JCM_TH_F_PM_ver01.0

JCM Proposed Methodology Form
Cover sheet of the Proposed Methodology Form
Form for submitting the proposed methodology
Host Country

The Kingdom of Thailand

Name of the methodology proponents Institute for Global Environmental Strategies
submitting this form

(IGES)

Sectoral scope(s) to which the Proposed 1. Energy industries (renewable- / nonMethodology applies

renewable sources)

Title of the proposed methodology, and Waste heat recovery and utilization by installingversion number

heat exchanger to heat recovery steam generatorof gas co-generation system, Ver. 01.0

List of documents to be attached to thisThe attached draft JCM-PDD:

form (please check):

Additional information

Date of completion

28/04/2022

History of the proposed methodology
Version01.0

Date
28/04/2022

Contents revisedFirst Edition1

JCM_TH_F_PM_ver01.0

A. Title of the methodology
Waste heat recovery and utilization by installing heat exchanger to heat recovery steam
generator of gas co-generation system, Ver. 01.0

B. Terms and definitions
Terms

Definitions

Gas co-generation SystemA system is composed of gas turbine and heat recovery steam
generator equipped with duct burner.
By recovering waste heat of exhaust gas emitted by gas turbine,
steam is generated being supported by duct burner.

Heat recovery steam

Heat recovery steam generator (HRSG) is a waste heat recoverygenerator (HRSG)

boiler which utilizes waste heat of exhaust gas emitted by gas
turbine as heat source.

Duct burner

Duct burner is an equipment which additionally burns fossil gas
fuel to support heat source of HRSG

Heat exchanger

Heat exchanger is a mechanical device that recovers andtransfers the waste heat from HRSG to the incoming feed waterof heat recovery steam generator, which increases the overallboiler’s thermal efficiency.

C. Summary of the methodology
Items
GHG

emissionmeasures

Summary
reduction By installing heat exchanger(s) to heat recovery steam
generator of gas co-generation system(s), feed water into heatrecovery steam generator is heated up. Consequently,
consumption of fossil gas fuel by duct burner is reduced,
leading to the reduction of GHG emissions.

Calculation
emissions

ofreference Reference emissions are calculated using amount of fossil gas
fuel consumed by duct burner of heat recovery steam generator
with project heat exchanger, density of fossil gas fuel consumed
by duct burner of heat recovery steam generator, net calorific2

JCM_TH_F_PM_ver01.0

value of fossil gas fuel consumed by duct burner of heatrecovery steam generator, CO2 emission factor for the fossil gas
fuel consumed by duct burner of heat recovery steam generator,
amount of heating energy recovered by project heat exchanger
and amount of heating energy transferred into the feed water ofthe heat recovery steam generator with project heat exchanger.
Calculation

ofproject (In case that project additionally consumes electricity) Projectemissions

emissions are calculated with electricity consumption of pretreatment equipment(s) and CO2 emission factor for electricity
consumed.

Monitoring parameters⚫ Amount of fossil gas fuel consumed by duct burner of heatrecovery steam generator with project heat exchanger⚫ Flow rate of feed water into project heat exchanger⚫ Temperature of water at the outlet of project heat exchanger⚫ Temperature of water at the inlet of project heat exchanger⚫ Flow rate of feed water into heat recovery steam generator
with project heat exchanger⚫ Temperature of feed water into heat recovery steam
generator with project heat exchanger⚫ Amount of electricity consumed by the project

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

Project installs heat exchanger(s) to heat up feed water into heat recovery steam
generator in gas co-generation system.

E. Emission Sources and GHG types
Reference emissions
Emission sources

GHG types

Fossil gas fuel consumed by duct burner(s) to generate the amount of CO2
heating energy recovered by project heat exchanger and utilized for heat
supplyProject emissions

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Emission sources

GHG types

Electricity consumed by project

CO2

F. Establishment and calculation of reference emissions
F.1. Establishment of reference emissions
By implementing the project, the amount of fossil gas fuel consumed by duct burner of heatrecovery steam generator (HRSG) is reduced because the temperature of feed water into HRSG
is increased by heat recovered by project heat exchanger. The amount of waste heat fromexhaust gas of gas turbine into heat recovery steam generator is more of the same as the one
without in the absence of the project.
Heating energy saved by the project is almost only from fossil gas fuel consumed by ductburner.
However, in this methodology, the total amount of heating energy saved by the project is
distributed into the one from fossil gas fuel consumed by duct burner and the one of waste heatfrom exhaust gas of gas turbine by a certain ratio. That means that the waste heat from the gas
turbine is easily transferred to the steam, and the amount of saving fossil gas fuel consumed byduct burner is conservatively identified.
This concept is applied to the equation for calculating reference emissions in order to ensure
net emission reductions.
F.2. Calculation of reference emissions

𝑅𝐸𝑝 = ∑ 𝐹𝐶𝑑𝑏,𝑃𝐽,𝑖,𝑝 × 𝐷𝑔𝑎𝑠 × 𝑁𝐶𝑉𝑔𝑎𝑠 × 𝐸𝐹𝑔𝑎𝑠,𝑓𝑢𝑒𝑙 × 𝑄𝐻𝑅ℎ𝑒,𝑃𝐽,𝑖,𝑝 /𝑄𝐻𝑇𝑓𝑤,𝑃𝐽,𝑖,𝑝 /1000𝑖

𝑄𝐻𝑅ℎ𝑒,𝑃𝐽,𝑖,𝑝 = 𝐹ℎ𝑒,𝑃𝐽,𝑖,𝑝 × (𝑇𝑂ℎ𝑒𝑖,𝑝 − 𝑇𝐼ℎ𝑒,𝑖,𝑝 ) × 𝐶𝑝 /1000
𝑄𝐻𝑇𝑓𝑤,𝑃𝐽,𝑖,𝑝 = 𝐹𝑓𝑤,𝑖,𝑝 × (ℎ′′ 𝑠𝑡𝑒𝑎𝑚,𝑖 − ℎ′𝑓𝑤,𝑃𝐽,𝑖,𝑝 )ℎ′𝑓𝑤,𝑃𝐽,𝑖,𝑝 = (𝑇𝑓𝑤,𝑃𝐽,𝑖,𝑝 − 0) × 𝐶𝑝 /1000
Where;REp: Reference emissions during the period p [tCO2/p]4

JCM_TH_F_PM_ver01.0

FCdb,PJ,i,p: Amount of fossil gas fuel consumed by duct burner of heat recovery steam
generator with project heat exchanger i during the period p [Nm3/p]

Dgas: Density of fossil gas fuel consumed by duct burner of heat recovery steam
generator [kg/Nm3]

NCVgas: Net calorific value of fossil gas fuel consumed by duct burner of heatrecovery steam generator [GJ/t]

EFgas,fuel: CO2 emission factor for the fossil gas fuel consumed by duct burner ofheat recovery steam generator [tCO2/GJ]

𝑄𝐻𝑅ℎ𝑒,𝑃𝐽,𝑖,𝑝 : Amount of heating energy recovered by project heat exchanger i during
the period p [GJ/p]
Fhe,PJ,i,p: Flow rate of feed water into project heat exchanger i during the period p[t/p]𝑇𝑂ℎ𝑒,𝑃𝐽,𝑖,𝑝: Temperature of water at the outlet of project heat exchanger i during theperiod p [degree Celsius]

𝑇𝐼ℎ𝑒,𝑃𝐽,𝑖,𝑝: Temperature of water at the inlet of project heat exchanger i during theperiod p [degree Celsius]

𝐶𝑝
𝑄𝐻𝑇𝑓𝑤,𝑃𝐽,𝑖,𝑝: Specific heat capacity of water [MJ/(t·°C)]
Amount of heating energy transferred into the feed water of the heatrecovery steam generator with project heat exchanger i during the periodp [GJ/p]

Ffw,i,p: Flow rate of feed water into the heat recovery steam generator with project
heat exchanger i during the period p [t/p]′′ℎ 𝑠𝑡𝑒𝑎𝑚,𝑖: Specific enthalpy of steam supplied by the heat recovery steam generator
with project heat exchanger i [GJ/t]ℎ′𝑓𝑤,𝑃𝐽,𝑖,𝑝: Specific enthalpy of feed water into heat recovery steam generator withproject heat exchanger i during the period p [GJ/t]

𝑇𝑓𝑤,𝑃𝐽,𝑖,𝑝: Temperature of feed water into the heat recovery steam generator withproject heat exchanger i during the period p [degree Celsius]

i: Identification number of the project heat exchanger

G. Calculation of project emissions

𝑃𝐸𝑝 = 𝐸𝐶𝑃𝐽,𝑝 × 𝐸𝐹𝑒𝑙𝑒𝑐
Where;

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JCM_TH_F_PM_ver01.0

𝑃𝐸𝑝: Project emissions during the period p [tCO2/p]

𝐸𝐶𝑃𝐽,𝑝: Amount of electricity consumed by project heat exchanger(s) during theperiod p [MWh/p]

𝐸𝐹𝑒𝑙𝑒𝑐: CO2 emission factor of consumed electricity [tCO2/MWh]

H. Calculation of emissions reductions

𝐸𝑅𝑝 = 𝑅𝐸𝑝 −𝑃𝐸𝑝Where;

𝐸𝑅𝑝: Emission reductions during the period p [tCO2/p]

𝑅𝐸𝑝: Reference emissions during the period p [tCO2/p]

𝑃𝐸𝑝: 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
𝐷𝑔𝑎𝑠

Description of data

SourceDensity of the fossil gas fuel consumed In the order of preference:by duct burner of heat recovery steam a) values provided by fuel supplier;generator [kg/Nm3]b) measurement by the project
participants; orc) regional or national default
values;𝑁𝐶𝑉𝑔𝑎𝑠Net calorific value of the fossil gas fuelIn the order of preference:

consumed by duct burner of heata) values provided by fuel supplier;recovery steam generator [GJ/t]b) measurement by the project
participants;c) regional or national default
values; ord) IPCC default values provided intable 1.2 of Ch.1 Vol.2 of 2006 IPCC
Guidelines

onNational

GHG

Inventories. Lower value is applied.

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JCM_TH_F_PM_ver01.0

𝐸𝐹𝑔𝑎𝑠,𝑓𝑢𝑒𝑙CO2 emission factor for the fossil gas In the order of preference:
fuel consumed by duct burner of heat a) values provided by fuel supplier;recovery steam generator [tCO2/GJ]b) measurement by the project
participants;c) regional or national default
values; ord) IPCC default values provided intable 1.4 of Ch.1 Vol.2 of 2006 IPCC
Guidelineson

National

GHG

Inventories. Lower value is applied.
𝐶𝑝Specific heat capacity of water

Theoretical value provided in table 6[MJ/(t·°C)]

of Cabinet Order No. 357 of 1992,

A default value is set to 4.184

Japan[MJ/(t·°C)]h’’steam,iSpecific enthalpy of steam supplied by

Saturated steam table based on

the heat recovery steam generator with

“IAPWS Industrial Formulation”

project heat exchanger i [GJ/t](e.g. steam table published by TheJapan

SocietyofMechanicalEngineers), using the values forsetting steam pressure according tovendor

specification,contract

condition by the steam buyer or
operation manual on the site.
𝐸𝐹𝑒𝑙𝑒𝑐CO2 emission factor of consumed Grid electricity:electricity [tCO2/MWh].

The most recent value available atthe time of validation is applied andWhen project heat exchanger (s) fixed for the monitoring period
consumes only 1) grid electricity, 2) thereafter. The data is sourced from
captive electricity or 3) electricity “Grid Emission Factor (GEF) of
directly supplied from small power Thailand”, endorsed by Thailand
producer (SPP) to the project site Greenhouse

Gas

Management

through its internal grid (e.g. industrial Organization,unlessotherwisepark), the project participant applies the instructed by the Joint Committee.
CO2 emission factor respectively.
Captive electricity:
When project heat exchanger(s) may For the option a)
consume electricity supplied from more Specification of the captive power7

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than 1 electric source, the project generation system connected to theparticipant applies the CO2 emission boiler, provided by the manufacturer
factor with highest value.

(𝜂𝑐𝑎𝑝 [%]).
CO2 emission factor of the fuel[CO2 emission factor]

consumed by the captive power

For 1) grid electricity: The most recent generation system connected to thevalue available from the source stated in boiler (𝐸𝐹𝑓𝑢𝑒𝑙,𝑐𝑎𝑝 [tCO2/GJ]) in orderthis table at the time of validation.

of preference:
1) values provided by the fuelFor 2) captive electricity:supplier;

It is determined based on the following 2) measurement by the project
options:

participants;
3) regional or national defaulta) Calculated from its power generation values;
efficiency (𝜂𝑐𝑎𝑝 [%]) obtained from 4) IPCC default values provided in
manufacturer’s specificationtable 1.4 of Ch.1 Vol.2 of 2006 IPCC

The power generation efficiency based Guidelines

onNationalGHG

on lower heating value (LHV) of the Inventories. Upper value is applied.
captive power generation system fromthe manufacturer’s specification is For the option b)
applied;Generated and supplied electricity

𝐸𝐹𝑒𝑙𝑒𝑐 = 3.6 ×100
× 𝐸𝐹𝑓𝑢𝑒𝑙,𝑐𝑎𝑝𝜂𝑐𝑎𝑝by the captive power generation
system connected to the biomass
boiler(s) (𝐸𝐺𝑐𝑎𝑝, [MWh/p]).

b) Calculated from measured dataThepower

generation

Fuel amount consumed by theefficiency captive power generation system

calculated from monitored data of the connected to the biomass boiler(s)amount of fuel input for power (𝐹𝐶𝑐𝑎𝑝, [mass or volume/p]).
generation (𝐹𝐶𝑐𝑎𝑝,𝑝) and the amount of Net calorific value (𝑁𝐶𝑉𝑓𝑢𝑒𝑙,𝑐𝑎𝑝
electricity generated (𝐸𝐺𝑐𝑎𝑝,𝑝) during [GJ/mass or volume]) and CO2
the monitoring period p is applied. The emission factor of the fuel (𝐸𝐹𝑓𝑢𝑒𝑙,𝑐𝑎𝑝
measurement is conducted with the [tCO2/GJ]) in order of preference:monitoring

equipmenttowhich 1) values provided by the fuelcalibration certificate is issued by an supplier;entityaccredited

under 2) measurement by the projectnational/international standards;

participants;
3) regional or national default

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JCM_TH_F_PM_ver01.0𝐸𝐹𝑒𝑙𝑒𝑐 = 𝐹𝐶𝑐𝑎𝑝,𝑝 × 𝑁𝐶𝑉𝑓𝑢𝑒𝑙,𝑐𝑎𝑝values;× 𝐸𝐹𝑓𝑢𝑒𝑙,𝑐𝑎𝑝4) IPCC default values provided in1tables 1.2 and 1.4 of Ch.1 Vol.2 of𝐸𝐺𝑐𝑎𝑝,𝑝2006 IPCC Guidelines on National×GHG Inventories. Upper value isWhere:

applied.

𝑁𝐶𝑉𝑓𝑢𝑒𝑙,𝑐𝑎𝑝 : Net calorific value of thefuel consumed by the captive power For the option c)generation system connected to the CDM methodological tool “TOOL
boiler [GJ/mass or volume]

05: Baseline, project and/or leakage
emissionsfromelectricityc) Conservative default value:consumption and monitoring ofA value of 1.3 tCO2/MWh is applied.

electricity generation, version 03.0”

For 3) electricity directly supplied from Electricity directly supplied fromsmall power producer (SPP) , it is SPP
determined based on the following
options:a) The value provided by the For option a) the evidence stating

SPP with the evidence; b) The value information relevant to the value of
calculated in the same manner for the emission factor e.g. data of power
option a) of 2) captive electricity as generation, type of power plant, type
instructedabove;c)The

value of fossil fuel, period of time.

calculated in the same manner for theoption b) of 2) captive electricity as
instructed above; When project heatexchanger may consume electricity
supplied from more than 1 SPP, theproject participant applies the CO2
emission factor with the highest value.

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