the project activity in the fixed crediting period (01/01/2012-

31/12/2021) is estimated to be 651, 910 tCO2e.

Year Estimation of

project activity

emissions

(tCO2e)

Estimation of

baseline

emissions

(tCO2e)

Estimation of

leakage

(tCO2e)

Estimation of

overall emission

reductions

(tCO2e)

2012 8,824 74,015 0 65,191

2013 8,824 74,015 0 65,191

2014 8,824 74,015 0 65,191

2015 8,824 74,015 0 65,191

2016 8,824 74,015 0 65,191

2017 8,824 74,015 0 65,191

2018 8,824 74,015 0 65,191

2019 8,824 74,015 0 65,191

2020 8,824 74,015 0 65,191

2021 8,824 74,015 0 65,191

Total (tCO2e) 88,240 740,150 0 651,910

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

>>

B.7.1 Data and parameters monitored:

>>

Data / Parameter: FCcoal,PJ,y

Data unit: Tonnes/yr

Description: Quantity of co-fired coal consumed by the boiler installed by the CDM project

activity during the year y

Source of data to be

used: Measured by a track scale

Value of data N/A

Description of

measurement methods

Measured periodically by a track scale



36

and procedures to be

applied:

QA/QC procedures to

be applied: The meter will be calibrated according to relevant standards.

Any comment: -

Data / Parameter: ECy

Data unit: MWh

Description: Electricity consumption of the project facility in the year y


used: Plant data

Value of data 1,900

Description of

measurement methods


applied:

PSR

QA/QC procedures to

be applied:

The meter will be calibrated according to relevant standards.

Any comment: -

Data / Parameter: Qww,y

Data unit: m3

Description: Volume of wastewater treated in baseline wastewater treatment system i in year y


used:

Measurement data by flow meter

Value of data 5.60×106

Description of

measurement methods


applied:

Continuously measured and recorded monthly.

QA/QC procedures to

be applied:


Any comment: -

Data / Parameter: CODinf low,i,y

Data unit: t/m3

Description: Chemical oxygen demand in the baseline situation in the year y to which the

sequential anaerobic treatment step is being introduced


used:

Measurement data by analyzer

Value of data 0.0030

Description of

measurement methods


applied:


QA/QC procedures to

be applied:


Any comment: -



37

Data / Parameter: CODww,discharge,PJ,y

Data unit: t/m3

Description: Chemical oxygen demand of the treated wastewater discharged into the sea, river

or lake in the project scenario in year y


used:

Measurement data by analyzer

Value of data 0.000075

Description of

measurement methods


applied:


QA/QC procedures to

be applied:


Any comment: -

Data / Parameter: Qbiogas,y

Data unit: m3/yr

Description: Amount of biogas recovered and fuelled


used:

Measurement data by a gas flow meter

Value of data 5.10×106

Description of

measurement methods


applied:


QA/QC procedures to

be applied:


Any comment: -

Data / Parameter: OpD

Data unit: Days

Description: Number of Operational Days


used:

Measurement data

Value of data 350

Description of

measurement methods


applied:

Continuously measured and recorded

QA/QC procedures to

be applied:

Any comment: -

Data / Parameter: OpH

Data unit: Hours

Description: Daily operational hours

Source of data to be Measurement data



38

used:

Value of data 24

Description of

measurement methods


applied:


QA/QC procedures to

be applied:

Any comment: -

Data / Parameter: Tbio,y

Data unit: ℃

Description: Temperature of steam generated


used:

Measurement data

Value of data NA

Description of

measurement methods


applied:


QA/QC procedures to

be applied:


Any comment: -

Data / Parameter: Pbio,y

Data unit: Pa

Description: Pressure of steam generated


used:

Measurement data

Value of data NA

Description of

measurement methods


applied:


QA/QC procedures to

be applied:


Any comment: -

Data / Parameter: Qst,y

Data unit: Nm3/yr

Description: Total quantity of steam generated by the conversed boiler during the year y


used:

Measured by flow meter

Value of data NA

Description of

measurement methods


applied:




39

QA/QC procedures to

be applied:


Any comment: -

B.7.2 Description of the monitoring plan:

>>

1. Guideline

Monitoring plan was made according to the Methodology applied: AMS III.H. “Methane Recovery in

Wastewater Treatment” (Version 16.0) and AMS I.C “Thermal energy for user with or without

electricity” (Version 19.0)

The monitoring plan explains a guideline of monitoring procedures, schedule and responsibility. The

monitoring plan should ensure that monitoring information is real and measurable so as to provide DOE

with real, reliable and transparent emission reduction calculation data.

2. Management system and Responsibility

The project owner will set up a special CDM group to take charge of data collection, supervision,

verification and recording. A group director will be selected and will be trained and supported in

technology by CDM consultation, the organization of the monitor group as follows:

Figure 6 Configuration of the CDM management Team

CDM group director is responsible for verification and calculation of the data. Data recorder is

responsible for data reading and documenting. Meter supervisor is in charge of inspection and

maintenance of measuring facility. Data checker is responsible for supervising data verification.

3. Monitoring equipments and calibration

Major monitoring equipments includes coal belt system have already been installed and used in daily

operation of the project. Production department will keep records of steam consumption for cross check.

Financial department will keep records of invoice for coal in order to guarantee the data accuracy.

Power measure equipment installation should be collocated according “Technique Management

Regulation of Power Measure Equipment” (DL/T448-2000, issued by State Economic and Trade

Represented

CDM group

director

Meter supervisor Data recorder Data checker

CDM

consultation



40

Commission on 03/11/2000 and implemented on 01/01/2001). Before the power measure equipment

operation, the project owner and power grid company should check and accept according “Technique

Management Regulation of Power Measure Equipment”(DL/T448-2000).

Amount of recovered and fuelled biogas is to be measured by a gas flow meter installed at the pipe

supplying biogas to the boiler. The flow meter will be inspected and installed in accordance with the

national standard of “Verification Regulation of Differential Pressure Type Flow Meter” (JJG640-1994).

Fraction of methane contained in the recovered and fuelled biogas is to be measured with continuous gas

analyzer or alternatively with periodical measurement by a gas analyzer at 95% confidential level.

4. Monitoring

The main parameters of the monitoring are described in B.7.1 “Data and parameters monitored”.

5. Monitoring report

The objective of the monitoring report is to monitor the process of the CDM project, to assist the DOE

verification and the assurance of CER.

The CDM monitoring team should gather all the data needed and carry out the crosscheck process. They

are also responsible for ERs calculation and the monitoring report accomplishment. Vice General

Manager of the plant should take charge of verifying ERs and approving the monitoring report.

6. Data management and QA/QC

The company has impeccable quality management system. The QA/QC will implement in accordance

with the requirements of the system. Furthermore, the company will do cross-check using evidence

documentation, such as purchase specification, to enhance the quality of data monitored.

All monitoring data will be preserved throughout the crediting period and the following two years.

B.8 Date of completion of the application of the baseline and monitoring methodology and the

name of the responsible person(s)/entity(ies)

>>

The study of the baseline and the monitoring methodology was completed on 31/07/2011.

The key individuals involved in the baseline study include:

Mr. Eric Li from Beijing Peacecarbon Environmental Technology Ltd.

Tel: +86 10 64165031 E-mail: [email protected]

None of them is the participant.

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:

>>

2528/0901/2010 2011which is the time of Construction Contract was signed.



41

C.1.2. Expected operational lifetime of the project activity:

>>

14 years

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:

>>

Not applicable

C.2.1.2. Length of the first crediting period:

>>

Not applicable

C.2.2. Fixed crediting period:

>>

C.2.2.1. Starting date:

>>

01/01/2012, or the date of registration, whichever is later.

C.2.2.2. Length:

>>

10 years

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 project implemented an environmental impact assessment (EIA), to ensure that the project complied

with national, regional and local environmental regulations. The EIA for this project was carried out in

08/2010 and was approved on 25/08/2010. The environmental impacts arising from the project are

analyzed in the following:

1. Air Quality

The air pollutants generated from the Project are SO2 which generated through combustion of H2S in

biogas. The SO2 emission will be reduced through desulfurization equipment to control the concentration

of H2S in biogas before combustion. By taking this abatement measure, concentration of SO2 in the waste

gas becomes lower than the applicable 2nd

class air emission standards of 200mg/Nm3, which is stipulated

in the “Boiler Atmospheric Pollutant Discharge Standards” (GB13271-2001). Therefore, no harmful air

pollution would occur.

2. Noise

The main source of noise is the operation of pumps. After taking soundproof and sound absorption



42

measures, noise level at the property line is lower than the 3rd

class noise standards of the “Standard of

Noise at Boundary of Industrial Enterprises” (GB12348-1990), which is applicable to the Project.

Therefore, noise nuisance to the neighbors would not likely to occur.

3. Water Quality

The wastewater generated from the alcohol production will be treated properly by the UASB reactors

installed by the proposed project activity. Wastewater discharged from the Yufeng Brewing is further

treated by the sewage treatment works. So the project has little impact on the local water quality.

4. Solid waste

The main waste generated by the Project is coal ash and sludge. Personnel for waste management shall be

appointed and the waste shall be collected and disposed in appropriate manner.

Hence, it is concluded that the Project is environmentally acceptable as its environmental impact is very

small.

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:

>>

According to the report of environment impacts and the ratification of relative government departments,

the project’s environment impacts are not considered significant. No instruction is applicable.

SECTION E. Stakeholders’ comments

>>

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

>>

The project owner carried out Public Opinion Survey with the main counties, village governments,

society communities and residents in the local area in 09/2010.

The survey was carried out by distributing and collecting questionnaires. The summary based on this

survey is as follows, which can be validated by DOE.

The questionnaire includes the following contents:

1. Do you approve of the actuality of the environment? (Greatly; Mildly; Lightly; No.)

2. Do you know the project? (Yes; No)

3. Where do you know the project from? (Newspaper; TV; scutcheon; oral.)

4. What do you think about the impact on environment? (Greatly; Mildly; Lightly; Don’t know.)

5. Do you approve the construction of the proposed project? (Greatly; Mildly; Lightly; No.)

6. Do you know CDM? (Yes; A little; No.)

7. Do you support the CDM application of the proposed project? (Greatly; Mildly; No.)

The project owner held a symposium on Longyuan Paper Co., Ltd. Boiler Replacement Project in

09/2010. Nineteen people presented the meeting. Project owner introduced the conditions of the project

and the representatives expressed their opinions on environment impact, benefits of workers and other

issues during the meeting.

Project owner had explained the above issues one by one. The project can reduce waste gas including

CO2 and H2S in steam production process and contribute to local environment, promote the development

of local economy and this will eliminate the worries of the surrounding residents.



43

E.2. Summary of the comments received:

>>

Comments and opinions received from Public Opinion Survey:

96.7% of the investigated approve of the actuality of the environment. Only two persons are

indifferent;

Almost all of the investigated know the proposed project activity and most of them get the

information from the scutcheon and oral;

85% of the investigated think that there is lightly impact on environment. The other person don’t

know the impact on environment;

91.7% of the investigated greatly approve the construction of the project and only five persons are

indifferent;

80% of the investigated know CDM and almost all of them support the CDM application of the

proposed project.

Comments and opinions received at stakeholder consultation meeting:

Each attendant of the stakeholder consultation meeting expressed their opinion on the proposed project.

As the negative impact of the proposed project is slim to zero comments were generally positive. An

overview of the main result of the meeting is provided below:

1. All local stakeholders believe the proposed project will have a positive effect on the local environment

and promote sustainable development.

2. All the stakeholders expressed their support for the development of the project.

3. No stakeholder articulated concerns or dissatisfaction with the construction or operation of the

proposed project activity.

After consultation with the local stakeholder, we can confirm the positive impression given in the EIA.

All stakeholders believe the project will increase comprehensive resource utilization with the cement

production facility and save energy, reduce the emission of dust and other pollutant gas emissions such as

SO2 which will benefit the local environment, reduce the local electricity shortage and thereby reducing

the negative impact of unreliable electricity supply to local residents and enterprises, and provide

employment opportunities. All local stakeholders expressed their support for the proposed CDM project

activity and expressed their hope that the expected that the project can be constructed as soon as possible.

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

>>

The proposed project is fully supported by the local residents. In accordance with the stakeholder

assessment, it’s unnecessary to adjust the design as well as the modalities of construction and running of

the project.



44

Annex 1

CONTACT INFORMATION ON PARTICIPANTS IN THE PROJECT ACTIVITY

Organization: Suixian Longyuan Paper Co., Ltd

Street/P.O.Box: North City Industrial Region

Building:

City: Shangqiu

State/Region: Sui County

Postfix/ZIP:

Country: China

Telephone: 0371-67187907

FAX:

E-Mail: [email protected]

URL:

Represented by: Ma Linchong

Title: Vice Chairman

Salutation: Mr.

Last Name: Ma

Middle Name:

First Name: Linchong

Department:

Mobile:

Direct FAX:

Direct tel: 0371-67187907

Personal E-Mail: [email protected]

mailto:[email protected]

mailto:[email protected]



45

Organization: Bunge Emissions Holdings S.A.R.L.

Street/P.O.Box: -

Building: 13, Rte de Florissant

City: Geneva

State/Region: -

Postcode/ZIP: CH -1206

Country: Swiss Confederation

Telephone: +41-22-5929621

FAX: +41-22-5803360

E-Mail: [email protected]

URL: -

Represented by: Alfred Evans

Title: -

Salutation: Mr.

Last name: Evans

Middle name: -

First name: Alfred

Department: -

Mobile: -

Direct FAX: +41-22-5803360

Direct tel: +41-22-5929621

Personal e-mail: [email protected]



46

Annex 2

INFORMATION REGARDING PUBLIC FUNDING

No public funding from Annex Ⅰcountries is involved in the proposed project.



47

Annex 3

BASELINE INFORMATION

According to Annex 1-3 of “Bulletin on the Baseline Emission Factors of the China’s Regional Grids”

issued reviewed by Office to National Climate Change Coordination Committee of National

Development and Reform Commission (NDRC) of China (DNA of China) on Dec 20th, 2010. Please refer

to the following information:

http://cdm.ccchina.gov.cn/WebSite/CDM/UpFile/File2552.pdf

http://cdm.ccchina.gov.cn/WebSite/CDM/UpFile/File2550.xls

http://cdm.ccchina.gov.cn/WebSite/CDM/UpFile/File2551.doc

http://cdm.ccchina.gov.cn/WebSite/CDM/UpFile/File2552.pdf

http://cdm.ccchina.gov.cn/WebSite/CDM/UpFile/File2550.xls

http://cdm.ccchina.gov.cn/WebSite/CDM/UpFile/File2551.doc



48

Calculation of OM: Table A1 Emission Calculation Sheet of Central China Power Grid in 2006

Fuel type Unit Jiangxi Henan Hubei Hunan Chongqing Sichuan Subtotal

A B C D E F G=A+B+C+D+E+F

Raw coal 104 ton 1926.02 8098.01 3179.79 2454.48 1184.3 3285.22 20127.82

Refined coal 104 ton 5.79 5.79

Other washed

coal 104 ton 4.51 104.12 8.59 79.21 196.43

Type coal 104 ton 0.01 0.01

Coke 104 ton 17.23 0.32 17.55

Coke oven gas 108 m

3 0.52 1.07 4.24 0.38 0.01 6.22

Other coal gas 108 m

3 12.69 3.95 1.7 4.36 0.01 22.71

Crude oil 104 ton 0.49 0.49

Gasoline 104 ton 0.01 0.01

Diesel oil 104 ton 0.91 2.23 1.41 1.78 0.96 7.29

Fuel oil 104 ton 0.51 1.26 1.31 0.8 0.57 3.49 7.94

LPG 104 ton 0

Refinery dry gas 104 ton 0.86 8.1 1 0.97 10.93

Natural gas 108 m

3 0.28 0.16 18.63 19.07

Other oil

products 104 ton 0

Other coke

product 104 ton 0.01 0.01

Other energy 104 tce 17.45 37.36 31.55 18.29 29.35 134



49

Fuel type

Emission

Factor

Oxidation

Factor Emission Factor

Average Net

Caloric Emission of CO2

（tc/TJ）（%） (kgCO2/TJ) （MJ/t,m3） L=G×J×K/100000（Mass unit）

H I J K L=G×J×K/10000 (Volum unit)

Raw coal 25.8 100 87,300 20,908 367,386,738

Refined coal 25.8 100 87,300 26,344 133,160

Other washed

coal 25.8 100 87,300 8,363 1,434,116

Type coal 26.6 100 87,300 20,908 183

Coke 29.2 100 95,700 28,435 477,576

Coke oven gas 12.1 100 37,300 16,726 388,053

Other coal gas 12.1 100 37,300 5,227 442,770

Crude oil 20 100 71,100 41,816 14,568

Gasoline 18.9 100 67,500 43,070 291

Diesel oil 20.2 100 72,600 42,652 225,737

Fuel oil 21.1 100 75,500 41,816 250,674

LPG 17.2 100 61,600 50,179 0

Refinery dry

gas 15.7 100 48,200 46,055 242,630

Natural gas 15.3 100 54,300 38,931 4,031,309

Other oil

products 20 100 72,200 41,816 0

Other coke

product 25.8 100 95,700 28,435 272

Other energy 0 0 0 0 0

Total 375,028,077

Data source: China Energy Statistics Yearbook 2007

Table A2 Electricity Generation from Fossil Fuel Power of Central China Power



50

Grid in 2006

Province

Electricity

generation

Electricity

generation

Internal

Consumption

rate

Electricity

supplied to grid

（108kWh) （MWh) （%）（MWh)

Jiangxi 344.49 34,449,000 6.17 32,323,497

Henan 1512.35 151,235,000 7.06 140,557,809

Hubei 548.41 54,841,000 2.75 53,332,873

Hunan 464.08 46,408,000 4.95 44,110,804

Chongqing 234.87 23,487,000 8.45 21,502,349

Sichuan 441.93 44,193,000 4.51 42,199,896

Total 334,027,226

Data resource: China Electric

Power Yearbook 2007

China Energy Yearbook 2007



51

Table A3 Emission Calculation Sheet of Central China Power Grid in 2007



Raw coal 104 ton 2200.57 9357 3479.81 2683.81 1547.7 3239 22507.89

Refined coal 104 ton 3.07 3.8 6.87

Other washed

coal 104 ton 0.04 87.16 2.06 96.42 185.68

Type coal 104 ton 0.01 0.01

Coke 104 ton 0

Coke oven gas 108 m

3 0.08 2.61 0.25 0.31 0.91 4.16


3 29.17 25.79 24.69 23.98 103.63


Gasoline 104 ton 0.04 0.01 0.05

Diesel oil 104 ton 0.98 3.21 2.51 2.83 1.93 11.46

Fuel oil 104 ton 0.42 1.25 1.33 0.63 0.64 1.74 6.01

LPG 104 ton 0

Refinery dry gas 104 ton 1.43 10.01 0.97 0.7 13.11

Natural gas 108 m

3 0.12 0.18 0.2 1.87 2.37

Other oil

products 104 ton 0

Other coke

product 104 ton 0

Other energy 104 tce 23.43 63.65 35.95 29.46 23.21 175.7



52

Fuel type

Emission

Factor

Oxidation


Average Net




Raw coal 25.8 100 87,300 20,908 410,829,404

Refined coal 25.8 100 87,300 26,344 157,998

Other washed

coal 25.8 100 87,300 8,363 1,355,631

Type coal 26.6 100 87,300 20,908 183

Coke 29.2 100 95,700 28,435 0

Coke oven gas 12.1 100 37,300 16,726 259,534

Other coal gas 12.1 100 37,300 5,227 2,020,444

Crude oil 20 100 71,100 41,816 12,784

Gasoline 18.9 100 67,500 43,070 1,454

Diesel oil 20.2 100 72,600 42,652 354,863

Fuel oil 21.1 100 75,500 41,816 189,742

LPG 17.2 100 61,600 50,179 0

Refinery dry

gas 15.7 100 48,200 46,055 291,022

Natural gas 15.3 100 54,300 38,931 501,007

Other oil

products 20 100 72,200 41,816 0

Other coke

product 25.8 100 95,700 28,435 0


Total 415,974,066





53

Grid in 2007

Province

Electricity

generation

Electricity

generation

Internal

Consumption

rate

Electricity

supplied to grid

（108kWh) （MWh) （%）（MWh)

Jiangxi 421 42,100,000 7.72 38,849,880

Henan 1773 177,300,000 7.55 163,913,850

Hubei 609 60,900,000 6.69 56,825,790

Hunan 542 54,200,000 7.18 50,308,440

Chongqing 288 28,800,000 9.2 26,150,400

Sichuan 451 45,100,000 8.68 41,185,320

Total 377,233,680


Power Yearbook 2008



54

Table A5 Emission Calculation Sheet of Central China Power Grid in 2008



Raw coal 104 ton 2137.08 9480.74 2852.29 2620.44 1421.42 2727.61 21239.58

Refined coal 104 ton 1.68 3.27 4.95

Other washed

coal 104 ton 0.04 80.54 2.06 101.75 184.39

Type coal 104 ton 6.12 0.01 6.13

Coke 104 ton 0.78 0.92 1.7

Coke oven gas 108 m

3 0.1 4.19 0.37 0.24 6.66 0.01 11.57


3 23.67 41.36 3.31 0.37 0.01 68.72


Gasoline 104 ton 0

Diesel oil 104 ton 0.88 7.02 2.82 3.41 1.59 15.72

Fuel oil 104 ton 0.07 1.45 1.29 3.14 5.95

LPG 104 ton 0

Refinery dry gas 104 ton 0.21 3.91 2.78 0.71 0.01 7.62

Natural gas 108 m

3 4.02 0.16 0.05 12.92 17.15

Other oil

products 104 ton 0.59 0.59

Other coke

product 104 ton 0.01 0.01

Other energy 104 tce 18.16 68.11 62.35 11.42 64.87 224.91



55

Fuel type

Emission

Factor

Oxidation


Average Net




Raw coal 25.8 100 87,300 20,908 387,679,342

Refined coal 25.8 100 87,300 26,344 113,842

Other washed

coal 25.8 100 87,300 8,363 1,346,213

Type coal 26.6 100 87,300 20,908 111,889

Coke 29.2 100 95,700 28,435 46,261

Coke oven gas 12.1 100 37,300 16,726 721,829

Other coal gas 12.1 100 37,300 5,227 1,339,814

Crude oil 20 100 71,100 41,816 5,054

Gasoline 18.9 100 67,500 43,070 0

Diesel oil 20.2 100 72,600 42,652 486,775

Fuel oil 21.1 100 75,500 41,816 187,848

LPG 17.2 100 61,600 50,179 0

Refinery dry

gas 15.7 100 48,200 46,055 169,153

Natural gas 15.3 100 54,300 38,931 3,625,430

Other oil

products 20 100 72,200 41,816 17,813

Other coke

product 25.8 100 95,700 28,435 272


Total 395,851,534





56

Grid in 2008

Province

Electricity

generation

Electricity

generation

Internal

Consumption

rate

Electricity

supplied to grid

（108kWh) （MWh) （%）（MWh)

Jiangxi 405 40,500,000 6.5 37,867,500

Henan 1890 189,000,000 7.22 175,354,200

Hubei 553 55,300,000 6.62 51,639,140

Hunan 537 53,700,000 6.46 50,230,980

Chongqing 286 28,600,000 28,600,000

Sichuan 401 40,100,000 10.21 36,005,790

Total 379,697,610


Power Yearbook 2009

Table A7 Weighted Average Emission Factor of East China Power Grid in the Past 3 Years (OM)

Year 2006 2007 2008 Weighted average value

Total emission of CO2 378,031,235 419,013,395 398,974,078

1.08712 Electricity generated by the fossil fuel power

plant 337,056,176

380,239,080 382,874,880

Emission factor 1.12157 1.10197 1.04205



57

Calculation for BM： Table A8 Calculation Sheet for λCoal, λOil, λGas of Central China Power Grid

Jiangxi Henan Hubei Hunan Chongqing Sichuan

Total Heat

value Emission

factor Oxidation

Factor CO2 Emission

Fuel type Unit A B C D E F G=A+…+F H I J K=G×H×I×J/100,000

Raw coal 104t 2,137.08 9,480.74 2,852.29 2,620.44 1,421.42 2,727.61 21,239.58 20,908 87,300 1 387,679,342

Refined coal 104t 0 1.68 0 0 3.27 0 4.95 26,344 87,300 1 113,842

Other washed

coal 10

4t 0.04 80.54 0 2.06 101.75 0 184.39 8,363 87,300 1

1,346,213

Type coal 104t 0 0 0 6.12 0 0.01 6.13 20,908 87,300 1 111,889

Coke 0 0.78 0 0.92 0 0 1.70 28,435 95,700 1 46,261

Raw coal 104t 0 0 0 0 0 0 0.00 28,435 95,700 1 0

Subtotal 104t 389,297,546

Crude oil 0 0.17 0 0 0 0 0.17 41,816 71,100 1 5,054

Gasoline 104t 0 0 0 0 0 0 0 43,070 67,500 1 0

Diesel oil 104t 0.88 7.02 2.82 3.41 1.59 0 15.72 42,652 72,600 1 486,775

Fuel oil 104t 0.07 1.45 0 1.29 0 3.14 5.95 41,816 75,500 1 187,848

Other 0 0 0.59 0 0 0 0.59 41,816 72,200 1 17,813

Subtotal 108m

3 697,490

Natural gas 108m

3 0 40.2 1.6 0 0.5 129.2 171.5 38,931 54,300 1 3,625,430

Coke oven gas 108m

3 1 41.9 3.7 2.4 66.6 0.1 115.7 16,726 37,300 1 721,829

Other coal gas 104t 236.7 413.6 0 33.1 3.7 0.1 687.2 5,227 37,300 1 1,339,814

LPG 104t 0 0 0 0 0 0 0 50,179 61,600 1 0

Refinery dry

gas 10

4t 0.21 3.91 2.78 0.71 0 0.01 7.62 46,055 48,200 1

169,153

subtotal 5,856,225

total 395,851,262

Data source: China Energy Statistical Yearbook 2009

PROJECT DESIGN DOCUMENT FORM (CDM PDD) - Version 03.1


Page58

According to the table above: yCoal, =98.34%， yOil , =0.18%， yGas, =1.48%。

yAdvGasyGasyAdvOilyOilyAdvCoalyCoalyThermal EFEFEFEF ,,,,,,,,,,

= 0.7974 tCO2/MWh

Table A9 Installed capacity of Central China in2008

Installed

capacity Unit Jiangxi Henan Hubei Hunan Chongqing

Sichuan Total

Fossil fuel

Power MW 9,340 42,680

14,210 14,430 6,660 12,770 100,090

Hydro Power MW 3,710 3,020 29,050 10,650 4,060 22,240 72,730

Nuclear

Power MW 0 0 0 0 0 0 0

Wind Power MW 30 30 10 0 0 0 70

Total MW 13,080 45,720 43,280 25,080 10,730 35,010 172,890

Data resource: China Electric Power Yearbook 2009



Page59


Installed


Sichuan Total

Fossil fuel

Power MW 9,270 38,540

13,040 13,360 6,370 12,000 92,580

Hydro Power MW 3,570 2,740 24,020 9,220 2,240 19,860 61,650

Nuclear

Power MW 0 0 0 0 0 0 0

Wind Power MW 0 0 10 17 24 0 51

Total MW 12,840 41,280 37,070 22,597 8,634 31,860 154,281



Installed


Sichuan Total

Fossil fuel

Power MW 6,568 32,603

11,623 10,715 5,594 9,555 76,658

Hydro Power MW 3,288 2,553 18,320 8,648 1,979 17,730 52,518

Nuclear

Power MW 0 0 0 0 0 0 0

Wind Power MW 0 0 0 17 24 0 41

Total MW 9,856 35,156 29,943 19,380 7,597 27,285 129,217




Page60

Table A12 BM Calculation Sheet（MW）

Installed

Capacity

in 2006

Installed

Capacity

in 2007

Installed

Capacity

in 2008

Installed

Capacity

Addition in

2006-2008

Installed

Capacity

Addition in

2007-2008

% of Installed

Capacity Addition

A B C D E F

Fossil fuel Power 76,658 92,580 100,090 30,500 9,813 56.97%

Hydro Power 52,518 61,650 72,730 23,005 11,227 42.97%

Nuclear Power 0 0 0 0 0 0.00%

Wind Power 41 51 70 29 19 0.05%

Total 129,217 154,281 172,890 53,534 21,059 100.00%

% of Installed Capacity in 2008 30.96% 12.18%

EFBM,y=0.7974×56.97%=0.4543 tCO2/MWh

Calculation of CM:

Table A13 Calculation Sheet of CM Emission Factor of Central China Power Grid

OM Emission Factor

(tCO2e/MWh)

BM Emission Factor

(tCO2e/MWh) CM Emission Factor =(OM+BM)/2

(tCO2e/MWh)

Central China Power Grid 1.08712 0.4543 0.7707

Remark: Weights OM and BM , by default, are 0.5



Page61

Annex 4

MONITORING INFORMATION

There is no supplementary information about the monitoring plan. For detailed information about the

plan, please refer to Section B.7.2.

- - -