Future Made in Australia (Guarantee of Origin) Legislation Amendment (Measures No. 1) Instrument 2026

Contents

1Name#

This instrument is the Future Made in Australia (Guarantee of Origin) Legislation Amendment (Measures No. 1) Instrument 2026.

2Commencement#

(1)Each provision of this instrument specified in column 1 of the table commences, or is taken to have commenced, in accordance with column 2 of the table. Any other statement in column 2 has effect according to its terms.

Commencement information
Column 1	Column 2	Column 3
Provisions	Commencement	Date/Details
1. The whole of this instrument	The day after this instrument is registered.

Note: This table relates only to the provisions of this instrument as originally made. It will not be amended to deal with any later amendments of this instrument.

(2)Any information in column 3 of the table is not part of this instrument. Information may be inserted in this column, or information in it may be edited, in any published version of this instrument.

3Authority#

This instrument is made under sections 29 and 160 of the Future Made in Australia (Guarantee of Origin) Act 2024.

4 Schedules #

Each instrument that is specified in a Schedule to this instrument is amended or repealed as set out in the applicable items in the Schedule concerned, and any other item in a Schedule to this instrument has effect according to its terms.

Chapter 4—Aluminium production pathway

Part 4.1 · Production of aluminium

40 Aluminium functional unit #

The functional unit of aluminium is 1 tonne of aluminium.

41 Aluminium batch size #

(1)For the purposes of subparagraph 29(4)(d)(i) of the Act, the amount of aluminium in a batch produced in accordance with a production pathway for aluminium is the amount measured at the production gate for the product at the facility.

(2)For the purposes of subsection (1), the amount of aluminium in a batch must be monitored or measured in accordance with section 9.

42 Aluminium production pathway #

(1)The aluminium production pathway is a production pathway for aluminium.

(2)The aluminium production module is the process of extracting aluminium from alumina by way of an electrochemical reduction using anodes (the smelting process) and includes the operation of any equipment required to produce the aluminium, including equipment used to transport the product or any other materials for the purposes of the smelting process.

(3)The aluminium production module is a minimum module for the aluminium production pathway.

(4)The following are sources of emissions for the aluminium production pathway:

(a)electricity supply and use for the pathway;

(b)fuel supply and combustion for the pathway;

(c)carbonates use for the pathway;

(d)synthetic gas use for the pathway;

(e)alumina supply for the pathway;

(f)anode supply for the pathway;

(g)anode use for the pathway;

(h)perfluorocarbon emissions from the pathway.

Note: Pursuant to subsection 29(6) of the Act, a source of emissions relating to a production pathway for a product is a production emissions source for the production pathway.

(5)If a source of emissions mentioned in subsection (4) exists for the aluminium production pathway, the emissions from that source must be determined in accordance with the following:

(a)for electricity supply and use—section 15;

(b)for fuel supply and combustion—section 16;

(c)for carbonates use—section 16B;

(d)for synthetic gas use—section 19;

(e)for alumina supply—section 46;

(f)for anode supply—section 48;

(g)for anode use—section 49;

(h)for perfluorocarbon emissions—section 50.

Note: For the aluminium production pathway, section 19 only applies to sulphur hexafluoride: see the definition of synthetic gas in subsection 19(7).

43 Optional modules #

Casting

(1)The casting production module is the process of casting molten aluminium into solid forms, such as ingots, slabs or billets, including melting any solid aluminium which is combined with the molten aluminium.

(2)The casting production module is an optional module for the aluminium production pathway.

(3)The following are sources of emissions for the casting production module:

(a)feedstock supply for the module;

(b)alloying metals supply and use for the module.

(4)If a source of emissions mentioned in subsection (3) exists for the casting production module, the emissions from that source must be determined in accordance with the following:

(a)for feedstock supply—section 16A;

(b)for alloying metals supply and use—section 19B.

Note 1: For the aluminium production pathway, section 16A only applies to pre-consumer and post-consumer scrap aluminium: see the definition of feedstock in subsection 16A(2).

Note 2: An optional module is a production module that forms part of the production pathway. The sources of emissions specified in subsection (3) are in addition to the sources of emissions for the aluminium production pathway, specified in subsection 42(4).

Carbon anode production

(5)The carbon anode production module is the process of forming anodes from carbon feedstocks and baking these anodes for use in smelting.

(6)The carbon anode production module is an optional module for the aluminium production pathway.

(7)The production of carbon anodes for the aluminium production pathway is a source of emissions for the carbon anode production module.

(8)If the production of carbon anodes exists as a source of emissions for the carbon anode production module, the emissions from that source must be determined in accordance with section 47.

Note: An optional module is a production module that forms part of the production pathway. The sources of emissions specified in subsection (7) are in addition to the sources of emissions for the aluminium production pathway, specified in subsection 42(4).

44 Aluminium production emissions #

The emissions for the production of a batch (b) of aluminium, Epathway,b, in kilograms of CO2-e, are the sum of the emissions for the batch from all sources of emissions for the aluminium production pathway.

Note: An optional module is a production module that forms part of the production pathway. All sources of emissions for the production pathway, including for optional modules for that production pathway, are specified in the relevant section for the pathway.

45 Aluminium post-production emissions #

The post-production emissions for the transport or storage of one or more functional units of a batch (b) of aluminium in accordance with one or more delivery modules (the transported quantity), Edel,transported, are the sum of the emissions from all sources of post-production emissions for the delivery modules for the transported quantity in kilograms of CO2-e.

Note: Where the transported quantity has been stored or transported in accordance with more than one delivery module, the post-production emissions for the transported quantity are the sum of emissions from all sources of post-production emissions for each delivery module.

46 Alumina supply #

The emissions from alumina used for the production pathway for the batch (b), Ealumina,b, in kilograms of CO2-e are worked out using the following formula:

𝑬𝒂𝒍𝒖𝒎𝒊𝒏𝒂,𝒃=෍𝑸𝒂𝒍𝒖𝒎𝒊𝒏𝒂,𝒃,𝒙×𝑬𝑭𝒂𝒍𝒖𝒎𝒊𝒏𝒂,𝒙

where:

Qalumina,b,x is the amount of alumina used for the production pathway for the batch (b) from source (x) in tonnes, measured in accordance with section 9.

EFalumina,x, the scope 3 emission factor for the alumina used for the production pathway for the batch (b) from source (x), in kilograms of CO2-e per tonne, is:

(a)if there is a registered PGO certificate in respect of the alumina—the delivered emissions intensity stated on the PGO certificate; or

(b)in any other case—1,301.4.

47 Carbon anode production #

(1)The emissions from the production of baked carbon anodes used for the production pathway for the batch (b), Eanode_prod,b, in kilograms of CO2-e are worked out using the following formula:

where:

Eap,scope 1,b is the scope 1 emissions from the production of baked carbon anodes used for the production pathway for the batch (b), in kilograms of CO2-e, worked out in accordance with subsection (2).

Eap,scope 3,b is the scope 3 emissions from the production of baked carbon anodes used for the production pathway for the batch (b), in kilograms of CO2-e, worked out in accordance with subsection (4).

Scope 1 emissions from the production of baked carbon anodes

(2)For the purposes of subsection (1), Eap,scope 1,b is worked out using the following formula:

where:

GAb is the quantity of green anodes used to produce the baked carbon anodes used for the production pathway for the batch (b), in tonnes, monitored or measured in accordance with subsection (3).

Hw,b is either:

(a)the hydrogen content of the quantity of green anodes used to produce the baked carbon anodes used for the production pathway for the batch (b), in tonnes, monitored or measured in accordance with subsection (3); or

(b)0.5% of GAb.

BAb is the quantity of baked carbon anodes used for the production pathway for the batch (b), in tonnes, monitored or measured in accordance with subsection (3).

WTb is the quantity of waste tar produced through the production of the baked carbon anodes used for the production pathway for the batch (b), in tonnes, monitored or measured in accordance with subsection (3).

Qpc,b is the quantity of packing coke consumed for the purposes of producing the batch (b), in tonnes, monitored or measured in accordance with subsection (3).

Spc,b is the mass of sulphur content in the packing coke consumed for the purposes of producing the batch (b), as a percentage of the mass of the packing coke, which is either:

(a)determined in accordance with NGER Method 2 sampling or NGER Method 3 sampling; or

(b)2%.

Ashpc,b is the mass of ash content in the packing coke consumed for the purposes of producing the batch (b), as a percentage of the mass of the packing coke, which is either:

(a)determined in accordance with NGER Method 2 sampling or NGER Method 3 sampling; or

(b)0.4%.

(3)For the purposes of subsection (2), the parameters GAb, Hw,b, BAb, WTb and Qpc,b must be either:

(a)monitored or measured in accordance with section 9; or

(b)estimated using an average value derived from a representative sample where that sample has been monitored or measured in accordance with section 9.

Scope 3 emissions from the production of baked carbon anodes

(4)For the purposes of subsection (1), Eap,scope 3,b is worked out using the following formula:

Qcpc,b is the quantity of calcined petroleum coke used to produce the baked carbon anodes used for the production pathway for the batch (b), in tonnes, monitored or measured in accordance with section 9.

EFscope 3,cpc, the scope 3 emission factor for calcined petroleum coke in kilograms of CO2-e per tonne of calcined petroleum coke, is 2,161.9.

Qpitch,b is the quantity of coal tar pitch used to produce the baked carbon anodes used for the production pathway for the batch (b), in tonnes, monitored or measured in accordance with section 9.

EFscope 3,pitch, the scope 3 emission factor for coal tar pitch in kilograms of CO2-e per tonne of coal tar pitch, is 1,364.9.

48 Anode supply #

The emissions from the supply of anodes for the production pathway for the batch (b), Eanode_sup,b, in kilograms of CO2-e, are worked out using the following formula:

𝑬𝒂𝒏𝒐𝒅𝒆𝒔_𝒔𝒖𝒑,𝒃=𝑸𝒂𝒏𝒐𝒅𝒆𝒔_𝒔𝒖𝒑,𝒃×𝑬𝑭𝒂𝒏𝒐𝒅𝒆𝒔_𝒔𝒖𝒑

where:

Qanodes_sup,b is the quantity of anodes supplied for the production pathway for the batch (b) in tonnes, monitored and measured in accordance with section 9.

Eanode_sup, the scope 3 emission factor for supplied anodes, in kilograms of CO2-e per tonne of anodes, is either:

(a)for carbon anodes—1,948.5; or

(b)for non-carbon anodes provided by an input supplier where the input supplier provides an emission factor for the anodes—the factor provided.

49 Anode use #

(1)The emissions from the use of baked carbon anodes for the production pathway for the batch (b), Eanode_smelt,b, in kilograms of CO2-e, are worked out using the following formula:

𝑬𝒂𝒏𝒐𝒅𝒆_𝒔𝒎𝒆𝒍𝒕,𝒃=𝑸𝒑𝒓𝒊𝒎𝒂𝒓𝒚,𝒃×𝑬𝑭𝒂𝒏𝒐𝒅𝒆

where:

Qprimary,b is the amount of aluminium in the batch (b), in tonnes, monitored or measured at the end of the aluminium production module in accordance with section 9.

EFanode is the scope 1 emission factor for carbon anode consumption in kilograms of CO2-e per tonne of aluminium worked out in accordance with subsection (2).

(2)For the purposes of subsection (1),the scope 1 emission factor for carbon anode consumption in kilograms of CO2-e per tonne of aluminium is worked out using the following formula:

𝑬𝑭𝒂𝒏𝒐𝒅𝒆=𝑵𝑨𝑪𝒃×𝟏𝟎𝟎−𝑺𝒂,𝒃−𝑨𝒔𝒉𝒂,𝒃𝟏𝟎𝟎×𝟑𝟔𝟔𝟒

where:

NACb is the amount of carbon consumed from a carbon anode during production of aluminium in the batch (b), in tonnes of carbon anode consumed per tonne of aluminium produced, which is either:

(a)monitored and measured in accordance with section 9; or

(b)0.413.

Sa,b is the mass of sulphur content in carbon anodes consumed during production of aluminium in the batch (b), in % of the mass of the carbon anodes, which is either:

(a)determined in accordance with NGER Method 2 sampling or NGER Method 3 sampling; or

(b)2%.

Asha,b is the mass of ash content in carbon anodes consumed during production of aluminium in the batch (b), in % of the mass of carbon anodes, which is either:

(a)determined in accordance with NGER Method 2 sampling or NGER Method 3 sampling; or

(b)0.4%.

(3)In this section:

aluminium production module: see subsection 42(2).

50 Perfluorocarbon emissions #

(1)The perfluorocarbon emissions for the production pathway for the batch (b), EPFC,b, in kilograms of CO2-e, are worked out using the following formula:

𝑬𝑷𝑭𝑪,𝒃=𝑬𝑪𝑭4,𝒃×𝑮𝑾𝑷𝑪𝑭4+𝑬𝑪2𝑭6,𝒃×𝑮𝑾𝑷𝑪2𝑭6

where:

ECF4,b is the tetrafluoromethane (CF4) emissions for the batch (b), in kilograms, worked out in accordance with subsection (2).

GWPCF4 is the Global Warming Potential of tetrafluoromethane (CF4).

EC2F6,b is the hexafluoroethane (C2F6) emissions for the batch (b), in kilograms, worked out in accordance with subsection (3).

GWPC2F6 is the Global Warming Potential of hexafluoroethane (C2F6).

(2)For the purposes of subsection (1), ECF4,b is worked out using the following formula:

𝑬𝑪𝑭4,𝒃=𝑬𝑪𝑭4,𝒚𝑸𝒑𝒓𝒊𝒎𝒂𝒓𝒚,𝒚×𝑸𝒑𝒓𝒊𝒎𝒂𝒓𝒚,𝒃

where:

ECF4,y is the tetrafluoromethane (CF4) emissions for the production pathway for the year (y), in kilograms, worked out in accordance with section 4.86 or 4.87 of the NGER Measurement Determination.

Qprimary,y is the amount of aluminium produced in accordance with the aluminium production module for the year (y), in tonnes, monitored or measured at the end of the aluminium production module in accordance with section 9.

y is either:

(a)the financial year immediately prior to the financial year in which the batch period started; or

(b)if the batch period ends on 30 June—the financial year in which the batch period started.

Qprimary,b is the amount of aluminium in the batch (b), in tonnes, monitored or measured at the end of the aluminium production module in accordance with section 9.

(3)For the purposes of subsection (1), EC2F6,b is worked out using the following formula:

𝑬𝑪2𝑭6,𝒃=𝑬𝑪2𝑭6,𝒚𝑸𝒑𝒓𝒊𝒎𝒂𝒓𝒚,𝒚×𝑸𝒑𝒓𝒊𝒎𝒂𝒓𝒚,𝒃

where:

EC2F6,y is the hexafluoroethane (C2F6) emissions for the production pathway for the year (y), in kilograms, worked out in accordance with section 4.90 or 4.91 of the NGER Measurement Determination.

y is either:

(a)the financial year immediately prior to the financial year in which the batch period started; or

(b)if the batch period ends on 30 June—the financial year in which the batch period started.

Qprimary,b is the amount of aluminium in the batch (b), in tonnes, monitored or measured at the end of the aluminium production module in accordance with section 9.

(4)In this section:

aluminium production module: see subsection 42(2).

51 Production emissions intensity—aluminium #

The emissions intensity for the production of a batch of aluminium, EIb, in tonnes of CO2-e per tonne of aluminium, is worked out using the following formula:

𝑬𝑰𝒃=𝑬𝒑𝒂𝒕𝒉𝒘𝒂𝒚,𝒃𝑸𝒃×𝟏𝟎𝟎𝟎

where:

Epathway,b is the emissions for the production of the batch (b) of aluminium in kilograms of CO2-e, worked out in accordance with section 44.

Qb is the amount of aluminium in the batch (b), in tonnes, worked out in accordance with section 41.

Note: The production emissions intensity for the batch must be included on the PGO certificate in accordance with the rules.

52 Delivered emissions intensity—aluminium #

The emissions intensity for the production and storage or transport for one or more functional units of a batch (b) of aluminium (the transported quantity), EIdel,product, in tonnes of CO2-e per tonne of aluminium, is worked out using the following formula:

𝑬𝑰𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕=𝑬𝑰𝒃+𝑬𝑰𝒑𝒐𝒔𝒕𝒑𝒓𝒐𝒅,𝒑𝒓𝒐𝒅𝒖𝒄𝒕

where:

EIb is the emissions intensity for the production of the batch of aluminium, in tonnes of CO2-e per tonne of aluminium, worked out in accordance with section 51.

EIpostprod,product is the post-production emissions intensity for the transported quantity, in tonnes of CO2-e per tonne of aluminium, worked out in accordance with section 53.

Note: The delivered emissions intensity for the transported quantity must be included on the PGO certificate in accordance with the rules.

53 Post-production emissions intensity—aluminium #

The emissions intensity for the transport of one or more functional units of a batch (b) of aluminium (the transported quantity), EIpostprod,product, in tonnes of CO2-e per tonne of aluminium, is worked out using the following formula:

𝑬𝑰𝒑𝒐𝒔𝒕𝒑𝒓𝒐𝒅,𝒑𝒓𝒐𝒅𝒖𝒄𝒕=𝑬𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕𝑸𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕×𝟏𝟎𝟎𝟎

where:

Edel,product is the post-production emissions for the transported quantity, in kilograms of CO2-e, worked out in accordance with section 45.

Qdel,product is the amount of product in the transported quantity that reached the delivery gate, in tonnes, worked out in accordance with Division 4.2.2.

Note: The post-production emissions intensity for the transported quantity must be included on the PGO certificate in accordance with the rules.

Part 4.2 · Delivery of aluminium

54 Delivery modules #

(1)The vehicle delivery module is a delivery module for aluminium.

(2)Vehicle emissions are a source of emissions for the vehicle delivery module for aluminium.

(3)The emissions from vehicle emissions must be determined in accordance with section 21.

Note: Subject to subsection 29(7) of the Act, a source of emissions relating to a delivery module for a product is a post-production emissions source for the delivery module.

55 Amount of aluminium that reaches the delivery gate or end of delivery module #

Amount that reaches the delivery gate

(1)Where a delivery module is the final delivery module for the aluminium, the amount of aluminium that reaches the delivery gate is worked out in accordance with section 56.

(2)Where no delivery module is required to convey the aluminium from the production gate to a delivery gate, the amount of aluminium that reaches the delivery gate is worked out in accordance with section 57.

Example: Molten aluminium is delivered to a customer next door to the aluminium smelter without requiring the use of a delivery module.

Amount that reaches the end of the delivery module

(3)Where the delivery module is an interim delivery module for the aluminium, the amount of aluminium that reaches the end of the delivery module is worked out in accordance with section 56 where a reference in that provision to delivery gate is taken to be a reference to end of the delivery module.

56 Vehicle transport delivered amount—aluminium #

Where one or more functional units of a batch of aluminium (the transported quantity) are transported in accordance with the vehicle delivery module for aluminium, the amount of aluminium that reaches the delivery gate is the amount measured:

(a)at the closest practicable point to the delivery gate; and

(b)in accordance with section 9.

57 Direct delivery delivered amount—aluminium #

Where one or more functional units of a batch of aluminium (the transported quantity) reach a delivery gate without being stored or transported in accordance with a delivery module, the amount of aluminium that reaches the delivery gate is the same as the amount of aluminium that reaches the production gate, monitored or measured in accordance with section 9.

Chapter 5 · Methane production pathway

Part 5.1 · Production of methane

58 Methane functional unit #

The functional unit of methane is 1 gigajoule of methane measured as the higher heating value.

59 Methane batch size #

(1)For the purposes of subparagraph 29(4)(d)(i) of the Act, the amount of methane in a batch produced in accordance with a production pathway for methane is the amount measured at the production gate for the product at the facility.

(2)For the purposes of subsection (1), the amount of methane in a batch must be monitored or measured in accordance with section 9.

60 Biogas by anaerobic digestion production pathway #

(1)The biogas by anaerobic digestion production pathway is a production pathway for methane.

(2)The anaerobic digestion production module is the biological conversion of biodegradable feedstock materials by micro-organisms in the absence of oxygen.

(3)The anaerobic digestion production module is a minimum module for the biogas by anaerobic digestion production pathway.

(4)The following are sources of emissions for the biogas by anaerobic digestion production pathway:

(a)electricity supply and use for the pathway;

(b)fuel supply and combustion for the pathway;

(c)feedstock supply for the pathway;

(d)steam supply for the pathway;

(e)synthetic gas use for the pathway;

(f)production fugitive emissions for the pathway;

(g)digestate storage for the pathway.

Note: Pursuant to subsection 29(6) of the Act, a source of emissions relating to a production pathway for a product is a production emissions source for the production pathway.

(5)If a source of emissions mentioned in subsection (4) exists for the biogas by anaerobic digestion production pathway, the emissions from that source must be determined in accordance with the following:

(a)for electricity supply and use—section 15;

(b)for fuel supply and combustion—section 16;

(c)for feedstock supply—section 16A;

(d)for steam supply—section 18;

(e)for synthetic gas use—section 19;

(f)for production fugitive emissions—section 66;

(g)for digestate storage—section 67.

Note: Section 16A only applies to feedstocks defined in that section: see the definition of feedstock in subsection 16A(2).

61 Optional modules—biogas by anaerobic digestion production pathway #

(1)The biogas feedstock transport production module is the process of transporting the feedstock from its production location to the location at which the feedstock will be used for the production pathway.

(2)The intermediate transport production module is the process of transporting methane during the production pathway.

(3)The following modules are optional modules for the biogas by anaerobic digestion production pathway:

(a)the biogas feedstock transport production module;

(b)the feedstock pre-treatment production module;

(c)the intermediate storage tank production module for methane;

(d)the intermediate transport production module;

(e)the gas conditioning production module.

62 Biomethane by biogas upgrading production pathway #

(1)The biomethane by biogas upgrading production pathway is a production pathway for methane.

(2)The biogas upgrading production module is the process of conditioning biogas to produce biomethane.

(3)The biogas upgrading production module is a minimum module for the biomethane by biogas upgrading production pathway.

(4)The following are sources of emissions for the biomethane by biogas upgrading production pathway:

(a)electricity supply and use for the pathway;

(b)fuel supply and combustion for the pathway;

(c)feedstock supply for the pathway;

(d)steam supply for the pathway;

(e)synthetic gas use for the pathway;

(f)production fugitive emissions for the pathway.

Note: Pursuant to subsection 29(6) of the Act, a source of emissions relating to a production pathway for a product is a production emissions source for the production pathway.

(5)If a source of emissions mentioned in subsection (4) exists for the biomethane by biogas upgrading production pathway, the emissions from that source must be determined in accordance with the following:

(a)for electricity supply and use—section 15;

(b)for fuel supply and combustion—section 16;

(c)for feedstock supply—section 16A;

(d)for steam supply—section 18;

(e)for synthetic gas use—section 19;

(f)for production fugitive emissions—section 66.

Note: Section 16A only applies to feedstocks defined in that section: see the definition of feedstock in subsection 16A(2).

63 Optional modules—biogas upgrading #

(1)The feedstock transport production module is the process of:

(a)for an anaerobic digestion production module—transporting a feedstock from its production location to the location at which the feedstock will be used for the production pathway; and

(b)for the biogas upgrading production module—transporting biogas from its production location to the location at which the biogas upgrading production module will be carried out.

(2)The following modules are optional modules for the biomethane by biogas upgrading production pathway:

(a)the feedstock transport production module;

(b)the feedstock pre-treatment production module;

(c)the intermediate storage tank production module for methane;

(d)the intermediate transport production module;

(e)the anaerobic digestion production module;

(f)the gas conditioning production module.

(3)If the anaerobic digestion production module is used in the biogas upgrading production pathway:

(a)digestate storage is as a source of emissions for the pathway; and

(b)the emissions from that source must be determined in accordance with section 67.

(4)In this section:

anaerobic digestion production module: see section 60(2).

intermediate transport production module: see section 61(2).

production location, of biogas, is:

(a)if there is a registered PGO certificate in respect of the biogas—the location of the production gate stated in the certificate; or

(b)in any other case—the location at which the feedstock is produced.

64 Methane production emissions #

The emissions for the production of a batch (b) of methane, Epathway,b, in kilograms of CO2-e, are the sum of the emissions for the batch from all sources of emissions for the production pathway.

65 Methane post-production emissions #

The post-production emissions for the transport or storage of one or more functional units of a batch (b) of methane in accordance with one or more delivery modules (the transported quantity), Edel,product, are the sum of the emissions from all sources of post-production emissions for the delivery modules for the transported quantity in kilograms of CO2-e.

66 Production fugitive emissions—methane #

(1)The fugitive emissions from the production pathway of the batch (b), Efug,b, in kilograms of CO2-e are calculated using the following formula:

𝑬𝒇𝒖𝒈,𝒃=𝑬𝒍𝒆𝒂𝒌𝒔,𝒃+𝑬𝒇𝒍𝒂𝒓𝒆,𝒃+𝑬𝒗𝒆𝒏𝒕,𝒃

where:

Eleaks,b is the emissions from leaks for the production pathway of the batch (b) in kilograms of CO2-e worked out using either of the following methods:

(a)the default approximation method in subsection (2); or

(b)the process-specific method in subsection (4).

Eflare,b is the emissions from flaring for the production pathway of the batch (b) in kilograms of CO2-e worked out in accordance with subsection (6).

Event,b is the emissions from venting for the production pathway of the batch (b) in kilograms of CO2-e worked out in accordance with subsection (7).

Default approximation method

(2)For the purposes of subsection (1), the emissions associated with leaks for the production pathway of the batch (b), Eleaks,b, in kilograms of CO2-e are calculated using the following formula:

𝑬𝒍𝒆𝒂𝒌𝒔,𝒃=𝑸𝒃×𝑭𝒍𝒆𝒂𝒌𝒔×𝑮𝑾𝑷𝒎𝒆𝒕𝒉𝒂𝒏𝒆

where:

Qb is the amount of product in the batch (b) in gigajoules, monitored or measured in accordance with section 9.

Fleaks is the leakage factor for the batch (b) in kilograms per gigajoule, calculated in accordance with subsection (3).

GWPmethane is the Global Warming Potential of methane.

(3)For the purposes of subsection (2), the emission factor Fleaks is calculated using the following formula:

𝑭𝒍𝒆𝒂𝒌𝒔=𝟎.𝟏𝟒𝟏×𝒆𝒌×𝑸𝒃𝒕𝒃𝟐+𝟎.𝟎𝟏𝟑𝟐

where:

e is the mathematical constant Euler’s number, accurate to at least 4 decimal places.

Note: Euler’s number to 4 decimal places is 2.7183.

k is a constant equal to −5.98 × 10⁻².

Qb is the amount of product in the batch (b) in gigajoules, monitored or measured in accordance with section 9.

tb is the duration of the batch period in hours.

Process-specific method

(4)For the purposes of subsection (1), the emissions associated with leaks for the production pathway of the batch (b), Eleaks,b, in kilograms of CO2-e are calculated using the following formula:

𝑬𝒍𝒆𝒂𝒌𝒔,𝒃=𝑸𝒃×෍𝑭𝒌𝒌×𝑮𝑾𝑷𝒎𝒆𝒕𝒉𝒂𝒏𝒆

where:

k is each equipment or process type used in the production of the batch.

Qb is the amount of product in the batch (b) in gigajoules, monitored or measured in accordance with section 9.

Fk is the leakage factor of each equipment or process type (k) in units of kilograms of methane per gigajoule as determined under subsection (5).

GWPmethane is the Global Warming Potential of methane.

(5)The leakage factor of equipment type or process type (k) used to produce batch (b), Fk, in units of kilograms of methane per gigajoule is either:

(a)for an equipment type or process type (k) mentioned in column 2 of an item in the following table—the leakage factor mentioned in column 3 of that item; or

Column 1Item	Column 2Equipment type or process type (k)	Column 3Leakage factor (Fk) in kg methane per GJ
1	Anaerobic digester with implemented LDAR program	9.00 × 10⁻²
2	Anaerobic digester	7.20 × 10⁻¹
3	Biogas upgrading	4.50 × 10⁻²
4	Biogas upgrading with implemented LDAR program	4.50 × 10⁻³

(b)if the manufacturer of the equipment supplies equipment-specific production factors for the equipment type—those factors.

(6)The emissions from flaring for the production pathway of the batch (b), Eflare,b, in kilograms of CO2-e are calculated using the following formula:

𝑬𝒇𝒍𝒂𝒓𝒆,𝒃=𝑸𝒇𝒍𝒂𝒓𝒆,𝒃×෍൫𝑭𝒊𝒊×𝑮𝑾𝑷𝒊൱

where:

Qflare,b is the quantity of product flared during the production pathway of the batch (b) in gigajoules, monitored or measured in accordance with section 9.

Fi is the density factor of fugitive gas (i), in kilograms per gigajoule, as follows:

(a)for methane—3.603 × 10⁻¹; and

(b)for nitrous oxide—1.505 × 10⁻³.

GWPi is the Global Warming Potential of fugitive gas (i).

Note The calculation in this subsection uses standard cubic metres of product. The conditions used for these equations are 101.325 kPa, 15 °C.

(7)The emissions from venting for the production pathway of the batch (b), Event,b, in kilograms of CO2-e are calculated using the following formula:

𝑬𝒗𝒆𝒏𝒕,𝒃=𝑸𝒗𝒆𝒏𝒕,𝒃×𝑭𝒗𝒆𝒏𝒕×𝑮𝑾𝑷𝒎𝒆𝒕𝒉𝒂𝒏𝒆

where:

Qvent,b is the quantity of product vented during the production pathway of the batch (b) in gigajoules, monitored or measured in accordance with section 9.

Fvent is a conversion factor equal to 18.01 kilograms per gigajoule.

GWPmethane is the Global Warming Potential of methane.

67 Digestate storage #

(1)The fugitive emissions from digestate storage for the production of the batch (b), Edig,b, in kilograms of CO2-e, are calculated using the following formula:

𝑬𝒅𝒊𝒈,𝒃=𝑸𝒃×𝑭𝒅𝒊𝒈×𝑮𝑾𝑷𝒎𝒆𝒕𝒉𝒂𝒏𝒆

where:

Qb is the amount of product in the batch (b) in gigajoules, monitored or measured in accordance with section 9.

Fdig is the leakage factor for the method of digestate storage employed for the production pathway in units of kilograms of methane per gigajoule determined in accordance with subsection (2).

GWPmethane is the Global Warming Potential of methane.

(2)The leakage factor Fdig, in kilograms per gigajoule, for the method of digestate storage mentioned in column 2 of an item in the following table is the leakage factor mentioned in column 3 of the item:

Column 1	Column 2	Column 3
Item	Method of digestate storage	Leakage factor (Fdig) in kg per GJ
1	Open digestate storage	1.80 × 10⁰
2	Gastight digestate storage	3.24 × 10⁻¹
3	Gastight digestate storage with implemented LDAR program	9.00 × 10⁻²
4	Gastight digestate storage with implemented LDAR program and 150 days hydraulic retention time of material	1.80 × 10⁻²

(3)In this section:

hydraulic retention time means the average time that material stays in the digester vessel and gastight digestate storage.

68 Production emissions intensity—methane #

(1)The emissions intensity for the production of a batch of methane, EIb, is worked out:

(a)if the intermediate storage tank production module is used to produce the batch (b) and the duration of the batch period is less than the time it took to fill the vessel for the purposes of the module—in accordance with subsection (2); or

(b)in any other case—in accordance with subsection (5).

Note: The production emissions intensity for the batch must be included on the PGO certificate in accordance with the rules.

(2)For the purposes of paragraph (1)(a), EIb is worked out:

(a)if the value of Qpathway,b is equal to or greater than the value of Qb—in accordance with subsection (3); and

(b)if the value of Qpathway,b is less than the value of Qb—in accordance with subsection (4).

(3)For the purposes of paragraph (2)(a), EIb is worked out using the following formula:

𝑬𝑰𝒃=𝑬𝒑𝒂𝒕𝒉𝒘𝒂𝒚,𝒃𝑸𝒑𝒂𝒕𝒉𝒘𝒂𝒚,𝒃

where:

Epathway,b is the emissions attributable to the batch (b) in kilograms of CO2-e, worked out in accordance with section 64.

Qpathway,b has the meaning given by subsection (6).

(4)For the purposes of paragraph (2)(b), EIb is worked out using the following formula:

𝑬𝑰𝒃=𝑬𝒑𝒂𝒕𝒉𝒘𝒂𝒚,𝒃+𝑸𝒃−𝑸𝒑𝒂𝒕𝒉𝒘𝒂𝒚,𝒃×𝑬𝑰𝒃−1𝑸𝒃

where:

Epathway,b is the emissions for the production pathway of the batch (b) in kilograms of CO2-e, worked out in accordance with section 64.

Qpathway,b has the meaning given by subsection (6).

Qb has the meaning given by subsection (6).

EIb-1 is:

(a)if the batch is the first batch of the product produced by the holder of the production profile—worked out in accordance with subsection (3); or

(b)in any other case—the production emissions intensity for the batch produced by the holder of the production profile immediately prior to the batch (b) in kilograms of CO2-e per gigajoule.

(5)For the purposes of paragraph (1)(b), EIb is worked out using the following formula:

𝑬𝑰𝒃=𝑬𝒑𝒂𝒕𝒉𝒘𝒂𝒚,𝒃𝑸𝒃

where:

Epathway,b is the emissions attributable to the batch (b) in kilograms of CO2-e, worked out in accordance with section 64.

Qb has the meaning given by subsection (6).

(6)In this section:

Qb is the amount of product in the batch (b) in gigajoules worked out in accordance with section 59.

Qpathway,b is the amount of product produced for the batch (b) in gigajoules measured:

(a)after the minimum production module has been completed, but before the intermediate storage tank production module has commenced, in relation to the product; and

(b)in accordance with section 9.

69 Delivered emissions intensity—methane #

The emissions intensity for the production and storage or transport for one or more functional units of a batch (b) of methane (the transported quantity), EIdel,product, in kilograms of CO2-e per gigajoule is worked out using the following formula:

𝑬𝑰𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕=𝑬𝑰𝒃×𝑸𝒃,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕𝒆𝒅+𝑬𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕𝑸𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕

where:

EIb is the emissions intensity for the production of the batch of methane, worked out in accordance with section 68.

Qb,transported is the amount of methane in the transported quantity in gigajoules:

(a)measured at the production gate for the product at the facility; and

(b)monitored or measured in accordance with section 9.

Edel,product is the post-production emissions for the transported quantity worked out in accordance with section 65.

Qdel,product is the amount of product in the transported quantity that reached the delivery gate worked out in accordance with Division 5.2.2 of Part 5.2.

Note: The production and post-production emissions intensity for the batch must be included on the PGO certificate in accordance with the rules.

70 Post-production emissions intensity—methane #

The emissions intensity for the storage or transport of one or more functional units of a batch (b) of methane (the transported quantity), EIpostprod,product, in kilograms of CO2-e per gigajoules of methane, is worked out using the following formula:

𝑬𝑰𝒑𝒐𝒔𝒕𝒑𝒓𝒐𝒅,𝒑𝒓𝒐𝒅𝒖𝒄𝒕=𝑬𝑰𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕−𝑬𝑰𝒃

where:

EIdel,product is the delivered emissions intensity for the transported quantity worked out in accordance with section 69.

EIb is the production emissions intensity for the batch (b) worked out in accordance with section 68.

Note: The production and post-production emissions intensity for the batch must be included on the PGO certificate in accordance with the rules.

Part 5.2 · Delivery of methane

71 Delivery modules #

(1)Each of the following methods for storing or transporting methane is a delivery module for methane:

(a)the pipeline delivery module;

(b)the vehicle delivery module;

(c)the storage vessel delivery module.

(2)The following are sources of emissions relating to the delivery modules mentioned in subsection (1):

(a)for the pipeline delivery module—post-production fugitive emissions and pipeline emissions;

(b)for the vehicle delivery module—post-production fugitive emissions and vehicle emissions;

(c)for the storage vessel delivery module—post-production fugitive emissions and storage vessel emissions.

Note: Pursuant to subsection 29(7) of the Act, a source of emissions relating to a delivery module for a product is a post-production emissions source for the delivery module.

(3)The sources of emissions for a delivery module mentioned in subsection (2) must be determined in accordance with the following:

(a)for pipeline emissions—section 20;

(b)for vehicle emissions—section 21;

(c)for storage vessel emissions—section 22;

(d)for post-production fugitive emissions—section 77.

72 Amount of methane that reaches the delivery gate or end of delivery module #

Amount that reaches the delivery gate

(1)Where a delivery module is the final delivery module for methane, the amount of methane that reaches the delivery gate is worked out as follows:

(a)for the pipeline delivery module:

(i)if the pipeline is a single access pipeline—in accordance with section 73; or

(ii)in any other case—in accordance with section 75;

(b)for the vehicle delivery module—in accordance with either section 74 or section 75;

(c)for the storage vessel delivery module—in accordance with section 75.

(2)Where no delivery module is required to convey the methane from the production gate to a delivery gate, the amount of methane that reaches the delivery gate is worked out in accordance with section 76.

Example: The holder of a production profile for methane has a connection directly from their production gate to a shared network pipeline. Methane that reaches the production gate effectively reaches the delivery gate at the same time and does not require the use of a delivery module.

Amount that reaches the end of the delivery module

(3)Where the delivery module is an interim delivery module for the methane, the amount of methane that reaches the end of the delivery module is worked out in accordance with the following provisions where a reference in the provision to delivery gate is taken to be a reference to end of the delivery module:

(a)for the pipeline delivery module:

(i)if the pipeline is a single access pipeline—in accordance with section 73; or

(ii)in any other case—in accordance with section 75;

(b)for the vehicle delivery module—in accordance with either section 74 or section 75;

(c)for the storage vessel delivery module—in accordance with section 75.

(4)In this section:

single access pipeline, for the pipeline delivery module, means a pipeline that:

(a)is a dedicated pipeline for methane; and

(b)has a single input point for the methane; and

(c)has a single delivery gate for the methane.

73 Single-access pipeline delivered amount #

Where one or more functional units of a batch of methane (the transported quantity) are transported in accordance with the pipeline delivery module, the amount of methane that reaches the delivery gate is the amount measured:

(a)at the closest practicable point to the delivery gate; and

(b)over a length of time equal to the time taken to inject the transported quantity into the delivery module; and

(c)in accordance with section 9.

74 Vehicle transport delivered amount #

(1)Where one or more functional units of a batch of methane (the transported quantity) are transported in accordance with the vehicle delivery module for methane, the amount of methane that reaches the delivery gate is the amount measured:

(a)at the closest practicable point to the delivery gate; and

(b)in accordance with section 9.

(2)The amount of methane measured under subsection (1) does not include an amount of the transported quantity that is returned to the holder of the delivery profile or the holder of the production profile.

75 Module-specific loss method delivered amount #

(1)Where one or more functional units of a batch of methane (the transported quantity) are stored or transported in accordance with a delivery module (the relevant delivery module), the amount of methane that reaches the delivery gate, Qdel,product, in gigajoules, is worked out using the following formula:

𝑸𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕=𝑸𝒃,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕𝒆𝒅×𝟏−𝑳𝑹𝒎−𝑸𝒔𝒆𝒍𝒇,𝒑𝒓𝒐𝒅𝒖𝒄𝒕

where:

Qb,transported is the amount of product in the transported quantity (q) in gigajoules, measured:

(a)if the product enters the relevant delivery module immediately after the production pathway has been completed—in accordance with section 59; or

(b)in any other case—in accordance with the method or formula specified in subsection 72(3) for working out the amount of the product that reaches the end of the delivery module immediately prior to the relevant delivery module.

LRm is:

(a)if the relevant delivery module (m) is the storage vessel delivery module and the vessel is a large methane storage vessel—worked out in accordance with subsection (4); or

(b)if the relevant delivery module (m) is the pipeline delivery module—either:

(i)worked out in accordance with subsection (2); or

(ii)0.02; or

(c)in any other case—worked out in accordance with subsection (2) or subsection (4).

Note: LRm represents the loss rate for the delivery module (m).

Qself,product is the amount of product in the transported quantity (q) consumed by the holder of the delivery profile for the purposes of the relevant delivery module (m) in gigajoules, monitored or measured in accordance with section 9.

Note: Qself,product represents the amount of product in the transported quantity that is consumed as an energy source for the delivery module and therefore does not reach the delivery gate.

m is the relevant delivery module used to store or transport the transported quantity (q).

(2)For the purposes of subparagraph (b)(i) and paragraph (c) of the definition of LRm in subsection (1), the loss rate for the relevant delivery module, LRm, is either:

(a)if the amount worked out in accordance with subsection (3) is greater than or equal to zero—that number; or

(b)in any other case—zero.

(3)For the purposes of subsection (2), LRm is worked out using the following formula:

𝑳𝑹𝒎=𝑸𝒊𝒏,𝒎,𝒚−𝑸𝒐𝒖𝒕,𝒎,𝒚𝑸𝒊𝒏,𝒎,𝒚

where:

Qin,m,y is the total amount of product put into the equipment used to store or transport the product in accordance with the relevant delivery module (m) for the year (y) in gigajoules, monitored or measured in accordance with section 9.

Qout,m,y is the total amount of product taken out of the equipment used to store or transport the product in accordance with the relevant delivery module (m) for the year (y) in gigajoules, monitored or measured in accordance with section 9.

Note: Qout,m,y includes any amount of product taken out by the holder of the delivery profile.

y is the financial year immediately prior to the financial year in which the batch period started.

Note: Section 14, which provides for an alternative definition of y where the holder of the delivery profile has an incomplete data set, applies to this subsection.

(4)For the purposes of paragraphs (a) and (c) of the definition of LRm in subsection (1), LRm, is worked out using the following formula:

𝑳𝑹𝒎=𝑸𝒊𝒏,𝒎,𝒚+𝑸𝒎,𝒔𝒕𝒂𝒓𝒕,𝒚−𝑸𝒐𝒖𝒕,𝒎,𝒚+𝑸𝒎,𝒆𝒏𝒅,𝒚𝑸𝒊𝒏,𝒎,𝒚

where:

Qm,start,y is the total amount of product in the equipment used to store or transport the product in accordance with the relevant delivery module (m) at the start of the year (y) in gigajoules, monitored or measured in accordance with section 9.

Qm,end,y is the total amount of product in the equipment used to store or transport the product in accordance with the relevant delivery module (m) at the end of the year (y) in gigajoules, monitored or measured in accordance with section 9.

Note: Qout,m,y includes any amount of product taken out by the holder of the delivery profile.

y is the financial year immediately prior to the financial year in which the batch period started.

Note: Section 14, which provides for an alternative definition of y where the holder of the delivery profile has an incomplete data set, applies to this subsection.

(5)In this section:

large methane storage vessel means a vessel for storing methane that has a storage capacity greater than 1,000 kilograms.

76 Direct delivery delivered amount #

Where one or more functional units of a batch of methane reach a delivery gate (the transported quantity) without being stored or transported in accordance with a delivery module, the amount of methane that reaches the delivery gate is the same as the amount of methane that reaches the production gate, monitored or measured in accordance with section 9.

77 Post-production fugitive emissions—methane #

(1)The emissions for the amount of product in the transported quantity that reached the delivery gate, Efug,del, in kilograms of CO2-e are calculated using the following formula:

𝑬𝒇𝒖𝒈,𝒅𝒆𝒍=𝑸𝒍𝒐𝒔𝒕,𝒑𝒓𝒐𝒅𝒖𝒄𝒕×𝑭𝒅𝒆𝒍×𝑮𝑾𝑷𝒎𝒆𝒕𝒉𝒂𝒏𝒆

where:

Qlost,product is the quantity of product lost from the delivery module, calculated in accordance with subsection (2), in gigajoules.

Fdel is a conversion factor equal to 18.01 kilograms per gigajoule.

GWPmethane is the Global Warming Potential of methane.

(2)For the purposes of subsection (1), Qlost,product is worked out using the following formula:

𝑸𝒍𝒐𝒔𝒕,𝒑𝒓𝒐𝒅𝒖𝒄𝒕=𝑸𝒃,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕𝒆𝒅−𝑸𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕−𝑸𝒔𝒆𝒍𝒇,𝒑𝒓𝒐𝒅𝒖𝒄𝒕

where:

Qb,transported is the amount of product in the transported quantity in gigajoules, measured in accordance with:

(a)if the product enters the relevant delivery module immediately after the production pathway has been completed—section 59; or

(b)in any other case—the method or formula specified in subsection 72(3) for working out the amount of the product that reaches the end of the delivery module immediately prior to the relevant delivery module.

Qdel,product is the amount of product in the transported quantity that reached the end of the delivery module in gigajoules, worked out in accordance with this Division.

Qself,product is the amount of product in the transported quantity consumed by the holder of the delivery profile for the purposes of the relevant delivery module in gigajoules, monitored or measured in accordance with section 9.

Chapter 6—Iron ore production pathway

78 Iron ore functional unit #

The functional unit of iron ore is 1 dry metric tonne of iron ore.

79 Iron ore batch size #

(1)For the purposes of subparagraph 29(4)(d)(i) of the Act, the amount of iron ore in a batch produced in accordance with the iron ore production pathway is the amount measured at the production gate for the product at the facility in dry metric tonnes.

(2)For the purposes of subsection (1), the amount of iron ore in a batch must be monitored or measured in accordance with section 9.

80 Iron ore production pathway #

(1)The iron ore production pathway is a production pathway for iron ore.

(2)Subject to subsection (4), the iron ore production module is the process of extracting iron ore from the earth by mining (the mining process).

(3)Without limiting subsection (2), the iron ore production module includes any of the following processes:

(a)preparing the ground for excavation, including by removing overburden;

(b)dewatering;

(c)breaking up the iron ore and waste rock;

(d)transporting the iron ore or any other materials for the purposes of the mining process;

(e)blending the iron ore with externally sourced iron ore.

(4)The iron ore production module only includes steps or processes undertaken to prepare the ground for excavation where those steps or processes occur immediately prior to, or during, excavation.

(5)The iron ore production module is a minimum module for the iron ore production pathway.

(6)The following are sources of emissions for the iron ore production pathway:

(a)electricity supply and use for the pathway;

(b)fuel supply and combustion for the pathway;

(c)feedstock supply for the pathway;

(d)water supply for the pathway;

(e)synthetic gas use for the pathway;

(f)explosives supply for the pathway.

Note: Pursuant to subsection 29(6) of the Act, a source of emissions relating to a production pathway for a product is a production emissions source for the production pathway.

(7)If a source of emissions mentioned in subsection (6) exists for the iron ore production pathway, the emissions from that source must be determined in accordance with the following:

(a)for electricity supply and use—section 15;

(b)for fuel supply and combustion—section 16;

(c)for feedstock supply—section 16A;

(d)for water supply—section 17;

(e)for synthetic gas use—section 19;

(f)for explosives supply—section 83.

Note: For the iron ore production pathway, section 16A only applies to externally sourced iron ore: see the definition of feedstock in subsection 16A(2).

81 Optional modules—processing #

(1)Subject to subsection (3), the iron ore processing module is the process of physically transforming and improving the quality of the iron ore so that the product is ready to be delivered or consumed.

(2)Without limiting subsection (1), the iron ore processing module includes any of the following processes:

(a)blending externally sourced iron ore with the product;

(b)transporting the iron ore for the purposes of processing the iron ore, including transporting the ore:

(i)to a location where the ore is processed; and

(ii)to the production gate;

(c)treating water for the purposes of processing the iron ore.

(3)The iron ore processing module does not include sintering or pelletising.

(4)The iron ore processing module is an optional module for the iron ore production pathway.

Note: An optional module is a production module that forms part of the production pathway. All sources of emissions for the iron ore production pathway, including for optional modules for that production pathway, are specified in subsection 80(6).

82 Iron ore production emissions #

The emissions for the production of a batch (b) of iron ore, Epathway,b, in kilograms of CO2-e, are the sum of the emissions for the batch from all sources of emissions for the iron ore production pathway.

Note: An optional module is a production module that forms part of the production pathway. If the production pathway for the iron ore includes the iron ore processing module, the production emissions include the emissions for the batch from all sources of emissions for that module specified in subsection 80(6).

83 Explosives supply #

The emissions from explosives supplied for the production pathway for the batch (b), Eexplosive,b, in kilograms of CO2-e, are worked out using the following formula:

𝑬𝒆𝒙𝒑𝒍𝒐𝒔𝒊𝒗𝒆,𝒃=𝑸𝑨𝑵,𝒃×𝑬𝑭𝑨𝑵

where:

QAN,b is the quantity of ammonium nitrate, in kilograms, used in explosives used for the production pathway for the batch (b), measured in accordance with section 9.

EFAN, the scope 3 emission factor for ammonium nitrate used in explosives in kilograms of CO2-e per kilogram of ammonium nitrate, is 1.87.

84 Iron ore post-production emissions #

The post-production emissions for the transport or storage of one or more functional units of a batch (b) of iron ore in accordance with one or more delivery modules (the transported quantity), Edel,transported, are the sum of the emissions from all sources of post-production emissions for the delivery modules for the transported quantity in kilograms of CO2-e.

85 Overland conveyer delivery module—overland conveyer emissions #

(1) The emissions for the transport of one or more functional units of a batch of iron ore (the transported quantity) in accordance with the overland conveyer delivery module, Econvey,transported, in kilograms of CO2-e, are worked out using either:

(a) the direct reporting method in subsection (2); or

(b) the overland conveyer emission factor method in subsection (3).

Direct reporting method

(2) For the purposes of paragraph (1)(a), Econvey,transported is worked out using the following formula:

𝑬𝒄𝒐𝒏𝒗𝒆𝒚,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕𝒆𝒅=𝑬𝒄𝒐𝒏𝒗𝒆𝒚,𝒆𝒍𝒆𝒄,𝒕+𝑬𝒄𝒐𝒏𝒗𝒆𝒚,𝒇𝒖𝒆𝒍,𝒕

where:

Econvey,elec,t is the emissions for the electricity supplied for the overland conveyer delivery module for the time period (t), in kilograms of CO2-e, worked out in accordance with section 15, subject to the following:

(a) a reference in section 15:

(i) to production pathway is taken to be a reference to overland conveyer delivery module; and

(ii) to batch (b) is taken to be a reference to time period (t);

(iii) to production profile is taken to be a reference to delivery profile; and

(b) the value of the parameter Qelec,ex,b in subsection 15(2) is taken to be zero;

Econvey,fuel,t is the emissions from the fuel used for the overland conveyer delivery module for the time period (t), in kilograms of CO2-e, worked out in accordance with section 16 where a reference in that provision:

(a) to production pathway is taken to be a reference to overland conveyer delivery module; and

(b) to batch (b) is taken to be a reference to time period (t).

t is the time period during which the transported quantity (q) is loaded, transported, unloaded and processed for the purposes of the overland conveyer delivery module.

Overland conveyer emission factor method

(3) For the purposes of paragraph (1)(b), Econvey,transported is worked out using the following formula:

𝑬𝒄𝒐𝒏𝒗𝒆𝒚,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕𝒆𝒅=𝑸𝒄𝒐𝒏𝒗𝒆𝒚,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕𝒆𝒅×𝑬𝑭𝒄𝒐𝒏𝒗𝒆𝒚,𝒚

where:

Qconvey,transported is:

(a) if the iron ore enters the overland conveyer delivery module immediately after the production pathway has been completed—the amount of iron ore in the transported quantity, in dry metric tonnes, measured at the production gate for the product in accordance with section 9; or

(b) in any other case—the amount of iron ore in the transported quantity, in dry metric tonnes, that reaches the end of the delivery module immediately prior to the overland conveyer delivery module worked out in accordance with subsection 91(3).

EFconvey,y is the overland conveyer-specific emission factor for the year (y), in kilograms of CO2-e per dry metric tonne of iron ore, worked out in accordance with subsection (4).

y is the financial year immediately prior to the financial year in which the batch period started.

(4) For the purposes of subsection (3), EFconvey,y is worked out using the following formula:

𝑬𝑭𝒄𝒐𝒏𝒗𝒆𝒚,𝒚=𝑬𝒄𝒐𝒏𝒗𝒆𝒚,𝒚𝑸𝒄𝒐𝒏𝒗𝒆𝒚,𝒚

where:

Econvey,y is the emissions for the transport of iron ore by the overland conveyer for the year (y), in kilograms of CO2-e, worked out in accordance with subsection (5).

Qconvey,y is the total amount of iron ore transported by the overland conveyer in accordance with the overland conveyer delivery module for the year (y), in dry metric tonnes, monitored or measured in accordance with section 9.

y is the financial year immediately prior to the financial year in which the batch period started.

Note: Section 14, which provides for an alternative definition of y where the holder of the delivery profile has an incomplete data set, applies to this subsection.

(5) For the purposes of subsection (4), Econvey,y is worked out using the following formula:

𝑬𝒄𝒐𝒏𝒗𝒆𝒚,𝒚=𝑬𝒄𝒐𝒏𝒗𝒆𝒚,𝒆𝒍𝒆𝒄,𝒚+𝑬𝒄𝒐𝒏𝒗𝒆𝒚,𝒇𝒖𝒆𝒍,𝒚

where:

Econvey,elec,y is the emissions for the electricity supplied for the overland conveyer delivery module for the year (y), in kilograms of CO2-e, worked out in accordance with section 15, subject to the following:

(a) a reference in section 15:

(i) to production pathway is taken to be a reference to overland conveyer delivery module; and

(ii) to batch (b) is taken to be a reference to year (y); and

(iii) to production profile is taken to be a reference to delivery profile;

(b) the value of the parameter Qelec,ex,b in subsection 15(2) is taken to be zero; and

Econvey,fuel,y is the emissions from the fuel used for the overland conveyer delivery module for the year (y), in kilograms of CO2-e, worked out in accordance with section 16 where a reference in that provision:

(a) to production pathway is taken to be a reference to overland conveyer delivery module; and

(b) to batch (b) is taken to be a reference to year (y).

y is the financial year immediately prior to the financial year in which the batch period started.

Note: Section 14, which provides for an alternative definition of y where the holder of the delivery profile has an incomplete data set, applies to this subsection.

(6) In this section:

overland conveyer delivery module: see paragraph 90(1)(b).

86 Slurry pipeline delivery module—slurry pipeline emissions #

(1) The emissions for the transport of one or more functional units of a batch of iron ore (the transported quantity) in accordance with the slurry pipeline delivery module, Espipe,transported, in kilograms of CO2-e, are worked out using either:

(a) the direct reporting method in subsection (2); or

(b) the slurry pipeline emission factor method in subsection (3).

Direct reporting method

(2) For the purposes of paragraph (1)(a), Espipe,transported is worked out using the following formula:

𝑬𝒔𝒑𝒊𝒑𝒆,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕𝒆𝒅=𝑬𝒔𝒑𝒊𝒑𝒆,𝒆𝒍𝒆𝒄,𝒕+𝑬𝒔𝒑𝒊𝒑𝒆,𝒇𝒖𝒆𝒍,𝒕+𝑬𝒔𝒑𝒊𝒑𝒆,𝒘𝒂𝒕𝒆𝒓,𝒕

where:

Espipe,elec,t is the emissions for the electricity supplied for the slurry pipeline delivery module for the time period (t), in kilograms of CO2-e, worked out in accordance with section 15, subject to the following:

(a) a reference in section 15:

(i) to production pathway is taken to be a reference to slurry pipeline delivery module; and

(ii) to batch (b) is taken to be a reference to time period (t); and

(iii) to production profile is taken to be a reference to delivery profile;

(b) the value of the parameter Qelec,ex,b in subsection 15(2) is taken to be zero; and

Espipe,fuel,t is the emissions from the fuel used for the slurry pipeline delivery module for the time period (t), in kilograms of CO2-e, worked out in accordance with section 16 where a reference in that provision:

(a) to production pathway is taken to be a reference to slurry pipeline delivery module; and

(b) to batch (b) is taken to be a reference to time period (t).

Espipe,water,t is the emissions from the water used for the slurry pipeline delivery module for the time period (t), in kilograms of CO2-e, worked out in accordance with section 17 where a reference in that provision:

(a) to production pathway is taken to be a reference to slurry pipeline delivery module; and

(b) to batch (b) is taken to be a reference to time period (t).

t is the time period during which the transported quantity (q) is loaded, transported, unloaded and processed for the purposes of the slurry pipeline delivery module.

Slurry pipeline emission factor method

(3) For the purposes of paragraph (1)(b), Espipe,transported is worked out using the following formula:

𝑬𝒔𝒑𝒊𝒑𝒆,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕𝒆𝒅=𝑸𝒔𝒑𝒊𝒑𝒆,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕𝒆𝒅×𝑬𝑭𝒔𝒑𝒊𝒑𝒆,𝒚

where:

Qspipe,transported is:

(a) if the iron ore enters the slurry pipeline delivery module immediately after the production pathway has been completed—the amount of iron ore in the transported quantity, in dry metric tonnes, measured at the production gate for the product in accordance with section 9; or

(b) in any other case—the amount of iron ore in the transported quantity, in dry metric tonnes, that reaches the end of the delivery module immediately prior to the slurry pipeline delivery module worked out in accordance with subsection 91(3).

EFspipe,y is the slurry pipeline-specific emission factor for the year (y), in kilograms of CO2-e per dry metric tonne of iron ore, worked out in accordance with subsection (4).

y is the financial year immediately prior to the financial year in which the batch period started.

(4) For the purposes of subsection (3), EFspipe,y is worked out using the following formula:

𝑬𝑭𝒔𝒑𝒊𝒑𝒆,𝒚=𝑬𝒔𝒑𝒊𝒑𝒆,𝒚𝑸𝒔𝒑𝒊𝒑𝒆,𝒚

where:

Espipe,y is the emissions for transport of iron ore by the slurry pipeline for the year (y), in kilograms of CO2-e, worked out in accordance with subsection (5).

Qspipe,y is the total amount of iron ore transported by the slurry pipeline in accordance with the slurry pipeline delivery module for the year (y), in dry metric tonnes, monitored or measured in accordance with section 9.

y is the financial year immediately prior to the financial year in which the batch period started.

Note: Section 14, which provides for an alternative definition of y where the holder of the delivery profile has an incomplete data set, applies to this subsection.

(5) For the purposes of subsection (4), Espipe,y is worked out using the following formula:

𝑬𝒔𝒑𝒊𝒑𝒆,𝒚=𝑬𝒔𝒑𝒊𝒑𝒆,𝒆𝒍𝒆𝒄,𝒚+𝑬𝒔𝒑𝒊𝒑𝒆,𝒇𝒖𝒆𝒍,𝒚+𝑬𝒔𝒑𝒊𝒑𝒆,𝒘𝒂𝒕𝒆𝒓,𝒚

where:

Espipe,elec,y is the emissions for the electricity supplied for the slurry pipeline delivery module for the year (y), in kilograms of CO2-e, worked out in accordance with section 15, subject to the following:

(a) a reference in section 15:

(i) to production pathway is taken to be a reference to slurry pipeline delivery module; and

(ii) to batch (b) is taken to be a reference to year (y); and

(iii) to production profile is taken to be a reference to delivery profile;

(b) the value of the parameter Qelec,ex,b in subsection 15(2) is taken to be zero;

Espipe,fuel,y is the emissions from the fuel used for the slurry pipeline delivery module for the year (y), in kilograms of CO2-e, worked out in accordance with section 16 where a reference in that provision:

(a) to production pathway is taken to be a reference to slurry pipeline delivery module; and

(b) to batch (b) is taken to be a reference to year (y).

Espipe,water,y is the emissions from the water used for the slurry pipeline delivery module for the year (y), in kilograms of CO2-e, worked out in accordance with section 17 where a reference in that provision:

(a) to production pathway is taken to be a reference to slurry pipeline delivery module; and

(b) to batch (b) is taken to be a reference to year (y).

y is the financial year immediately prior to the financial year in which the batch period started.

Note: Section 14, which provides for an alternative definition of y where the holder of the delivery profile has an incomplete data set, applies to this subsection.

(6) In this section:

slurry pipeline delivery module: see paragraph 90(1)(c).

87 Production emissions intensity—iron ore #

The emissions intensity for the production of a batch of iron ore, EIb, in kilograms of CO2-e per dry metric tonne of iron ore, is worked out using the following formula:

𝑬𝑰𝒃=𝑬𝒑𝒂𝒕𝒉𝒘𝒂𝒚,𝒃𝑸𝒃

where:

Epathway,b is the emissions for the production of the batch (b) of iron ore, in kilograms of CO2-e, worked out in accordance with section 82.

Qb is the amount of iron ore in the batch (b), in dry metric tonnes, worked out in accordance with section 79.

Note: The production emissions intensity for the batch must be included on the PGO certificate in accordance with the rules.

88 Delivered emissions intensity—iron ore #

The emissions intensity for the production and storage or transport for one or more functional units of a batch (b) of iron ore (the transported quantity), EIdel,product, in kilograms of CO2-e per dry metric tonne of iron ore, is worked out using the following formula:

where:

EIb is the emissions intensity for the production of the batch of iron ore, in kilograms of CO2-e per dry metric tonne of iron ore, worked out in accordance with section 87.

Qb,transported is the amount of iron ore in the transported quantity, in dry metric tonnes, measured at the production gate for the product in accordance with section 9.

Edel,product is the post-production emissions for the transported quantity, in kilograms of CO2-e, worked out in accordance with section 84.

Qdel,product is the amount of iron ore in the transported quantity, in dry metric tonnes, that reached the delivery gate worked out in accordance with Division 6.2.2.

Note: The production and post-production emissions intensity for the batch must be included on the PGO certificate in accordance with the rules.

89 Post-production emissions intensity—iron ore #

The emissions intensity for the storage or transport of one or more functional units of a batch (b) of iron ore (the transported quantity), EIpostprod,product, in kilograms of CO2-e per dry metric tonne of iron ore, is worked out using the following formula:

𝑬𝑰𝒑𝒐𝒔𝒕𝒑𝒓𝒐𝒅,𝒑𝒓𝒐𝒅𝒖𝒄𝒕=𝑬𝑰𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕−𝑬𝑰𝒃

where:

EIdel,product is the delivered emissions intensity for the transported quantity, in kilograms of CO2-e per dry metric tonne of iron ore, worked out in accordance with section 88.

EIb is the production emissions intensity for the batch, in kilograms of CO2-e per dry metric tonne of iron ore, worked out in accordance with section 87.

Note: The post-production emissions intensity for the transported quantity must be included on the PGO certificate in accordance with the rules.

90 Delivery modules #

(1)Each of the following methods for storing or transporting iron ore is a delivery module for iron ore:

(a)the vehicle delivery module for iron ore;

(b)transport by overland conveyer, including loading iron ore onto the conveyer, unloading it from the conveyer and processing the product for the purposes of transporting it (the overland conveyer delivery module);

(c)transport by slurry pipeline, including loading iron ore into the pipeline, unloading it from the pipeline, processing the product for the purposes of transporting it and returning and treating water used by the pipeline (the slurry pipeline delivery module).

(2)The following are sources of emissions relating to the delivery modules mentioned in subsection (1):

(a)for the vehicle delivery module—vehicle emissions;

(b)for the overland conveyer delivery module—overland conveyer emissions;

(c)for the slurry pipeline delivery module—slurry pipeline emissions.

Note: Pursuant to subsection 29(7) of the Act, a source of emissions relating to a delivery module for a product is a post-production emissions source for the delivery module.

(3)The sources of emissions for a delivery module mentioned in subsection (2) must be determined in accordance with the following:

(a)for vehicle emissions—section 21;

(b)for overland conveyer emissions—section 85;

(c)for slurry pipeline emissions—section 86.

91 Amount of iron ore that reaches the delivery gate or end of delivery module #

Amount that reaches the delivery gate

(1)Where a delivery module is the final delivery module for the iron ore, the amount of iron ore that reaches the delivery gate is worked out as follows:

(a)if the iron ore is blended with iron ore that is not part of the batch after the iron ore leaves the production gate but before it reaches the delivery gate—in accordance with section 93; or

(b)in any other case—in accordance with either section 92 or section 93.

(2)Where no delivery module is required to convey the iron ore from the production gate to a delivery gate, the amount of iron ore that reaches the delivery gate is worked out in accordance with section 94.

Example: The facility for an iron ore production pathway is located next to the facility that produces iron. Iron ore that reaches the production gate effectively reaches the delivery gate at the same time and does not require the use of a delivery module.

Amount that reaches the end of the delivery module

(3)Where the delivery module is an interim delivery module for the iron ore, the amount of iron ore that reaches the end of the delivery module is worked out in accordance with the following provisions where a reference in the provision to delivery gate is taken to be a reference to the end of the delivery module:

(a)if the iron ore is blended with iron ore that is not part of the batch after the iron ore leaves the production gate but before it reaches the end of the delivery module—in accordance with section 93;

(b)in any other case—in accordance with either section 92 or section 93.

92 Measured delivered amount—iron ore #

Where one or more functional units of a batch of iron ore (the transported quantity) are transported in accordance with a delivery module, the amount of iron ore that reaches the delivery gate is the amount measured in dry metric tonnes:

(a)at the closest practicable point to the delivery gate; and

(b)in accordance with section 9.

93 Module-specific loss method delivered amount—iron ore #

(1)Where one or more functional units of a batch of iron ore (the transported quantity) are transported in accordance with a delivery module (the relevant delivery module), the amount of iron ore that reaches the delivery gate, Qdel,product, in dry metric tonnes, is worked out using the following formula:

𝑸𝒅𝒆𝒍,𝒑𝒓𝒐𝒅𝒖𝒄𝒕=𝑸𝒃,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕𝒆𝒅×𝟏−𝑳𝑹𝒎

where:

Qb,transported is the amount of iron ore in the transported quantity (q), in dry metric tonnes, measured as:

(a)if the iron ore enters the relevant delivery module immediately after the production pathway has been completed—the amount of iron ore in the transported quantity, in dry metric tonnes, measured at the production gate for the product in accordance with section 9; or

(b) in any other case—the amount of iron ore in the transported quantity, in dry metric tonnes, that reaches the end of the delivery module immediately prior to the relevant delivery module worked out in accordance with subsection 91(3).

LRm, the loss rate for the relevant delivery module (m), is either:

(a)if the amount worked out in accordance with subsection (2) is greater than or equal to zero—that number; or

(b)in any other case—zero.

m is the relevant delivery module used to transport the transported quantity (q).

(2)For the purposes of subsection (1), LRm is worked out using the following formula:

𝑳𝑹𝒎=𝑸𝒊𝒏,𝒎,𝒚−𝑸𝒐𝒖𝒕,𝒎,𝒚𝑸𝒊𝒏,𝒎,𝒚

where:

Qin,m,y is the total amount of iron ore in dry metric tonnes put into the equipment used to transport the product in accordance with the relevant delivery module (m) for the year (y), monitored or measured in accordance with section 9.

Qout,m,y is the total amount of iron ore in dry metric tonnes taken out of the equipment used to transport the product in accordance with the relevant delivery module (m) for the year (y), monitored or measured in accordance with section 9.

Note: Qout,m,y includes any amount of iron ore taken out by the holder of the delivery profile.

y is the financial year immediately prior to the financial year in which the batch period started.

Note: Section 14, which provides for an alternative definition of y where the holder of the delivery profile has an incomplete data set, applies to this subsection.

94 Direct delivery delivered amount—iron ore #

Where one or more functional units of a batch of iron ore (the transported quantity) reach the delivery gate without being transported in accordance with a delivery module, the amount of iron ore that reaches the delivery gate is the same as the amount of iron ore that reaches the production gate, monitored or measured in accordance with section 9.

77 Part 1 of Schedule 1 (table item 4)

Repeal the item, substitute:

Potable water from New South Wales

0.000385

78 Part 1 of Schedule 1 (table items 6 to 11)

Repeal the items, substitute:

6	Potable water from South Australia	0.000241
7	Potable water from Tasmania	0.000227
8	Potable water from the Australian Capital Territory	0.000433
9	Potable water from the Northern Territory	0.000529
10	Potable water from Victoria	0.000252
11	Potable water from Western Australia	0.000627

79 Parts 4 to 7 of Schedule 1

Repeal the Parts, substitute:

Part 4—Scope 3 emission factors for alloying metals

Note: See section 19B.

Column 1	Column 2	Column 3
Item	Type of alloying metal	Emission factor for alloying metal in kg of CO2-e per kg of metal
1	Magnesium	21.8
2	Silicon	12.1
3	Manganese	9.5
4	Copper	4.1
5	Zinc	3.8
6	Iron	2.2

Part 5—Emission factors for pipeline transport

Note: See section 12.

Column 1	Column 2	Column 3
Item	Type of gaseous feedstock or fuel	Emission factor in kg CO2-e per GJ-km
1	Biogas	0.005111

Part 6—Production scope 3 emission factors for feedstocks measured in kilograms

Note: See section 12.

Column 1	Column 2	Column 3	Column 4
Item	Feedstock or fuel type	Emission factor in kg CO2-e per kg	Biogenic carbon content (%)
1	Iron ore – magnetite ore	0.0768	n/a
2	Iron ore – non-magnetite ore	0.0169	n/a
3	Pre-consumer aluminium scrap	0	n/a
4	Post-consumer aluminium scrap	0.52	n/a
5	Bituminous coal	0.0810	0
6	Sub-bituminous coal	0.0525	0
7	Brown coal (lignite)	0.00408	0
8	Coking coal	0.192	0
9	Anthracite	Not estimated	0
10	Coal briquettes	Not estimated	0
11	Coal coke	Not estimated	0
12	Coal tar	Not estimated	0
13	A solid fossil fuel not specifically mentioned in this table	Not estimated	0
14	Recycled industrial material derived from fossil fuels	0	0
15	Recycled passenger car tyres	0	23.1
16	Recycled truck and off road tyres	0	31.5
17	Recycled non-biomass municipal materials	0	0
18	Mixed solid waste	0	Based on sampling
19	Sulphite lyes	0	100
20	Animal effluent (for example, dairy cows, beef cattle, pigs, poultry)	0	100
21	Sugarcane bagasse and tops and trash	0	100
22	Cereal crop straw or stover residues (for example, sorghum straw, wheat straw, rice straw, stalks and leaves)	0	100
23	Non-cereal crop residues (for example, pea straw, bean straw, cotton gin trash)	0	100
24	Winery residues (for example grape marc)	0	100
25	Spoiled silage	0	100
26	Plantation forestry residue (excluding any biomass from native forest)	0	100
27	Native forestry residue	0	100
28	Food processing biogenic waste (for example, peels, pulps, damaged produce)	0	100
29	Distillery and brewery wastes (for example, spent grains, used yeast, pot ale)	0	100
30	Source-separated biogenic municipal solid waste at kerb side collection	0	100
31	Source-separated biogenic commercial or industrial waste at business collection	0	100
32	Facility-separated biogenic municipal solid waste	0	100
33	Facility-separated biogenic commercial or industrial waste	0	100
34	Domestic, commercial or industrial wastewater	0	100
35	A feedstock listed in items 24, 28, 29, 30, 31, 32 and 33 that have undergone primary size reduction	0.00304	100
36	A feedstock listed in items 24, 28, 29, 30, 31, 32 and 33 that have undergone secondary size reduction	0.0329	100
37	A feedstock listed in items 26 and 27 that have undergone primary size reduction	0.00518	100
38	A feedstock listed in items 26 and 27 that have undergone secondary size reduction	0.030	100
39	A feedstock listed in items 21, 22, 23 and 25 that have undergone primary size reduction	0.00969	100
40	A feedstock listed in items 21, 22, 23 and 25 that have undergone secondary size reduction	0.0314	100

Part 7—Scope 3 emission factors for liquid fuel consumption

Note: See section 12.

Column 1	Column 2	Column 3	Column 4
Item	Fuel type	Emission factor in kg CO2-e per GJ	Biogenic carbon content (%)
1	Petroleum based oils	18.0	0
2	Petroleum based greases	18.0	0
3	Automotive gasoline or petrol (other than for use as fuel in an aircraft)	17.2	0
4	Aviation gasoline	18.0	0
5	Kerosene (other than for use as fuel in an aircraft)	18.0	0
6	Aviation turbine fuel or kerosene	18.0	0
7	Heating oil	18.0	0
8	Diesel oil	17.3	0
9	Fuel oil	18.0	0
10	Liquefied aromatic hydrocarbons	18.0	0
11	Mineral turpentine or white spirits	18.0	0
12	Liquefied petroleum gas (LPG)	20.2	0
13	Naphtha	18.0	0
14	Petroleum coke	18.0	0
15	Refinery gas and liquids	18.0	0
16	Refinery coke	18.0	0
17	Crude oil & Refinery Stock	13.9	0
18	Petroleum based products other than those mentioned in the items above	18.0	0
19	Biogenic based products	Not estimated	100
20	Ethanol	Not estimated	0
21	Biodiesel	Not estimated	100
22	Renewable aviation kerosene	Not estimated	100
23	Renewable diesel	Not estimated	100

Part 8—Production scope 3 emission factors for gas consumption other than natural gas

Note: See section 12.

Column 1	Column 2	Column 3	Column 4
Item	Feedstock type	Emission factor in kg CO2-e per GJ	Biogenic carbon content (%)
1	Landfill gas at the point of creation	0.0	100
2	Landfill gas that has been collected and cleaned	15.52	100
3	Gas from a passive covered anaerobic lagoon at the point of creation	0.0	100
4	Gas from a passive covered anaerobic lagoon that has been collected and cleaned	15.52	100
5	Gas from an anaerobic digester fed only by waste and/or residue feedstock, powered by own biogas and with gastight digestate storage, prior to entering a gas transport system	17.08	100
6	Gas from an anaerobic digester fed only by waste and/or residue feedstock, powered by own biogas and with non-gastight digestate storage, prior to entering a gas transport system	36.15	100
7	Biomethane	Not estimated	100
8	Hydrogen	Not estimated	N/A

Part 9—Scope 3 emission factors for natural gas consumption

Note: See section 12.

Column 1	Column 2	Column 3	Column 4
Item	State or Territory	Emission factor in kg CO2-e per GJ—area connected to a distribution pipeline	Emission factor in kg CO2-e per GJ—area connected to a transmission pipeline
1	New South Wales	13.1	14
2	Victoria	4	4
3	Queensland	8.8	7.9
4	Western Australia	4.1	4
5	South Australia	10.7	10.6
6	Tasmania	4	4
7	Australian Capital Territory	13.1	14
8	Northern Territory	4.1	4

Part 10—Scope 3 emission factors for compressed or liquified natural gas consumption

Note: See section 12.

Column 1	Column 2	Column 3	Column 4
Item	Fuel combusted	Emission factor in kg CO2-e per GJ	Biogenic carbon content (%)
1	Compressed Natural Gas (CNG)	18	0
2	Liquefied Natural Gas (LNG)	18	0

80 At the end of the instrument

Add:

Note: See subparagraph 9(3)(a)(i).

Column 1	Column 2	Column 3
Item	Parameter	Provision
1	Qelec,market,b	Subsections 15(2) and 15(5)
2	Qelec,ex,y	Subsection 15(5)
3	Qelec,market,y	Subsection 15(5)
4	Qf,CHP,b	Subsection 16(3)
5	Qf,b	Subsections 16A(1), 16(2) and 19C(1)
6	Qcarb,c,b	Subsection 16B(1)
7	Qwater,x,b	Subsection 17(1)
8	Qsteam,x,b	Subsection 18(1)
9	QO2,is,b	Subsection 19A(1)
10	Qalloy,x,b	Section 19B
11	Qalumina,b,x	Section 46
12	Qcpc,b	Subsection 47(4)
13	Qpitch,b	Subsection 47(4)
14	Qanodes_sup,b	Section 48

Note: See paragraph 9(3)(b).

Column 1	Column 2	Column 3
Item	Parameter	Provision
1	Df	Subsection 12(3)
2	DJ	Subsection 21(5)
3	Dfleet,SJ	Subsection 21(6)

Schedule 1 · Amendments

1 Section 4

Insert:

alloying metal means magnesium, silicon, copper, iron, manganese or zinc.

aluminium production pathway: see subsection 42(1).

biogas has the same meaning as in the NGER Regulations.

biogas by anaerobic digestion production pathway: see subsection 60(1).

biomethane has the same meaning as in the NGER Regulations.

biomethane by biogas upgrading production pathway: see subsection 62(1).

CHP emission allocation method means any the following methods as set out in Section II of the CHP Tool:

(a) the efficiency method;

(b) the energy content method;

combustion, of a feedstock, includes oxidation of the feedstock.

compressed natural gas has the same meaning as in the NGER Regulations.

conditioning, a gas, includes the following:

(a) stripping impurities;

(b) drying;

(d) pumping;

(e) cooling.

dry metric tonne, of iron ore, means:

(a) if the iron ore does not contain moisture—a tonne of iron ore; or

(b) if the iron ore contains moisture—a tonne of iron ore adjusted so as to exclude the moisture by:

(i) measuring the amount of moisture in the iron ore as a percentage of the total volume of the iron ore, including moisture, in accordance with section 9; and

(ii) multiplying the total volume of the iron ore, including moisture, by 100% minus the percentage worked out under subparagraph (i).

Note: The total volume of the iron ore, including moisture, is commonly referred to as the amount in wet metric tonnes.

2 Section 4 (definition of electrolysis production pathway)

Repeal the definition.

3 Section 4

Insert:

externally sourced iron ore means iron ore that has been acquired from an input supplier.

feedstock pre-treatment production module is the process of pre-treating a feedstock.

4 Section 4 (definition of gas conditioning production module)

Repeal the definition, substitute:

gas conditioning production module is the process of conditioning a gas.

5 Section 4 (definition of gaseous fuel)

Repeal the definition, substitute:

gaseous fuel:

(a) has the same meaning as in the NGER Measurement Determination; and

(b) includes a feedstock that is a gaseous fuel as defined in that determination.

6 Section 4

Insert:

Global Warming Potential, for a kind of greenhouse gas, is the value specified as the Global Warming Potential for that greenhouse gas in the table in section 2.02 of the NGER Regulations.

hydrogen by electrolysis production pathway: see subsection 25(1).

7 Section 4 (definition of input)

Repeal the definition, substitute:

input includes:

(a) for a production pathway—anything used in the production of the product; and

(b) for a delivery module—anything used for:

(i) storing the product; or

(ii) transporting the product; or

(iii) both transporting and storing the product.

8 Section 4 (definition of intermediate storage tank production module)

Repeal the definition, substitute:

intermediate storage tank production module, for a product, is the process of storing the product in a vessel.

9 Section 4

Insert:

iron ore:

(a) means ore from which hematite, magnetite or any other type of mineral of iron oxide can be extracted; and

(b) includes any impurities contained in the ore.

iron ore production pathway: see subsection 80(1).

Leak Detection and Repair program or LDAR program means a system of procedures used at a facility to monitor, locate and repair leaking components in order to minimise emissions.

liquefied natural gas has the same meaning as in the NGER Regulations.

10 Section 4 (definition of liquid fuel)

Repeal the definition, substitute:

liquid fuel:

(a) has the same meaning as in the NGER Measurement Determination; and

(b) includes a feedstock that is a liquid fuel as defined in that determination.

11 Section 4

Insert:

NGAF means the document titled National Greenhouse Accounts Factors published by the Department as existing from time to time.

Note: The NGAF could in 2026 be viewed on the Department’s website (https://www.dcceew.gov.au).

NGER Method 2 sampling: see section 14A.

NGER Method 3 sampling: see section 14A.

NGER Regulations means the National Greenhouse and Energy Reporting Regulations 2008.

12 Section 4 (definition of pipeline delivery module)

Repeal the definition, substitute:

pipeline delivery module, for a product, means transporting the product by dedicated pipeline, including the injecting of the product into the pipeline.

13 Section 4

Insert:

post-consumer scrap aluminium means aluminium recovered from a product that has been used.

pre-consumer scrap aluminium:

(a) means aluminium diverted from the waste stream of a manufacturing process; but

(b) does not include material mentioned in paragraph (a) produced by the holder of the production profile.

pre-treatment, of a feedstock, is the process of preparing the feedstock for use and includes any of the following processes:

(a) crushing or milling;

(b) shredding;

(d) washing;

(e) drying;

(f) pelletising;

(g) pre-heating.

primary size reduction, of a feedstock, means reducing the size of a feedstock to produce coarse particles, including by use of any of the following techniques:

(a) shredding;

(b) chipping;

primary type of mineral iron oxide, in relation to iron ore, is the type of mineral iron oxide contained in the ore in the largest amount.

14 Section 4 (definition of production emissions intensity)

Repeal the definition, substitute:

production emissions intensity: see section 5.

15 Section 4

Insert:

secondary size reduction, of a feedstock, means reducing the size of a feedstock to produce fine particles, including by milling the feedstock.

16 Section 4 (definition of solid fuel)

Repeal the definition, substitute:

solid fuel:

(a) has the same meaning as in the NGER Measurement Determination; and

(b) includes a feedstock that is a solid fuel as defined in that determination.

17 Section 4 (definition of storage vessel delivery module)

Repeal the definition, substitute:

storage vessel delivery module, for a product, means storing the product in a storage vessel.

18 Section 4 (definition of vehicle delivery module)

Repeal the definition, substitute:

vehicle delivery module, for a product:

(a) means transporting the product by vehicle; and

(b) includes loading and unloading the product from the vehicle for the purposes of transporting it.

19 Section 5 (after table item 1)

Insert:

2	Aluminium	Section 51
3	Methane	Section 68
4	Iron ore	Section 87

20 Section 6 (after table item 1)

Insert:

2	Aluminium	Section 52
3	Methane	Section 69
4	Iron ore	Section 88

21 Section 7 (after table item 1)

Insert:

2	Aluminium	Section 53
3	Methane	Section 70
4	Iron ore	Section 89

22 Section 8 (table, item 1, column 4)

Omit “Electrolysis production pathway”, substitute “Hydrogen by electrolysis production pathway”.

23 Section 9

Repeal the section, substitute:

9 Monitoring and measuring requirements—general #

(1)A parameter is monitored or measured in accordance with this section if the parameter is monitored or measured using:

(a)the direct measurement method in subsection (2); or

(b)a method mentioned in subsection (3).

Direct measurement method

(2)For the purposes of paragraph (1)(a), the parameter must be monitored or measured:

(a)directly using calibrated measuring equipment; or

(b)by calculating the value of the parameter using one or more variables that are monitored or measured directly using calibrated measuring equipment.

Example: For the purposes of paragraph (b), calculating the mass of a gas in a storage tank by directly measuring the temperature and pressure of the gas using calibrated measuring equipment.

(3)For the purposes of paragraph (1)(b), a parameter may be monitored or measured in accordance with this section using:

(a)the invoice method in subsection (4) if the parameter is:

(i)mentioned in column 2 of an item in the table in Part 1 of Schedule 2; and

(ii)an input acquired because of a commercial transaction; or

(b)if the parameter is mentioned in column 2 of an item in the table in Part 2 of Schedule 2—the mapping tool method in subsection (5).

Invoice method

(4)For the purposes of paragraph (3)(a), the parameter must be:

(a)evidenced by invoices issued by the vendor of the input to which the parameter relates (supplier invoices); or

(b)if the parameter cannot be accounted for using supplier invoices—monitored or measured using a combination of:

(i)evidence provided by supplier invoices; and

(ii)direct measurement using the method in subsection (2) of related variables to enable the accurate calculation of the part not accounted for using supplier invoices.

Example: The parameter Qwater,x,b in subsection 17(1) is the quantity of water used for a production pathway. If the water has been acquired because of a commercial transaction, subsection (4) provides that the quantity may be evidenced using invoices issued by the vendor of the water. If a small part of the invoiced amount has not been used for the production pathway for the batch, paragraph (4)(b) provides that the amount of unused water may be directly measured using calibrated measuring equipment and then deducted from the invoiced amount to calculate the amount of water used for the batch. Measuring the smaller portion of water allowed the use of a flow meter that caters to low flows rather than large flows.

Mapping tool method

(5)For the purposes of paragraph (3)(b), a distance required to be monitored or measured for the purposes of the parameter must be estimated using a tool designed to estimate the distance of a route taken by a vehicle between 2 or more places.

Example: The National Key Freight Routes Map application published by the Department of Infrastructure, Transport, Regional Development, Communication, Sport and the Arts may be used to estimate the distance of key road and rail routes within Australia.

Note: The National Key Freight Routes Map could in 2026 be viewed on the Department of Infrastructure, Transport, Regional Development, Communication, Sport and the Arts’ website (https://www.infrastructure.gov.au/).

(6)In this section:

calibrated measuring equipment means monitoring or measuring equipment calibrated:

(a)to monitor or measure one or more physical properties in accordance with:

(i)a measurement requirement provided for under the National Measurement Act 1960, or any instrument made under that Act, for that equipment; or

(ii)a measurement requirement under an equivalent standard for that physical property (however described); and

(b)if the monitoring or measuring equipment cannot be calibrated in accordance with paragraph (a)—by an accredited technician at intervals, and using methods, that are in accordance with the manufacturer’s specifications.

Examples: In subparagraph (a)(ii), physical properties include weight, length, mass, temperature, pressure and volume.

9A General principles for formulas and methods #

(1)This section applies if:

(a)this instrument provides alternative methods or formulas for a person to comply with a requirement; and

(b)it is reasonably practicable for the person to use more than one of the methods or formulas.

Example: To determine the emissions associated with the use of a gas the person has purchased from an input supplier, the person has a choice of calculating the volume of gas by direct measurement or by invoice method. The person suspects that the information provided in the invoice is inaccurate and already has calibrated measuring equipment capable of directly measuring the volume of gas for the purposes of calculating emissions.

(2)The person must use the formula or method, the use of which would best apply the following principles:

(a)transparency—information used to work out the formula or method is documented and verifiable;

(b)comparability—the formula or method is one that:

(i)would be performed by persons in corresponding, or substantially corresponding industries; and

(ii)best conforms to what is commonly accepted as standard for the production pathway, including Australian Standards, or international standards;

(c)integrity—information used to work out the formula or method is credible and traceable, including where that information has been obtained from another person;

(d)accuracy—the formula or method is worked out in a way that minimises uncertainties by employing accurate methods that comply with the latest available scientific evidence.

24 Subsection 10(2) (example)

Omit “subsection 15(5)”, substitute “subsection 15(4)”.

25 Section 11

Omit “EFij” (wherever occurring), substitute “EFfj”.

26 Section 11

Omit “feedstock or” (wherever occurring).

27 Section 11

Omit “for stationary energy purposes” (wherever occurring).

28 Subsection 11(1), (table, item 4, column 2)

Omit “, for stationary energy purposes”.

29 Subsection 11(2)

Omit “relevant feedstock or fuel”, substitute “relevant fuel”.

30 Subsection 11(2) (example)

Omit “subsection 16(2)”, substitute “subsection 16(5)”.

31 Subsection 11(2) (example)

Omit “for a stationary energy purpose” (wherever occurring).

32 Subsection 11(3) (example)

Omit “or feedstock”.

33 Subsection 11(3) (note)

Omit “and feedstocks”.

34 Section 12

Repeal the section, substitute:

12 Scope 3 emission factors #

Determining the scope 3 emission factor

(1)For the purposes of the parameter EFscope 3,f, the scope 3 emission factor for the consumption of a feedstock or fuel (f) is:

(a)if there is a registered PGO certificate in respect of the feedstock or fuel—the delivered emissions intensity on the PGO certificate; or

(b)in any other case—one of the following:

(i)for the consumption of a liquid fuel—the emission factor mentioned in column 3 of an item in the table in Part 7 of Schedule 1 for the fuel type mentioned in column 2 of that item;

(ii)for the consumption of natural gas (other than compressed or liquefied natural gas) in an area connected to a natural gas distribution pipeline—the emission factor mentioned in column 3 of an item in the table in Part 9 of Schedule 1 for the State or Territory where the consumption occurs mentioned in column 2 of that item;

(iii)for the consumption of natural gas (other than compressed or liquefied natural gas) in an area connected to a natural gas transmission pipeline—the emission factor mentioned in column 4 of an item in the table in Part 9 of Schedule 1 for the State or Territory where the consumption occurs mentioned in column 2 of that item;

(iv)for the consumption of compressed or liquefied natural gas—the emission factor mentioned in column 3 of an item in the table in Part 10 of Schedule 1 for the fuel combusted mentioned in column 2 of that item;

(v)for any other feedstock or fuel—determined in accordance with subsection (2).

(2)For the purposes of subparagraph (1)(b)(v), the scope 3 emission factor is calculated as follows:

𝑬𝑭𝒔𝒄𝒐𝒑𝒆3,𝒇=𝑬𝑭𝒔𝒄𝒐𝒑𝒆3,𝒇,𝒑𝒓𝒐𝒅+𝑬𝑭𝒔𝒄𝒐𝒑𝒆3,𝒇,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕

where:

EFscope 3,f,prod is the scope 3 emission factor for the production of the feedstock or fuel (f) determined as follows:

(a)for the supply of gaseous feedstock or fuel, other than natural gas—the emission factor mentioned in column 3 of an item in the table in Part 8 of Schedule 1 for the feedstock type mentioned in column 2 of that item; and

(b)for the supply of solid feedstock or fuel, and any other mass-based feedstocks—the emission factor mentioned in column 3 of an item in the table in Part 6 of Schedule 1 for the feedstock or fuel type mentioned in column 2 for that item.

EFscope 3,f,transport is the scope 3 emissions factor for the transport of the feedstock or fuel (f) determined in accordance with subsection (3).

(3)For the purposes of subsection (2), the EFscope 3,f,transport is calculated as follows:

𝑬𝑭𝒔𝒄𝒐𝒑𝒆3,𝒇,𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕=𝑫𝒇×𝑬𝑭𝒕𝒓𝒂𝒏𝒔𝒑𝒐𝒓𝒕,𝒇

where:

Df, the distance in kilometres the feedstock or fuel (f) is transported to the location at which it is used in the production pathway, monitored and measured in accordance with section 9, is:

(a)for transport by pipeline—the length of the pipeline system; and

(b)for transport by vehicle—the distance from the location where the feedstock or fuel originated.

EFtransport,f is the emission factor mentioned in:

(a)for transport by pipeline—column 3 of an item in the table in Part 5 of Schedule 1 for the type of gaseous feedstock or fuel mentioned in column 2 of that item; and

(b)for transport by vehicle—column 3 of an item in the table in Part 3 of Schedule 1 for the type of vehicle mentioned in column 2 of that item used to transport the feedstock or fuel (f).

Missing scope 3 emission factors

(4)Subsection (5) applies if:

(a)a calculation in this instrument includes the parameter EFscope 3,f for a feedstock or fuel type (the relevant feedstock or fuel); and

(b)that parameter cannot be determined in accordance with subsection (1); and

(c)the relevant feedstock or fuel has either:

(i)a carbon content; or

(ii)an energy content; and

(d)a table in Schedule 1 provides an emission factor for the relevant feedstock or fuel that is “Not estimated”.

Example: The calculation in subsection 16A(2) includes the parameter EFscope 3,f which, for the purposes of paragraph (b) of the parameter, is the scope 3 emission factor for the feedstock used for the production pathway for the batch (b)). The fuel combusted is a biogenic-based product. The table in Part 7 of Schedule 1 lists Biogenic-based products with an emission factor that is “Not estimated”. Subsection (5) may be used to determine the value of the scope 3 emission factor.

(5)The emission factor for the relevant feedstock or fuel which may be used for the purposes of the parameter EFscope 3,f in the calculation is:

(a)if the relevant feedstock or fuel is provided by an input supplier and the input supplier provides an emission factor for the feedstock or fuel—the factor provided; or

(b)in any other case—the scope 3 emission factor determined in accordance with subsection (1) for a feedstock or fuel with:

(i)the same state of matter as the relevant feedstock or fuel; and

(ii)either:

(A)if the relevant feedstock or fuel has an energy content—the closest comparable energy content factor to the relevant feedstock or fuel; or

(B)in any other case—the closest comparable carbon content to the relevant feedstock or fuel.

Note: Schedule 3 to the NGER Measurement Determination sets out the carbon content for certain feedstocks and fuels.

(6)For the purposes of sub-subparagraph (5)(b)(ii)(A), the energy content factor for the relevant feedstock or fuel is worked out in accordance with section 13.

(7)In this section:

natural gas has the same meaning as in the NGER Regulations.

natural gas distribution pipelines has the same meaning as in the NGER Measurement Determination.

natural gas transmission pipeline has the same meaning as in the NGER Measurement Determination.

35 Subsection 13(1)

Repeal the subsection (not including the table), substitute:

(1)For the parameter ECf, the energy content factor for a fuel type (f) measured in the manner specified in the description of column 2 of an item in the following table is determined in accordance with column 3 of that item.

36 Subsection 13(1) (after table item 5)

Insert:

6	Hydrogen measured in kilograms.	The energy content factor is 0.142 gigajoules per kilogram.
7	Plantation forestry residue in kilograms.	The energy content factor, in gigajoules per tonne, is:(a) if the moisture content of the plantation forestry residue, calculated on a wet basis, is 20% or less—the energy content factor for dry wood mentioned in Part 1 of Schedule 1 to the NGER Measurement Determination; or(b) in any other case—the energy content factor for green and air dried wood mentioned in Part 1 of Schedule 1 to the NGER Measurement Determination.
8	Native forestry residue in kilograms.	The energy content factor, in gigajoules per tonne, is:(a) if the moisture content of the native forestry residue, calculated on a wet basis, is 20% or less—the energy content factor for dry wood mentioned in Part 1 of Schedule 1 to the NGER Measurement Determination; or(b) in any other case—the energy content factor for green and air dried wood mentioned in Part 1 of Schedule 1 to the NGER Measurement Determination.

37 At the end of subsection 14(1)

Add:

; (f) subsection 75(3);

(g)subsection 75(4);

(h)subsection 85(4);

(i)subsection 85(5);

(j)subsection 86(4);

(k)subsection 86(5);

(l)subsection 93(2).

38 At the end of Part 1.2 of Chapter 1

Add:

14A NGER Method 2 and 3 sampling and analysis #

NGER Method 2 sampling

(1)If a provision of this instrument provides for a parameter to be determined in accordance with NGER Method 2 sampling, sampling and analysis must be done in accordance with the method set out in the following provisions of the NGER Measurement Determination:

(a)for a solid fuel or an ash—subject to subsection (2), Subdivision 2.2.3.3;

(b)for a gaseous fuel—subject to subsection (3), Subdivision 2.3.3.2;

(c)for a liquid fuel—Subdivision 2.4.3.2.

(2)When sampling and analysing a solid fuel or an ash in accordance with Subdivision 2.2.3.3 of the NGER Measurement Determination for the purposes of paragraph (1)(a):

(a)subsection 2.10(1) of that Subdivision does not apply; and

(b)section 2.10(2) and (3) of that Subdivision apply to furnace ash sampled for its carbon content if the ash is produced from the production of a product in accordance with a production pathway.

(3)When sampling and analysing a gaseous fuel in accordance with Subdivision 2.3.3.2 of the NGER Measurement Determination for the purposes of paragraph (1)(b):

(a)item 2 of the table in section 2.25 of the NGER Measurement Determination does not apply; and

(b)all gaseous fuels (including fugitive emissions) other than pipeline quality gases must be analysed at least monthly.

NGER Method 3 sampling

(4)If a provision of this instrument provides for a parameter to be determined in accordance with NGER Method 3 sampling, sampling and analysis must be done in accordance with NGER Method 2 sampling subject to the following provisions of the NGER Measurement Determination:

(a)for a solid fuel—subsections 2.12(2), (3) and (4);

(b)for a gaseous fuel—subsections 2.26(2), (3) and (4);

(c)for a liquid fuel—subsections 2.47(2), (3) and (4).

39 Sections 15 and 16

Repeal the sections, substitute:

15 Electricity supply and use #

Supplied electricity

(1)The emissions from electricity supplied for the production pathway for the batch (b), Eelec,market,b, in kilograms of CO2-e are worked out using the following formula:

𝑬𝒆𝒍𝒆𝒄,𝒎𝒂𝒓𝒌𝒆𝒕,𝒃=ሺ𝑸𝒆𝒍𝒊𝒈𝒊𝒃𝒍𝒆,𝒃−𝑸𝒓𝒆𝒄,𝒃ቁ×𝑬𝑭𝒆𝒍𝒆𝒄

where:

Qeligible,b is the eligible quantity of electricity supplied for the production pathway for the batch (b) in kilowatt hours, worked out in accordance with subsection (2).

Qrec,b, the quantity of electricity used for the production pathway for the batch (b) in kilowatt hours in respect of which a Renewable Energy Certificate has been surrendered, is either:

(a)if the amount worked out in accordance with subsection (3) is less than or equal to Qeligible,b—that amount; or

(b)if the amount worked out in accordance with subsection (3) is greater than Qeligible,b—Qeligible,b.

Note: If the value of Qrec,b is a negative value, the formula in subsection (1) will result in an increase in the emissions attributed to electricity supplied for the batch.

EFelec is the emission factor for the electricity supplied for the production pathway for the batch (b) in kilograms of CO2-e per kilowatt hour worked out in accordance with subsection (4).

(2)For the purposes of subsection (1), Qeligible,b is worked out using the following formula:

𝑸𝒆𝒍𝒊𝒈𝒊𝒃𝒍𝒆,𝒃=𝑸𝒆𝒍𝒆𝒄,𝒎𝒂𝒓𝒌𝒆𝒕,𝒃−𝑸𝒆𝒍𝒆𝒄,𝒆𝒙,𝒃×𝟏𝟎𝟎%−𝑹𝑷𝑷+𝑱𝑹𝑷𝑷+𝑸𝒆𝒍𝒆𝒄,𝒆𝒙,𝒃×𝟏𝟎𝟎%−𝑱𝑹𝑷𝑷

where:

Qelec,market,b is the quantity of purchased or acquired electricity supplied for the production pathway for the batch (b) in kilowatt hours, monitored or measured in accordance with section 9.

Qelec,ex,b is the quantity of exempt electricity supplied for the production pathway for the batch (b) in kilowatt hours worked out in accordance with subsection (5).

RPP is the renewable power percentage for the calendar year in which the batch period started.

JRPP is the Jurisdictional Renewable Power Percentage as a percentage for:

(a)the State or Territory where the production profile is located; and

(b)the financial year in which the batch period started.

(3)For the purposes of subsection (1), Qrec,b is worked out using the following formula:

𝑸𝒓𝒆𝒄,𝒃=ሺ𝑹𝑬𝑪𝒔𝒖𝒓𝒓,𝒃−𝑹𝑬𝑪𝒉𝒐𝒍,𝒃ቁ×𝟏𝟎𝟎𝟎

where:

RECsurr,b is the quantity of electricity used for the production pathway for the batch (b) in respect of which a Renewable Energy Certificate has been surrendered in megawatt hours.

REChol,b is the quantity of electricity generated by the holder of the production profile and used for the production pathway for the batch (b) in respect of which a Renewable Energy Certificate has been, or is expected to be, created in megawatt hours.

(4)For the purposes of subsection (1), EFelec is worked out using the following formula:

Note: The emission factor for the supplied market that is worked out in accordance with subsection (4) is commonly referred to as the “residual mix factor”.

𝑬𝑭𝒆𝒍𝒆𝒄=𝑬𝑭𝒆𝒍𝒆𝒄,𝒔𝒄𝒐𝒑𝒆2+𝑬𝑭𝒆𝒍𝒆𝒄,𝒔𝒄𝒐𝒑𝒆3

where:

EFelec,scope 2 the scope 2 residual mix factor in kilograms of CO2-e per kilowatt hour, is:

(a)if the electricity supplied for the production pathway for the batch (b) was generated in Western Australia—the value in column 3 of the table in Part 6 of Schedule 1 to the NGER Measurement Determination for the South West Interconnected System in Western Australia; and

(b)in any other case—the value in column 3 of an item in the table in Part 6 of Schedule 1 to the NGER Measurement Determination for the State or Territory or grid description mentioned in column 1 of that item where the electricity supplied for the production pathway for the batch (b) was generated.

EFelec,scope 3, the scope 3 emission factor for purchased or acquired electricity in kilograms of CO2-e per kilowatt hour, is 0.11.

(5)For the purposes of subsection (2), Qelec,ex,b is worked out using the following formula:

𝑸𝒆𝒍𝒆𝒄,𝒆𝒙,𝒃=𝑸𝒆𝒍𝒆𝒄,𝒆𝒙,𝒚𝑸𝒆𝒍𝒆𝒄,𝒎𝒂𝒓𝒌𝒆𝒕,𝒚×𝑸𝒆𝒍𝒆𝒄,𝒎𝒂𝒓𝒌𝒆𝒕,𝒃

where:

Qelec,ex,y is the quantity of purchased or acquired electricity supplied to the holder of the production profile for the year (y) in megawatt hours monitored or measured in accordance with section 9 that:

(a)has been, or is expected to be, claimed against an exemption under the REE Act; or

(b)has been acquired under an acquisition that is not a relevant acquisition within the meaning of section 31 of the REE Act.

Qelec,market,y is the quantity of purchased or acquired electricity supplied to the holder of the production profile for the year (y) in megawatt hours, monitored or measured in accordance with section 9.

Qelec,market,b is the quantity of purchased or acquired electricity supplied for the production pathway for the batch (b) in kilowatt hours, monitored or measured in accordance with section 9.

y is either:

(a)the financial year immediately prior to the financial year in which the batch period started; or

(b)the calendar year immediately prior to the calendar year in which the batch period started.

(6)In this section:

created means:

(a)for a REGO certificate—registered under section 104 of the Act; and

(b)for a large-scale generation certificate—created and registered under the REE Act.

exemption has the same meaning as in the REE Act.

Jurisdictional Renewable Power Percentage, for a State or Territory for a financial year, means the percentage known as the jurisdictional renewable power percentage for the State or Territory for the financial year published in the NGAF.

REE Act means the Renewable Energy (Electricity) Act 2000.

Renewable Energy Certificate means a certificate that:

(a)is one of the following:

(i)a large-scale generation certificate surrendered under section 28A of the REE Act, other than a certificate:

(A)created in contravention of section 24 or 25 of that Act; or

(B)surrendered to meet a liable entity’s obligations under Subdivision A of Division 1 of Part 5 or section 95 of that Act; or

(ii)a REGO certificate, other than a certificate created in contravention of section 103 of the Act; and

(b)is not in respect of electricity that was generated more than 1 year before the start of the batch period.

renewable power percentage has the same meaning as in the REE Act.

surrendered means:

(a)for a REGO certificate—retired under section 107 of the Act; and

(b)for a large-scale generation certificate—surrendered under the REE Act.

16 Fuel supply and combustion #

(1)The emissions from fuel supplied and combusted for the production pathway for the batch (b) Efuel,b, in kilograms of CO2-e are calculated using the following formula:

𝑬𝒇𝒖𝒆𝒍,𝒃=𝑬𝒇𝒖𝒆𝒍,𝒇,𝒃−𝑬𝒇𝒖𝒆𝒍,𝑪𝑯𝑷,𝒐𝒖𝒕𝒔𝒊𝒅𝒆

where:

Efuel,f,b is the emissions from all fuels (f) combusted for the production pathway for the batch (b) including fuel combusted in a CHP where steam or electricity is not used for the production pathway for the batch in kilograms of CO2-e, worked out in accordance with subsection (2).

Efuel,CHP,outside is the emissions attributable to fuel combusted to operate a CHP plant for steam or electricity that is not used for the production pathway for the batch (b), worked out in accordance with subsection (3).

(2)For the purposes of subsection (1), Efuel,f,b, is calculated as follows:

𝑬𝒇𝒖𝒆𝒍,𝒇,𝒃=෍𝑸𝒇,𝒃×𝑬𝑪𝒇×𝑬𝑭𝒔𝒄𝒐𝒑𝒆1,𝒇+𝑬𝑭𝒔𝒄𝒐𝒑𝒆3,𝒇×𝑼𝑪𝒇

where:

Qf,b is the quantity of the fuel type (f) combusted for the production pathway for the batch (b), monitored or measured in accordance with section 9.

ECf is the energy content factor for the fuel type (f) determined in accordance with section 13.

EFscope 1,f is the scope 1 emission factor for the fuel type (f) in kilograms of CO2-e per gigajoule worked out using either:

(a)for a fuel type that is a solid fuel—either:

(i)the default values scope 1 emission factor calculation in subsection (8); or

(ii)the carbon sampled scope 1 emission factor calculation in subsection (9); or

(b)in any other case—the default values scope 1 emission factor calculation in subsection (8).

EFscope 3,f, the scope 3 emission factor for the fuel type (f) is:

(a)if the fuel type (f) is produced within the production pathway for the product—zero; or

(b)in any other case—determined in accordance with section 12.

UC, the unit conversion factor, is:

(a)for a fuel mentioned in Part 6 of Schedule 1—1,000 divided by ECf; and

(b)for hydrogen for which there is a registered PGO certificate—1 divided by ECf; and

(c)in any other case—1.

Note For the equation in this subsection, all emissions factors must be on a per GJ basis.

(3)For the purposes of subsection (1), Efuel,CHP,outside, is calculated as follows:

𝑬𝒇𝒖𝒆𝒍,𝑪𝑯𝑷,𝒐𝒖𝒕𝒔𝒊𝒅𝒆=𝑪𝑯𝑷𝒔,𝒐𝒖𝒕,𝒃+𝑪𝑯𝑷𝒆,𝒐𝒖𝒕,𝒃×෍𝑸𝒇,𝑪𝑯𝑷,𝒃×𝑬𝑪𝒇×𝑬𝑭𝒔𝒄𝒐𝒑𝒆1,𝒇+𝑬𝑭𝒔𝒄𝒐𝒑𝒆3,𝒇×𝑼𝑪𝒇

where:

CHPs,out,b is the proportion of the total emissions attributable to the steam generated by the CHP plant other than for the batch (b), worked out in accordance with subsection (4).

CHPe,out,b is the proportion of the total emissions attributable to the electricity generated by the CHP plant other than for the batch (b), worked out in accordance with subsection (5).

Qf,CHP,b is the quantity of fuel type (f) combusted to operate the CHP plant during the batch (b) monitored or measured in accordance with section 9.

ECf is the energy content factor for the fuel type (f) determined in accordance with section 13.

EFscope 1,f is the scope 1 emission factor for the fuel type (f) in kilograms of CO2-e per gigajoule worked out using either:

(a)for a fuel type that is a solid fuel—the carbon sampled scope 1 emission factor calculation in subsection (9); or

(b)in any other case—the default values scope 1 emission factor calculation in subsection (8).

EFscope 3,f is the scope 3 emission factor for the fuel type (f) determined in accordance with section 12.

UC, the unit conversion factor, is:

(a)for a fuel mentioned in Part 6 of Schedule 1—1,000 divided by ECf; and

(b)in any other case—1.

Note UC is required because the units of EFscope 3,f are per kg for solid fuels, and per GJ for gaseous and liquid fuels. For this equation, all EF must be on a per GJ basis.

(4)For the purposes of subsection (3), CHPs,out,b, is calculated as follows:

𝑪𝑯𝑷𝒔,𝒐𝒖𝒕,𝒃=1−𝑸𝒔,𝒃𝑸𝒔,𝑪𝑯𝑷,𝒃×𝑪𝑯𝑷𝒔,𝒃

where:

Qs,b is the quantity of steam generated by the CHP plant that is used for the batch (b), monitored or measured in accordance with section 9.

Qs,CHP,b is the quantity of steam generated by the CHP plant (including the steam used for the batch and not used for the batch), monitored or measured in accordance with section 9.

CHPs,b is the proportion of the total emissions attributable to the steam generated by the CHP plant worked out in accordance with subsection (6).

(5)For the purposes of subsection (3), CHPe,out,b, is calculated as follows:

𝑪𝑯𝑷𝒆,𝒐𝒖𝒕,𝒃=1−𝑸𝒆,𝒃𝑸𝒆,𝑪𝑯𝑷,𝒃×𝑪𝑯𝑷𝒆,𝒃

where:

Qe,b is the quantity of electricity generated by the CHP plant that is used for the batch (b), monitored or measured in accordance with section 9.

Qe,CHP,b is the quantity of electricity generated by the CHP plant (including the electricity used for the batch and not used for the batch), monitored or measured in accordance with section 9.

CHPe,b is the proportion of the total emissions attributable to the electricity generated by the CHP plant worked out in accordance with subsection (7).

(6)For the purposes of subsection (4), CHPs,b, determined in accordance with the CHP Tool using a CHP emission allocation method, is:

(a)for the efficiency method—the result of dividing the value described in that method as ‘the emissions share attributable to steam production’ by the value described in that method as ‘the total direct emissions from CHP plant’; and

(b)for the energy content method—the fraction of total emissions to allocate to the steam energy stream worked out in accordance with that method;

(c)for the work potential method—the fraction of total emissions to allocate to the steam energy stream worked out in accordance with that method.

(7)For the purposes of subsection (5), CHPe,b, determined in accordance with the CHP Tool using a CHP emission allocation method, is:

(a)for the efficiency method—the result of dividing the value described in that method as ‘the emissions share attributable to electricity production’ by the value described in that method as ‘the total direct emissions from CHP plant’; and

(b)the energy content method—the fraction of total emissions to allocate to the electricity energy stream worked out in accordance with that method;

(c)the work potential method—the fraction of total emissions to allocate to the electricity energy stream worked out in accordance with that method.

Default values scope 1 emission factor calculation

(8)For the purposes of subsections (2) and (3), EFscope 1,f, is worked out using the following formula:

𝑬𝑭𝒔𝒄𝒐𝒑𝒆1,𝒇=෍𝑬𝑭𝒇𝒋𝒇

where:

EFfj is the scope 1 emission factor for each greenhouse gas type (j) released from the combustion of the fuel type (f), in kilograms of CO2-e per gigajoule of fuel type (f), determined in accordance with section 11.

Carbon sampled scope 1 emission factor calculation

(9)For the purposes of subsections (2) and (3), EFscope 1,f, is worked out using the following formula:

𝑬𝑭𝒔𝒄𝒐𝒑𝒆𝟏,𝒇=𝑬𝑭𝑪𝑶𝟐𝒐𝒙,𝒇𝑬𝑪𝒇×𝟏𝟎𝟎𝟎+෍𝑬𝑭𝒇𝒋𝒋

where:

EFCO2ox,f is the carbon dioxide emission factor for the fuel type (f), in kilograms of CO2-e per kilogram of fuel worked out in accordance with subsection (10).

ECf is the energy content factor for the fuel type (f) determined in accordance with section 13.

EFfj is the scope 1 emission factor for each greenhouse gas type (j) (other than carbon dioxide) released from the combustion of the fuel type (f), in kilograms of CO2-e per gigajoule of fuel type (f), determined in accordance with section 11.

Note: The scope 1 emission factor for carbon dioxide is already accounted for using the EFCO2ox,f over ECf term and therefore is disregarded when determining EFfj in accordance with section 11.

(10)For the purposes of subsection (9), the carbon dioxide emission factor for the fuel type (f), in kilograms of CO2-e per kilogram of fuel, EFCO2ox,f, is worked out using the following formula:

𝑬𝑭𝑪𝑶𝟐𝒐𝒙,𝒇=𝑪𝒂𝒓,𝒇𝟏𝟎𝟎−𝑪𝒂×𝑨𝒂𝒓,𝒇𝟏𝟎𝟎−𝑪𝒂×𝟏𝟎𝟎×𝟑.𝟔𝟔𝟒

where:

Car,f is the carbon in fuel type (f) as a percentage, worked out in accordance with subsection (11).

Ca is the percentage of carbon in the ash, being the weighted average of fly ash and furnace ash, determined in accordance with NGER Method 2 sampling.

Aar,f is the amount of ash in fuel type (f) as a percentage of the ‘as received’ mass of the fuel determined in accordance with NGER Method 2 sampling.

(11)For the purposes of subsection (10), carbon in fuel type (f), Car,f, is worked out using the following formula:

𝑪𝒂𝒓,𝒇=𝑪𝒅𝒂𝒇,𝒇×𝟏𝟎𝟎−𝑴𝒂𝒓,𝒇−𝑨𝒂𝒓,𝒇𝟏𝟎𝟎

where:

Cdaf,f is the amount of carbon in fuel type (f) as a percentage of the dry ash free mass of the fuel determined in accordance with NGER Method 2 sampling.

Mar,f is the amount of moisture in fuel type (f) as a percentage of the ‘as received’ mass of the fuel determined in accordance with NGER Method 2 sampling.

Aar,f is the amount of ash in fuel type (f) as a percentage of the ‘as received’ mass of the fuel determined in accordance with NGER Method 2 sampling.

16A Feedstock supply #

(1)The emissions associated with feedstocks used for production of the batch (b), Ef,b, in kilograms of CO2-e are calculated using the following formula:

𝑬𝒇,𝒃=෍𝑸𝒇,𝒃×𝑬𝑭𝒔𝒄𝒐𝒑𝒆𝟑,𝒇𝒇

where:

Qf,b is the quantity of feedstock (f) used for the production pathway for the batch (b) in the relevant unit, monitored or measured in accordance with section 9.

EFscope 3,f is the scope 3 emission factor for the feedstock (f) in kilograms of CO2-e per the relevant unit, worked out in accordance with section 12.

(2)In this section:

feedstock means:

(a)in relation to a production pathway for aluminium—pre-consumer and post-consumer scrap aluminium; and

(b)in relation to a production pathway for iron ore—externally sourced iron ore; and

(c)in relation to a production pathway for methane—a feedstock or fuel type mentioned in an item in a table in Parts 6 and 8 of Schedule 1 for which a biogenic content of 100% is specified for the item; and

(d)in relation to a production pathway for hydrogen—a feedstock or fuel type mentioned in Parts 6, 8 and 9 of Schedule 1.

relevant unit, for a feedstock, is:

(a)if there is a registered PGO certificate in respect of the feedstock—the unit of the feedstock mentioned on the registered PGO certificate; and

(b)in any other case—the unit of measurement against which the carbon dioxide equivalence is compared, mentioned in a table in Schedule 1 in relation to the feedstock.

Example: Aviation gasoline has an emission factor in Schedule 1 that is measured in kg CO2-e per GJ, therefore the relevant unit for aviation gasoline is gigajoules (GJ).

16B Carbonates use #

(1)The emissions associated with carbonates used for production of the batch (b), Ecarb,b, in kilograms of CO2-e are worked out using the following formula:

𝑬𝒄𝒂𝒓𝒃,𝒃=෍𝑸𝒄𝒂𝒓𝒃,𝒄,𝒃×𝑬𝑭𝒔𝒄𝒐𝒑𝒆1,𝒄𝒄

where:

Qcarb,c,b is the quantity of carbonate type (c) for the batch (b), in kilograms, measured in accordance with section 9.

EFscope 1,c is the scope 1 emission factor for the carbonate type (c), in kilograms of CO2-e per kilogram of carbonate, as follows:

(a)for calcium carbonate (CaCO3)—0.396;

(b)for magnesium carbonate (MgCO3)—0.522;

(c)for dolomite (CaMg(CO3)2)—0.453;

(d)for iron carbonate (FeCO3)—0.380;

(e)for ankerite (Ca(Fe,Mg,Mn)(CO3)2)—0.476;

(f)for manganese carbonate (MnCO3)—0.383;

(g)for sodium carbonate (Na2CO3)—0.415;

(h)for clay materials—calculated in accordance with subsection (2).

(2)For the purposes of subsection (1), the scope 1 emission factor for clay materials, in kilograms of CO2-e per kilogram of carbonate, EFscope 1,c, is calculated as follows:

where:

ICCc is the inorganic carbon content factor of the clay material (c), in kilograms of carbon per kilogram of carbonate, mentioned in column 3 of an item in the table in section 4.22A(2) of the NGER Measurement Determination, for the State or Territory from which the clay has been sourced, mentioned in column 2 of that item.

40 Sections 18 and 19

Repeal the sections, substitute:

18 Steam supply #

Steam from an input supplier

(1)The emissions from steam supplied for the production pathway for the batch (b), Esteam,b, in kilograms of CO2-e is worked out using the following formula:

𝑬𝒔𝒕𝒆𝒂𝒎,𝒃=෍𝑸𝒔𝒕𝒆𝒂𝒎,𝒙,𝒃×𝑬𝑭𝒔𝒕𝒆𝒂𝒎,𝒙𝒙

where:

Qsteam,x,b is the quantity of steam supplied by an input supplier for the production pathway for the batch (b) from source (x) in gigajoules, monitored or measured in accordance with section 9.

EFsteam,x is either:

(a)116.667 kilograms of CO2-e per gigajoule; or

(b)worked out in accordance with subsection (2).

(2)For the purposes of subsection (1), EFsteam,x, the supplier specific emission factor for steam from a source (x) in kilograms of CO2-e per gigajoule steam, is worked out using the following formula:

𝑬𝑭𝒔𝒕𝒆𝒂𝒎,𝒙=𝑬𝒔𝒕𝒆𝒂𝒎,𝒊𝒔,𝒚𝑸𝒔𝒕𝒆𝒂𝒎,𝒊𝒔,𝒚

where:

Esteam,is,y is the scope 1 and scope 3 emissions related to steam production by the input supplier for the year (y) in kilograms of CO2-e, worked out in accordance with subsection (3).

Qsteam,is,y is the quantity of steam produced by the input supplier for the year (y) in gigajoules, provided by the input supplier.

y is the financial year immediately prior to the financial year in which the batch period started.

(3)For the purposes of subsection (2), Esteam,is,y is worked out using the following formula:

𝑬𝒔𝒕𝒆𝒂𝒎,𝒊𝒔,𝒚=𝑪𝑯𝑷𝒔,𝒚×෍𝑸𝒇,𝒊𝒔,𝒚×𝑬𝑪𝒇×𝑬𝑭𝒔𝒄𝒐𝒑𝒆1,𝒇+𝑬𝑭𝒔𝒄𝒐𝒑𝒆3,𝒇×𝑼𝑪𝒇

where:

CHPs,y is:

(a)if the steam is produced in a CHP plant—the proportion of the total emissions attributable to the steam generated from the CHP plant, determined in accordance with subsection (5) for the year (y); or

(b)in any other case—1.

Qf,is,y is:

(a)if the steam is produced in a CHP plant—the quantity of the relevant fuel type (f) used in the CHP plant for the year (y) in litres, kilograms or gigajoules, provided by the input supplier; or

(b)in any other case—the quantity of the relevant fuel type (f) used in steam production for the site where the steam is generated for the year (y) in litres, kilograms or gigajoules, provided by the input supplier.

ECf is the energy content factor for the fuel type (f) determined in accordance with section 13.

EFscope 1,f is the scope 1 emission factor for the relevant fuel type (f) in kilograms of CO2-e per gigajoule, worked out in accordance with subsection (4).

EFscope 3,f is the scope 3 emission factor for the fuel type (f) determined in accordance with section 12.

UC, the unit conversion factor, is:

(a)for a fuel mentioned in Part 6 of Schedule 1—1,000 divided by ECf; and

(b)in any other case—1.

Note UC is required because the units of EFscope 3,f are per kg for solid fuels, and per GJ for gaseous and liquid fuels. For this equation, all EF must be on a per GJ basis.

y is the financial year immediately prior to the financial year in which the batch period started.

(4)For the purposes of subsection (3), EFscope 1,f is worked out using the following formula:

𝑬𝑭𝒔𝒄𝒐𝒑𝒆1,𝒇=෍𝑬𝑭𝒇𝒋𝒇

where:

EFfj is the scope 1 emission factor for each greenhouse gas type (j) released from the use of the fuel type (f), in kilograms of CO2-e per gigajoule of fuel type (f), determined in accordance with section 11.

(5)For the purposes of subsection (3), CHPs,y, determined in accordance with the CHP Tool using a CHP emission allocation method, is:

(b)for the energy content method—the fraction of total emissions to allocate to the steam energy stream worked out in accordance with that method;

(c)for the work potential method—the fraction of total emissions to allocate to the steam energy stream worked out in accordance with that method.

19 Synthetic gas use #

(1)The emissions from synthetic gas contained in equipment used for the production pathway for the batch (b), Eleaks,b, in kilograms of CO2-e, are worked out using the following formula:

𝑬𝒍𝒆𝒂𝒌𝒔,𝒃=𝑹𝒃×𝑬𝒍𝒆𝒂𝒌𝒔,𝒚

where:

Rb is:

(a)for calculating emissions in relation to a delivery module—worked out in accordance with subsection (3); or

(b)in any other case—worked out in accordance with subsection (2) or (3).

Note: Rb represents the ratio of synthetic gas leakage in a year attributable to the batch.

Eleaks,y is the emissions from synthetic gas contained in the equipment used for the production pathway for the year worked out in accordance with one of the following provisions:

(a)subsection (4); or

(b)subsection (5); or

(c)subsection (6).

(2)For the purposes of subsection (1), Rb is worked out using the following formula:

𝑹𝒃=𝑸𝒃𝑸𝒚

where:

Qb is the amount of product in the batch (b) in the unit of measurement of the functional unit of the product.

Qy is the amount of product produced in accordance with the production pathway for the year (y), in the unit of measurement of the functional unit of the product.

(3)For the purposes of subsection (1), Rb is worked out using the following formula:

𝑹𝒃=𝒕𝒃𝟖𝟕𝟔𝟎

where:

tb is the duration of the batch period in hours.

(4)For the purposes of subsection (1), Eleaks,y is worked out using the following formula:

𝑬𝒍𝒆𝒂𝒌𝒔,𝒚=෍𝑪𝒂𝒑𝒂𝒄𝒊𝒕𝒚𝒋,𝒌×𝑳𝒋,𝒌×𝑮𝑾𝑷𝒋𝒋,𝒌

Capacityj,k is the stated capacity of the synthetic gas type (j) in the equipment type (k) according to the manufacturer’s nameplate in tonnes.

Lj,k is:

(a)if the synthetic gas type (j) is sulphur hexafluoride—the default annual leakage rate mentioned in column 4 of an item in the table in subsection 4.102(4) of the NGER Measurement Determination for the equipment type (k) in column 2 of the table of that item; or

(b)if the synthetic gas type (j) is hydrofluorocarbons—the default annual leakage rate mentioned in column 3 of an item in the table in subsection 4.102(4) of the NGER Measurement Determination for the equipment type (k) in column 2 of the table of that item.

GWPj is the Global Warming Potential of the synthetic gas type (j).

k is the equipment type used for the production pathway for the year (y) mentioned in column 2 of the table in subsection 4.102(4) of the NGER Measurement Determination.

j is the type of synthetic gas contained in the equipment type (k).

y is the financial year in which the batch period started.

(5)For the purposes of subsection (1), Eleaks,y is worked out in accordance with section 4.103 of the NGER Measurement Determination where a reference to a year is taken to be a reference to:

(a)the financial year immediately prior to the financial year in which the batch period started; or

(b)if the batch period ends on 30 June—the financial year in which the batch period started.

(6)For the purposes of subsection (1), Eleaks,y is worked out using the following formula:

𝑬𝒍𝒆𝒂𝒌𝒔,𝒚=෍𝑸𝒍,𝒋,𝒚×𝑮𝑾𝑷𝒋𝒍,𝒋

Ql,j,y is the quantity of synthetic gas type (j) from a source of loss (l) in the year (y) in kilograms.

GWPj is the Global Warming Potential of the synthetic gas type (j).

l is a source of loss of synthetic gas, including the following:

(a)top up of synthetic gas for leaking equipment;

(b)complete loss of containment of equipment;

(c)losses during filling of new (or refurbished) equipment;

(d)complete loss of containment of cylinders;

(e)leakage of synthetic gas from cylinders;

(f)losses during decanting between cylinders;

(g)losses during manual handling including handling equipment failure or accidental venting;

(h)leakage from equipment spares in storage;

(i)leakage from decommissioned equipment awaiting disposal;

(j)determinations of synthetic gas loss from sealed equipment at point of disposal;

(k)losses during reprocessing, recycling or rebottling of synthetic gas;

(l)losses due to synthetic gas sampling and analysis.

j is the type of synthetic gas contained in the equipment.

y is either:

(a)the financial year immediately prior to the financial year in which the batch period started; or

(b)if the batch period ends on 30 June—the financial year in which the batch period started.

(7)In this section:

synthetic gas means:

(a)in relation to the aluminium production pathway—sulphur hexafluoride; or

(b)in any other case—sulphur hexafluoride and hydrofluorocarbons.

19A Oxygen supply and use #

(1)The emissions from oxygen used for the production pathway for the batch (b), EO2,is,b, in kilograms of CO2-e are calculated using the following formula:

𝑬𝑶2,𝒊𝒔,𝒃=𝑸𝑶2,𝒊𝒔,𝒃×𝑫𝑬𝑶2×𝑬𝑭𝒆𝒍𝒆𝒄

where:

QO2,is,b is the quantity of oxygen provided by an input supplier for the production pathway for the batch (b), in kilograms, monitored or measured in accordance with section 9.

DEO2 is either:

(a)if the oxygen provided for the production pathway for the batch is in a gaseous state—0.32; or

(b)if the oxygen provided for the production pathway for the batch is in a liquid state—0.64.

Note: DEO2 represents the default energy requirement value for producing oxygen, in kilowatt hours per kilogram of oxygen.

EFelec is the emission factor for the electricity purchased or acquired to produce the oxygen used for the production pathway for the batch, in kilograms of CO2-e per kilowatt hour, worked out in accordance with subsection (2).

(2)For the purposes of subsection (1), EFelec is worked out using the following formula:

𝑬𝑭𝒆𝒍𝒆𝒄=𝑬𝑭𝒆𝒍𝒆𝒄,𝒔𝒄𝒐𝒑𝒆2+𝑬𝑭𝒆𝒍𝒆𝒄,𝒔𝒄𝒐𝒑𝒆3

where:

EFelec,scope 2 is the scope 2 emission factor in kilograms of CO2-e per kilowatt hour mentioned in column 2 of an item in the table in Part 6 of Schedule 1 to the NGER Measurement Determination for the State or Territory, or grid description mentioned in column 1 of that item that best describes:

(a)the location where the oxygen used for the production pathway for the batch (b) was produced; or

(b)if the location in paragraph (a) cannot be identified—the location where the batch (b) was produced.

EFelec,scope 3 is the value mentioned in an item of the column headed ‘Scope 3 Emission Factors’ in Table 1 of section 2.2 of the NGAF for the item in the column headed ‘State, Territory or grid description’ that best describes:

(a)the location where the oxygen used for the production pathway for the batch (b) was produced; or

(b)if the location in paragraph (a) cannot be identified—the location where the batch (b) was produced.

19B Alloying metal supply and use #

The emissions from alloying metals used for the production pathway for the batch (b), Ealloy,b, in kilograms of CO2-e are worked out using the following formula:

𝑬𝒂𝒍𝒍𝒐𝒚,𝒃=෍𝑸𝒂𝒍𝒍𝒐𝒚,𝒙,𝒃×𝑬𝑭𝒂𝒍𝒍𝒐𝒚,𝒙𝒙

where:

Qalloy,x,b is the quantity of the alloying metal (x) used for the production pathway for the batch (b), in kilograms, monitored or measured in accordance with section 9.

EFalloy,x is the scope 3 emission factor mentioned in column 3 of an item in the table in Part 4 of Schedule 1 for the alloying metal (x) mentioned in column 2 of that item, in kilograms of CO2-e per kilogram of alloying metal.

19C Carbon containing feedstock use #

(1)The emissions from carbon containing feedstocks used for the production pathway for the batch (b), Ecf,b, in kilograms of CO2-e are calculated using the following formula:

𝑬𝒄𝒇,𝒃=෍𝑸𝒇,𝒃×𝑬𝑪𝒇×𝑬𝑭𝒔𝒄𝒐𝒑𝒆1,𝒇𝒇

where:

Qf,b is the quantity of the carbon containing feedstock type (f) used for the production pathway for the batch (b) in tonnes for solid feedstock and cubic metres for gaseous feedstocks, monitored or measured in accordance with section 9.

ECf is the energy content factor for the carbon containing feedstock type (f) determined in accordance with section 13, where a reference in that section to fuel is taken to include a reference to carbon containing feedstock.

EFscope 1,f is the scope 1 emission factor for the carbon containing feedstock type (f) in kilograms of CO2-e per gigajoule worked out:

(a)if the feedstock is mixed solid waste—using the carbon sampled scope 1 emission factor calculation in subsection (3); and

(b)if the feedstock is a solid (other than mixed solid waste)—using either:

(i)the default values scope 1 emission factor calculation in subsection (2); or

(ii)the carbon sampled scope 1 emission factor calculation in subsection (3); and

(c)in any other case—the default values scope 1 emission factor calculation in subsection (2).

Default values scope 1 emission factor calculation

(2)For the purposes of subsection (1), EFscope 1,f, is worked out using the following formula:

𝑬𝑭𝒔𝒄𝒐𝒑𝒆1,𝒇=෍𝑬𝑭𝒇𝒋𝒇

where:

EFfj is the scope 1 emission factor for each greenhouse gas type (j) released from the use of the carbon containing feedstock type (f), in kilograms of CO2-e per gigajoule of carbon containing feedstock type (f), determined in accordance with section 11, where a reference in that section to fuel is taken to include a reference to carbon containing feedstock.

Carbon sampled scope 1 emission factor calculation

(3)For the purposes of subsection (1), EFscope 1,f, is worked out using the following formula:

where:

EFCO2ox,f is the carbon dioxide emission factor for the carbon containing feedstock type (f), in kilograms of CO2-e per kilogram of carbon containing feedstock worked out in accordance with subsection (4).

EFfj is the scope 1 emission factor for each greenhouse gas type (j) (other than carbon dioxide) released from the use of the carbon containing feedstock type (f), in kilograms of CO2-e per gigajoule of carbon containing feedstock type (f), determined in accordance with section 11, where a reference in that section to fuel is taken to include a reference to carbon containing feedstock.

Note: The scope 1 emission factor for carbon dioxide is already accounted for using the EFCO2ox,f over ECf term and therefore is disregarded when determining EFfj in accordance with section 11.

(4)For the purposes of subsection (3), the carbon dioxide emission factor for the carbon containing feedstock type (f), in kilograms of CO2-e per kilogram of carbon containing feedstock, EFCO2ox,f, is worked out using the following formula:

𝑬𝑭𝑪𝑶𝟐𝒐𝒙,𝒇=𝑪𝒂𝒓,𝒇𝟏𝟎𝟎−𝑪𝒂×𝑨𝒂𝒓,𝒇𝟏𝟎𝟎−𝑪𝒂×𝟏𝟎𝟎×𝟏−𝑩𝑪𝑪𝒇𝟏𝟎𝟎×𝟑.𝟔𝟔𝟒

where:

Car,f is the carbon in carbon containing feedstock type (f) as a percentage, worked out in accordance with subsection (5).

Ca is the percentage of carbon in the ash, being the weighted average of fly ash and furnace ash, determined in accordance with NGER Method 2 sampling.

Aar,f is the amount of ash in carbon containing feedstock type (f) as a percentage of the ‘as received’ mass of the carbon containing feedstock determined in accordance with NGER Method 2 sampling.

BCCf is the proportion of carbon content in feedstock (f) that is of biogenic origin, which is:

(a)if the feedstock is mentioned in column 2 of an item in a table in Part 6 of Schedule 1 and the value of the biogenic carbon content mentioned in column 4 of that item is not ‘n/a’—that value;

(b)in any other case—determined using sampling and analysis in accordance with section 2.66 of the NGER Measurement Determination.

(5)For the purposes of subsection (4), carbon in carbon containing feedstock type (f), Car,f, is worked out using the following formula:

𝑪𝒂𝒓,𝒇=𝑪𝒅𝒂𝒇,𝒇×𝟏𝟎𝟎−𝑴𝒂𝒓,𝒇−𝑨𝒂𝒓,𝒇𝟏𝟎𝟎

where:

Cdaf,f is the amount of carbon in carbon containing feedstock type (f) as a percentage of the dry ash free mass of the carbon containing feedstock determined in accordance with NGER Method 2 sampling.

Mar,f is the amount of moisture in carbon containing feedstock type (f) as a percentage of the ‘as received’ mass of the carbon containing feedstock determined in accordance with NGER Method 2 sampling.

41 Subsection 20(2) (subparagraph (a)(ii) of the definition of Epipe,elec,y)

Omit “, other than a reference to the batch in the parameter EFscope3,i in subsection 15(9)”.

42 Subsection 20(2) (paragraph (b) of the definition of Epipe,elec,y)

Omit “subsection 15(3)”, substitute “subsection 15(2)”.

43 Subsection 20(2) (paragraph (c) of the definition of Epipe,elec,y)

Omit “subsection 15(6)”, substitute “subsection 15(5)”.

44 Subsection 20(2) (paragraph (b) of the definition of Epipe,fuel,y)

Renumber as (a).

45 Subsection 20(2) (paragraph (c) of the definition of Epipe,fuel,y)

Renumber as (b).

46 Subsection 21(2) (subparagraph (a)(ii) of the definition of Eveh,elec,J)

Omit “, other than a reference to the batch in the parameter EFscope3,i in subsection 15(9)”.

47 Subsection 21(2) (paragraph (b) of the definition of Eveh,elec,J)

Omit “subsection 15(3)”, substitute “subsection 15(2)”.

48 Subsection 21(2) (paragraph (c) of the definition of Eveh,elec,J)

Omit “subsection 15(6)”, substitute “subsection 15(5)”.

49 Subsection 21(4) (subparagraph (a)(ii) of the definition of Eveh,elec,s)

Omit “, other than a reference to the batch in the parameter EFscope3,i in subsection 15(9)”.

50 Subsection 21(4) (paragraph (b) of the definition of Eveh,elec,s)

Omit “subsection 15(3)”, substitute “subsection 15(2)”.

51 Subsection 21(4) (paragraph (c) of the definition of Eveh,elec,s)

Omit “subsection 15(6)”, substitute “subsection 15(5)”.

52 Subsection 21(7) (paragraph (b) of the definition of Efleet,fuel,SJ)

Renumber as (a).

53 Subsection 21(7) (paragraph (c) of the definition of Efleet,fuel,SJ)

Renumber as (b).

54 Subsection 21(7) (subparagraph (a)(ii) of the definition of Efleet,elec,SJ)

Omit “, other than a reference to the batch in the parameter EFscope3,i in subsection 15(9)”.

55 Subsection 21(7) (paragraph (b) of the definition of Efleet,elec,SJ)

Omit “subsection 15(3)”, substitute “subsection 15(2)”.

56 Subsection 21(7) (paragraph (c) of the definition of Efleet,elec,SJ)

Omit “subsection 15(6)”, substitute “subsection 15(5)”.

57 Subsection 22(2) (paragraphs (a) to (c) of the definition of Estore,elec,t)

Repeal the paragraphs, substitute:

(a)a reference in section 15:

(i)to production pathway is taken to be a reference to storage vessel delivery module; and

(ii)to batch (b) is taken to be a reference to time period (t); and

(iii)to production profile is taken to be a reference to delivery profile; and

(b)the value of the parameter Qelec,ex,b in subsection 15(2) is taken to be zero; and

(c)subsection 15(5) does not apply.

58 Subsection 22(2) (paragraphs (a) and (b) of the definition of Estore,steam,t)

Repeal the paragraphs, substitute:

(a)to production pathway is taken to be a reference to storage vessel delivery module; and

(b)to batch (b) is taken to be a reference to time period (t); and

59 Subsection 22(5) (paragraph (b) of the definition of Estore,elec,y)

Omit “, other than a reference to the batch in the parameter EFscope3,i in subsection 15(9)”.

60 Subsection 22(5) (paragraphs (b) and (c) of the definition of Estore,elec,y)

Repeal the paragraphs, substitute:

(b)the value of the parameter Qelec,ex,b in subsection 15(2) is taken to be zero; and

(c)subsection 15(5) does not apply.

61 Subsection 22(5) (definition of Estore,steam,y)

Omit “section 19”, substitute “section 18”.

62 Subsection 22(5) (paragraph (b) of the definition of Estore,steam,y)

Repeal the paragraph, substitute:

(b)to batch (b) is taken to be a reference to year (y); and

63 Subsection 25(1)

Omit “electrolysis production pathway”, substitute “hydrogen by electrolysis production pathway”.

64 Subsections 25(3) to (5)

Omit “electrolysis production pathway”, substitute “hydrogen by electrolysis production pathway”.

65 Paragraphs 25(4)(c) and (5)(c)

Omit “steam supply and use”, substitute “steam supply”.

66 Paragraph 25(4)(e)

Omit “fuel supply and use”, substitute “fuel supply and combustion”.

67 Subsection 25(5)

Omit “monitored, measured and reported in accordance with”, substitute “determined in accordance with”.

68 Paragraph 25(5)(e)

Omit “fuel supply and use”, substitute “fuel supply and combustion”.

69 Section 26

Repeal the section, substitute:

26 Optional modules—electrolysis #

The following are optional modules for the hydrogen by electrolysis production pathway:

(a)the intermediate storage tank production module for hydrogen;

(b)the gas conditioning production module.

Note: An optional module is a production module that forms part of the production pathway. All sources of emissions for the hydrogen by electrolysis production pathway, including for optional modules for that production pathway, are specified in subsection 25(4).

70 After Division 3.1.2 of Part 3.1 of Chapter 3

Insert:

26A Gas reforming production pathway #

(1)The hydrogen by gas reforming production pathway is a production pathway for hydrogen.

(2)The gas reforming production module is the process of chemically converting hydrocarbon feedstocks into hydrogen (H2) via thermal reforming processes using one of the following as an oxidising agent:

(a)steam;

(b)oxygen;

(c)both steam and oxygen.

(3)The gas reforming production module is a minimum module for the hydrogen by gas reforming production pathway.

(4)The following are sources of emissions for the hydrogen by gas reforming production pathway:

(a)electricity supply and use for the pathway;

(b)fuel supply and combustion for the pathway;

(c)feedstock supply for the pathway;

(d)steam supply for the pathway;

(e)synthetic gas use for the pathway;

(f)oxygen supply and use for the pathway;

(g)carbon containing feedstock use for the pathway.

(5)If a source of greenhouse gas emissions mentioned in subsection (4) exists for the hydrogen by gas reforming production pathway, the emissions from that source must be determined in accordance with the following:

(a)for electricity supply and use—section 15;

(b)for fuel supply and combustion—section 16;

(c)for feedstock supply—section 16A;

(d)for steam supply—section 18;

(e)for synthetic gas use—section 19;

(f)for oxygen supply and use—section 19A;

(g)for carbon containing feedstock use—section 19C.

Note: Section 16A only applies to feedstocks defined in that section: see the definition of feedstock in subsection 16A(2).

26B Optional modules—gas reforming #

The following are optional modules for the hydrogen by gas reforming production pathway:

(a)the intermediate storage tank production module for hydrogen;

(b)the gas conditioning production module.

Note: An optional module is a production module that forms part of the production pathway. All sources of emissions for the hydrogen by gas reforming production pathway, including for optional modules for that production pathway, are specified in subsection 26A(4).

26C Solid gasification and pyrolysis production pathway #

(1)The hydrogen by solid gasification and pyrolysis production pathway is a production pathway for hydrogen.

(2)The solid gasification and pyrolysis production module is the process of:

(a)thermochemically converting solid carbon-based matter into synthesis gas using a gasifier or pyrolyser; and

(b)refining hydrogen from the synthesis gas using all the following processes:

(i)cleaning the gas by removing particulate and contaminant matter;

(ii)shifting the gas by reacting cleaned synthesis gases with steam over a catalyst;

(iii)separation, purification and cooling of the resulting hydrogen from the processes mentioned in paragraphs (a) or (b).

(3)The solid gasification and pyrolysis production module is a minimum module for the hydrogen by solid gasification and pyrolysis production pathway.

(4)The following are sources of emissions for the hydrogen by solid gasification and pyrolysis production pathway:

(a)electricity supply and use for the pathway;

(b)fuel supply and combustion for the pathway;

(c)feedstock supply for the pathway;

(d)carbonates use for the pathway;

(e)steam supply for the pathway;

(f)synthetic gas use for the pathway;

(g)oxygen supply and use for the pathway;

(h)carbon containing feedstock use for the pathway.

Note: Pursuant to subsection 29(6) of the Act, a source of emissions relating to a production pathway for a product is a production emissions source for the production pathway.

(5)If a source of emissions mentioned in subsection (4) exists for the hydrogen by solid gasification and pyrolysis production pathway, the emissions from that source must be determined in accordance with the following:

(a)for electricity supply and use—section 15;

(b)for fuel supply and combustion—section 16;

(c)for feedstock supply—section 16A;

(d)for carbonates use—section 16B;

(e)for steam supply—section 18;

(f)for synthetic gas use—section 19;

(g)for oxygen supply and use—section 19A;

(h)for carbon containing feedstock use—section 19C.

Note: Section 16A only applies to feedstocks defined in that section: see the definition of feedstock in subsection 16A(2).

26D Optional modules—solid gasification and pyrolysis production pathway #

The following modules are optional modules for the hydrogen by solid gasification and pyrolysis production pathway:

(a)the feedstock pre-treatment production module;

(b)the intermediate storage tank production module for hydrogen;

(c)the gas conditioning production module.

Note: An optional module is a production module that forms part of the production pathway. All sources of emissions for the hydrogen by solid gasification and pyrolysis production pathway, including for optional modules, are specified in subsection 26C(4).

71 Paragraph 27(a)

Omit “electrolysis production pathway”, substitute “hydrogen by electrolysis production pathway”.

72 Subsection 29(2) (definition of SO2)

Omit “electrolysis production pathway”, substitute “hydrogen by electrolysis production pathway”.

73 Section 31

After “kilograms of CO2-e”, insert “per kilogram of hydrogen,”.

74 Subsection 34(1)

Omit the subsection, substitute:

(1)Each of the following methods for storing or transporting hydrogen is a delivery module for hydrogen:

(a)the pipeline delivery module;

(b)the vehicle delivery module;

(c)the storage vessel delivery module.

75 Subsection 34(3)

Omit “monitored, measured and reported in accordance with”, substitute “determined in accordance with”.

76 After Chapter 3

Insert:

Schedule 2 · Amendments

1 Section 4

Insert:

post-production product-specific attribute, for a production pathway, means an attribute mentioned in column 3 of an item in the table in Part 2 of Schedule 2 for the production pathway mentioned in column 2 of that item.

production emissions intensity has the same meaning as in the Future Made in Australia (Guarantee of Origin) Methodology Determination 2025.

product-specific attribute, for a production pathway, means an attribute mentioned in column 3 of an item in the table in Part 1 of Schedule 2 for the production pathway mentioned in column 2 of that item.

2 After section 5

Insert:

5A Production pathways—determination and attributes #

(1)If a provision of these rules mentions a production pathway for a product, the production pathway is the pathway in the methodology determination for the product.

(2)If a provision of these rules mentions a product attribute for a product for a production pathway, the terms used in that attribute have the same meaning as in the methodology determination for the production pathway.

Example: Part 1 of Schedule 2 provides that for the aluminium production pathway, a product-specific attribute for the pathway is whether or not the batch contains pre-consumer scrap aluminium. The Future Made in Australia (Guarantee of Origin) Methodology Determination 2025 determined the aluminium production pathway and in the relevant chapter of that methodology, defined pre-consumer scrap aluminium. The definition in the methodology applies to Schedule 2.

(3)In this section:

product attribute means a post-production product-specific attribute and a product-specific attribute.

3 Paragraph 25(1)(g)

Repeal the paragraph, substitute:

(g)if a product-specific attribute is specified for the production pathway—that attribute in accordance with subsection (3A).

4 After subsection 25(3)

Insert:

(3A)If a methodology determination specifies a formula or method for working out a product specific attribute of a product, the amount stated for the purposes of paragraph (1)(g) must be worked out in accordance with that formula or method.

5 Subsection 25(4) (definition of production emissions intensity)

Repeal the definition.

6 At the end of subsection 26(1)

Add:

; (h) if a post-production product-specific attribute is specified for the production pathway—that attribute.

7 After subsection 26(1)

Insert:

(1A)If a methodology determination specifies a formula or method for working out a post-production product specific attribute of a product, the amount stated for the purposes of paragraph (1)(h) must be worked out in accordance with that formula or method.

8 Subsection 52(3)

Repeal the subsection, substitute:

(3)If a REGO certificate is retired or an LGC is surrendered in respect of the creation of a REGO certificate, the created REGO certificate may also specify eligible renewable energy sources that relate to the retired or surrendered certificate.

9 Paragraph 59(4)(a)

Omit “productions”, substitute “production”.

10 Section 62

Repeal the section, substitute:

62 Fee-bearing activities—Act, subs 117(1), pars 118(a) and 118(c)#

(1)A person who makes an application or request mentioned in column 1 of an item in Table 62A is liable to pay the fee:

(a)mentioned in column 2 of the item for the fee-bearing activity mentioned in column 1 of that item; and

(b)at the time the application is made.

Table 62A
Item	Column 1	Column 2
	Fee-bearing activity	Amount
1	deciding an application for registration made under section 12 of the Act	$490
2	deciding an application made under section 74 of the Act to register an accredited power station the nameplate capacity of which is less than 10MW	$50
3	deciding an application made under section 74 of the Act to register an accredited power station the nameplate capacity of which is:(a) at least 10MW; but(b) not more than 25MW	$200
4	deciding an application made under section 74 of the Act to register an accredited power station the nameplate capacity of which is more than 25MW	$1,000
5	deciding an application made under section 75 of the Act to register an electricity generation system the nameplate capacity of which is less than 10MW	$50
6	deciding an application made under section 75 of the Act to register an electricity generation system the nameplate capacity of which is:(a) at least 10MW; but(b) not more than 25MW	$200
7	deciding an application made under section 75 of the Act to register an electricity generation system the nameplate capacity of which is more than 25MW	$1,000
8	deciding an application made under section 75 of the Act to register an energy storage system	$1,429
9	deciding an application made under section 104 of the Act to register a REGO certificate	$0.08

(2)A person who makes an application or request mentioned in a heading to columns 2 to 6 of an item in Table 62B is liable to pay the fee:

(a)mentioned in the column for the item for the production pathway mentioned in column 1 of that item; and

(b)at the time the application is made.

Table 62B
Item	Column 1	Column 2	Column 3	Column 4	Column 5	Column 6
	Production pathway	Production profile registration	Delivery profile registration	Consumption profile registration	Certificate registration	Consumption information addition
1	Aluminium production pathway	$2,162	$433	$433	$1	$0.40
2	Biogas by anaerobic digestion production pathway	$741	$370	$370	$1.78	$0.84
3	Biomethane by biogas upgrading production pathway	$741	$370	$370	$1.78	$0.84
4	Hydrogen by electrolysis production pathway	$2,647	$1,323	$1,323	$0.0021	$0.0012
5	Hydrogen by gas reforming production pathway	$721	$361	$361	$0.019	$0.014
6	Hydrogen by solid gasification and pyrolysis production pathway	$186	$93	$93	$0.16	$0.08
7	Iron ore production pathway	$3,219	$838	$838	$0.0039	$0.014

11 Section 67

Repeal the section, substitute:

67 Phasing-in charges for certain production pathways—Act, par 123(1)(b)#

(1)If a person is eligible for remission under a provision of Part 6.1 of Schedule 6 for a cost-recovery charge, the Regulator must remit an amount of the charge at or before the time it is payable.

(2)For the purposes of subsection (1), the amount of the charge that must be remitted is the amount represented by the percentage of the charge mentioned in column 1 of an item in the table in Part 6.2 of Schedule 6 if the charge is due and payable in the financial year beginning on the day mentioned in column 2 of that item.

(3)This section and Schedule 6 are repealed at the end of 30 June 2031.

12 Schedule 2

Repeal the Schedule, substitute:

(see paragraph 25(1)(g))

Item	Column 1	Column 2	Column 3
	Product	Production pathway	Attribute
1	Aluminium	Aluminium production pathway	(i) pre-consumer scrap aluminium; or(ii) post-consumer scrap aluminium; or(iii)pre-consumer scrap aluminium and post-consumer scrap aluminium;(i) the scope 1 carbon dioxide (CO2) emissions for the batch;(ii) the scope 1 tetrafluoromethane (CF4) emissions for the batch;(iii) the scope 1 hexafluoroethane (C2F6) emissions for the batch;(iv) the scope 2 carbon dioxide (CO2) emissions for the batch;(i) the type of alloying metal; and(ii) the amount of the alloying metal as a percentage of the total volume of the aluminium.
2	Hydrogen	All pathways	For gaseous hydrogen—the pressure in kilopascals; and for gaseous hydrogen or liquid hydrogen—the purity as a percentage of the total volume.
3	Hydrogen	Hydrogen by electrolysis production pathway	Each type of water used in the production pathway to produce the relevant batch of hydrogen; The quantity of water used to produce the relevant batch, in litres per kilogram of hydrogen in the batch.
4	Hydrogen	Hydrogen by gas reforming production pathway	Each type of gaseous hydrocarbon feedstock converted into hydrogen to produce the relevant batch. The quantity of each gaseous hydrocarbon feedstock converted into hydrogen to produce the relevant batch in gigajoules per kilogram of hydrogen in the batch.
5	Hydrogen	Hydrogen by solid gasification and pyrolysis production pathway	Each type of solid feedstock converted into hydrogen to produce the relevant batch. If native forestry residue is used as a feedstock—that fact. The quantity of each solid feedstock converted into hydrogen to produce the relevant batch in kilograms per kilogram of hydrogen in the batch. The biogenic carbon content percentage of each type of solid feedstock used to produce the batch.
6	Iron ore	Iron ore production pathway	Note: Types of mineral iron oxide include hematite, magnetite, pisolitic limonite or goethite.
7	Methane	Anaerobic digestion production pathway	The methane (CH4) content of the batch as a percentage of its total volume. The moisture content of the batch as a percentage of its total volume. The type of feedstock used to produce the batch (*input feedstock*). The percentage by mass of input feedstock derived from energy crops.
8	Methane	Biomethane by biogas upgrading production pathway	The methane (CH4) content of the batch as a percentage of its total volume. The moisture content of the batch as a percentage of its total volume. The type of feedstock used to produce the batch. The percentage by mass of input feedstock derived from energy crops.

Item	Column 1	Column 2	Column 3
	Product	Production pathway	Attribute
1	Iron ore	Iron ore production pathway	(i) represented as a percentage of the amount of iron ore that reached the delivery gate; and(ii) measured at the delivery gate for the product in accordance with section 9 of the Future Made in Australia (Guarantee of Origin) Methodology Determination 2025.

Note: The production pathways and attributes prescribed in this Schedule have the same meaning as in the Future Made in Australia (Guarantee of Origin) Methodology Determination 2025 (see section 5A).

13 Schedule 5, section 1.1 (heading)

Omit “sch 1”, substitute “sch 5”.

14 Schedule 6

Repeal the schedule, substitute:

Schedule 6—Phase-in remission

(see section 67)

Part 6.1—Eligibility for remission

1.1 General eligibility for remission #

(1)Subject to subclause (2), a person is eligible for remission of a cost-recovery charge if the charge is payable for one of the following:

(a)the registration of a production profile that specifies an eligible production pathway;

(b)the registration of a profile, the registration of which the Regulator is satisfied is to deliver or consume a product produced using an eligible production pathway;

(c)the registration of a certificate created by the holder of a production profile that specifies an eligible production pathway;

(d)the addition of consumption information to a certificate created by the holder of a production profile that specifies an eligible production pathway;

(e)a charge under the Charges Act payable in relation to an eligible profile.

(2)A charge payable in relation to a delivery profile or consumption profile is only eligible for remission if the Regulator is satisfied that product could reasonably pass from the production gate specified in a production profile that specifies an eligible production pathway to a delivery gate of the delivery profile or consumption profile.

(3)In this clause:

eligible production pathway means any one of the following production pathways determined for a product under section 29 of the Act:

(a)biogas by anaerobic digestion production pathway;

(b)biomethane by biogas upgrading production pathway;

(c)hydrogen by electrolysis production pathway;

(d)hydrogen by gas reforming production pathway;

(e)hydrogen by solid gasification and pyrolysis production pathway;

(f)aluminium production pathway;

(g)iron ore production pathway.

eligible profile means the following:

(a)a production profile that specifies an eligible production pathway;

(b)a delivery profile, the holder of which is authorised under section 54 of the Act to add post-production information to a certificate that was created by the holder of a production profile that specifies an eligible production pathway;

(c)a consumption profile, the holder of which is authorised under section 57 of the Act to add post-production information to a certificate that was created by the holder of a production profile that specifies an eligible production pathway.

Part 6.2—Amounts of phase-in remission

Remission amounts
Item	Column 1	Column 2
	Percentage of charge	Financial year beginning on
1	100%	1 July 2025
2	100%	1 July 2026
3	90%	1 July 2027
4	75%	1 July 2028
5	60%	1 July 2029
6	30%	1 July 2030

Sourced from the Federal Register of Legislation at legislation.gov.au, © Commonwealth of Australia, licensed under CC BY 4.0. Compilations may have been reformatted.