JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03
Joint Crediting Mechanism Approved Methodology ID_AM023“Installation of gas engine cogeneration system with absorption chiller to supply electricity,
heating energy and cooling energy”
A. Title of the methodology

Installation of gas engine cogeneration system with absorption chiller to supply electricity,
heating energy and cooling energy, Version 01.0

B. Terms and definitions

Terms
Cogeneration System (CGS)Definitions
A system that consists of power generator(s) and heatgenerating equipment (e.g. heat recovery steam generator,
exhaust heat exchanger, etc.) that supplies both electricity
and heating energy, recovering waste heat exhausted from thepower generator(s). The power generator(s) in thismethodology is a gas engine(s).

Absorption chiller

Refrigerating machine using heat source such as heatingenergy generated by fuel combustion and/or waste heat in theform of hot water, steam or exhaust gas, refrigerant (eg.
water) and absorption solution (eg. Lithium bromide,ammonia) to generate chilled water or other chilled liquids
by absorption refrigeration cycle.

Recipient Facility

A cluster of buildings and/or plants (or building/plant itself)
to which electricity, heating energy and cooling energy
generated by CGS are supplied.

Boiler Efficiency

Net quantity of heat generated per quantity of energy
contained in fuel fired in the boiler.

Cooling capacity

Capability of individual chiller to remove heat. In thismethodology, “cooling capacity” is used to represent a
cooling capacity per a single chiller unit and not for a systemwith multiple chiller units.

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JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03
C. Summary of the methodology

Items
GHG

emissionmeasures

Summary
reduction Electricity and heating energy generated by a CGS installed in a
project site substitute all or part of grid and/or captive electricity
as well as heating energy. Absorption chiller utilizing heatingenergy generated by a CGS is also introduced to save energy forcooling energy demand. Installation of CGS and absorption
chiller leads to efficient energy use of recipient facility(ies) andin turn GHG emission reductions.

Calculationofemissionsreference [Reference emissions for CGS]
Reference emissions are CO2 emissions from the use of grid
and/or captive electricity and heating energy (e.g. steam and hot
water) generated by a reference boiler, which are calculated withthe amount of electricity consumed by the recipient facility(ies)which is generated by the CGS, the amount of heating energy
consumed by the recipient facility(ies) which is generated by the
CGS, CO2 emission factors for consumed electricity in therecipient facility(ies), reference boiler efficiency and CO2
emission factor for fossil fuel consumed by the reference boiler.
[Reference emissions for absorption chiller]
Reference emissions are GHG emissions from using reference
chiller(s) which is determined as centrifugal chiller in thismethodology. Reference emissions are calculated with coolingenergy of project chiller(s), COP of reference chiller, and CO2
emission factor for electricity consumed.
GHG emissions from using chilled water pump, cooling water
pump and cooling tower are excluded from calculation sincethose pumps exist in both reference and project chiller systemand they can cancel each other out.

Calculation
emissionsofproject [Project emissions from CGS]
Project emissions are CO2 emissions from the use of CGS,
which are calculated with the amount of gas fuel consumed by
the CGS, net calorific value of gas fuel consumed by the CGS,
and CO2 emission factor for gas fuel consumed by the CGS.

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JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03[Project emissions from absorption chiller]
Project emissions are GHG emissions from using projectchiller(s), which are the sum of emissions from electricity
consumption and fossil fuel consumption. GHG emissions fromelectricity

consumption

arecalculated

withelectricity

consumption of pumps absorbing solution and refrigerant built
in the project chiller(s) and CO2 emission factor for electricity
consumed.
GHG emissions from fossil fuel consumption, where applicable,
are calculated with fuel consumption of project chiller(s) andCO2 emission factor for fuel consumed.
GHG emissions from using chilled water pump, cooling water
pump and cooling tower are excluded from calculation sincethose pumps exist in both reference and project chiller systemand they can be canceled each other out.
Monitoring parameters

Electricity consumption by the recipient facility(ies) whichis generated by the CGS
Heating energy consumption by the recipient facility(ies)which is generated by the CGS
Cooling energy generated by the project absorption chiller
Gas fuel consumption by the CGS
Electricity consumption by the project absorption chiller
Gas fuel consumption by the project absorption chiller,
where applicable
The amount of fuel consumed and/or the amount ofelectricity generated by captive power, where applicable

D. Eligibility criteria

This methodology is applicable to projects that satisfy all of the following criteria.
Criterion 1

A CGS, whose electricity is generated by a gas engine(s), with absorption
chiller(s) utilizing waste heat from CGS is installed and supplies electricity,
heating energy and cooling energy (e.g. steam, hot water and chilled water) torecipient facility(ies).

Criterion 2

Electricity and heating energy, each of which is generated in separate systems, is
supplied to and consumed by recipient facility(ies) before the installation of a
project CGS.

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JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03
Criterion 3

In the case of replacing the existing chiller with the project chiller, a plan forprevention of releasing refrigerant used in the existing chiller to the air (e.g.
re-use of the equipment) is prepared. Execution of this plan is checked at thetime of verification, in order to confirm that refrigerant used for the existing one
replaced by the project is prevented from being released to the air.
In the case that the existing chiller is NOT replaced with the project chiller, thiscriterion is not applied.

E. Emission Sources and GHG types

Reference emissions
Emission sources

GHG types

Electricity consumption in recipient facility(ies)

CO2

Fossil fuel consumption for production of heating energy consumed in CO2
recipient facility(ies)Electricity consumption by reference chiller

CO2

Project emissions
Emission sources

GHG types

Gas fuel consumption by CGS

CO2Electricity consumption by project chiller

CO2

Gas fuel consumption by project chiller

CO2

F. Establishment and calculation of reference emissions

F.1. Establishment of reference emissions
The following two measures are taken into consideration to ensure the net emission reductionsin this methodology.
[Reference boiler efficiency for the CGS]
Reference emissions are calculated with the amount of electricity generated by the CGS andconsumed by the recipient facility(ies), the amount of heating energy generated by the CGS andconsumed by the recipient facility(ies), reference boiler efficiency, CO2 emission factors for
consumed electricity in the recipient facility(ies) and fossil fuel consumed by the reference
boiler.

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JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03
A default value for the reference boiler efficiency is conservatively set to 89 [%] taking thehighest value among those products sold in Indonesia, so as to ensure net emission reductions.
[Reference COP for the absorption chiller]
Reference emissions are calculated with cooling energy of project chiller(s), COP of reference
chiller, and CO2 emission factor for electricity consumed.
GHG emissions from using chilled water pump, cooling water pump and cooling tower are
excluded from calculation since those pumps exist in both reference and project chiller systemand they can cancel each other out.
The COP of reference chiller, which is centrifugal chiller, is conservatively set as a default value
in the following manner to ensure the net emission reductions.
1. The COP value tends to increase as the cooling capacity becomes larger.
2. The reference COP value varies by its cooling capacity.
3. The maximum values of COP in each cooling capacity range set for this methodology aredefined as COPRE,j as described in Section I.
F.2. Calculation of reference emissions

=
=

,,
,

×

+

,,
,

+

+

,,

+

,,

×

,
,

×

×

,

,

Where
: Reference emissions during the period p [tCO2/p]: Reference emissions for electricity consumed by the recipient facility i,,which is generated by the CGS during the period p [tCO2/p]: Reference emissions for heating energy consumed by the recipient facility i,,which is generated by the CGS during the period p [tCO2/p], ,,: Reference emissions by reference chiller j during the period p [tCO2/p]: Electricity consumption by the recipient facility i which is generated by the
CGS during the period p [MWh/p],: CO2 emission factor for consumed electricity in the recipient facility i[tCO2/MWh]5

JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03: Heating energy consumption by the recipient facility i which is generated,

by the CGS during the period p [GJ/p]*1: Reference boiler efficiency [%]: CO2 emission factor for fossil fuel consumed by the reference boiler,[tCO2/GJ]: Cooling energy generated by the project absorption chiller j during the, ,period p [MWh/p],: COP of reference chiller j [dimensionless],: CO2 emission factor for consumed electricity by the project absorption
chiller j [tCO2/MWh]: Identification number of the recipient facility to which electricity andheating energy generated by the CGS is supplied: Identification number of the project absorption chillerj*1: Amount of heating energy generated by the CGS and consumed by the project absorption
chiller is not included in,

G. Calculation of project emissions

Where
,

,

,

,

=

,

,

+

=

,

,

×

=

Where

,

,

×

,
,

,,

×

,
,

+

,

×

,

,

,,

×

,

,

× ,

: Project emissions during the period p [tCO2/p],,,: Project emissions from the CGS during the period p [tCO2/p],: Project emissions from project absorption chiller during the period p[tCO2/p]6

JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03,,: Gas fuel consumption by the CGS during the period p [mass or volume/p],,: Net calorific value of gas fuel consumed by the CGS [GJ/mass or volume],: CO2 emission factor for gas fuel consumed by the CGS [tCO2/GJ]: Electricity consumption by project absorption chiller j during the period p, ,[MWh/p]: CO2 emission factor for electricity consumed by the project absorption,,

chiller j [tCO2/MWh]: Gas fuel consumption by project absorption chiller j during the period p, ,[Nm3/p],,,,: Net calorific value of gas fuel consumed by project absorption chiller j[MJ/Nm3]: CO2 emission factor for gas fuel consumed by project absorption chiller j[tCO2/GJ]: Identification number of the project absorption chillerjH. Calculation of emissions reductions

=

−

Where
: Emission reductions during the period p [tCO2/p]: Reference emissions during the period p [tCO2/p]: Project emissions during the period p [tCO2/p]

I.

Data and parameters fixed ex ante

The source of each data and parameter fixed ex ante is listed as below.
Parameter,

Description of data

SourceCO2 emission factor for consumed electricity in[Grid electricity]

the recipient facility i [tCO2/MWh]

The most recent value
available at the time of

When the recipient facility consumes only grid

validation is applied and fixed

electricity or captive electricity, the project

for the monitoring period

participant applies the CO2 emission factor

thereafter. The data is sourced

respectively.

from “Emission Factors of7

JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03
Electricity Interconnection
When both grid electricity and captive

Systems”, National

electricity may be consumed in the recipient

Committee on Clean

facility, the project participant applies the CO2

Development Mechanism

emission factor with lower value.

(Indonesian DNA for CDM),
based on data obtained by[CO2 emission factor]

Directorate General of

For grid electricity: The most recent value

Electricity, Ministry ofavailable from the source stated in this table atEnergy and Mineral

the time of validation

Resources, Indonesia, unlessotherwise instructed by the

For captive electricity including cogeneration

Joint Committee.

system, it is determined based on the following
options:[Captive electricity]a) Calculated from its power generation

For the option a)efficiency (Specification of the captive,[%]) obtained frommanufacturer’s specification

power generation system

The power generation efficiency based on lower

connected to the recipientheating value (LHV) of the captive power

facility i, provided by thegeneration system from the manufacturer’s

manufacturer (specification is applied;

CO2 emission factor of the,= 3.6 ×

100
,

[%]).

,

fuel consumed by the captive

×

,

,

power generation system
connected to the recipientb) Calculated from measured data

facility i (The power generation efficiency calculated[tCO2/GJ]) in order offrom monitored data of the amount of fuel input

preference:for power generation (1) values provided by the fuelof electricity generated (, , ) and the amount, , ) during the,,

supplier;

monitoring period p is applied. The

2) measurement by the projectmeasurement is conducted with the monitoring

participants;

equipment to which calibration certificate is3) regional or national default

issued by an entity accredited undervalues;national/international standards;

4) IPCC default values
provided in table 1.4 of Ch.1
Vol.2 of 2006 IPCC

8

JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03,=

Where:
,

,

,,

×

×

,

,

×

,

,

Guidelines on National GHG
1

Inventories. Lower value is,,: Net calorific value of the fuelapplied.
For the option b)

consumed by the captive power generation

Generated and suppliedsystem connected to the recipient facility ielectricity by the captive[GJ/mass or volume]

power generation system
connected to the recipientNote:facility i (In case the captive electricity generation system[MWh/p]).

connected to the recipient facility i meets all of

Fuel amount consumed by thethe following conditions, the value in thecaptive power generation

following table may be applied todepending on the consumed fuel type.

,,,system connected to therecipient facility i (,,[mass or volume/p]).
The system is non-renewable generation

Net calorific value

system(Electricity generation capacity of thevolume]) and CO2 emission

system is less than or equal to 15 MW

factor of the fuel (,,[GJ/mass or[tCO2/GJ]) in order offuel type,

Dieselfuel

Natural gas

0.8 *10.46 *2,,

preference:
1) values provided by the fuelsupplier;2) measurement by the project*1 The most recent value at the time ofparticipants;

validation is applied.

3) regional or national default*2 The value is calculated with the equation invalues;the option a) above. The lower value of default4) IPCC default values

effective CO2 emission factor for natural gas

provided in tables 1.2 and 1.4(0.0543 tCO2/GJ), and the most efficient valueof Ch.1 Vol.2 of 2006 IPCC

of default efficiency for off-grid gas turbine

Guidelines on National GHG

systems (42%) are applied.

Inventories. Lower value isapplied.
[Captive electricity withdiesel fuel]9

JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03
CDM approved small scale
methodology: AMS-I.A.
[Captive electricity withnatural gas]
2006 IPCC Guidelines on
National GHG Inventories forthe source of EF of naturalgas.
CDM Methodological tool
"Determining the baseline
efficiency of thermal orelectric energy generation
systems version02.0" for thedefault efficiency for off-grid
power plants.
Reference boiler efficiency

Value derived from the resultof survey. The default value,

Default value is set to 89 [%].

89 [%], should be revised if
necessary.

,

CO2 emission factor for fossil fuel consumed by

In the order of preference:

the reference boiler [tCO2/GJ]a) values provided by fuelsupplier;

CO2 emission factor of natural gas is applied inthis methodology in a conservative manner.

b) measurement by the
project participants;c) regional or national
default values; ord) IPCC default values

provided in table 1.4 of
Ch.1 Vol.2 of 2006 IPCC
Guidelines on National
GHG Inventories. Lower
value is applied.
,

COP of reference chiller jSpecifications of projectchiller j prepared for the

The COP of the reference chiller j is selected

quotation or factoryfrom the default COP value in the following

acceptance test data by

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JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03
table in line with cooling capacity of the project

manufacturer.

chiller j. (“x” in the table represents cooling
capacity per unit.)

The default COP values arederived from the result of[Default COP values of reference chillers]survey on COP of chillers

Cooling
capacity
per unit(USRt)

300≤
x
≤350

350<
x
≤550

550<
x
≤750

750<
x
≤1,300from manufacturers that have

COPRE,i

5.46

5.69

5.90

6.03

methodology. The default

high market share. The survey
should prove the use of clear
COP values should be revised
if necessary from survey
result which is conducted by
JC or project participants.

,

Net calorific value of gas fuel consumed by the

In the order of preference:

CGS [GJ/mass or volume]a) values provided by fuelsupplier;b) measurement by the
project participants;c) regional or national
default values; ord) IPCC default values

provided in table 1.2 of
Ch.1 Vol.2 of 2006 IPCC
Guidelines on National
GHG Inventories. Upper
value is applied.
,

CO2 emission factor for gas fuel consumed by

In order of preference:

the CGS [tCO2/GJ]a) values provided by fuelsupplier;b) measurement by the
project participants;c) regional or national
default values; ord) IPCC default values

provided in table 1.4 of
Ch.1 Vol.2 of 2006 IPCC
Guidelines on National11

JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03
GHG Inventories. Upper
value is applied.
,

CO2 emission factor for consumed electricity by[Grid electricity]

the project absorption chiller j [tCO2/MWh]

The most recent value
available at the time of

When the absorption chiller consumes only grid

validation is applied and fixed

electricity or captive electricity, the project

for the monitoring period

participant applies the CO2 emission factor

thereafter. The data is sourced

respectively.

from “Emission Factors ofElectricity Interconnection

When both grid electricity and captive

Systems”, National

electricity may be consumed in the absorption

Committee on Clean

chiller, the project participant applies the CO2

Development Mechanism

emission factor with lower value.

(Indonesian DNA for CDM),
based on data obtained by[CO2 emission factor]

Directorate General of

For grid electricity: The most recent value

Electricity, Ministry ofavailable from the source stated in this table atEnergy and Mineral

the time of validation

Resources, Indonesia, unlessotherwise instructed by the

For captive electricity including cogeneration

Joint Committee.

system, it is determined based on the following
options:[Captive electricity]a) Calculated from its power generation

For the option a)efficiency (Specification of the captive,[%]) obtained frommanufacturer’s specification

power generation system

The power generation efficiency based on lower

connected to the absorption

heating value (LHV) of the captive powerchiller j, provided by thegeneration system from the manufacturer’s

manufacturer (specification is applied;

CO2 emission factor of the,= 3.6 ×

100
,

,

[%]).

fuel consumed by the captive

×

,

,

power generation system
connected to the absorptionb) Calculated from measured data

chiller j (The power generation efficiency calculated[tCO2/GJ]) in order offrom monitored data of the amount of fuel input

preference:

12

,

,

JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03
for power generation (of electricity generated (, , ) and the amount, , ) during the1) values provided by the fuelsupplier;

monitoring period p is applied. The

2) measurement by the projectmeasurement is conducted with the monitoring

participants;

equipment to which calibration certificate is3) regional or national default

issued by an entity accredited undervalues;national/international standards;

4) IPCC default values,=

Where:
,

,

, ,

×

×

,

,

×

,

,

provided in table 1.4 of Ch.1
1

Vol.2 of 2006 IPCC
, ,: Net calorific value of the fuelGuidelines on National GHG
Inventories. Lower value isapplied.

consumed by the captive power generation
system connected to the absorption chiller j

For the option b)[GJ/mass or volume]

Generated and supplied
electricity by the captive

Note:

power generation system

In case the captive electricity generation system

connected to the absorption

connected to the absorption chiller j meets all ofchiller j (the following conditions, the value in the

Fuel amount consumed by thefollowing table may be applied todepending on the consumed fuel type.

,, ,[MWh/p]).

captive power generation
system connected to therecipient facility j (, ,The system is non-renewable generation[mass or volume/p]).

systemNet calorific value

Electricity generation capacity of the(system is less than or equal to 15 MW

volume]) and CO2 emission,,[GJ/mass orfactor of the fuel (fuel type,

Dieselfuel

Natural gas

0.8 *10.46 *2[tCO2/GJ]) in order of,,preference:
1) values provided by the fuelsupplier;*1 The most recent value at the time of2) measurement by the projectvalidation is applied.

participants;*2 The value is calculated with the equation in3) regional or national default

the option a) above. The lower value of default

values;effective CO2 emission factor for natural gas4) IPCC default values

13

JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03(0.0543 tCO2/GJ), and the most efficient value

provided in tables 1.2 and 1.4of default efficiency for off-grid gas turbineof Ch.1 Vol.2 of 2006 IPCC

systems (42%) are applied.

Guidelines on National GHG
Inventories. Lower value isapplied.
[Captive electricity withdiesel fuel]CDM approved small scale
methodology: AMS-I.A.
[Captive electricity withnatural gas]
2006 IPCC Guidelines on
National GHG Inventories forthe source of EF of naturalgas.
CDM Methodological tool
"Determining the baseline
efficiency of thermal orelectric energy generation
systems version02.0" for thedefault efficiency for off-grid
power plants.

,,

Net calorific value of gas fuel consumed by the

In the order of preference:

project absorption chiller j [GJ/mass or volume]a) values provided by fuelsupplier;b) measurement by the
project participants;c) regional or national
default values; ord) IPCC default values
provided in table 1.2 of
Ch.1 Vol.2 of 2006 IPCC
Guidelines on National
GHG Inventories. Upper
value is applied.

14

JCM_ID_AM023_ver01.0
Sectoral scopes: 01 and 03,,

CO2 emission factor for gas fuel consumed by

In order of preference:the project absorption chiller j [tCO2/GJ]

a)values provided by fuelsupplier;b)measurement by the
project participants;c)regional or national
default values; ord) IPCC default values
provided in table 1.4 of
Ch.1 Vol.2 of 2006 IPCC
Guidelines on National
GHG Inventories. Upper
value is applied.
History of the document
Version
01.0

Date
17 September 2020

Contents revisedElectronic decision by the Joint Committee
Initial approval.

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