JCM_ID_AM007_ver01.1
Sectoral scope: 03
Joint Crediting Mechanism Approved Methodology ID_AM007“GHG emission reductions through optimization of boiler operation in Indonesia”
A. Title of the methodology
GHG emission reductions through optimization of boiler operation in Indonesia, ver 1.1

B. Terms and definitions
Terms

Definitions

Utility Facility Operation

Technology to optimize the operation of existing utility

Optimization Technology

facilities such as boilers through application of softwarealgorithm using linear programming method or non-linear
programming method.

C. Summary of the methodology
Items
GHGemissionSummary
reduction The project achieves energy conservation in boilers, throughmeasuresoperation optimization by applying Utility Facility Operation
Optimization Technology.

Calculation

ofreference Reference emissions are calculated on the basis of monitored

emissionsproject steam generation and specific CO2 emissions per steam
generated, through analysis of historical relationship between
steam generation and fuel consumption of boilers.

Calculationofproject Project emissions are calculated on the basis of monitored fuelemissionsconsumption and emission factor of fuel consumed after
implementation of the project.

Monitoring parametersEnergy consumption and steam generation in boilers; and

Number of hour(s) recorded for steam generation.

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

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Criterion 1

The project is implementation of operation optimization of boilers to generatesteam, through introduction of Utility Facility Operation Optimization
Technology.

Criterion 2

The site of introduction is an existing industrial facility which includes two ormore boilers to generate steam.

Criterion 3

Historical data for fuel consumption, fuel characteristics (type of fuel, net
calorific value) and generation of steam is identifiable for individual boiler for atleast one year, as specified in the methodology.

Criterion 4All steam demand is met internally and not sourced from outside the industrialfacility.

E. Emission Sources and GHG types
Reference emissions
Emission sources

GHG types

Emissions from fossil fuel consumption by boilers

CO2

Project emissions
Emission sources

GHG types

Emissions from fossil fuel consumption by boilers

CO2

F. Establishment and calculation of reference emissions
F.1. Establishment of reference emissions
Reference emissions are calculated under the assumption that the current boilers continue to beused. When new boilers are introduced to substitute existing boilers or as capacity expansion,2

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procedure to recalculate reference emissions is provided.
In order to establish reference emissions, CO2 emissions are calculated on the basis ofregression obtained through regression analysis of historical CO2 emissions, with historicalsteam generation as variables.
Ensuring net emission reductions
The methodology ensures conservativeness by not including the associated reduction of fuel for
auxiliary equipments (e.g. fans and pumps) which is expected to occur as a result of the project.
Furthermore, the methodology ensures net reduction by adopting a conservative assumption
when boilers are replaced.
F.2. Calculation of reference emissions
Step 1. Calculation of historical emissions
Historical emissions are calculated as follows:Obtain data on hourly fuel consumption for the historical period of one year preceding
introduction of Utility Facility Operation Optimization Technology up to the period notearlier than 6 months before submission of the draft PDD to the secretariat.

Calculate hourly CO2 emissions according to the following formulae.

HE j ,xh = å( FCi , j ,xh ´ NCVi ´ EFi )(1)

HExh = å HE j , xh

(2)

ij

WhereHExh=

Historical CO2 emissions on hour h in the historical 1-year period x.
[tCO2/h]HEj,xh=Historical CO2 emissions from boiler j on hour h in the historical 1-year
period x. [tCO2/h]
Consumption of fossil fuel i by the boiler j on hour h in the historicalFCi,j,xh=NCVi=

Net calorific value of fossil fuel type i.[GJ/mass or volume unit]EFi=

CO2 emission factor of fossil fuel type i. [tCO2/GJ]

1-year period x.[mass or volume unit/h]

Step 2. Regression analysis

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Plot the data with hourly data of historical steam generation by the boilers (STxh) on the x-axis
and hourly total CO2 emissions by the boilers (HExh) on the y-axis. Omit data obtained during
periods of startup, shutdown, maintenance or malfunction of equipment or measurement device,and periods of operating outside the operating range specified by the project participants or by
the equipment manufacturer.
Perform a linear regression analysis. If the regression coefficient R2 of the plotted data is smaller
than 0.49, omit statistical outliers with a plot outside 2 times the standard deviation from theregression line.
Repeat the process until the R2 of the plotted data is larger than 0.49. Perform a linear regression
analysis with the remaining data to derive a linear regression equation as follows

HE xh = a ´ STxh + b(3)WhereHExh=Historical CO2 emissions from boilers on hour h in the historical 1-yearperiod x. [tCO2/h]

STxh

=

Historical steam generation by the boilers on hour h in the historical
1-year period x. [tonnes steam/h]a=Parameter derived as a result of linear regression analysis (specificemission factor).[tCO2/tonnes steam]b

Parameter derived as a result of linear regression analysis (y-intercept).
[tCO2/h].

If the resulting regression coefficient R2 remains below 0.49 as a result of the analysis, thenconduct the following procedure.
-Perform regression analysis for individual boiler for the same historical 1-year period x.
Obtain regression coefficient R for each boiler by using the same procedure as stated above.

-Identify boilers which resulted in the resulting regression coefficient R2 is lower than 0.49.
For such boiler, re-calibrate measurement equipments attached to the boiler (fuel flowmeters, steam flow meters). Conduct a one-month campaign without operating the Utility
Facility Operation Optimization Technology. Perform a linear regression analysis based on
the data obtained during the one-month campaign, by using the same procedure as statedabove, to yield a regression equation as follows:4

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HE j ,ch = a j ´ STj , ch + b j(4)

WhereHE j ,ch = å( FCi , j ,ch ´ NCVi ´ EFi )(5)iHEj,ch=Historical CO2 emissions from the boiler j on hour h in the one-month
campaign c. [tCO2/h]

STj,ch=Historical steam generation by the boiler j on hour h in the one-month
campaign c. [tonnes steam/h]aj, bj=Parameters derived as a result of linear multivariate regression analysis forindividual boiler j based on the data obtained in the one-month campaign.

FCi,j,ch=Consumption of fuel i by the boiler j on hour h in the one-month campaign
c. [mass or volume unit/h]

NCVi

=

Net calorific value of fossil fuel type i. [GJ/mass or volume unit]EFi=

CO2 emission factor of fossil fuel type i. [tCO2/GJ]-Re-perform steps 1 and 2 but by substituting for the boiler which has conducted thecampaign, STj,xh by [(HEj,xh – bj) / aj] for cases where only steam flow meters are found to
be deficient, and HEj,xh by (aj×STj,xh.+bj) in all other cases. STj,xh is the historical steam
generation by the boiler j on hour h in the historical 1-year period x.
If the regression coefficient R2 of the regression analysis according to step 2 with the-adjusted data is still below 0.49, the methodology is not applicable.
Step 3. Calculation of reference emissions
Reference emissions are calculated as follows:

RE p = å( a ´ STp ,h + b )h= ൫ܽ × ܵܶ௣,ଵ + ܾ൯ + ൫ܽ × ܵܶ௣,ଶ + ܾ൯ + ⋯ + ൫ܽ × ܵܶ௣,ுିଵ + ܾ൯ + ൫ܽ × ܵܶ௣,ு + ܾ൯= ܽ × ෍ ܵܶ௣,௛ + ܾ × ‫ܪ‬௣௛= ܽ × ܵܶ௣ + ܾ × ‫ܪ‬௣

(6)

Where
REp

=

Reference emissions during the period p. [tCO2/p]

STp,h=

Process steam generation on hour h during the period p. [tonnes steam/h]a=Parameter derived as a result of linear regression analysis (specific5

JCM_ID_AM007_ver01.1
Sectoral scope: 03emission factor). [tCO2/tonnes steam]b=

Parameter derived as a result of linear regression analysis (y-intercept).
[tCO2/h]STp,=Process steam generation during the period p. [tonnes steam/p]

Hp=

Number of hour(s) h recorded for steam generation during the period p.
[h/p]Annex: Provisions for recalculation of reference emissions when new boilers areintroduced.
When new boilers are introduced, reference emissions obtained as above are no longer valid,
and need to be recalculated under the following procedure. To undergo this procedure, historical
data for energy consumption and generation of each boiler is required. The procedure applies tocases when new boilers replace existing boilers, and when new boilers are introduced to provide
additional capacity.
Step i: Calculate historical CO2 emissions on hour h in the historical period x for all
existing boilers.
The calculation is conducted according to the following equation.
‫ܧܪ‬௝,௫௛ = ∑௜ ‫ܥܨ‬௜,௝,௫௛ × ܰ‫ܸܥ‬௜ × ‫ܨܧ‬௜(7)WhereHEj,xh=Historical CO2 emissions from the boiler j on hour h in the historical
1-year period x. [tCO2/h]
Consumption of fuel i by the boiler j on hour h in the historical 1-year

FCi,j,xh

=

NCVi

=

Net calorific value of fossil fuel type i. [GJ/mass or volume unit]EFi=

CO2 emission factor of fossil fuel type i. [tCO2/GJ]

period x. [mass or volume unit/h]

Step ii: Calculate design CO2 emission factor of existing boiler
For each existing boiler, calculate its design CO2 emission factor as follows‫ܨܧ‬௝ =

WhereEF,jாி೔,ೕ

(8)

ఎೕ=

Design CO2 emission factor of boiler j. [tCO2/GJ-steam]6

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EFi,j=

ηj=

Weighted average CO2 emission factor of the fuel i consumed by boiler jin the historical 1-year period x. [tCO2/ GJ-fuel]Design efficiency of existing boiler j. [dimensionless][GJ-fuel/ GJ-steam]For boilers providing the same utility as the new boiler, rank each existing boiler
according to the descending order of design CO2 emission factor.
Step iii: Adjust CO2 emission factor of existing boiler (HEj,xh)
Adjust CO2 emission factor of existing boiler (HEj,xh), starting from the existing boiler
whose design CO2 emission factor is highest, up to the theoretical maximum amount ofutility that can be provided by the new boiler (assuming a capacity factor of 100%), asfollows:ாி೙೐ೢ, 1)‫ܧܪ‬௔ௗ௝,௝,௫௛ = ‫ܧܪ‬௝,௫௛ × min( ாி(9)ೕWhere EFnew is EFj for the new boiler.
Step iv: Recalculate HExh
Recalculate HExh (Historical CO2 emissions on hour h in the historical 1-year period x)
based on the adjusted and non-adjusted values of HEj,xh.
Step v: Recalculate the regression analysis
Linear multivariate regression analysis as described in step 2 is recalculated, using
HEadj,xh obtained above instead of HEx,h.
When boilers are introduced during the 1-year historical period, undergo the recalculation steps
i and v for the period before introduction of new boilers.
G. Calculation of project emissions
Project emissions are calculated on the basis of fuel consumption.

PE p = å( FCi , p ´ NCVi ´ EFi )

(10)

i

WherePEp=FCi,p=NCVi=Project emissions during the period p. [tCO2/p]
Consumption of fossil fuel i by the boiler during the period p. [mass orvolume unit/p]
Net calorific value of fossil fuel type i. [GJ/mass or volume unit]

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CO2 emission factor of fossil fuel type i. [tCO2/GJ]

H. Calculation of emissions reductions
Emission reductions are calculated as follows:

ER p = RE p - PE p

(11)

Where
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 anteThe source of each data and parameter fixed ex ante is listed as below.
Parameter
FCi,j,xh

Description of data

SourceConsumption of fuel i by the boiler

Site record.

j on hour h in the historical 1-year
period x.
FCi,j,chConsumption of fuel i by the boiler

Site record.

j on hour h in the one-month
campaign c.
NCVi

Net calorific value of fossil fueltype i.

EFi

CO2 emission factor of fossil fueltype i.

STxh

Historical steam generation by the8In the order of preference:a) values provided by the fuel supplier;b) measurementby
theproject
participants;c) regional or national default values;d) IPCC default values provided in table
1.2 of Ch.1 Vol.2 of 2006 IPCC
Guidelines on National GHG
Inventories. Lower value is applied.
In the order of preference:a) values provided by the fuel supplier;b) measurementbytheproject
participants;c) regional or national default values;d) 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.
Site record.

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boilers on hour h in the historical
1-year period x.
STj,chHistorical steam generation by theSite record.

boiler j on hour h in the one-month
campaign c.
STj,xhHistorical steam generation by theSite record.

boilers j on hour h in the historical
1-year period x.
a, bParameters derived as a result ofCalculated according to step 2 in section

linear multivariate regression

F2.

analysis.
aj, bjParameters derived as a result ofCalculated according to step 2 in section

linear multivariate regression

F2.

analysis.
History of the document
Version01.1

Date
28 November 2018

01.0

18 May 2015

Contents revisedElectronic decision by the Joint Committee
Revisions to: Add a monitoring parameter and equation to calculate theoriginal equation appropriately; Correct units of the default values on the monitoring
spreadsheet; and Change editorially.
JC4, Annex 2
Initial approval.

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