National Greenhouse and Energy Reporting (Measurement) Determination 2008

Chapter 1—General

Part 1.1—Preliminary

1.1 Name of Determination

Division 1.1.1—Overview

1.3 Overview—general

1.4 Overview—methods for measurement

1.5 Overview—energy

1.6 Overview—scope 2 emissions

1.7 Overview—assessment of uncertainty

Division 1.1.2—Definitions and interpretation

1.8 Definitions

1.9 Interpretation

1.9A Meaning of separate instance of a source

1.9B Meaning of separate occurrence of a source

1.10 Meaning of source

Part 1.2—General

1.11 Purpose of Part

Division 1.2.1—Measurement and standards

1.12 Measurement of emissions and energy

1.13 General principles for measuring emissions and energy

1.14 Assessment of uncertainty

1.15 Units of measurement

1.16 Rounding of amounts

1.17 Status of standards

Division 1.2.2—Methods

1.18 Method to be used for a separate occurrence of a source

1.18A Conditions—persons preparing report must use same method

1.19 Temporary unavailability of method

Division 1.2.3—Requirements in relation to carbon capture and storage

1.19A Meaning of captured for permanent storage

1.19B Deducting greenhouse gas that is captured for permanent storage

1.19C Capture from facility with multiple sources jointly generated

1.19D Capture from a source where multiple fuels consumed

1.19E Measure of quantity of captured greenhouse gas

1.19F Volume of greenhouse gas stream—criterion A

1.19G Volume of greenhouse gas stream—criterion AAA

1.19GA Volume of greenhouse gas stream—criterion BBB

1.19H Volumetric measurement—compressed greenhouse gas stream

1.19I Volumetric measurement—super‑compressed greenhouse gas stream

1.19J Gas measuring equipment—requirements

1.19K Flow devices—requirements

1.19L Flow computers—requirements

1.19M Gas chromatographs

Part 1.3—Method 4—Direct measurement of emissions

Division 1.3.1—Preliminary

1.20 Overview

Division 1.3.2—Operation of method 4 (CEM)

Subdivision 1.3.2.1—Method 4 (CEM)

1.21 Method 4 (CEM)—estimation of emissions

1.21A Emissions from a source where multiple fuels consumed

Subdivision 1.3.2.2—Method 4 (CEM)—use of equipment

1.22 Overview

1.23 Selection of sampling positions for CEM equipment

1.24 Measurement of flow rates by CEM

1.25 Measurement of gas concentrations by CEM

1.26 Frequency of measurement by CEM

Division 1.3.3—Operation of method 4 (PEM)

Subdivision 1.3.3.1—Method 4 (PEM)

1.27 Method 4 (PEM)—estimation of emissions

1.27A Emissions from a source where multiple fuels consumed

1.28 Calculation of emission factors

Subdivision 1.3.3.2—Method 4 (PEM)—use of equipment

1.29 Overview

1.30 Selection of sampling positions for PEM equipment

1.31 Measurement of flow rates by PEM equipment

1.32 Measurement of gas concentrations by PEM

1.33 Representative data for PEM

Division 1.3.4—Performance characteristics of equipment

1.34 Performance characteristics of CEM or PEM equipment

Chapter 2—Fuel combustion

Part 2.1—Preliminary

2.1 Outline of Chapter

Part 2.2—Emissions released from the combustion of solid fuels

Division 2.2.1—Preliminary

2.2 Application

2.3 Available methods for estimating emissions of carbon dioxide, methane and nitrous oxide

Division 2.2.2—Method 1—emissions of carbon dioxide, methane and nitrous oxide from solid fuels

2.4 Method 1—solid fuels

Division 2.2.3—Method 2—emissions from solid fuels

Subdivision 2.2.3.1—Method 2—estimating carbon dioxide using default oxidation factor

2.5 Method 2—estimating carbon dioxide using oxidation factor

Subdivision 2.2.3.2—Method 2—estimating carbon dioxide using an estimated oxidation factor

2.6 Method 2—estimating carbon dioxide using an estimated oxidation factor

Subdivision 2.2.3.3—Sampling and analysis for method 2 under sections 2.5 and 2.6

2.7 General requirements for sampling solid fuels

2.8 General requirements for analysis of solid fuels

2.9 Requirements for analysis of furnace ash and fly ash

2.10 Requirements for sampling for carbon in furnace ash

2.11 Sampling for carbon in fly ash

Division 2.2.4—Method 3—Solid fuels

2.12 Method 3—solid fuels using oxidation factor or an estimated oxidation factor

Division 2.2.5—Measurement of consumption of solid fuels

2.13 Purpose of Division

2.14 Criteria for measurement

2.15 Indirect measurement at point of consumption—criterion AA

2.16 Direct measurement at point of consumption—criterion AAA

2.17 Simplified consumption measurements—criterion BBB

Part 2.3—Emissions released from the combustion of gaseous fuels

Division 2.3.1—Preliminary

2.18 Application

2.19 Available methods

Division 2.3.2—Method 1—emissions of carbon dioxide, methane and nitrous oxide

2.20 Method 1—emissions of carbon dioxide, methane and nitrous oxide

Division 2.3.3—Method 2—emissions of carbon dioxide from the combustion of gaseous fuels

Subdivision 2.3.3.1—Method 2—emissions of carbon dioxide from the combustion of gaseous fuels

2.21 Method 2—emissions of carbon dioxide from the combustion of gaseous fuels

2.22 Calculation of emission factors from combustion of gaseous fuel

Subdivision 2.3.3.2—Sampling and analysis

2.23 General requirements for sampling under method 2

2.24 Standards for analysing samples of gaseous fuels

2.25 Frequency of analysis

Division 2.3.4—Method 3—emissions of carbon dioxide released from the combustion of gaseous fuels

2.26 Method 3—emissions of carbon dioxide from the combustion of gaseous fuels

Division 2.3.5—Method 2—emissions of methane from the combustion of gaseous fuels

2.27 Method 2—emissions of methane from the combustion of gaseous fuels

Division 2.3.6—Measurement of quantity of gaseous fuels

2.28 Purpose of Division

2.29 Criteria for measurement

2.30 Indirect measurement—criterion AA

2.31 Direct measurement—criterion AAA

2.32 Volumetric measurement—all natural gases

2.33 Volumetric measurement—super‑compressed gases

2.34 Gas measuring equipment—requirements

2.35 Flow devices—requirements

2.36 Flow computers—requirements

2.37 Gas chromatographs—requirements

2.38 Simplified consumption measurements—criterion BBB

Part 2.4—Emissions released from the combustion of liquid fuels

Division 2.4.1—Preliminary

2.39 Application

2.39A Definition of petroleum based oils for Part 2.4

Subdivision 2.4.1.1—Liquid fuels—other than petroleum based oils and greases

2.40 Available methods

Subdivision 2.4.1.2—Liquid fuels—petroleum based oils and greases

2.40A Available methods

Division 2.4.2—Method 1—emissions of carbon dioxide, methane and nitrous oxide from liquid fuels other than petroleum based oils or greases

2.41 Method 1—emissions of carbon dioxide, methane and nitrous oxide

Division 2.4.3—Method 2—emissions of carbon dioxide from liquid fuels other than petroleum based oils or greases

Subdivision 2.4.3.1—Method 2—emissions of carbon dioxide from liquid fuels other than petroleum based oils or greases

2.42 Method 2—emissions of carbon dioxide from the combustion of liquid fuels

2.43 Calculation of emission factors from combustion of liquid fuel

Subdivision 2.4.3.2—Sampling and analysis

2.44 General requirements for sampling under method 2

2.45 Standards for analysing samples of liquid fuels

2.46 Frequency of analysis

Division 2.4.4—Method 3—emissions of carbon dioxide from liquid fuels other than petroleum based oils or greases

2.47 Method 3—emissions of carbon dioxide from the combustion of liquid fuels

Division 2.4.5—Method 2—emissions of methane and nitrous oxide from liquid fuels other than petroleum based oils or greases

2.48 Method 2—emissions of methane and nitrous oxide from the combustion of liquid fuels

Division 2.4.5A—Methods for estimating emissions of carbon dioxide from petroleum based oils or greases

2.48A Method 1—estimating emissions of carbon dioxide using an estimated oxidation factor

2.48B Method 2—estimating emissions of carbon dioxide using an estimated oxidation factor

2.48C Method 3—estimating emissions of carbon dioxide using an estimated oxidation factor

Division 2.4.6—Measurement of quantity of liquid fuels

2.49 Purpose of Division

2.50 Criteria for measurement

2.51 Indirect measurement—criterion AA

2.52 Direct measurement—criterion AAA

2.53 Simplified consumption measurements—criterion BBB

Part 2.5—Emissions released from fuel use by certain industries

2.54 Application

Division 2.5.1—Energy—petroleum refining

2.55 Application

2.56 Methods

Division 2.5.2—Energy—manufacture of solid fuels

2.57 Application

2.58 Methods

Division 2.5.3—Energy—petrochemical production

2.59 Application

2.60 Available methods

2.61 Method 1—petrochemical production

2.62 Method 2—petrochemical production

2.63 Method 3—petrochemical production

Part 2.6—Blended fuels

2.64 Purpose

2.65 Application

2.66 Blended solid fuels

2.67 Blended liquid fuels

2.67A Blended gaseous fuels

2.67B Market‑based approach for determining the amount of renewable liquid fuel in a blended fuel supplied through shared infrastructure

2.67C Market‑based approach for determining the amount of renewable gas in a blended fuel received from a natural gas network

Part 2.7—Estimation of energy for certain purposes

2.68 Amount of energy consumed without combustion

2.69 Apportionment of fuel consumed as carbon reductant or feedstock and energy

2.70 Amount of energy consumed in a cogeneration process

2.71 Apportionment of energy consumed for electricity, transport and for stationary energy

Chapter 3—Fugitive emissions

Part 3.1—Preliminary

3.1 Outline of Chapter

Part 3.2—Coal mining—fugitive emissions

Division 3.2.1—Preliminary

3.2 Outline of Part

Division 3.2.2—Underground mines

Subdivision 3.2.2.1—Preliminary

3.3 Application

3.4 Available methods

Subdivision 3.2.2.2—Fugitive emissions from extraction of coal

3.5 Method 1—extraction of coal

3.6 Method 4—extraction of coal

3.7 Estimation of emissions

3.8 Overview—use of equipment

3.9 Selection of sampling positions for PEM

3.10 Measurement of volumetric flow rates by PEM

3.11 Measurement of concentrations by PEM

3.12 Representative data for PEM

3.13 Performance characteristics of equipment

Subdivision 3.2.2.3—Emissions released from coal mine waste gas flared

3.14 Method 1—coal mine waste gas flared

3.15 Method 2—emissions of carbon dioxide from coal mine waste gas flared

3.15A Method 2—emissions of methane and nitrous oxide from coal mine waste gas flared

3.16 Method 3—coal mine waste gas flared

Subdivision 3.2.2.4—Fugitive emissions from post‑mining activities

3.17 Method 1—post‑mining activities related to gassy mines

Division 3.2.3—Open cut mines

Subdivision 3.2.3.1—Preliminary

3.18 Application

3.19 Available methods

Subdivision 3.2.3.2—Fugitive emissions from extraction of coal

3.20 Method 1—extraction of coal

3.21 Method 2—extraction of coal

3.22 Total gas contained by gas bearing strata

3.23 Estimate of proportion of gas content released below pit floor

3.24 General requirements for sampling

3.25 General requirements for analysis of gas and gas bearing strata

3.25A Method of working out base of the low gas zone

3.25B Further requirements for estimator

3.25C Default gas content for gas bearing strata in low gas zone

3.25D Requirements for estimating total gas contained in gas bearing strata

3.26 Method 3—extraction of coal

Subdivision 3.2.3.3—Emissions released from coal mine waste gas flared

3.27 Method 1—coal mine waste gas flared

3.28 Method 2—coal mine waste gas flared

3.29 Method 3—coal mine waste gas flared

Division 3.2.4—Decommissioned underground mines

Subdivision 3.2.4.1—Preliminary

3.30 Application

3.31 Available methods

Subdivision 3.2.4.2—Fugitive emissions from decommissioned underground mines

3.32 Method 1—decommissioned underground mines

3.33 Emission factor for decommissioned underground mines

3.34 Measurement of proportion of mine that is flooded

3.35 Water flow into mine

3.36 Size of mine void volume

3.37 Method 4—decommissioned underground mines

Subdivision 3.2.4.3—Fugitive emissions from coal mine waste gas flared

3.38 Method 1—coal mine waste gas flared

3.39 Method 2—coal mine waste gas flared

3.40 Method 3—coal mine waste gas flared

Part 3.3—Oil and natural gas—fugitive emissions

Division 3.3.1—Preliminary

3.41 Outline of Part

3.41A Interpretation

Division 3.3.2—Oil or gas exploration and development

Subdivision 3.3.2.1—Preliminary

3.42 Application

Subdivision 3.3.2.2—Oil or gas exploration and development (emissions that are flared)

3.43 Available methods

3.44 Method 1—oil or gas exploration and development

3.45 Method 2—oil or gas exploration and development (flared carbon dioxide emissions)

3.45A Method 2A—oil or gas exploration and development (flared methane or nitrous oxide emissions)

3.46 Method 3—oil or gas exploration and development

Subdivision 3.3.2.3—Oil or gas exploration and development—fugitive emissions from system upsets, accidents and deliberate releases

3.46A Available methods

Subdivision 3.3.2.3.1—Fugitive emissions that result from deliberate releases from process vents, system upsets and accidents–well completions

3.46AB Method 1—vented emissions from natural gas well completions

3.46AC Method 1— emissions from system upsets, accidents and deliberate releases from process vents— mud degassing

3.46B Method 4—vented emissions from natural gas well completions, well workovers, cold process vents and well blowouts

Division 3.3.3—Crude oil production

Subdivision 3.3.3.1—Preliminary

3.47 Application

Subdivision 3.3.3.2—Crude oil production (non‑flared)—fugitive leak emissions of methane

3.48 Available methods

3.49 Method 1—crude oil production (non‑flared) emissions of methane

3.50 Method 2—crude oil production (non‑flared) emissions of methane

Subdivision 3.3.3.3—Crude oil production (flared)—fugitive emissions of carbon dioxide, methane and nitrous oxide

3.52 Available methods

3.53 Method 1—crude oil production (flared) emissions

3.54 Method 2—crude oil production

3.54A Method 2A—crude oil production (flared methane or nitrous oxide emissions)

3.55 Method 3—crude oil production

Subdivision 3.3.3.4—Crude oil production (non‑flared)—fugitive vent emissions of methane and carbon dioxide

3.56A Available methods

3.56B Method 1—emissions from system upsets, accidents and deliberate releases from process vents

Division 3.3.4—Crude oil transport

3.57 Application

3.58 Available methods

3.59 Method 1—crude oil transport

3.60 Method 2—fugitive emissions from crude oil transport

Division 3.3.5—Crude oil refining

3.62 Application

3.63 Available methods

Subdivision 3.3.5.1—Fugitive emissions from crude oil refining and from storage tanks for crude oil

3.64 Method 1—crude oil refining and storage tanks for crude oil

3.65 Method 2—crude oil refining and storage tanks for crude oil

Subdivision 3.3.5.2—Fugitive emissions from deliberate releases from process vents, system upsets and accidents

3.67 Method 1—fugitive emissions from deliberate releases from process vents, system upsets and accidents

3.68 Method 4—deliberate releases from process vents, system upsets and accidents

Subdivision 3.3.5.3—Fugitive emissions released from gas flared from the oil refinery

3.69 Method 1—gas flared from crude oil refining

3.70 Method 2—gas flared from crude oil refining

3.70A Method 2A—crude oil refining (flared methane or nitrous oxide emissions)

3.71 Method 3—gas flared from crude oil refining

Division 3.3.6A—Onshore natural gas production (other than emissions that are vented or flared)

3.72 Application

Subdivision 3.3.6A.1—Onshore natural gas production, other than emissions that are vented or flared—wellheads

3.73 Available methods

3.73B Method 2—onshore natural gas production, other than emissions that are vented or flared—wellheads

Division 3.3.6B—Offshore natural gas production (other than emissions that are vented or flared)

3.73D Application

Subdivision 3.3.6B.1—Offshore natural gas production, other than emissions that are vented or flared—offshore platforms

3.73E Available methods

3.73F Method 1—offshore natural gas production (other than emissions that are vented or flared)

3.73G Method 2—offshore natural gas production (other than venting and flaring)

Division 3.3.6C—Natural gas gathering and boosting (other than emissions that are vented or flared)

3.73I Application

3.73J Available methods

3.73K Method 1—natural gas gathering and boosting (other than venting and flaring)

3.73L Method 2—natural gas gathering and boosting (other than venting and flaring)

3.73LA Method 2—natural gas gathering and boosting, other than emissions that are vented or flared—natural gas gathering and boosting stations

Division 3.3.6D—Produced water from oil and gas exploration and development, crude oil production, natural gas production or natural gas gathering and boosting (other than emissions that are vented or flared)

3.73N Available methods

3.73NA Method 1—produced water (other than emissions that are vented or flared)

3.73NB Method 2—produced water (other than emissions that are vented or flared)

Division 3.3.6E—Natural gas processing (other than emissions that are vented or flared)

3.73O Application

3.73P Available methods

3.73Q Method 1—natural gas processing (other than emissions that are vented or flared)

3.73R Method 2—natural gas processing (other than venting and flaring)

3.73S Method 3—natural gas processing (other than venting and flaring)

Division 3.3.7—Natural gas transmission (other than emissions that are flared)

3.74 Application

3.75 Available methods

3.76 Method 1—natural gas transmission (other than flaring)

3.77 Method 2—natural gas transmission (other than flaring)

Division 3.3.7A—Natural gas storage (other than emissions that are vented or flared)

3.78A Application

3.78B Available methods

3.78C Method 1—natural gas storage (other than emissions that are vented or flared)

3.78D Method 2—natural gas storage (other than emissions that are vented or flared)

3.78E Method 3—natural gas storage (other than emissions that are vented or flared)

Division 3.3.7B—Natural gas liquefaction, storage and transfer (other than emissions that are vented or flared)

3.78F Application

3.78G Available methods

3.78H Method 1—natural gas liquefaction, storage and transfer (other than emissions that are vented or flared)

3.78I Method 2—natural gas liquefaction, storage and transfer (other than emissions that are vented or flared)

3.78J Method 3—natural gas liquefaction, storage and transfer (other than venting and flaring)

Division 3.3.8—Natural gas distribution (other than emissions that are flared)

3.79 Application

3.80 Available methods

3.81 Method 1—natural gas distribution

3.82 Method 2—natural gas distribution

3.82A Method 3—natural gas distribution

Division 3.3.9A—Natural gas production (emissions that are vented or flared)

3.83 Application

Subdivision 3.3.9A.1—Natural gas production—emissions that are vented—gas treatment processes

3.84 Available methods

3.85 Method 1—emissions from system upsets, accidents and deliberate releases from process vents—gas treatment processes

Subdivision 3.3.9A.2—Natural gas production—emissions that are vented—cold process vents

3.85A Available methods

3.85B Method 2—emissions from system upsets, accidents and deliberate releases from process vents

Subdivision 3.3.9A.3—Natural gas production—emissions that are vented—natural gas blanketed tanks and condensate storage tanks

3.85C Available methods

3.85D Method 1—emissions from system upsets, accidents and deliberate releases from process vents—natural gas blanketed tanks and condensate storage tanks

Subdivision 3.3.9A.4—Natural gas production—emissions that are vented—gas driven pneumatic devices

3.85E Available methods

3.85F Method 1—emissions from system upsets, accidents and deliberate releases from process vents—gas driven pneumatic devices

Subdivision 3.3.9A.5—Natural gas production—emissions that are vented—gas driven chemical injection pumps

3.85G Available methods

3.85H Method 1—emissions from system upsets, accidents and deliberate releases from process vents—gas driven chemical injection pumps

Subdivision 3.3.9A.6—Natural gas production—emissions that are vented—well blowouts

3.85K Available methods

3.85L Method 2—emissions from system upsets, accidents and deliberate releases from process vents—production related non‑routine emissions—well blowouts

Subdivision 3.3.9A.7—Natural gas production—emissions that are vented—CO2 stimulation

3.85M Available methods

3.85N Method 2—emissions from system upsets, accidents and deliberate releases from process vents—production related non‑routine emissions—CO2 stimulation

Subdivision 3.3.9A.8—Natural gas production—emissions that are vented—well workovers

3.85O Available methods

3.85P Method 1—vented emissions from well workovers

3.85Q Method 4—vented emissions from gas well workovers

Subdivision 3.3.9A.9—Natural gas production—emissions that are vented—vessel blowdowns, compressor starts and compressor blowdowns

3.85R Available methods

3.85S Method 1—emissions from system upsets, accidents and deliberate releases from process vents—production related non‑routine emissions—vessel blowdowns, compressor starts and compressor blowdowns

Subdivision 3.3.9A.10—Natural gas production (emissions that are flared)

3.85T Available methods

3.86 Method 1—gas flared from natural gas production

3.87 Method 2—gas flared from natural gas production

3.87A Method 2A—natural gas production (flared methane or nitrous oxide emissions)

3.87B Method 2B—Natural gas production mass balance approach (flared methane and carbon dioxide emissions)

3.88 Method 3—gas flared from natural gas production

Division 3.3.9B—Natural gas gathering and boosting (emissions that are vented or flared)

3.88A Application

Subdivision 3.3.9B.1—Natural gas gathering and boosting (emissions that are vented)

3.88B Available methods

3.88C Method 1—emissions from system upsets, accidents and deliberate releases from process vents—gas gathering and boosting emissions

Subdivision 3.3.9B.2—Natural gas gathering and boosting (emissions that are flared)

Division 3.3.9C—Natural gas processing (emissions that are vented or flared)

3.88E Application

Subdivision 3.3.9C.1—Natural gas processing (emissions that are vented)

3.88F Available methods

3.88G Method 1—emissions from system upsets, accidents and deliberate releases from process vents—gas processing

Subdivision 3.3.9C.2—Natural gas processing (emissions that are flared)

Division 3.3.9D—Natural gas transmission (emissions that are flared)

3.88I Application

Division 3.3.9E—Natural gas storage (emissions that are vented or flared)

3.88K Application

Subdivision 3.3.9E.1——Natural gas storage (emissions that are vented)

3.88L Available methods

3.88M Method 1—emissions from system upsets, accidents and deliberate releases from process vents—gas storage related non‑routine emissions

Subdivision 3.3.9E.2—Natural gas storage (emissions that are flared)

Division 3.3.9F— Natural gas liquefaction, storage and transfer (emissions that are vented or flared)

3.88O Application

Subdivision 3.3.9F.1—Natural gas liquefaction, storage and transfer (emissions that are vented)

3.88P Available methods

3.88Q Method 1—emissions from system upsets, accidents and deliberate releases from process vents— natural gas liquefaction, storage and transfer

Subdivision 3.3.9F.2—Natural gas liquefaction, storage and transfer (emissions that are flared)

Division 3.3.9G—Natural gas distribution (emissions that are flared)

3.88S Application

Part 3.4—Carbon capture and storage and enhanced oil recovery—fugitive emissions

Division 3.4.1—Preliminary

3.88U Outline of Part

Division 3.4.2—Transport of greenhouse gases

Subdivision 3.4.2.1—Preliminary

3.89 Application

3.90 Available methods

Subdivision 3.4.2.2—Emissions from transport of greenhouse gases involving transfer

3.91 Method 1—emissions from transport of greenhouse gases involving transfer

Subdivision 3.4.2.3—Emissions from transport of greenhouse gases not involving transfer

3.92 Method 1—emissions from transport of greenhouse gases not involving transfer

Division 3.4.3—Injection of greenhouse gases

Subdivision 3.4.3.1—Preliminary

3.93 Application

3.94 Available methods

Subdivision 3.4.3.2—Fugitive emissions from deliberate releases from process vents, system upsets and accidents

3.95 Method 2—fugitive emissions from deliberate releases from process vents, system upsets and accidents

Subdivision 3.4.3.3—Fugitive emissions from injection of greenhouse gases (other than emissions from deliberate releases from process vents, system upsets and accidents)

3.96 Method 2—fugitive emissions from injection of a greenhouse gas into a geological formation (other than deliberate releases from process vents, system upsets and accidents)

3.97 Method 3—fugitive emissions from injection of greenhouse gases (other than deliberate releases from process vents, system upsets and accidents)

Division 3.4.4—Storage of greenhouse gases

Subdivision 3.4.4.1—Preliminary

3.98 Application

3.99 Available method

Subdivision 3.4.4.2—Fugitive emissions from the storage of greenhouse gases

3.100 Method 2—fugitive emissions from geological formations used for the storage of greenhouse gases

Chapter 4—Industrial processes emissions

Part 4.1—Preliminary

4.1 Outline of Chapter

Part 4.2—Industrial processes—mineral products

Division 4.2.1—Cement clinker production

4.2 Application

4.3 Available methods

4.4 Method 1—cement clinker production

4.5 Method 2—cement clinker production

4.6 General requirements for sampling cement clinker

4.7 General requirements for analysing cement clinker

4.8 Method 3—cement clinker production

4.9 General requirements for sampling carbonates

4.10 General requirements for analysing carbonates

Division 4.2.2—Lime production

4.11 Application

4.12 Available methods

4.13 Method 1—lime production

4.14 Method 2—lime production

4.15 General requirements for sampling

4.16 General requirements for analysis of lime

4.17 Method 3—lime production

4.18 General requirements for sampling

4.19 General requirements for analysis of carbonates

Division 4.2.3—Use of carbonates for production of a product other than cement clinker, lime or soda ash

4.20 Application

4.21 Available methods

4.22 Method 1—product other than cement clinker, lime or soda ash

4.22A Method 1A—product other than cement clinker, lime or soda ash for use of carbonates in clay materials

4.23 Method 3—product other than cement clinker, lime or soda ash

4.23A Method 3A—product other than cement clinker, lime or soda ash for use of carbonates in clay materials

4.23B General requirements for sampling clay material

4.23C General requirements for analysing clay material

4.24 General requirements for sampling carbonates

4.25 General requirements for analysis of carbonates

Division 4.2.4—Soda ash use and production

4.26 Application

4.27 Outline of Division

Subdivision 4.2.4.1—Soda ash use

4.28 Available methods

4.29 Method 1—use of soda ash

Subdivision 4.2.4.2—Soda ash production

4.30 Available methods

4.31 Method 1—production of soda ash

4.32 Method 2—production of soda ash

4.33 Method 3—production of soda ash

Division 4.2.5—Measurement of quantity of carbonates consumed and products derived from carbonates

4.34 Purpose of Division

4.35 Criteria for measurement

4.36 Indirect measurement at point of consumption or production—criterion AA

4.37 Direct measurement at point of consumption or production—criterion AAA

4.38 Acquisition or use or disposal without commercial transaction—criterion BBB

4.39 Units of measurement

Part 4.3—Industrial processes—chemical industry

Division 4.3.1—Ammonia production

4.40 Application

4.41 Available methods

4.42 Method 1—ammonia production

4.43 Method 2—ammonia production

4.44 Method 3—ammonia production

Division 4.3.2—Nitric acid production

4.45 Application

4.46 Available methods

4.47 Method 1—nitric acid production

4.48 Method 2—nitric acid production

Division 4.3.3—Adipic acid production

4.49 Application

4.50 Available methods

Division 4.3.4—Carbide production

4.51 Application

4.52 Available methods

Division 4.3.5—Chemical or mineral production, other than carbide production, using a carbon reductant or carbon anode

4.53 Application

4.54 Available methods

4.55 Method 1—chemical or mineral production, other than carbide production, using a carbon reductant or carbon anode

4.56 Method 2—chemical or mineral production, other than carbide production, using a carbon reductant or carbon anode

4.57 Method 3—chemical or mineral production, other than carbide production, using a carbon reductant or carbon anode

Division 4.3.6—Sodium cyanide production

4.58 Application

4.59 Available methods

Division 4.3.7—Hydrogen production

4.60 Application

4.61 Available methods

4.62A Method 2—hydrogen production

4.62B Method 3—hydrogen production

Part 4.4—Industrial processes—metal industry

Division 4.4.1—Iron, steel or other metal production using an integrated metalworks

4.63 Application

4.64 Purpose of Division

4.65 Available methods for production of a metal from an integrated metalworks

4.66 Method 1—production of a metal from an integrated metalworks

4.67 Method 2—production of a metal from an integrated metalworks

4.68 Method 3—production of a metal from an integrated metalworks

Division 4.4.2—Ferroalloys production

4.69 Application

4.70 Available methods

4.71 Method 1—ferroalloy metal

4.72 Method 2—ferroalloy metal

4.73 Method 3—ferroalloy metal

Division 4.4.3—Aluminium production (carbon dioxide emissions)

4.74 Application

Sudivision 4.4.3.1—Aluminium—emissions from consumption of carbon anodes in aluminium production

4.75 Available methods

4.76 Method 1—aluminium (carbon anode consumption)

4.77 Method 2—aluminium (carbon anode consumption)

4.78 Method 3—aluminium (carbon anode consumption)

Subdivision 4.4.3.2—Aluminium—emissions from production of baked carbon anodes in aluminium production

4.79 Available methods

4.80 Method 1—aluminium (baked carbon anode production)

4.81 Method 2—aluminium (baked carbon anode production)

4.82 Method 3—aluminium (baked carbon anode production)

Division 4.4.4—Aluminium production (perfluoronated carbon compound emissions)

4.83 Application

Subdivision 4.4.4.1—Aluminium—emissions of tetrafluoromethane in aluminium production

4.84 Available methods

4.86 Method 2—aluminium (tetrafluoromethane)

4.87 Method 3—aluminium (tetrafluoromethane)

Subdivision 4.4.4.2—Aluminium—emissions of hexafluoroethane in aluminium production

4.88 Available methods

4.90 Method 2—aluminium production (hexafluoroethane)

4.91 Method 3—aluminium production (hexafluoroethane)

Division 4.4.5—Other metals production

4.92 Application

4.93 Available methods

4.94 Method 1—other metals

4.95 Method 2—other metals

4.96 Method 3—other metals

Part 4.5—Industrial processes—emissions of hydrofluorocarbons and sulphur hexafluoride gases

4.97 Application

4.98 Available method

4.99 Meaning of hydrofluorocarbons

4.100 Meaning of synthetic gas generating activities

4.101 Reporting threshold

4.102 Method 1

4.103 Method 2

4.104 Method 3

Chapter 5—Waste

Part 5.1—Preliminary

5.1 Outline of Chapter

Part 5.2—Solid waste disposal on land

Division 5.2.1—Preliminary

5.2 Application

5.3 Available methods

Division 5.2.2—Method 1—emissions of methane released from landfills

5.4 Method 1—methane released from landfills (other than from flaring of methane)

5.4A Estimates for calculating CH4gen

5.4B Equation—change in quantity of particular opening stock at landfill for calculating CH4gen

5.4C Equation—quantity of closing stock at landfill in particular reporting year

5.4D Equation—quantity of methane generated by landfill for calculating CH4gen

5.5 Criteria for estimating tonnage of total solid waste

5.6 Criterion A

5.7 Criterion AAA

5.8 Criterion BBB

5.9 Composition of solid waste

5.10 General waste streams

5.10A Homogenous waste streams

5.11 Waste mix types

5.11A Certain waste to be deducted from waste received at landfill when estimating waste disposed in landfill

5.12 Degradable organic carbon content

5.13 Opening stock of degradable organic carbon for the first reporting period

5.14 Methane generation constants—(k values)

5.14A Fraction of degradable organic carbon dissimilated (DOCF)

5.14B Methane correction factor (MCF) for aerobic decomposition

5.14C Fraction by volume generated in landfill gas that is methane (F)

5.14D Number of months before methane generation at landfill commences

Division 5.2.3—Method 2—emissions of methane released from landfills

Subdivision 5.2.3.1—methane released from landfills

5.15 Method 2—methane released by landfill (other than from flaring of methane)

5.15A Equation—change in quantity of particular opening stock at landfill for calculating CH4gen

5.15B Equation—quantity of closing stock at landfill in particular reporting year

5.15C Equation—collection efficiency limit at landfill in particular reporting year

Subdivision 5.2.3.2—Requirements for calculating the methane generation constant (k)

5.16 Procedures for selecting representative zone

5.17 Site plan—preparation and requirements

5.17AA Sub‑facility zones—maximum number and requirements

5.17A Representative zones—selection and requirements

5.17B Independent verification

5.17C Estimation of waste and degradable organic content in representative zone

5.17D Estimation of gas collected at the representative zone

5.17E Estimating methane generated but not collected in the representative zone

5.17F Walkover survey

5.17G Installation of flux boxes in representative zone

5.17H Flux box measurements

5.17I When flux box measurements must be taken

5.17J Restrictions on taking flux box measurements

5.17K Frequency of measurement

5.17L Calculating the methane generation constant (ki) for certain waste mix types

Division 5.2.4—Method 3—emissions of methane released from solid waste at landfills

5.18 Method 3—methane released from solid waste at landfills (other than from flaring of methane)

Division 5.2.5—Solid waste at landfills—Flaring

5.19 Method 1—landfill gas flared

5.20 Method 2—landfill gas flared

5.21 Method 3—landfill gas flared

Division 5.2.6—Biological treatment of solid waste

5.22 Method 1—emissions of methane and nitrous oxide from biological treatment of solid waste

5.22AA Method 4—emissions of methane and nitrous oxide from biological treatment of solid waste

Division 5.2.7—Legacy emissions and non‑legacy emissions

5.22A Legacy emissions estimated using method 1—sub‑facility zone options

5.22B Legacy emissions—formula and unit of measurement

5.22C How to estimate quantity of methane captured for combustion from legacy waste for each sub‑facility zone

5.22D How to estimate quantity of methane in landfill gas flared from legacy waste in a sub‑facility zone

5.22E How to estimate quantity of methane captured for transfer out of landfill from legacy waste for each sub‑facility zone

5.22F How to calculate the quantity of methane generated from legacy waste for a sub‑facility zone (CH4genlw z)

5.22G How to calculate total methane generated from legacy waste

5.22H How to calculate total methane captured and combusted from methane generated from legacy waste

5.22J How to calculate total methane captured and transferred offsite from methane generated from legacy waste

5.22K How to calculate total methane flared from methane generated from legacy waste

5.22L How to calculate methane generated in landfill gas from non‑legacy waste

5.22M Calculating amount of total waste deposited at landfill

Part 5.3—Wastewater handling (domestic and commercial)

Division 5.3.1—Preliminary

5.23 Application

5.24 Available methods

Division 5.3.2—Method 1—methane released from wastewater handling (domestic and commercial)

5.25 Method 1—methane released from wastewater handling (domestic and commercial)

Division 5.3.3—Method 2—methane released from wastewater handling (domestic and commercial)

5.26 Method 2—methane released from wastewater handling (domestic and commercial)

5.26A Requirements relating to sub‑facilities

5.27 General requirements for sampling under method 2

5.28 Standards for analysis

5.29 Frequency of sampling and analysis

Division 5.3.4—Method 3—methane released from wastewater handling (domestic and commercial)

5.30 Method 3—methane released from wastewater handling (domestic and commercial)

Division 5.3.5—Method 1—emissions of nitrous oxide released from wastewater handling (domestic and commercial)

5.31 Method 1—nitrous oxide released from wastewater handling (domestic and commercial)

Division 5.3.6—Method 2—emissions of nitrous oxide released from wastewater handling (domestic and commercial)

5.32 Method 2—nitrous oxide released from wastewater handling (domestic and commercial)

5.33 General requirements for sampling under method 2

5.34 Standards for analysis

5.35 Frequency of sampling and analysis

Division 5.3.7—Method 3—emissions of nitrous oxide released from wastewater handling (domestic and commercial)

5.36 Method 3—nitrous oxide released from wastewater handling (domestic and commercial)

Division 5.3.8—Wastewater handling (domestic and commercial)—Flaring

5.37 Method 1—Flaring of methane in sludge biogas from wastewater handling (domestic and commercial)

5.38 Method 2—flaring of methane in sludge biogas

5.39 Method 3—flaring of methane in sludge biogas

Part 5.4—Wastewater handling (industrial)

Division 5.4.1—Preliminary

5.40 Application

5.41 Available methods

Division 5.4.2—Method 1—methane released from wastewater handling (industrial)

5.42 Method 1—methane released from wastewater handling (industrial)

Division 5.4.3—Method 2—methane released from wastewater handling (industrial)

5.43 Method 2—methane released from wastewater handling (industrial)

5.44 General requirements for sampling under method 2

5.45 Standards for analysis

5.46 Frequency of sampling and analysis

Division 5.4.4—Method 3—methane released from wastewater handling (industrial)

5.47 Method 3—methane released from wastewater handling (industrial)

Division 5.4.5—Wastewater handling (industrial)—Flaring of methane in sludge biogas

5.48 Method 1—flaring of methane in sludge biogas

5.49 Method 2—flaring of methane in sludge biogas

5.50 Method 3—flaring of methane in sludge biogas

Part 5.5—Waste incineration

5.51 Application

5.52 Available methods—emissions of carbon dioxide from waste incineration

5.53 Method 1—emissions of carbon dioxide released from waste incineration

Chapter 6—Energy

Part 6.1—Production

6.1 Purpose

6.2 Quantity of energy produced

6.3 Energy content of fuel produced

Part 6.2—Consumption

6.4 Purpose

6.5 Energy content of energy consumed

Chapter 7—Scope 2 emissions

7.1 Application

7.2 Method A1—location‑based method—electricity purchased, acquired or lost from main electricity grid in a State or Territory

7.3 Method A2—location‑based method—electricity purchased, acquired or lost from other sources

7.4 Method B—market‑based method

Chapter 8—Assessment of uncertainty

Part 8.1—Preliminary

8.1 Outline of Chapter

Part 8.2—General rules for assessing uncertainty

8.2 Range for emission estimates

8.3 Required method

Part 8.3—How to assess uncertainty when using method 1

8.4 Purpose of Part

8.5 General rules about uncertainty estimates for emissions estimates using method 1

8.6 Assessment of uncertainty for estimates of carbon dioxide emissions from combustion of fuels

8.7 Assessment of uncertainty for estimates of methane and nitrous oxide emissions from combustion of fuels

8.8 Assessment of uncertainty for estimates of fugitive emissions

8.9 Assessment of uncertainty for estimates of emissions from industrial process sources

8.10 Assessment of uncertainty for estimates of emissions from waste

8.11 Assessing uncertainty of emissions estimates for a source by aggregating parameter uncertainties

Part 8.4—How to assess uncertainty levels when using method 2, 3 or 4

8.14 Purpose of Part

8.15 Rules for assessment of uncertainty using method 2, 3 or 4

Chapter 9—Application and transitional provisions

9.10 Amendments made by the National Greenhouse and Energy Reporting (Measurement) Amendment (Energy) Determination 2017

9.11 Amendments made by the National Greenhouse and Energy Reporting (Measurement) Amendment (2018 Update) Determination 2018

9.12 Amendments made by the National Greenhouse and Energy Reporting (Measurement) Amendment (2019 Update) Determination 2019

9.13 Amendments made by the National Greenhouse and Energy Reporting (Measurement) Amendment (2020 Update) Determination 2020

9.14 Amendments made by the National Greenhouse and Energy Reporting (Measurement) Amendment (2021 Update) Determination 2021

9.15 Amendments made by the National Greenhouse and Energy Reporting (Measurement) Amendment (2022 Update) Determination 2022

9.16 Amendments made by the National Greenhouse and Energy Reporting (Measurement) Amendment (2023 Update) Determination 2023

9.17 Amendment made by the National Greenhouse and Energy Reporting (Measurement) Amendment (2023 Update No. 2) Determination 2023

9.18 Amendments made by the National Greenhouse and Energy Reporting (Measurement) Amendment (2024 Update) Determination 2024

9.19 Amendments made by the National Greenhouse and Energy Reporting Legislation Amendment (Best Practice Emissions Intensities Update) Instrument 2024

9.20 Amendments made by the National Greenhouse and Energy Reporting (Measurement) Amendment (2025 Update) Determination 2025

9.21 Amendments made by the National Greenhouse and Energy Reporting (Measurement) Amendment (2025 Update No. 2) Determination 2025

Schedule 1—Energy content factors and emission factors

Part 1—Fuel combustion—solid fuels and certain coal‑based products

Part 2—Fuel combustion—gaseous fuels

Part 3—Fuel combustion—liquid fuels and certain petroleum‑based products for stationary energy purposes

Part 4—Fuel combustion—fuels for transport energy purposes

Division 4.1—Fuel combustion—fuels for transport energy purposes

Division 4.2—Fuel combustion—liquid fuels for transport energy purposes for post‑2004 vehicles

Division 4.3—Fuel combustion—liquid fuels for transport energy purposes for certain trucks

Part 5—Consumption of fuels for non‑energy product purposes

Part 6—Indirect (scope 2) emission factors and residual mix factors for consumption of electricity

Part 7—Energy commodities

Schedule 2—Standards and frequency for analysing energy content factor etc for solid fuels

Schedule 3—Carbon content factors

Part 1—Solid fuels and certain coal‑based products

Part 2—Gaseous fuels

Part 3—Liquid fuels and certain petroleum‑based products

Part 4—Petrochemical feedstocks and products

Part 5—Carbonates

Schedule 4—Matters to be identified for sources

Part 1A—Fuel combustion

Part 1—Coal mining

Part 2—Oil or gas

Part 3—Mineral products

Part 4—Chemical products

Part 5—Metal products

Part 6—Waste

Part 7—Scope 2 emissions

Endnotes

Chapter 1—General

Part 1.1—Preliminary

1.1  Name of Determination

  This Determination is the National Greenhouse and Energy Reporting (Measurement) Determination 2008.

Division 1.1.1—Overview

1.3  Overview—general

 (1) This determination is made under section 10 of the National Greenhouse and Energy Reporting Act 2007. It provides for the measurement of the following:

 (a) greenhouse gas emissions arising from the operation of facilities;

 (b) the production of energy arising from the operation of facilities;

 (c) the consumption of energy arising from the operation of facilities.

Note: Facility has the meaning given by section 9 of the Act.

 (2) This determination deals with scope 1 emissions and scope 2 emissions.

Note: Scope 1 emission and scope 2 emission have the meaning given by section 10 of the Act (also see, respectively, regulations 2.23 and 2.24 of the Regulations).

 (3) There are 4 categories of scope 1 emissions dealt with in this Determination.

Note: This Determination does not deal with emissions released directly from land management.

 (4) The categories of scope 1 emissions are:

 (a) fuel combustion, which deals with emissions released from fuel combustion (see Chapter 2); and

 (b) fugitive emissions from fuels, which deals with emissions mainly released from the extraction, production, processing and distribution of fossil fuels (see Chapter 3); and

 (c) industrial processes emissions, which deals with emissions released from the consumption of carbonates and the use of fuels as feedstock or as carbon reductants, and the emission of synthetic gases in particular cases (see Chapter 4); and

 (d) waste emissions, which deals with emissions mainly released from the decomposition of organic material in landfill or other facilities, or wastewater handling facilities (see Chapter 5).

 (5) Each of the categories has various subcategories.

1.4  Overview—methods for measurement

 (1) This Determination provides methods and criteria for the measurement of the matters mentioned in subsection 1.3(1).

 (2) For scope 1 emissions or scope 2 emissions:

 (a) method 1 (known as the default method) is derived from the National Greenhouse Accounts methods and is based on national average estimates; and

 (b) method 2 is generally a facility specific method using industry practices for sampling and Australian or equivalent standards for analysis; and

 (c) method 3 is generally the same as method 2 but is based on Australian or equivalent standards for both sampling and analysis; and

 (d) method 4 provides for facility specific measurement of emissions by continuous or periodic emissions monitoring.

Note: Method 4, that applies as indicated by provisions of this Determination, is as set out in Part 1.3.

 (3) Data points relevant to the implementation of particular methods are set out in column 3 of the tables in Schedule 4 as ‘matters to be identified’. 

Note: Regulations 4.07(2), 4.10, 4.11, 4.13, 4.14, 4.15, 4.17 and 4.17B of the Regulations require these matters to be identified to be included in reports under the Act.

1.5  Overview—energy

  Chapter 6 deals with the estimation of the production and consumption of energy.

1.6  Overview—scope 2 emissions

  Chapter 7 deals with scope 2 emissions.

1.7  Overview—assessment of uncertainty

  Chapter 8 deals with the assessment of uncertainty.

Division 1.1.2—Definitions and interpretation

1.8  Definitions

  In this Determination: