Emission factors and reference values

Version 4.0
September 2026

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Document revision history

Version number	Publication Date	Summary of changes
4.0	September 9, 2026	Addition of emission factors and other reference values applicable to the Reducing Manure Methane Emissions federal offset protocol Addition of reference values applicable to protocols with methane destruction and displacement of fossil fuels Update of emission factors and other reference values in alignment with the National Inventory Report 1990–2024: Greenhouse Gas Sources and Sinks in Canada
3.0	October 24, 2025	Addition of emission factors and other reference values applicable to the Reducing Enteric Methane Emissions from Beef Cattle federal offset protocol Update of emission factors and other reference values in alignment with the National Inventory Report 1990–2023: Greenhouse Gas Sources and Sinks in Canada
2.0	May 6, 2024	Addition of reference values applicable to the Improved Forest Management on Private Land federal offset protocol Update of emission factors and other reference values in alignment with the National Inventory Report 1990–2022: Greenhouse Gas Sources and Sinks in Canada Addition of rules on the timing applicability of emission factors and other reference values Changes to clarify the structure and facilitate the use of the document
1.1	June 13, 2023	Update of information and emission factors in alignment with the April 2023 publication of the National Inventory Report 1990–2021: Greenhouse Gas Sources and Sinks in Canada
1.0	June 8, 2022	Initial version

1.0 Introduction

Canada’s Greenhouse Gas (GHG) Offset Credit System is established under Part 2 of the Greenhouse Gas Pollution Pricing Act to provide an incentive to implement projects that result in domestic GHG reductions that would not have been generated in the absence of the project, that go beyond legal requirements and that are not subject to carbon pollution pricing mechanisms.

Canada’s GHG Offset Credit System consists of:

the Canadian Greenhouse Gas Offset Credit System Regulations (the Regulations), which establish the system, implement the operational aspects and set the general requirements applicable to all project types
federal offset protocols, included in the Compendium of Federal Offset Protocols (the Compendium), each containing requirements for project implementation and methods for quantifying GHG reductions for a given project type, and
the Credit and Tracking System (CATS) to register offset projects, issue and track offset credits, and share key information through Canada’s GHG Offset Credit System Public Registry

The Regulations apply to a proponent of a project which is of a type for which a protocol has been included in the Compendium; that aims to generate GHG reductions by preventing GHG emissions or removing GHGs from the atmosphere; and with respect to which the GHG reductions are real, additional, quantified, verified, unique and permanent. Offset credits will be issued to a proponent of a project for the period covered by a project report in the amount determined in accordance with subsection 29(2) of the Regulations if requirements of subsection 29(1) of the Regulations are met.

As per subsection 19(1) of the Regulations, this document provides emission factors and other reference values that a proponent must use in conjunction with a federal offset protocol to quantify the GHG reductions generated by a project. It also specifies timing applicability for the emission factors and other reference values that are to be used for the quantification of GHG reductions occurring in a given calendar year.

This document is categorized into general emission factors and other reference values that are applicable to more than one federal offset protocol, and protocol-specific emission factors and other reference values. For all emission factors and other reference values, it is specified which parameter in a given protocol the emission factor or other reference value corresponds to. The proponent may need to convert the units of the emission factors and other reference values provided in this document to align with the units presented in the quantification methodology of the relevant federal offset protocol.

Emission factors and other reference values are subject to periodic updates when a new federal offset protocol is included in the Compendium, or when updated versions of the sources referenced in this document are published. As per subsection 1(2) of the Regulations, proponents must use the latest version of this document.

2.0 Abbreviations and acronyms

The following abbreviations and acronyms are used in this document:

Act: Greenhouse Gas Pollution Pricing Act
CH₄: methane
CO₂: carbon dioxide
CO₂e: carbon dioxide equivalent
g: gram
kg: kilogram
kWh: kilowatt hour
L: litre
m³: cubic meter
N₂O: nitrous oxide
SF₆: sulfur hexafluoride
t: metric tonne

Many emission factors and other reference values contained in this document are sourced from the annual National inventory reports for GHG sources and sinks in Canada (NIR), published by Environment and Climate Change Canada (ECCC). To simplify references to these reports in the footnotes, a short form citation is used. The complete citation of “Environment and Climate Change Canada. (year x). National Inventory Report 1990–year y: Greenhouse Gas Sources and Sinks in Canada” is replaced by “ECCC. (year x). NIR 1990–year y.” The short form citation in the footnotes also includes the relevant report part number, table number and table title corresponding to the emission factor or other reference value.

3.0 General

3.1 Global warming potentials

Global warming potentials to be used for the quantification of GHG reductions are the ones published in Schedule 3 to the Act at the time GHG reductions occur.

3.2 Timing applicability of emission factors and other reference values

Many emission factors and other reference values contained in this document are sourced from Canada’s NIR, which is submitted annually to the United Nations Framework Convention on Climate Change by April 15 of each year. The NIR covers GHG emissions from 1990 to two calendar years prior to publication (e.g., the NIR published in April 2026 contains the national inventory of GHG emissions for 2024).

To reflect the emission factors and other reference values from the most recently published NIR, this document is published each year. Given the difference between the year of NIR publication and the last year included in the GHG emission inventory, as well as the need to provide project proponents time to obtain and apply emission factors and other reference values to their project after this document is published, the following general approach is used for the timing applicability of emission factors and other reference values in this document:

Emission factors and other reference values from an NIR published in a given year apply to the quantification of GHG reductions that occur in the subsequent calendar year. For clarity and ease of reference, this document contains a table applicable to each calendar year for any emission factor or other reference value, regardless of whether the factor or other value has changed compared with the previous NIR.

This approach is only applicable for projects in Canada’s GHG Offset Credit System. It is not applicable to the national GHG inventory or other pricing mechanisms for GHG emissions.

4.0 General emission factors and other reference values

Emission factors and other reference values in Section 4.0 may be applicable to more than one federal offset protocol.

4.1 Fossil fuel combustion

Emission factors contained in Tables 1.1, 1.2, 1.3, and 1.4 correspond to the parameter EF_CO2 in applicable protocols.

Emission factors contained in Table 1.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024.

Table 1.1: CO₂ emission factors for natural gas (g CO₂/m³ natural gas) for 2023 and 2024
Province / Territory	Marketable^{Footnote 1} ^a	Non-marketable^{Footnote 2} ^b
British Columbia	1 966	2 162
Alberta	1 962	2 109
Saskatchewan	1 920	2 441
Manitoba	1 915	2 401
Ontario	1 921	2 401
Quebec	1 926	-
New Brunswick	1 919	2 401
Nova Scotia	1 919	2 494
Prince Edward Island	1 919	-
Newfoundland and Labrador	1 919	2 202
Yukon	1 966	2 401
Northwest Territories	1 966	2 466
Nunavut	1 966	-

^a The term “marketable” applies to fuel consumed by the Utility, Industry, Residential, Commercial, and Transport subsectors.

^b The term “non-marketable” applies to raw/unprocessed gas consumption, mainly by natural gas producers.

Emission factors contained in Table 1.2 must be used for the quantification of GHG reductions occurring in calendar year 2025.

Table 1.2: CO₂ emission factors for natural gas (g CO₂/m³ natural gas) for 2025
Province / Territory	Marketable^{Footnote 3}	Non-marketable^{Footnote 4}
British Columbia	1 966	2 162
Alberta	1 962	2 113
Saskatchewan	1 920	2 441
Manitoba	1 915	2 401
Ontario	1 921	2 401
Quebec	1 926	-
New Brunswick	1 919	2 401
Nova Scotia	1 919	2 494
Prince Edward Island	1 919	-
Newfoundland and Labrador	1 919	2 340
Yukon	1 966	2 401
Northwest Territories	1 966	2 466
Nunavut	1 966	-

Emission factors contained in Table 1.3 must be used for the quantification of GHG reductions occurring in calendar year 2026.

Table 1.3: CO₂ emission factors for natural gas (g CO₂/m³ natural gas) for 2026
Province / Territory	Marketable^{Footnote 5}	Non-marketable^{Footnote 6}
British Columbia	1 966	2 162
Alberta	1 962	2 112
Saskatchewan	1 920	2 441
Manitoba	1 915	2 401
Ontario	1 921	2 401
Quebec	1 926	-
New Brunswick	1 919	2 401
Nova Scotia	1 919	2 494
Prince Edward Island	1 919	-
Newfoundland and Labrador	1 919	2 260
Yukon	1 966	2 401
Northwest Territories	1 966	2 466
Nunavut	1 966	-

Emission factors contained in Table 1.4 must be used for the quantification of GHG reductions occurring in calendar year 2027.

Table 1.4: CO₂ emission factors for natural gas (g CO₂/m³ natural gas) for 2027
Province / Territory	Marketable^{Footnote 7}	Non-marketable^{Footnote 8}
British Columbia	1 966	2 199
Alberta	1 962	2 115
Saskatchewan	1 920	2 441
Manitoba	1 915	2 401
Ontario	1 921	2 401
Quebec	1 926	-
New Brunswick	1 919	2 401
Nova Scotia	1 919	2 494
Prince Edward Island	1 919	-
Newfoundland and Labrador	1 919	2 290
Yukon	1 966	2 401
Northwest Territories	1 966	2 466
Nunavut	1 966	-

Emission factors contained in Tables 2.1, 2.2, 2.3, and 2.4 correspond to the parameters EF_CH4 or EF_N2O in applicable protocols.

Emission factors contained in Table 2.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024.

Table 2.1: CH₄ and N₂O emission factors for natural gas (g GHG/m³ natural gas)^{Footnote 9} for 2023 and 2024
Source	CH₄	N₂O
Electric Utilities	0.490	0.049
Industrial	0.037	0.033
Producer Consumption (Non-marketable)	6.4	0.060
Producer Consumption (Non-marketable) – Newfoundland and Labrador	0.490	0.060
Pipelines	1.900	0.050
Cement	0.037	0.034
Manufacturing Industries	0.037	0.033
Residential, Construction, Commercial/Institutional, Agriculture	0.037	0.035

Emission factors contained in Table 2.2 must be used for the quantification of GHG reductions occurring in calendar year 2025.

Table 2.2: CH₄ and N₂O emission factors for natural gas (g GHG/m³ natural gas)^{Footnote 10} for 2025
Source	CH₄	N₂O
Electric Utilities	0.490	0.049
Industrial	0.037	0.033
Producer Consumption (Non-marketable) – Newfoundland and Labrador	0.490	0.060
Producer Consumption (Non-marketable) – British Columbia	8.83^{Footnote 11}	0.060
Producer Consumption (Non-marketable) – Alberta	8.22^{Footnote 11}	0.060
Producer Consumption (Non-marketable) – Saskatchewan	4.64^{Footnote 11}	0.060
Producer Consumption (Non-marketable) – Other provinces and territories	6.4	0.060
Pipelines	1.900	0.050
Cement	0.037	0.034
Manufacturing Industries	0.037	0.033
Residential, Construction, Commercial/Institutional, Agriculture	0.037	0.035

Emission factors contained in Table 2.3 must be used for the quantification of GHG reductions occurring in calendar year 2026.

Table 2.3: CH₄ and N₂O emission factors for natural gas (g GHG/m³ natural gas)^{Footnote 12} for 2026
Source	CH₄	N₂O
Electric Utilities	0.490	0.049
Industrial	0.037	0.033
Producer Consumption (Non-marketable) – Newfoundland and Labrador	0.490	0.060
Producer Consumption (Non-marketable) – British Columbia	9.20^{Footnote 13}	0.060
Producer Consumption (Non-marketable) – Alberta	8.22^{Footnote 13}	0.060
Producer Consumption (Non-marketable) – Saskatchewan	4.20^{Footnote 13}	0.060
Producer Consumption (Non-marketable) – Other provinces and territories	6.4	0.060
Pipelines	1.900	0.050
Cement	0.037	0.034
Manufacturing Industries	0.037	0.033
Residential, Construction, Commercial/Institutional, Agriculture	0.037	0.035

Emission factors contained in Table 2.4 must be used for the quantification of GHG reductions occurring in calendar year 2027.

Table 2.4: CH₄ and N₂O emission factors for natural gas (g GHG/m³ natural gas)^{Footnote 14} for 2027
Source	CH₄	N₂O
Electric Utilities	0.490	0.049
Industrial	0.037	0.033
Producer Consumption (Non-marketable) – Newfoundland and Labrador	0.490	0.060
Producer Consumption (Non-marketable) – British Columbia	9.35^{Footnote 15}	0.060
Producer Consumption (Non-marketable) – Alberta	8.14^{Footnote 15}	0.060
Producer Consumption (Non-marketable) – Saskatchewan	4.10^{Footnote 15}	0.060
Producer Consumption (Non-marketable) – Other provinces and territories	6.4	0.060
Pipelines	1.9	0.050
Cement	0.037	0.034
Manufacturing Industries	0.037	0.033
Residential, Construction, Commercial/Institutional, Agriculture	0.037	0.035

Emission factors contained in Tables 3.1, 3.2, 3.3, and 3.4 correspond to the parameters EF_CO2, EF_CH4 or EF_N2O in applicable protocols.

Emission factors contained in Table 3.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024.

Table 3.1: Emission factors for natural gas liquids (g GHG/L fuel)^{Footnote 16} for 2023 and 2024
Fuel	CO₂	CH₄	N₂O
Propane – Residential	1 515	0.027	0.108
Propane – All Other Uses	1 515	0.024	0.108
Ethane	986	0.024	0.108
Butane	1 747	0.024	0.108

Emission factors contained in Table 3.2 must be used for the quantification of GHG reductions occurring in calendar year 2025.

Table 3.2: Emission factors for natural gas liquids (g GHG/L fuel)^{Footnote 17} for 2025
Fuel	CO₂	CH₄	N₂O
Propane – Residential	1 515	0.027	0.108
Propane – All Other Uses	1 515	0.024	0.108
Ethane	986	0.024	0.108
Butane	1 747	0.024	0.108

Emission factors contained in Table 3.3 must be used for the quantification of GHG reductions occurring in calendar year 2026.

Table 3.3: Emission factors for natural gas liquids (g GHG/L fuel)^{Footnote 18} for 2026
Fuel	CO₂	CH₄	N₂O
Propane – Residential	1 515	0.027	0.108
Propane – All Other Uses	1 515	0.024	0.108
Ethane	986	0.024	0.108
Butane	1 747	0.024	0.108

Emission factors contained in Table 3.3 must be used for the quantification of GHG reductions occurring in calendar year 2027.

Table 3.4: Emission factors for natural gas liquids (g GHG/L fuel)^{Footnote 19} for 2026
Fuel	CO₂	CH₄	N₂O
Propane – Residential	1 515	0.027	0.108
Propane – All Other Uses	1 515	0.024	0.108
Ethane	986	0.024	0.108
Butane	1 747	0.024	0.108

Emission factors contained in Tables 4.1, 4.2, 4.3, and 4.4 correspond to the parameters EF_CO2, EF_CH4 or EF_N2O in applicable protocols.

Emission factors contained in Table 4.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024.

Table 4.1: Emission factors for refined petroleum products (g GHG/L fuel)^{Footnote 20} for 2023 and 2024
Fuel	CO₂	CH₄	N₂O
Light Fuel Oil – Electric Utilities	2 753	0.18	0.031
Light Fuel Oil – Industrial	2 753	0.006	0.031
Light Fuel Oil – Producer Consumption	2 670	0.006	0.031
Light Fuel Oil – Residential	2 753	0.026	0.006
Light Fuel Oil – Forestry, Construction, Public Administration and Commercial/Institutional	2 753	0.026	0.031
Heavy Fuel Oil – Electric Utilities	3 156	0.034	0.064
Heavy Fuel Oil – Industrial	3 156	0.12	0.064
Heavy Fuel Oil – Producer Consumption	3 190	0.12	0.064
Heavy Fuel Oil – Residential, Forestry, Construction, Public Administration and Commercial/Institutional	3 156	0.057	0.064
Kerosene – Electric Utilities	2 560	0.006	0.031
Kerosene – Industrial	2 560	0.006	0.031
Kerosene – Producer Consumption	2 560	0.006	0.031
Kerosene – Residential	2 560	0.026	0.006
Kerosene – Forestry, Construction, Public Administration and Commercial/Institutional	2 560	0.026	0.031
Diesel – Refineries and Others	2 681	0.078	0.022
Diesel – Upgraders	2 681	0.078	0.022
Petroleum Coke – Refineries and Others	3 877^{Footnote 21}	0.12	27.5 g/m³^{Footnote 22}
Petroleum Coke – Upgraders	3 494^{Footnote 21}	0.12	24.0 g/m³^{Footnote 22}
Still Gas – Refineries and Others	1 755 g/m³^{Footnote 21}	0.032 g/m³^{Footnote 23}	0.00002
Still Gas – Upgraders	2 140 g/m³^{Footnote 21}	0.000039	0.00002
Motor Gasoline	2 307	0.100	0.02

Emission factors contained in Table 4.2 must be used for the quantification of GHG reductions occurring in calendar year 2025.

Table 4.2: Emission factors for refined petroleum products (g GHG/L fuel)^{Footnote 24} for 2025
Fuel	CO₂	CH₄	N₂O
Light Fuel Oil – Electric Utilities	2 753	0.18	0.031
Light Fuel Oil – Industrial	2 753	0.006	0.031
Light Fuel Oil – Producer Consumption	2 670	0.006	0.031
Light Fuel Oil – Residential	2 753	0.026	0.006
Light Fuel Oil – Forestry, Construction, Public Administration and Commercial/Institutional	2 753	0.026	0.031
Heavy Fuel Oil – Electric Utilities	3 156	0.034	0.064
Heavy Fuel Oil – Industrial	3 156	0.12	0.064
Heavy Fuel Oil – Producer Consumption	3 190	0.12	0.064
Heavy Fuel Oil – Residential, Forestry, Construction, Public Administration and Commercial/Institutional	3 156	0.057	0.064
Kerosene – Electric Utilities	2 560	0.006	0.031
Kerosene – Industrial	2 560	0.006	0.031
Kerosene – Producer Consumption	2 560	0.006	0.031
Kerosene – Residential	2 560	0.026	0.006
Kerosene – Forestry, Construction, Public Administration and Commercial/Institutional	2 560	0.026	0.031
Diesel – Refineries and Others	2 681	0.078	0.022
Diesel – Upgraders	2 681	0.078	0.022
Petroleum Coke – Refineries and Others	3 776^{Footnote 25}	0.12	27.5 g/m³^{Footnote 26}
Petroleum Coke – Upgraders	3 494^{Footnote 25}	0.12	24.0 g/m³^{Footnote 26}
Still Gas – Refineries and Others	1 780 g/m³^{Footnote 25}	0.032 g/m³^{Footnote 27}	0.00002
Still Gas – Upgraders	2 140 g/m³^{Footnote 25}	0.000039	0.00002
Motor Gasoline	2 307	0.100	0.02

Emission factors contained in Table 4.3 must be used for the quantification of GHG reductions occurring in calendar year 2026.

Table 4.3: Emission factors for refined petroleum products (g GHG/L fuel)^{Footnote 28} for 2026
Fuel	CO₂	CH₄	N₂O
Light Fuel Oil – Electric Utilities	2 753	0.18	0.031
Light Fuel Oil – Industrial	2 753	0.006	0.031
Light Fuel Oil – Producer Consumption	2 670	0.006	0.031
Light Fuel Oil – Residential	2 753	0.026	0.006
Light Fuel Oil – Forestry, Construction, Public Administration and Commercial/Institutional	2 753	0.026	0.031
Heavy Fuel Oil – Electric Utilities	3 156	0.034	0.064
Heavy Fuel Oil – Industrial	3 156	0.12	0.064
Heavy Fuel Oil – Producer Consumption	3 190	0.12	0.064
Heavy Fuel Oil – Residential, Forestry, Construction, Public Administration and Commercial/Institutional	3 156	0.057	0.064
Kerosene – Electric Utilities	2 560	0.006	0.031
Kerosene – Industrial	2 560	0.006	0.031
Kerosene – Producer Consumption	2 560	0.006	0.031
Kerosene – Residential	2 560	0.026	0.006
Kerosene – Forestry, Construction, Public Administration and Commercial/Institutional	2 560	0.026	0.031
Diesel – Refineries and Others	2 681	0.078	0.022
Diesel – Upgraders	2 681	0.078	0.022
Petroleum Coke – Refineries and Others	3 254^{Footnote 29}	0.12	23.6 g/m³^{Footnote 30}
Petroleum Coke – Upgraders	2 717^{Footnote 29}	0.12	18.7 g/m³^{Footnote 30}
Still Gas – Refineries and Others	1 773 g/m³^{Footnote 29}	0.032 g/m³^{Footnote 31}	0.00002
Still Gas – Upgraders	2 140 g/m³^{Footnote 29}	0.000039	0.00002
Motor Gasoline	2 307	0.100	0.02

Emission factors contained in Table 4.3 must be used for the quantification of GHG reductions occurring in calendar year 2027.

Table 4.4: Emission factors for refined petroleum products (g GHG/L fuel)^{Footnote 32} for 2026
Fuel	CO₂	CH₄	N₂O
Light Fuel Oil – Electric Utilities	2 753	0.18	0.031
Light Fuel Oil – Industrial	2 753	0.006	0.031
Light Fuel Oil – Producer Consumption	2 670	0.006	0.031
Light Fuel Oil – Residential	2 753	0.026	0.006
Light Fuel Oil – Forestry, Construction, Public Administration and Commercial/Institutional	2 753	0.026	0.031
Heavy Fuel Oil – Electric Utilities	3 156	0.034	0.064
Heavy Fuel Oil – Industrial	3 156	0.12	0.064
Heavy Fuel Oil – Producer Consumption	3 190	0.12	0.064
Heavy Fuel Oil – Residential, Forestry, Construction, Public Administration and Commercial/Institutional	3 156	0.057	0.064
Kerosene – Electric Utilities	2 560	0.006	0.031
Kerosene – Industrial	2 560	0.006	0.031
Kerosene – Producer Consumption	2 560	0.006	0.031
Kerosene – Residential	2 560	0.026	0.006
Kerosene – Forestry, Construction, Public Administration and Commercial/Institutional	2 560	0.026	0.031
Diesel – Refineries and Others	2 681	0.078	0.022
Diesel – Upgraders	2 681	0.078	0.022
Petroleum Coke – Refineries and Others	3 319^{Footnote 33}	0.12	23.4 g/m³^{Footnote 34}
Petroleum Coke – Upgraders	2 703^{Footnote 33}	0.12	18.6 g/m³^{Footnote 34}
Still Gas – Refineries and Others	1 790 g/m³^{Footnote 33}	0.033 g/m³^{Footnote 35}	0.00002
Still Gas – Upgraders	2 140 g/m³^{Footnote 33}	0.000039	0.00002
Motor Gasoline	2 307	0.100	0.02

4.2 Grid electricity consumption

A ‘consumption intensity’ indicator reflects the GHG emissions intensity of electricity as it is delivered to the consumer.

Emission factors contained in Tables 5.1, 5.2, 5.3, and 5.4 correspond to the parameter EF_EL,GHGin applicable protocols.

Emission factors contained in Table 5.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024.

Table 5.1: Electricity consumption intensities (g CO₂e/kWh electricity consumed)^{Footnote 36} for 2023 and 2024
Province / Territory	Consumption intensity^c
British Columbia	15
Alberta	540
Saskatchewan	730
Manitoba	2.0
Ontario	30
Quebec	1.7
New Brunswick	300
Nova Scotia	690
Prince Edward Island^{Footnote 37}	300
Newfoundland and Labrador	17
Yukon	80
Northwest Territories	170
Nunavut	840

^cConsumption intensity values are impacted by unallocated energy and SF6 transmission emissions.

Emission factors contained in Table 5.2 must be used for the quantification of GHG reductions occurring in calendar year 2025.

Table 5.2: Electricity consumption intensities (g CO₂e/kWh electricity consumed)^{Footnote 38} for 2025
Province / Territory	Consumption intensity
British Columbia	15
Alberta	490
Saskatchewan	670
Manitoba	1.4
Ontario	38
Quebec	1.7
New Brunswick	350
Nova Scotia	700
Prince Edward Island^{Footnote 39}	350
Newfoundland and Labrador	18
Yukon	70
Northwest Territories	190
Nunavut	820

Emission factors contained in Table 5.3 must be used for the quantification of GHG reductions occurring in calendar year 2026.

Table 5.3: Electricity consumption intensities (g CO₂e/kWh electricity consumed)^{Footnote 40} for 2026
Province / Territory	Consumption intensity
British Columbia	18
Alberta	438
Saskatchewan	631
Manitoba	2.5
Ontario	59
Quebec	1.9
New Brunswick	234
Nova Scotia	581
Prince Edward Island^{Footnote 41}	234
Newfoundland and Labrador	17
Yukon	74
Northwest Territories	420
Nunavut	800

Emission factors contained in Table 5.4 must be used for the quantification of GHG reductions occurring in calendar year 2027.

Table 5.4: Electricity consumption intensities (g CO₂e/kWh electricity consumed)^{Footnote 42} for 2026
Province / Territory	Consumption intensity
British Columbia	18
Alberta	346
Saskatchewan	581
Manitoba	3.0
Ontario	73
Quebec	2.6
New Brunswick	375
Nova Scotia	628
Prince Edward Island	265
Newfoundland and Labrador	17
Yukon	134
Northwest Territories	490
Nunavut	760

4.3 Biogas combustion

Biogas includes landfill gas and biogas from manure.

Emission factors contained in Tables 6.1, 6.2, 6.3, and 6.4 correspond to the parameter EF_LFG,N2O or EF_BG,N2O in applicable protocols.

Emission factors contained in Table 6.1 must be used for the quantification of GHG reductions occurring in calendar years 2023 and 2024.

Table 6.1: N₂O emission factors for biogas combustion (kg N₂O/t CH₄)^{Footnote 43} for 2023 and 2024
Biogas combustion type	N₂O
Combustion for energy generation through a boiler, turbine, internal combustion engine or station for natural gas network	0.005
Flaring^{Footnote 44}	0

Emission factors contained in Table 6.2 must be used for the quantification of GHG reductions occurring in calendar year 2025.

Table 6.2: N₂O emission factors for biogas combustion (kg N₂O/tonne CH₄)^{Footnote 45} for 2025
Description	N₂O
Combustion for energy generation through a boiler, turbine, internal combustion engine or station for natural gas network	0.005
Flaring^{Footnote 46}	0.005

Emission factors contained in Table 6.3 must be used for the quantification of GHG reductions occurring in calendar year 2026.

Table 6.3: N₂O emission factors for biogas combustion (kg N₂O/tonne CH₄)^{Footnote 47} for 2026
Description	N₂O
Combustion for energy generation through a boiler, turbine, internal combustion engine or station for natural gas network	0.005
Flaring^{Footnote 48}	0.005

Emission factors contained in Table 6.4 must be used for the quantification of GHG reductions occurring in calendar year 2027.

Table 6.4: N₂O emission factors for biogas combustion (kg N₂O/tonne CH₄)^{Footnote 49} for 2027
Description	N₂O
Combustion for energy generation through a boiler, turbine, internal combustion engine or station for natural gas network	0.005
Flaring^{Footnote 50}	0.005

4.4 CH₄ destruction by eligible destruction device

Default CH₄ destruction efficiencies by eligible destruction device contained in Table 7 correspond to the parameter DE_CH4 in applicable protocols.

These CH₄ destruction efficiencies must be used for GHG reductions occurring from calendar year 2022 onwards, as applicable.

Table 7: Default CH₄ destruction efficiencies by eligible destruction device^{Footnote 51}
Eligible destruction device	CH₄ destruction efficiency (DE_CH4)
Open flare	0.96
Enclosed flare	0.995
Boiler	0.98
Turbine (micro or large)	0.995
Internal combustion engine (stationary or mobile)	0.936
Station for direct injection of upgraded biogas into a natural gas network	0.98
Station for compression or liquefaction of upgraded biogas prior to transport and injection into a natural gas network	0.95

4.5 Displacement of fossil fuels

Higher heating values (HHV) of fuels contained in Table 8 correspond to the parameters HHV_BG or HHV_FF in applicable protocols.

These higher heating values must be used for GHG reductions occurring from calendar year 2026 onwards.

Table 8: Higher heating values (HHV) of fuels (MJ/m³)^{Footnote 52}
Fuel type	HHV
Biogas ^d	18.61
Renewable natural gas (RNG), gaseous	38.39
Renewable natural gas (RNG), liquid	23 640.92
Natural gas, gaseous	38.39
Natural gas, liquid	23 640.92
Diesel	38 351.95
Gasoline	33 452.32
Heavy fuel oil	42 501.77
Light fuel oil	38 801.69

^d HHV of biogas assumes a 50/50 ratio of CH₄/CO₂.

5.0 Protocol-specific emission factors and other reference values

Emission factors and other reference values in Section 5.0 are only applicable to the federal offset protocol specified.

5.1 Improved forest management on private land

Reference values contained in Tables 9 and 10 must be used for the quantification of GHG reductions generated by projects implemented following the Improved Forest Management on Private Land protocol and occurring from calendar year 2024 onwards.

Reference values contained in Table 9 correspond to the parameter PC in the protocol.

Table 9: Percentage of harvest by wood product class^{Footnote 53}
Wood product class	Percentage of harvest (%)
Softwood lumber	37.76
Hardwood lumber	0.38
Pulp and paper	34.60
Panels (plywood and oriented strandboard)	12.42
Other industrial roundwood	3.55
Fuelwood	11.29

Reference values contained in Table 10 correspond to the parameter SF in the protocol.

Table 10: 100-year storage factor by wood product class^{Footnote 54}
Wood product class	100-year storage factor
Softwood lumber	0.213
Hardwood lumber	0.156
Softwood plywood	0.215
Oriented strandboard	0.285
Non-structural panels	0.174
Other industrial roundwood	0.149
Fuelwood	0
Pulp and paper	0

5.2 Reducing enteric methane emissions from beef cattle

Emission factors and other reference values contained in Tables 11 to 14 must be used for the quantification of GHG reductions generated by projects implemented following the Reducing Enteric Methane Emissions from Beef Cattle protocol and occurring from calendar year 2025 onwards.

Reference values contained in Table 11 correspond to the parameter Y_m in the protocol.

Table 11: Enteric CH₄ conversion factors based on diet composition and quality^{Footnote 55}
Diet description	Enteric CH₄ conversion factor (Y_m)
Diets of more than 75% low to medium quality forage containing < 60% total digestible nutrients	0.07
Diets of more than 75% high quality forage containing ≥ 60% total digestible nutrients	0.063
Mixed diets with forage content of 15 to 75% and the total diet is mixed with grain	0.063
All other grains with 0 to 15% forage	0.04
Steam-flaked corn and ionophore supplement with 0 to 10% forage	0.03

Emission factors contained in Table 12 correspond to the parameter EF_lip in the protocol.

Table 12: Emission factors for the addition of supplemented lipid determined by the percentage of total dry weight of feed delivered
Supplemented lipid added (%)	Emission factor (EF_lip)
< 1.0	1.0
1.0 to 1.99	0.96
2.0 to 2.99	0.92
3.0 to 3.99	0.88
4.0 to 4.99	0.84
≥ 5.0	0.80

Emission factors and other reference values contained in Table 13 correspond to the parameters MCF, EF_MS, Frac_v,or Frac_L in the protocol.

Table 13: Emission factors and other reference values for manure CH₄ and N₂O based on manure storage system
Manure storage system^{Footnote 56}	CH₄ conversion factor (MCF)^{Footnote 57}	Emission factor for direct N₂O emissions (EF_MS)^{Footnote 58}	Fraction of nitrogen (N) excreted in manure that volatilizes (Frac_v)^{Footnote 59}	Fraction of N excreted in manure leached (Frac_L)^{Footnote 60}
Solid storage and dry lot	0.02	0.02	0.3	0.03
Liquid, slurry or pit storage below confinements	0.2	0.001	0.4	0
Other manure storage system	0.01	0.005	0.24^{Footnote 60}	0.05

Emission factors contained in Table 14 correspond to the parameter EF_V in the protocol.

Table 14: Emission factors for indirect N₂O emissions from volatilization of manure by ecozone^{Footnote 61}
Ecozone	Emission factor for indirect N₂O emissions from volatilization of manure (EF_V)
Taiga Plains	0.005
Boreal Shield	0.014
Atlantic Maritime	0.014
Mixedwood Plains	0.014
Boreal Plains	0.005
Prairies	0.005
Pacific Maritime	0.014
Montane Cordillera	0.005

5.3 Reducing manure methane emissions

Emission factors and other reference values contained in Tables 15 to 17 must be used for the quantification of GHG reductions generated by projects implemented following the Reducing Manure Methane Emissions protocol and occurring from calendar year 2026 onwards.

Reference values contained in Table 15 correspond to the parameters VS_rate or B₀ in the protocol.

Table 15: Volatile solids (VS) excretion rates (kg VS/head/day) and maximum CH₄ producing potentials (m³ CH₄/kg VS) by livestock type

Livestock type	Livestock type description	VS excretion rate (VS_rate)^{Footnote 62}	Maximum CH₄ producing potential(B₀)^{Footnote 63}
Dairy cow	Female cattle 1 year or older which have calved at least once and are used for dairy production	6.51	0.24
Dairy heifer	Female cattle 1 year or older which have never calved and are used for dairy herd replacement	3.59	0.19
Beef cow	Female cattle 1 year or older which have calved at least once and are used for the reproduction of beef calves	6.16	0.19
Bull	Male cattle 1 year or older which have not been castrated and are kept for breeding purposes or fed for slaughter	6.38	0.19
Beef heifer – bred	Female cattle 1 year or older which have never calved and are used for beef herd replacement	4.43	0.19
Beef heifer – slaughter	Female cattle 1 year or older fed for slaughter	2.94	0.19
Steer	Castrated male cattle 1 year or older fed for slaughter	2.66	0.19
Calve	Cattle of either sex under 1 year old	2.21	0.19
Swine (<20 kg)	Swine under 20 kg such as weaner	0.10	0.48
Swine (20-60 kg)	Swine from 20 to 60 kg fed for slaughter	0.19	0.48
Swine (>60 kg)	Swine over 60 kg fed for slaughter	0.42	0.48
Breeding swine	Mature sows or boars used for breeding	0.31	0.48
Chicken – Layers	Chickens raised for egg production	0.02	0.39
Poultry	All other poultry including those raised for meat production	0.02	0.36
Sheep	Sheep of any size, sex or purpose	0.60	0.19
Goat	Goats of any size, sex or purpose	0.72	0.18
Horse	Horses of any size, sex or purpose	3.50	0.30

Reference values contained in Table 16 correspond to the parameter CF_MCF in the protocol. The “MCF correction factor” is a modifier applied to the methane conversion factor (MCF) determined in accordance with the protocol.

Table 16: MCF correction factors by storage type for liquid treated manure
Storage type	MCF correction factor (CF_MCF)
Anaerobic storage, non acidified	1
Anaerobic storage, acidified	0.05

Emission factors contained in Table 17 correspond to the parameters EF_TM,CH4 or EF_TM,N2O in the protocol.

Table 17: Storage emission factors (kg GHG/t treated manure, wet weight) by storage type for solid treated manure
Storage type	Storage CH₄ emission factor (EF_TM,CH4)	Storage N₂O emission factor (EF_TM,N2O)
Static pile or other composting^{Footnote 64}	3.54	0.18
Deep bedding^{Footnote 65}	0	0

Footnote 1

ECCC. (2023). NIR 1990-2021, Part 2, Table A6.1-1, “CO2 Emission Factors for Marketable Natural Gas”

Return to footnote1 referrer

Footnote 2

ECCC. (2023). NIR 1990-2021, Part 2, Table A6.1-2, “CO2 Emission Factors for Non-Marketable Natural Gas”

Return to footnote2 referrer

Footnote 3

ECCC. (2024). NIR 1990-2022, Part 2, Table A6.1-1, “CO2 Emission Factors for Marketable Natural Gas”

Return to footnote3 referrer

Footnote 4

ECCC. (2024). NIR 1990-2022, Part 2, Table A6.1-2, “CO2 Emission Factors for Non-Marketable Natural Gas”

Return to footnote4 referrer

Footnote 5

ECCC. (2025). NIR 1990-2023, Part 2, Table A6.1-1, “CO2 Emission Factors for Marketable Natural Gas”

Return to footnote5 referrer

Footnote 6

ECCC. (2025). NIR 1990-2023, Part 2, Table A6.1-2, “CO2 Emission Factors for Non-Marketable Natural Gas”

Return to footnote6 referrer

Footnote 7

ECCC. (2026). NIR 1990-2024, Part 2, Table A6.1-1, “CO2 Emission Factors for Marketable Natural Gas”

Return to footnote7 referrer

Footnote 8

ECCC. (2026). NIR 1990-2024, Part 2, Table A6.1-2, “CO2 Emission Factors for Non-Marketable Natural Gas”

Return to footnote8 referrer

Footnote 9

ECCC. (2023). NIR 1990-2021, Part 2, Table A6.1-3, “CH4 and N2O Emission Factors for Natural Gas”

Return to footnote9 referrer

Footnote 10

ECCC. (2024). NIR 1990-2022, Part 2, Table A6.1-3, “CH4 and N2O Emission Factors for Natural Gas”

Return to footnote10 referrer

Footnote 11

ECCC. (2024). NIR 1990-2022, Part 2, Table A6.1-4, “CH4 Emission Factors for Natural Gas Producer Consumption in Western Provinces”

Return to footnote11 referrer

Footnote 12

ECCC. (2025). NIR 1990-2023, Part 2, Table A6.1-3, “CH4 and N2O Emission Factors for Natural Gas”

Return to footnote12 referrer

Footnote 13

ECCC. (2025). NIR 1990-2023, Part 2, Table A6.1-4, “CH4 Emission Factors for Natural Gas Producer Consumption in Western Provinces”

Return to footnote13 referrer

Footnote 14

ECCC. (2026). NIR 1990-2024, Part 2, Table A6.1-4, “CH4 and N2O Emission Factors for Natural Gas”

Return to footnote14 referrer

Footnote 15

ECCC. (2026). NIR 1990-2024, Part 2, Table A6.1-54, “CH4 Emission Factors for Natural Gas Producer Consumption in Western Provinces”

Return to footnote15 referrer

Footnote 16

ECCC. (2023). NIR 1990-2021, Part 2, Table A6.1-4, “Emission Factors for Natural Gas Liquids”

Return to footnote16 referrer

Footnote 17

ECCC. (2024). NIR 1990-2022, Part 2, Table A6.1-5, “Emission Factors for Natural Gas Liquids”

Return to footnote17 referrer

Footnote 18

ECCC. (2025). NIR 1990-2023, Part 2, Table A6.1-5, “Emission Factors for Natural Gas Liquids”

Return to footnote18 referrer

Footnote 19

ECCC. (2026). NIR 1990-2024, Part 2, Table A6.1-35, “Emission Factors for Natural Gas Liquids”

Return to footnote19 referrer

Footnote 20

ECCC. (2023). NIR 1990-2021, Part 2, Table A6.1-5, “Emission Factors for Refined Petroleum Products”

Return to footnote20 referrer

Footnote 21

ECCC. (2023). NIR 1990-2021, Part 2, Table A6.1-6, “”CO2 Emission Factors for Petroleum Coke and Still Gas”

Return to footnote21 referrer

Footnote 22

ECCC. (2023). NIR 1990-2021, Part 2, Table A6.1-7, “N2O Emission Factors for Petroleum Coke”

Return to footnote22 referrer

Footnote 23

ECCC. (2023). NIR 1990-2021, Part 2, Table A6.1-8, “CH4 Emission Factors for Still Gas (Refineries and Others)”

Return to footnote23 referrer

Footnote 24

ECCC. (2024). NIR 1990-2022, Part 2, Table A6.1-6, “Emission Factors for Refined Petroleum Products”

Return to footnote24 referrer

Footnote 25

ECCC. (2024). NIR 1990-2022, Part 2, Table A6.1-7, “”CO2 Emission Factors for Petroleum Coke and Still Gas”

Return to footnote25 referrer

Footnote 26

ECCC. (2024). NIR 1990-2022, Part 2, Table A6.1-8, “N2O Emission Factors for Petroleum Coke”

Return to footnote26 referrer

Footnote 27

ECCC. (2024). NIR 1990-2022, Part 2, Table A6.1-9, “CH4 Emission Factors for Still Gas (Refineries and Others)”

Return to footnote27 referrer

Footnote 28

ECCC. (2025). NIR 1990-2023, Part 2, Table A6.1-6, “Emission Factors for Refined Petroleum Products”

Return to footnote28 referrer

Footnote 29

ECCC. (2025). NIR 1990-2023. Part 2, Table A6.1-7, “”CO2 Emission Factors for Petroleum Coke and Still Gas”

Return to footnote29 referrer

Footnote 30

ECCC. (2025). NIR 1990-2023. Part 2, Table A6.1-8, “N2O Emission Factors for Petroleum Coke”

Return to footnote30 referrer

Footnote 31

ECCC. (2025). NIR 1990-2023. Part 2, Table A6.1-9, “CH4 Emission Factors for Still Gas (Refineries and Others)”

Return to footnote31 referrer

Footnote 32

ECCC. (2026). NIR 1990-2024, Part 2, Table A6.1-6, “Emission Factors for Refined Petroleum Products”

Return to footnote32 referrer

Footnote 33

ECCC. (2026). NIR 1990-2024. Part 2, Table A6.1-7, “”CO2 Emission Factors for Petroleum Coke and Still Gas”

Return to footnote33 referrer

Footnote 34

ECCC. (2026). NIR 1990-2024. Part 2, Table A6.1-8, “N2O Emission Factors for Petroleum Coke”

Return to footnote34 referrer

Footnote 35

ECCC. (2026). NIR 1990-2024. Part 2, Table A6.1-9, “CH4 Emission Factors for Still Gas (Refineries and Others)”

Return to footnote35 referrer

Footnote 36

ECCC. (2023). NIR 1990-2021, Part 3, Tables A13-2 to A13-14

Return to footnote36 referrer

Footnote 37

Due to the high level of imports from New Brunswick, Prince Edward Island takes New Brunswick’s value.

Return to footnote37 referrer

Footnote 38

ECCC. (2024). NIR 1990-2022, Part 3, Tables A13-2 to A13-14

Return to footnote38 referrer

Footnote 39

Due to the high level of imports from New Brunswick, Prince Edward Island takes New Brunswick’s value.

Return to footnote39 referrer

Footnote 40

ECCC. (2025). NIR 1990-2023, Part 3, Tables A13-2 to A13-14

Return to footnote40 referrer

Footnote 41

Due to the high level of imports from New Brunswick, Prince Edward Island takes New Brunswick’s value.

Return to footnote41 referrer

Footnote 42

ECCC. (2026). NIR 1990-2024, Part 3, Tables A7-2 to A7-14

Return to footnote42 referrer

Footnote 43

ECCC. (2023). NIR 1990-2021, Part 2, Table A6.6-2, “Emission Factors for Landfill Gas Combustion”

Return to footnote43 referrer

Footnote 44

This emission factor is currently reported as “not estimated” in Canada’s National Inventory Report. A value of zero has been assigned to this emission factor for the purposes of the quantification of GHG reductions.

Return to footnote44 referrer

Footnote 45

ECCC. (2024). NIR 1990-2022, Part 2, Table A6.6-2, “Emission Factors for Landfill Gas Combustion”

Return to footnote45 referrer

Footnote 46

This emission factor is currently reported as “not estimated” in Canada’s National Inventory Report. To be conservative, the emission factor applicable to combustion of biogas for energy is applied to flaring of biogas.

Return to footnote46 referrer

Footnote 47

ECCC. (2025). NIR 1990-2023, Part 2, Table A6.6-2, “Emission Factors for Gaseous Biomass Combustion”

Return to footnote47 referrer

Footnote 48

Return to footnote48 referrer

Footnote 49

ECCC. (2026). NIR 1990-2024, Part 2, Table A6.6-2, “Emission Factors for Gaseous Biomass Combustion”

Return to footnote49 referrer

Footnote 50

Return to footnote50 referrer

Footnote 51

These destruction efficiencies align with those of most similar offset protocols from other systems.

Return to footnote51 referrer

Footnote 52

HHV values are from the Clean Fuel Regulations Data Workbook

Return to footnote52 referrer

Footnote 53

Values are based off the national average harvested wood product production ratios developed by the Food and Agriculture Organization (FAO) based on a reference period of 1990-2020. Ratio of softwood lumber to hardwood lumber for harvested industrial roundwood was based on a reference period of 2014-2021 from Statistics Canada (Table 16-10-0017-01 Lumber production, shipments, and stocks by species, monthly (x 1,000), doi: 10.25318/1610001701-eng).

Return to footnote53 referrer

Footnote 54

Hoover et al. (2014). Chapter 6: quantifying greenhouse gas sources and sinks in managed forest systems. M., D. Pape, M. Flugge, R. Steele, D. Man, M. Riley‐Gilbert, and S. Biggar, (Eds.). Greenhouse Gas Fluxes in Agriculture and Forestry: Methods for Entity‐Scale Inventory (Technical Bulletin Number 1939). US Department of Agriculture.

Return to footnote54 referrer

Footnote 55

Reference values are adapted from International Panel on Climate Change. (2019). Chapter 10: Agriculture, Forestry and Other Land Use. Calvo Buendia, E., Tanabe, K., Kranjc, A., Baasansuren, J., Fukuda, M., Ngarize S., Osako, A., Pyrozhenko, Y., Shermanau, P. and Federici, S. (eds). in 2019 refinement to the 2006 IPCC Guidelines for National Greenhouse Gas Inventories, Table 10.12.

Return to footnote55 referrer

Footnote 56

Description of each type of manure storage system can be found in International Panel on Climate Change. (2019). 2019 refinement to the 2006 IPCC Guidelines for National Greenhouse Gas Inventories Volume 4, Chapter 10 Emissions from Livestock and Manure Management, Table 10.18.

Return to footnote56 referrer

Footnote 57

ECCC. (2025). NIR 1990-2023, Part 2, Table A6.4-4, “Methane Conversion Factors (MCF) by Animal Category and Manure Management System”

Return to footnote57 referrer

Footnote 58

ECCC. (2025). NIR 1990-2023, Part 2, Table A6.4-10, “Emission Factors (EF) for Manure Nitrogen (N) Lost as N2O-N by Animal Category and Animal Waste Management Systems”

Return to footnote58 referrer

Footnote 59

ECCC. (2025). NIR 1990-2023, Part 2, Table A3.4-27, “Total N, NH3- and NOx-N Losses Associated with Various Livestock and Manure Management Systems”

Return to footnote59 referrer

Footnote 60

ECCC. (2025). NIR 1990-2023, Part 2, Table A3.4-28, “Total N, NH3- and NOx-N Losses Associated with Manure Management Systems for Dairy Cattle”

Return to footnote60 referrer

Footnote 61

ECCC. (2025). NIR 1990-2023, Part 2, Table A3.4-26, “Application of Emission Factor EF4 from the 2019 Refinement to the 2006 IPCC Guidelines, by Ecozone”

Return to footnote61 referrer

Footnote 62

For cattle, VS excretion rates have been developed by ECCC. For swine, VS excretion rates are from ECCC. (2026). NIR 1990-2024, Part 2, Table A3.4-14 “Mean Volatile Solids Values in Swine Manure”. For other livestock, VS excretion rates are from ECCC. (2026). NIR 1990-2024, Part 2, Table A3.4-13 “Mean Volatile Solids Values in Manure from Non-Cattle Categories”.

Return to footnote62 referrer

Footnote 63

International Panel on Climate Change. (2019). Chapter 10: Agriculture, Forestry and Other Land Use. Calvo Buendia, E., Tanabe, K., Kranjc, A., Baasansuren, J., Fukuda, M., Ngarize S., Osako, A., Pyrozhenko, Y., Shermanau, P. and Federici, S. (eds). in 2019 refinement to the 2006 IPCC Guidelines for National Greenhouse Gas Inventories, Table 10.16

Return to footnote63 referrer

Footnote 64

ECCC. (2026). NIR 1990-2024, Part 2, Table A6.7-6 “EFs for Biological Treatment of Solid Waste” for composting of biosolids or manure

Return to footnote64 referrer

Footnote 65

Deep bedding means the coarse fraction of treated manure from a mechanical manure treatment system used as bedding for the purpose of absorbing moisture from fresh livestock excreta, typically for several months. GHG emissions for deep bedding storage are assumed to be zero as the coarse fraction of treated manure replaces material used in the baseline scenario, such as straw or wood shavings, with similar GHG emissions.

Return to footnote65 referrer

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2026-09-09

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Emission factors and reference values

Document revision history

1.0 Introduction

2.0 Abbreviations and acronyms

3.0 General

3.1 Global warming potentials

3.2 Timing applicability of emission factors and other reference values

4.0 General emission factors and other reference values

4.1 Fossil fuel combustion

4.2 Grid electricity consumption

4.3 Biogas combustion

4.4 CH₄ destruction by eligible destruction device

4.5 Displacement of fossil fuels

5.0 Protocol-specific emission factors and other reference values

5.1 Improved forest management on private land

5.2 Reducing enteric methane emissions from beef cattle

5.3 Reducing manure methane emissions

Page details

Emission factors and reference values

Document revision history

1.0 Introduction

2.0 Abbreviations and acronyms

3.0 General

3.1 Global warming potentials

3.2 Timing applicability of emission factors and other reference values

4.0 General emission factors and other reference values

4.1 Fossil fuel combustion

4.2 Grid electricity consumption

4.3 Biogas combustion

4.4 CH4 destruction by eligible destruction device

4.5 Displacement of fossil fuels

5.0 Protocol-specific emission factors and other reference values

5.1 Improved forest management on private land

5.2 Reducing enteric methane emissions from beef cattle

5.3 Reducing manure methane emissions

Page details

4.4 CH₄ destruction by eligible destruction device