Federal Register of Legislation - Australian Government

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Determinations/Other as made
This Determination amends the National Greenhouse and Energy Reporting (Measurement) Determination 2008.
Administered by: Climate Change and Energy Efficiency
Registered 29 Jun 2010
Tabling HistoryDate
Tabled HR28-Sep-2010
Tabled Senate28-Sep-2010
Date of repeal 09 Aug 2013
Repealed by Industry, Innovation, Climate Change, Science, Research and Tertiary Education (Spent and Redundant Instruments) Repeal Regulation 2013

National Greenhouse and Energy Reporting (Measurement) Amendment Determination 2010 (No. 1)1

National Greenhouse and Energy Reporting Act 2007

I, PENELOPE YING YEN WONG, Minister for Climate Change, Energy Efficiency and Water, make this Determination under subsection 10 (3) of the National Greenhouse and Energy Reporting Act 2007.

Dated 24 June 2010

PENELOPE YING YEN WONG


1              Name of Determination

                This Determination is the National Greenhouse and Energy Reporting (Measurement) Amendment Determination 2010 (No. 1).

2              Commencement

                This Determination commences on the day after it is registered.

3              Amendment of National Greenhouse and Energy Reporting (Measurement) Determination 2008

                Schedule 1 amends the National Greenhouse and Energy Reporting (Measurement) Determination 2008.

4              Application

                The amendments made by Schedule 1 apply in relation to the 2010–2011 financial year and to later financial years.


Schedule 1        Amendments

(section 3)

  

[1]           Section 1.8, definition of API Compendium

substitute

API Compendium means the document known as the Compendium of Greenhouse Gas Emissions Methodologies for the Oil and Gas Industry, 2004, published by the American Petroleum Institute.

[2]           Section 1.8, after definition of calibrated to a measurement requirement

insert

captured for permanent storage, in relation to carbon dioxide, has the meaning given by section 1.19A.

carbon dioxide stream means a stream of gaseous substances that consists overwhelmingly of carbon dioxide that is captured for permanent storage.

[3]           Section 1.8, after definition of feedstock

insert

ferroalloy has the meaning given by subsection 4.69 (2).

[4]           Section 1.8, after definition of Regulations

insert

relevant person means a person mentioned in paragraph 1.19A (a), (b), (c), (d), (e) or (f).

[5]           Subsection 1.9 (4)

omit

2009

insert

2010

[6]           After Division 1.2.2

insert

Division 1.2.3        Requirements in relation to carbon capture and storage

1.19A      Meaning of captured for permanent storage

                For this Determination, carbon dioxide is captured for permanent storage only if it is captured by, or transferred to:

                (a)    the registered holder of a greenhouse gas injection licence under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 for the purpose of being injected into an identified greenhouse gas storage formation under the licence in accordance with that Act; or

               (b)    the holder of an injection and monitoring licence under the Greenhouse Gas Geological Sequestration Act 2008 (Vic) for the purpose of being injected into an underground geological formation under the licence in accordance with that Act; or

                (c)    the registered holder of a greenhouse gas injection licence under the Offshore Petroleum and Greenhouse Gas Storage Act 2010 (Vic) for the purpose of being injected into an identified greenhouse gas storage formation under the licence in accordance with that Act; or

               (d)    the holder of a GHG injection and storage lease under the Greenhouse Gas Storage Act 2009 (Qld) for the purpose of being injected into a GHG stream storage site under the lease in accordance with that Act; or

                (e)    the holder of an approval under the Barrow Island Act 2003 (WA) for the purpose of being injected into an underground reservoir or other subsurface formation in accordance with that Act; or

                (f)    the holder of a gas storage licence under the Petroleum and Geothermal Energy Act 2000 (SA) for the purpose of being injected into a natural reservoir under the licence in accordance with that Act.

1.19B     Deducting carbon dioxide that is captured for permanent storage

         (1)   If a provision of this Determination provides that an amount of carbon dioxide that is captured for permanent storage may be deducted in the estimation of emissions under the provision, then the amount of carbon dioxide may be deducted only if:

                (a)    the carbon dioxide that is captured for permanent storage is captured by, or transferred to, a relevant person; and

               (b)    the amount of carbon dioxide that is captured for permanent storage is estimated in accordance with section 1.19E; and

                (c)    the relevant person issues a written certificate that complies with subsection (2).

         (2)   The certificate must specify:

                (a)    if the carbon dioxide is captured by the relevant person and is neither transferred to the relevant person nor transferred by the relevant person to another person — the following information:

                          (i)    the amount of carbon dioxide captured by the relevant person;

                         (ii)    the volume of the carbon dioxide stream containing the captured carbon dioxide;

                         (iii)    the concentration of carbon dioxide in the stream; or

               (b)    if the carbon dioxide is transferred to the relevant person — the following information:

                          (i)    the amount of carbon dioxide that was transferred to the relevant person;

                         (ii)    the volume of the carbon dioxide stream containing the transferred carbon dioxide;

                         (iii)    the concentration of carbon dioxide in the stream.

         (3)   The amount of carbon dioxide that may be deducted is the amount specified in the certificate under paragraph (1) (c).

1.19C     Capture from facility with multiple sources jointly generated

                If, during the operation of a facility, more than 1 source generates carbon dioxide, the total amount of carbon dioxide that may be deducted in relation to the facility is to be attributed:

                (a)    if it is possible to determine the amount of carbon dioxide that is captured for permanent storage from each source — to each source from which the carbon dioxide is captured according to the amount captured from the source; or

               (b)    if it is not possible to determine the amount of carbon dioxide captured for permanent storage from each source — to the main source that generated the carbon dioxide that is captured during the operation of the facility.

1.19D     Capture from a source where multiple fuels consumed

                If more than 1 fuel is consumed for a source that generates carbon dioxide that is captured for permanent storage, the total amount of carbon dioxide that may be deducted in relation to the source is to be attributed to each fuel consumed in proportion to the carbon content of the fuel relative to the total carbon content of all fuel consumed for that source.

1.19E      Measure of quantity of carbon dioxide captured

         (1)   For paragraph 1.19B (1) (b), the amount of captured carbon dioxide must be estimated in accordance with this section.

         (2)   The volume of the carbon dioxide stream containing the captured carbon dioxide must be estimated:

                (a)    if the carbon dioxide stream is transferred to a relevant person — using:

                          (i)    criterion A in section 1.19F; or

                         (ii)    criterion AAA in section 1.19G; or

               (b)    if the carbon dioxide stream is captured by the relevant person and is neither transferred to the relevant person nor transferred by the relevant person to another person — using:

                          (i)    criterion AAA in section 1.19G; or

                         (ii)    criterion BBB in section 1.19N.

         (3)   The carbon dioxide stream must be sampled in accordance with ISO 10715:1997, or an equivalent standard.

         (4)   The concentration of carbon dioxide in the carbon dioxide stream must be analysed in accordance with the following parts of ISO 6974 or an equivalent standard:

                (a)    Part 1 (2000);

               (b)    Part 2 (2001);

                (c)    Part 3 (2000);

               (d)    Part 4 (2000);

                (e)    Part 5 (2000);

                (f)    Part 6 (2002).

         (5)   The volume of the carbon dioxide stream must be expressed in cubic metres.

         (6)   The carbon dioxide stream must be analysed for concentration of carbon dioxide on at least a monthly basis.

1.19F      Volume of carbon dioxide stream — criterion A

         (1)   For subparagraph 1.19E (2) (a) (i), criterion A is the volume of the carbon dioxide stream that is:

                (a)    transferred to the relevant person during the year; and

               (b)    specified in a certificate issued by the relevant person under paragraph 1.19B (1) (c).

         (2)   The volume specified in the certificate must be accurate and must be evidenced by invoices issued by the relevant person.

1.19G     Volume of carbon dioxide stream — criterion AAA

         (1)   For subparagraphs 1.19E (2) (a) (ii) and (b) (i), criterion AAA is the measurement during the year of the captured carbon dioxide stream from the operation of a facility at the point of capture.

         (2)   In measuring the quantity of the carbon dioxide stream at the point of capture, the quantity of the carbon dioxide stream must be measured:

                (a)    using volumetric measurement in accordance with:

                          (i)    for a carbon dioxide stream that is not supercompressed — section 1.19H; and

                         (ii)    for a supercompressed carbon dioxide stream — section 1.19I; and

               (b)    using gas measuring equipment that complies with section 1.19J.

         (3)   The measurement must be carried out using measuring equipment that:

                (a)    is in a category specified in column 2 of an item in the table in subsection (4) according to the maximum daily quantity of the carbon dioxide stream captured specified in column 3 for that item from the operation of the facility; and

               (b)    complies with the transmitter and accuracy requirements for that equipment specified in column 4 for that item.

         (4)   For subsection (3), the table is as follows.

Item

Gas measuring equipment category

Maximum daily quantity of carbon dioxide stream cubic metres/day

Transmitter and accuracy requirements (% of range)

1

1

0–50 000

Pressure <±0.25%

Diff. pressure <±0.25%

Temperature <±0.50%

2

2

50 001–100 000

Pressure <±0.25%

Diff. pressure <±0.25%

Temperature <±0.50%

3

3

100 001–500 000

Smart transmitters:

Pressure <±0.10%

Diff. pressure <±0.10%

Temperature <±0.25%

4

4

500 001 or more

Smart transmitters:

Pressure <±0.10%

Diff. pressure <±0.10%

Temperature <±0.25%

1.19H     Volumetric measurement — carbon dioxide stream not super‑compressed

         (1)   For subparagraph 1.19G (2) (a) (i), volumetric measurement of a carbon dioxide stream that is not super-compressed must be in cubic metres at standard conditions.

         (2)   The volumetric measurement is to be calculated using a flow computer that measures and analyses flow signals and relative density:

                (a)    if the carbon dioxide stream is captured by the relevant person and is neither transferred to the relevant person nor transferred by the relevant person to another person — at the point of capture of the carbon dioxide stream; or

               (b)    if the carbon dioxide stream is transferred to a relevant person — at the point of transfer of the carbon dioxide stream.

         (3)   The volumetric flow rate must be continuously recorded and integrated using an integration device that is isolated from the flow computer in such a way that if the computer fails, the integration device will retain the last reading, or the previously stored information, that was on the computer immediately before the failure.

         (4)   Subject to subsection (5), all measurements, calculations and procedures used in determining volume (except for any correction for deviation from the ideal gas law) must be made in accordance with the instructions contained in the following:

                (a)    for orifice plate measuring systems — the publication entitled American Gas Report No. 3 published by the American Gas Association or Parts 1 to 4 of the publication entitled API 14.3 published by the American Petroleum Institute;

               (b)    for turbine measuring systems — the publication entitled American Gas Association Transmission Measurement Committee Report No. 7 published by the American Gas Association;

                (c)    for positive displacement measuring systems — ANSI B109.3—2000.

         (5)   Measurements, calculations and procedures used in determining volume may also be made in accordance with an equivalent internationally recognised documentary standard or code.

         (6)   Measurements must comply with units of measurement required by or under the National Measurement Act 1960.

1.19I       Volumetric measurement — supercompressed carbon dioxide stream

         (1)   For subparagraph 1.19G (2) (a) (ii), volumetric measurement of a super-compressed carbon dioxide stream must be in accordance with this section.

         (2)   If, in determining volume in relation to the supercompressed carbon dioxide stream, it is necessary to correct for deviation from the ideal gas law, the correction must be determined using the relevant method contained in the publication entitled American Gas Association Transmission Measurement Committee Report No. 8 (1992) Super‑compressibility published by the American Gas Association.

         (3)   The measuring equipment used must calculate super‑compressibility by:

                (a)    if the measuring equipment is category 3 or 4 equipment in accordance with column 2 the table in subsection 1.19G (4) — using composition data; or

               (b)    if the measuring equipment is category 1 or 2 equipment in accordance with column 2 of the table in subsection 1.19G (4) — using an alternative method set out in the publication entitled American Gas Association Transmission Measurement Committee Report No. 8 (1992) Super‑compressibility published by the American Gas Association.

1.19J      Gas measuring equipment — requirements

                For paragraph 1.19G (2) (b), gas measuring equipment that is category 3 or 4 equipment in accordance with column 2 of the table in subsection 1.19G (4) must comply with the following requirements:

                (a)    if the equipment uses flow devices — the requirements relating to flow devices set out in section 1.19K;

               (b)    if the equipment uses flow computers — the requirement relating to flow computers set out in section 1.19L;

                (c)    if the equipment uses gas chromatographs— the requirements relating to chromatographs set out in section 1.19M.

1.19K     Flow devices — requirements

         (1)   If the measuring equipment has flow devices that use orifice measuring systems, the flow devices must be constructed in a manner that ensures that the maximum uncertainty of the discharge coefficient is not greater than ±1.5%.

Note   The publication entitled American Gas Association Report No. 3, published by the American Gas Association, sets out a manner that ensures that the maximum uncertainty of the discharge coefficient is not greater than ±1.5%.

         (2)   If the measuring equipment has flow devices that use turbine measuring systems, the flow devices must be installed in a manner that ensures that the maximum uncertainty of the flow measurement is not greater than ±1.5%.

Note   The publication entitled American Gas Association Transmission Measurement Committee Report No. 8 (1992) Super‑compressibility, published by the American Gas Association, sets out a manner that ensures that the maximum uncertainty of the flow measurement is not greater than ±1.5%.

         (3)   If the measuring equipment has flow devices that use positive displacement measuring systems, the flow devices must be installed in a manner that ensures that the maximum uncertainty of flow is ±1.5%.

Note   ANSI B109.3—2000 sets out a manner for installation that ensures that the maximum uncertainty of flow is ±1.5%.

         (4)   If the measuring equipment uses any other type of flow device, the maximum uncertainty of flow measurement must not be greater than ±1.5%.

         (5)   All flow devices that are used by measuring equipment of a category specified in column 2 of the table in subsection 1.19G (4) must, wherever possible, be calibrated for pressure, differential pressure and temperature in accordance with the requirements specified in column 4 for the category of equipment specified in column 2 for that item. The calibrations must take into account the effects of static pressure and ambient temperature.

1.19L      Flow computers — requirements

                For paragraph 1.19J (b), the requirement is that the flow computer that is used by the equipment for measuring purposes must record the instantaneous values for all primary measurement inputs and must also record the following outputs:

                (a)    instantaneous corrected volumetric flow;

               (b)    cumulative corrected volumetric flow;

                (c)    for turbine and positive displacement metering systems — instantaneous uncorrected volumetric flow;

               (d)    for turbine and positive displacement metering systems — cumulative uncorrected volumetric flow;

                (e)    super‑compressibility factor.

1.19M     Gas chromatographs

                For paragraph 1.19J (c), the requirements are that gas chromatographs used by the measuring equipment must:

                (a)    be factory tested and calibrated using a measurement standard produced by gravimetric methods and traceable to Australian units of measurement required by or under the National Measurement Act 1960; and

               (b)    perform gas composition analysis with an accuracy of ±0.25% for calculation of relative density; and

                (c)    include a mechanism for re‑calibration against a certified reference gas.

1.19N     Volume of carbon dioxide stream — criterion BBB

                For subparagraph 1.19E (2) (b) (ii), criterion BBB is the estimation of the volume of the captured carbon dioxide stream from the operation of the facility during a year measured in accordance with industry practice if the equipment used to measure the volume of the captured carbon dioxide stream does not meet the requirements of criterion AAA.

Note   An estimate obtained using industry practice must be consistent with the principles in section 1.13.

[7]           Subsection 2.5 (1), formula

substitute

[8]           Subsection 2.5 (1), after definition of EFico2oxec

insert

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[9]           Subsection 2.6 (1), formula

substitute

[10]         Subsection 2.6 (1), after definition of EFico2oxec

insert

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[11]         Subsection 2.20 (1), definition of Qi

after

combusted

insert

, whether for stationary energy purposes or transport energy purposes,

[12]         Subsection 2.20 (1), definition of EFijoxec

omit

as mentioned in Part 2 of Schedule 1.

insert

as mentioned in:

        (a)    for stationary energy purposes — Part 2 of Schedule 1; and

        (b)    for transport energy purposes — Division 4.1 of Schedule 1.

[13]         After subsection 2.20 (1)

insert

         (2)   In this section:

stationary energy purposes means purposes for which fuel is combusted that do not involve transport energy purposes.

transport energy purposes includes purposes for which fuel is combusted that consist of any of the following:

                (a)    transport by vehicles registered for road use;

               (b)    rail transport;

                (c)    marine navigation;

               (d)    air transport.

Note   The combustion of gaseous fuels releases emissions of carbon dioxide, methane and nitrous oxide.

[14]         Subsection 2.21 (1), formula

substitute

[15]         Subsection 2.21 (1), definition of Ei,CO2

substitute

EiCO2 is emissions of carbon dioxide released from fuel type (i) combusted from the operation of the facility during the year measured in CO2‑e tonnes.

[16]         Subsection 2.21 (1), definition of EFiCO2ox,ec

substitute

EFiCO2oxec is the carbon dioxide emission factor for fuel type (i) measured in kilograms CO2‑e per gigajoule and calculated in accordance with section 2.22.

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[17]         Subsection 2.22 (1)

omit

factor EFi,CO2,ox,ec

insert

factor EFiCO2oxec

[18]         Subsection 2.22 (1)

omit

estimate EFi,CO2,,ox,kg

insert

estimate EFi,CO2,ox,kg

[19]         Subsection 2.22 (4)

omit

factor EFi CO2,ox,ec

insert

factor EFiCO2oxec

[20]         Subsection 2.22 (4), formula

substitute

[21]         Section 2.25, table, item 2, column 2

substitute

All other gases (including fugitive emissions)

[22]         Paragraph 2.32 (4) (c)

omit

ANSI B109.3 — 1986

insert

ANSI B109.3 — 2000

[23]         Subsection 2.35 (3), note

omit

ANSI B109.3 — 1986

insert

ANSI B109.3 — 2000

[24]         Subsection 2.41 (2), definition of transport energy purposes

substitute

transport energy purposes includes purposes for which fuel is combusted that consist of any of the following:

                (a)    transport by vehicles registered for road use;

               (b)    rail transport;

                (c)    marine navigation;

               (d)    air transport.

[25]         Subsection 2.42 (1), formula

substitute

[26]         Subsection 2.42 (1), definition of Ei,CO2

substitute

EiCO2 is the emissions of carbon dioxide released from the combustion of fuel type (i) from the operation of the facility during the year measured in CO2‑e tonnes.

[27]         Subsection 2.42 (1), definition of EFiCO2ox,ec

substitute

EFiCO2oxec is the carbon dioxide emission factor for fuel type (i) measured in kilograms of CO2‑e per gigajoule.

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[28]         Subsection 2.43 (1)

omit

factor EFiCO2ox,ec

insert

factor EFi,CO2,ox,ec

[29]         Subsection 2.45 (1), table, item 3, column 5

after

ASTM D 1298 – 99 (2005)

insert

ASTM D 5002 – 99 (2005)

[30]         Subsection 2.45 (1), table, item 7, column 5

after

ASTM D 1298 – 99 (2005)

insert

ASTM D 4052 – 96 (2002) e1

[31]         Subsection 2.45 (1), table, item 8, column 5

after

ASTM D 1298 – 99 (2005)

insert

ASTM D 4052 – 96 (2002) e1

[32]         Subsection 2.45 (1), table, item 14, column 5

after

ISO 8973:1997

insert

ASTM D 1657 – 02

[33]         Section 2.51

omit

2.50 (b)

insert

2.50 (2) (b)

[34]         Subsection 2.52 (1)

omit

2.50 (c)

insert

2.50 (2) (c)

[35]         Section 2.53

omit

2.50 (d)

insert

2.50 (4) (b)

[36]         Subsection 2.62 (1)

omit

Method 2 is the same as method 1

insert

Subject to subsections (2) and (3), method 2 is the same as method 1 under section 2.61

[37]         After subsection 2.62 (2)

insert

         (3)   In applying method 1 as method 2, step 4 in section 2.61 is to be omitted and the following step 4 substituted:

Step 4

Calculate the carbon content in the amount of the increase in stocks of inputs, products and waste by-products held within the boundary of the activity during the year as follows:

where:

Si has the same meaning as in step 1.

CCFi has the same meaning as in step 1.

ΔSqi is the increase in stocks of fuel type (i) for the activity and held within the boundary of the activity during the year measured in tonnes.

Sp has the same meaning as in step 2.

CCFp has the same meaning as in step 2.

ΔSap is the increase in stocks of products produced (p) by the activity and held within the boundary of the activity during the year measured in tonnes.

Sr has the same meaning as in step 3.

CCFr has the same meaning as in step 3.

ΔSyr is the increase in stocks of waste by-products (r) produced by the activity and held within the boundary of the activity during the year measured in tonnes.

α is the factor  for converting the mass of carbon dioxide to a mass of carbon.

γ is the factor 1.861 x 10-3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2-e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[38]         Subsection 2.63 (1)

omit

Method 3 is the same as method 1

insert

Subject to subsections (2) and (3), method 3 is the same as method 1 in section 2.61

[39]         After subsection 2.63 (2)

insert

         (3)   In applying method 1 as method 3, step 4 in section 2.61 is to be omitted and the following step 4 substituted.

Step 4

Calculate the carbon content in the amount of the increase in stocks of inputs, products and waste by-products held within the boundary of the activity during the year as follows:

where:

Si has the same meaning as in step 1.

CCFi has the same meaning as in step 1.

ΔSqi is the increase in stocks of fuel type (i) for the activity and held within the boundary of the activity during the year measured in tonnes.

Sp has the same meaning as in step 2.

CCFp has the same meaning as in step 2.

ΔSap is the increase in stocks of products produced (p) by the activity and held within the boundary of the activity during the year measured in tonnes.

 

Sr has the same meaning as in step 3.

CCFr has the same meaning as in step 3.

ΔSyr is the increase in stocks of waste by-products (r) produced by the activity and held within the boundary of the activity during the year measured in tonnes.

α is the factor  for converting the mass of carbon dioxide to a mass of carbon.

γ is the factor 1.861 x 10-3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2-e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[40]         Chapter 3, heading

substitute

Chapter 3    Fugitive emissions

  

[41]         Section 3.1

substitute

3.1           Outline of Chapter

                This Chapter provides for fugitive emissions from the following:

                (a)    coal mining (see Part 3.2);

               (b)    oil and natural gas (see Part 3.3);

                (c)    carbon capture and storage (see Part 3.4).

[42]         After subsection 3.22 (2)

insert

         (3)   In subsection (1), ∑Qijtr applies to carbon dioxide only if the carbon dioxide is captured for permanent storage.

Note   Division 1.2.3 contains a number of requirements in relation to deductions of carbon dioxide captured for permanent storage.

[43]         Subsection 3.32 (1), definition of Fdm

substitute

Fdm is the proportion of the mine flooded at the end of the year, as estimated under section 3.34, and must not be greater than 1.

[44]         Section 3.34

substitute

3.34        Measurement of proportion of mine that is flooded

                For subsection 3.32 (1), Fdm is:

where:

MWI is the rate of water flow into the mine in cubic metres per year as measured under section 3.35.

MVV is the mine void volume in cubic metres as measured under section 3.36.

years is the number of years since the mine was decommissioned.

[45]         Before section 3.42

insert

Subdivision 3.3.2.1     Preliminary

[46]         Section 3.42

omit

from flaring

insert

from venting or flaring

[47]         After section 3.42

insert

Subdivision 3.3.2.2     Oil or gas exploration (flared) emissions

[48]         After section 3.46 in Division 3.3.2

insert

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

3.46A      Available methods

                Subject to section 1.18, method 1 under section 3.84 must be used for estimating fugitive emissions that result from system upsets, accidents and deliberate releases from process vents during a year from the operation of a facility that is constituted by oil or gas exploration.

Note   There is no method 2, 3 or 4 for this Division.

[49]         Subdivision 3.3.3.2, heading

substitute

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

[50]         Subsection 3.48 (1)

omit

methane, other than from oil or gas flaring,

insert

methane, other than fugitive emissions of methane specified in subsection (1A),

[51]         After subsection 3.48 (1)

insert

      (1A)   For subsection (1), the following fugitive emissions of methane are specified:

                (a)    fugitive emissions from oil or gas flaring;

               (b)    fugitive emissions that result from system upsets, accidents or deliberate releases from process vents.

[52]         After subsection 3.49 (2)

insert

         (3)   For EF(l) ij in subsection (1), general leaks in the crude oil production comprise the emissions (other than vent emissions) from equipment listed in sections 5.4.3, 5.6.4 and 6.1.2 of the API Compendium, if the equipment is used in the crude oil production.

[53]         Subsection 3.50 (1), definitions of Σk, Qik and EFijk

omit

sections 5

insert

sections 5.4.1, 5.4.2, 5.4.3, 5.6.4

[54]         Paragraph 3.50 (2) (a)

omit

sections 5

insert

sections 5.4.1, 5.4.2, 5.4.3, 5.6.4

[55]         Section 3.56, heading

substitute

3.56        Method 2 — crude oil production (flared) emissions of methane

[56]         After Subdivision 3.3.3.3 in Division 3.3.3

insert

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

3.56A      Available methods

                Subject to section 1.18, method 1 under section 3.84 must be used for estimating fugitive emissions that result from system upsets, accidents and deliberate releases from process vents during a year from the operation of a facility that is constituted by crude oil production.

Note   There is no method 2, 3 or 4 for this Subdivision.

[57]         After subsection 3.72 (2)

insert

         (3)   For EF(l) ij in subsection (1), general leaks in the natural gas production and processing comprise the emissions (other than vent emissions) from equipment listed in sections 5.4.3, 5.6.4 and 6.1.2 of the API Compendium, if the equipment is used in the natural gas production and processing.

[58]         Subsection 3.73 (1), definitions of Σk,, Qik and EFijk

omit

sections 5

insert

sections 5.4.1, 5.4.2, 5.4.3, 5.6.4

[59]         Paragraph 3.73 (2) (a)

omit

sections 5

insert

sections 5.4.1, 5.4.2, 5.4.3, 5.6.4

[60]         Subsection 3.83 (2)

omit

of methane

[61]         Section 3.84

substitute

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

                Method 1 is, for a process mentioned in column 2 of an item in the following table, as described in the section of the API Compendium mentioned in column 3 for the item.

Item

Emission process

API Compendium section

1

Gas treatment processes

Section 5.1

2

Cold process vents

Section 5.3

3

Natural gas blanketed tank emissions

Section 5.4.4

4

Other venting sources  — gas driven pneumatic devices

Section 5.6.1

5

Other venting sources — gas driven chemical injection pumps

Section 5.6.2

6

Other venting sources — exploratory drilling and well testing

Section 5.6.3

7

Non-routine activities — production related non-routine emissions

Section 5.7.1 or 5.7.2

8

Non-routine activities — gas processing related non-routine emissions

Section 5.7.1 or 5.7.3

[62]         After Part 3.3

insert

Part 3.4              Carbon capture and storage — fugitive emissions

Division 3.4.1        Preliminary

3.88        Outline of Part

                This Part provides for fugitive emissions from carbon capture and storage.

Division 3.4.2        Transport of captured carbon dioxide

Subdivision 3.4.2.1     Preliminary

3.89        Application

                This Division applies to fugitive emissions from the transport of carbon dioxide captured for permanent storage.

Note   Section 1.19A defines when carbon dioxide is captured for permanent storage.

3.90        Available methods

         (1)   Subject to section 1.18, for estimating emissions released during a year from the operation of a facility that is constituted by the transport of carbon dioxide captured for permanent storage the methods as set out in this section must be used.

Emissions from transport of carbon dioxide involving transfer

         (2)   If the carbon dioxide is transferred to a relevant person for injection in accordance with the legislation mentioned in section 1.19A for the person, method 1 under section 3.91 must be used for estimating fugitive emissions of carbon dioxide that result from the transport of the carbon dioxide for that injection.

Emissions from transport of carbon dioxide not involving transfer

         (3)   If:

                (a)    the carbon dioxide is captured by a relevant person for injection in accordance with the legislation mentioned in section 1.19A for the person; and

               (b)    the carbon dioxide is not transferred to another person for the purpose of injection;

then method 1 under section 3.92 must be used for estimating fugitive emissions of carbon dioxide that result from the transport of the carbon dioxide for that injection.

Note   There is no method 2, 3 or 4 for subsections (2) and (3).

         (4)   However, for incidental emissions another method may be used that is consistent with the principles in section 1.13.

Subdivision 3.4.2.2     Emissions from transport of carbon dioxide captured for permanent storage involving transfer

3.91        Method 1 — emissions from transport of carbon dioxide involving transfer

                For subsection 3.90 (2), method 1 is:

where:

ECO2 is the emissions of carbon dioxide during the year from transportation of carbon dioxide captured for permanent storage to the storage site, measured in CO2‑e tonnes.

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is the quantity of carbon dioxide transferred during the year worked out under Division 1.2.3  and measured in cubic metres at standard conditions of pressure and temperature.

Qinj is the quantity of carbon dioxide injected into the storage site during the year and measured in cubic metres at standard conditions of pressure and temperature.

Subdivision 3.4.2.2     Emissions from transport of carbon dioxide captured for permanent storage not involving transfer

3.92        Method 1 — emissions from transport of carbon dioxide not involving transfer

                For subsection 3.90 (3), method 1 is:

where:

ECO2 is the emissions of carbon dioxide during the year from transportation of carbon dioxide captured for permanent storage to the storage site, measured in CO2‑e tonnes.

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is the quantity of carbon dioxide captured during the year worked out under Division 1.2.3  and measured in cubic metres at standard conditions of pressure and temperature.

Qinj is the quantity of carbon dioxide injected into the storage site during the year and measured in cubic metres at standard conditions of pressure and temperature.

[63]         Section 4.5

substitute

4.5           Method 2 — cement clinker production

         (1)   Method 2 is:

where:

Eij is the emissions of carbon dioxide (j) released from the production of cement clinker (i) during the year measured in CO2‑e tonnes.

EFij is as set out in subsection (2).

EFtoc,j is 0.010, which is the carbon dioxide (j) emission factor for carbon‑bearing non‑fuel raw material, measured in tonnes of emissions of carbon dioxide per tonne of cement clinker produced.

Ai is the quantity of cement clinker (i) produced during the year measured in tonnes and estimated under Division 4.2.5.

Ackd is the quantity of cement kiln dust produced as a result of the production of cement clinker during the year, measured in tonnes and estimated under Division 4.2.5.

Fckd is:

                (a)    the degree of calcination of cement kiln dust produced as a result of the production of cement clinker during the year, expressed as a decimal fraction; or

               (b)    if the information mentioned in paragraph (a) is not available — the value 1.

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

         (2)   For subsection (1), EFij is:

where:

FCaO is the estimated fraction of cement clinker that is calcium oxide derived from carbonate sources and produced from the operation of the facility.

FMgO is the estimated fraction of cement clinker that is magnesium oxide derived from carbonate sources and produced from the operation of the facility.

Note   The molecular weight ratio of carbon dioxide to calcium oxide is 0.785, and the molecular weight ratio of carbon dioxide to magnesium oxide is 1.092.

         (3)   The cement clinker must be sampled and analysed in accordance with sections 4.6 and 4.7.

[64]         Subsection 4.8 (1), step 1, formula

substitute

[65]         Subsection 4.8 (1), step 1, after definition of EFtoc

insert

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[66]         Subsections 4.14 (1) and (2)

substitute

         (1)   Method 2 is:

where:

Eij is the emissions of carbon dioxide (j) released from the production            of lime (i) during the year measured in CO2‑e tonnes.

Ai is the quantity of lime produced during the year measured in tonnes            and estimated under Division 4.2.5.

EFij is worked out using the following formula:

where:

Fi is the estimated fractional purity of lime.

Note   44.01 is the molecular weight of carbon dioxide, and 56.08 is the molecular weight of calcium oxide.

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[67]         Subsection 4.17 (1), step 1, formula

substitute

[68]         Subsection 4.17 (1), step 1, definition of EFij, paragraph (d)

omit

Tier 3 of Part 1

insert

section 2.1 of Chapter 2

[69]         Subsection 4.17 (1), step 1, after definition of Flkd

insert

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[70]         Section 4.20

substitute

4.20        Application

                This Division applies to emissions of carbon dioxide from the consumption of a carbonate (other than soda ash) but does not apply to:

                (a)    emissions of carbon dioxide from the calcination of a carbonate in the production of cement clinker; or

               (b)    emissions of carbon dioxide from the calcination of a carbonate in the production of lime; or

                (c)    emissions of carbon dioxide from the calcination of a carbonate in the process of production of soda ash; or

               (d)    emissions from the consumption of carbonates following their application to soil.

Examples of activities involving the consumption of carbonates

1   Metallurgy.

2   Glass manufacture, including fibreglass and mineral wools.

3   Magnesia production.

4   Construction.

5   Environment pollution control.

6   Use as a flux or slagging agent.

7   In-house production of lime in the metals industry.

[71]         Subsection 4.23 (1), step 1, formula

substitute

[72]         Subsection 4.23 (1), step 1, after definition of Fcal

insert

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[73]         Section 4.26

substitute

4.26        Application

                This Division applies to emissions from the use of soda ash and emissions of carbon dioxide from the chemical transformation of calcium carbonate, sodium chloride, ammonia and coke into sodium bicarbonate and soda ash.

Examples of uses of soda ash in industrial processes

1   Glass production.

2   Soap and detergent production.

3   Flue gas desulphurisation.

4   Pulp and paper production.

[74]         Subsection 4.30 (1)

omit

constituted by the production of

insert

that is constituted by an activity that produces

[75]         Sections 4.31 to 4.33

substitute

4.31        Method 1 — production of soda ash

                Method 1 is:

Step 1

Calculate the carbon content in fuel type (i) or carbonate material (j) delivered for the activity during the year measured in tonnes of carbon as follows:

 

where:

i means sum the carbon content values obtained for all fuel types (i).

CCFi is the carbon content factor mentioned in Schedule 3 measured in tonnes of carbon for each appropriate unit of fuel type (i) consumed during the year from the operation of the activity.

Qi is the quantity of fuel type (i) delivered for the activity during the year measured in an appropriate unit and estimated in accordance with Division 2.2.5, 2.3.6 and 2.4.6.

 

j means sum the carbon content values obtained for all pure carbonate material (j).

 

CCFj is the carbon content factor mentioned in Schedule 3 measured in tonnes of carbon for each tonne of pure carbonate material (j) consumed during the year from the operation of the activity.

Fj is the fraction of pure carbonate material (j) in the raw carbonate input material and taken to be 0.97 for calcium carbonate and 0.018 for magnesium carbonate.

L j is the quantity of raw carbonate input material (j) delivered for the activity during the year measured in tonnes and estimated in accordance with Division 4.2.5.

Step 2

Calculate the carbon content in products (p) leaving the activity during the year measured in tonnes of carbon as follows:

where:

p means sum the carbon content values obtained for all product types (p).

CCFp is the carbon content factor mentioned in Schedule 3 and measured in tonnes of carbon for each tonne of product type (p) produced during the year.

Fp is the fraction of pure carbonate material in the product type (p).

Ap is the quantity of product types (p) produced leaving the activity during the year measured in tonnes.

Step 3

Calculate the carbon content in waste by‑product types (r) leaving the activity, other than as an emission of greenhouse gas, during the year, measured in tonnes of carbon, as follows:

where:

Sr means sum the carbon content values obtained for all waste by‑product types (r).

CCFr is the carbon content factor mentioned in Schedule 3 measured in tonnes of carbon for each tonne of waste by‑product types (r).

Fr is the fraction of pure carbonate material in the waste by‑product types (r).

Yr is the quantity of waste by‑product types (r) leaving the activity during the year measured in tonnes.

Step 4

Calculate the carbon content in the amount of the increase in stocks of inputs, products and waste by-products held within the boundary of the activity during the year in tonnes of carbon as follows:

where:

Si has the same meaning as in step 1.

CCFi has the same meaning as in step 1.

ΔSqi is the increase in stocks of fuel type (i) for the activity and held within the boundary of the activity during the year measured in tonnes.

Sj has the same meaning as in step 1.

CCFj has the same meaning as in step 1.

ΔSqj is the increase in stocks of pure carbonate material (j) for the activity and held within the boundary of the activity during the year measured in tonnes.

Sp has the same meaning as in step 2.

CCFp has the same meaning as in step 2.

ΔSap is the increase in stocks of product types (p) produced by the activity and held within the boundary of the activity during the year measured in tonnes.

 

Sr has the same meaning as in step 3.

CCFr has the same meaning as in step 3.

ΔSyr is the increase in stocks of waste by‑product types (r) produced from the operation of the activity and held within the boundary of the activity during the year measured in tonnes.

Step 5

Calculate the emissions of carbon dioxide released from the operation of the activity during the year measured in CO2‑e tonnes as follows:

   (a)  add the amounts worked out under steps 2, 3 and 4 to work out a new amount (amount A);

   (b)  subtract amount A from the amount worked out under step 1 to work out a new amount (amount B);

   (c)  multiply amount B by 3.664 to work out the amount of emissions released from the operation of the activity during a year.

4.32        Method 2 — production of soda ash

                Method 2 is:

Step 1

Calculate the carbon content in fuel types (i) or carbonate material (j) delivered for the activity during the year measured in tonnes of carbon as follows:

 

where:

i means sum the carbon content values obtained for all fuel types (i).

 

CCFi is the carbon content factor measured in tonnes of carbon for each appropriate unit of fuel type (i) consumed during the year from the operation of the activity.

 

Qi is the quantity of fuel type (i) delivered for the activity during the year measured in an appropriate unit and estimated in accordance with Divisions 2.2.5, 2.3.6 and 2.4.6.

 

j means sum the carbon content values obtained for all pure carbonate material (j).

CCFj is the carbon content factor measured in tonnes of carbon for each pure carbonate material (j) consumed during the year from the operation of the activity.

Lj is the quantity of pure carbonate material (j) delivered for the activity during the year measured in tonnes and estimated in accordance with Division 4.2.5.

Step 2

Calculate the carbon content in products (p) leaving the activity during the year measured in tonnes of carbon as follows:

where:

p means sum the carbon content values obtained for all product types (p).

CCFp is the carbon content factor measured in tonnes of carbon for each tonne of product type (p) produced during the year.

Ap is the quantity of product types (p) produced leaving the activity during the year measured in tonnes.

Step 3

Calculate the carbon content in waste by‑product types (r) leaving the activity, other than as an emission of greenhouse gas, during the year, measured in tonnes of carbon, as follows:

where:

Sr means sum the carbon content values obtained for all waste by‑product types (r).

CCFr is the carbon content factor measured in tonnes of carbon for each tonne of waste by‑product types (r).

Yr is the quantity of waste by‑product types (r) leaving the activity during the year measured in tonnes.

Step 4

Calculate the carbon content in the amount of the increase in stocks of inputs, products and waste by-products held within the boundary of the activity during the year in tonnes of carbon as follows:

where:

Si has the same meaning as in step 1.

CCFi has the same meaning as in step 1.

ΔSqi is the increase in stocks of fuel type (i) for the activity and held within the boundary of the activity during the year measured in tonnes.

Sj has the same meaning as in step 1.

CCFj has the same meaning as in step 1.

ΔSqj is the increase in stocks of pure carbonate material (j) for the activity and held within the boundary of the activity during the year measured in tonnes.

Sp has the same meaning as in step 2.

CCFp has the same meaning as in step 2.

ΔSap is the increase in stocks of product types (p) produced by the activity and held within the boundary of the activity during the year measured in tonnes.

 

Sr has the same meaning as in step 3.

CCFr has the same meaning as in step 3.

ΔSyr is the increase in stocks of waste by-product types (r) produced from the operation of the activity and held within the boundary of the activity during the year measured in tonnes.

α is the factor  for converting the mass of carbon dioxide to a mass of carbon.

γ is the factor 1.861 × 10-3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2-e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

Step 5

Calculate the emissions of carbon dioxide released from the operation of the activity during the year measured in CO2‑e tonnes as follows:

   (a)  add the amounts worked out under steps 2, 3 and 4 to work out a new amount (amount A);

   (b)  subtract amount A from the amount worked out under step 1 to work out a new amount (amount B);

   (c)  multiply amount B by 3.664 to work out the amount of emissions released from the operation of the activity during a year.

         (2)   If a fuel type (i) or carbonate material (j) delivered for the activity during the year accounts for more than 5% of total carbon input for the activity based on a calculation using the factors mentioned in Schedule 3, sampling and analysis of fuel type (i) or carbonate material (j) must be carried out to determine its carbon content.

         (3)   The sampling and analysis for fuel type (i) is to be carried out using the sampling and analysis provided for in Divisions 2.2.3, 2.3.3 and 2.4.3.

         (4)   The sampling for carbonate materials (j) is to be carried out in accordance with section 4.24.

         (5)   The analysis for carbonate materials (j) is to be carried out in accordance with ASTM C25-06, Standard Test Methods for Chemical Analysis of Limestone, Quicklime, and Hydrated Lime or an equivalent standard.

4.33        Method 3 — production of soda ash

         (1)   Subject to subsections (2) and (3), method 3 is the same as method 2.

         (2)   The sampling and analysis for fuel type (i) is to be carried out using the sampling and analysis provided for in Divisions 2.2.4, 2.3.4 and 2.4.4 or an equivalent sampling and analysis method.

         (3)   The sampling for carbonate material (j) is to be carried out in accordance with ASTM C50-00 (2006), Standard Practice for Sampling, Sample Preparation, Packaging, and Marking of Lime and Limestone Products.

[76]         Sections 4.43 and 4.44

substitute

4.43        Method 2 — ammonia production

         (1)   Method 2 is:

where:

Eij is the emissions of carbon dioxide released from the production of ammonia during the year measured in CO2‑e tonnes.

Qi is the quantity of each type of feedstock or type of fuel (i) consumed from the production of ammonia during the year, measured in the appropriate unit and estimated using an applicable criterion in Division 2.3.6.

ECi is the energy content factor for fuel type (i) used as a feedstock in the production of ammonia during the year, estimated under section 6.5.

EFij is the carbon dioxide emission factor for each type of feedstock or type of fuel (i) used in the production of ammonia during the year, including the effects of oxidation, measured in kilograms for each gigajoule according to source in accordance with subsection (3).

R is the quantity of carbon dioxide measured in tonnes derived from the production of ammonia during the year, captured and transferred for use in the operation of another facility, estimated using an applicable criterion in Division 2.3.6 and in accordance with any other requirements of that Division.

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

         (2)   The method for estimating emission factors for gaseous fuels in Division 2.3.3 applies for working out the factor EFij.

4.44        Method 3 — ammonia production

         (1)   Method 3 is the same as method 2 under section 4.43.

         (2)   In applying method 2 as method 3, the method for estimating emission factors for gaseous fuels in Division 2.3.4 applies for working out the factor EFij.

[77]         Subsection 4.67 (1)

after

method 1

insert

under section 4.66

[78]         After subsection 4.67 (1)

insert

      (1A)   In applying method 1 as method 2, step 4 in section 4.66 is to be omitted and the following step 4 substituted.

Step 4

Calculate the carbon content in the amount of the increase in stocks of inputs, products and waste by-products held within the boundary of the activity during the year in tonnes of carbon as follows:

where:

Si has the same meaning as in step 1.

CCFi has the same meaning as in step 1.

ΔSqi is the increase in stocks of fuel type (i) for the activity and held within the boundary of the activity during the year measured in tonnes.

Sp has the same meaning as in step 2.

CCFp has the same meaning as in step 2.

ΔSap is the increase in stocks of product types (p) produced by the activity and held within the boundary of the activity during the year measured in tonnes.

 

Sr has the same meaning as in step 3.

CCFr has the same meaning as in step 3.

 

ΔSyr is the increase in stocks of waste by‑product types (r) produced from the operation of the activity and held within the boundary of the activity during the year measured in tonnes.

 

α is the factor  for converting the mass of carbon dioxide to a mass of carbon.

 

γ is the factor 1.861 × 10‑3 for converting a quantity of carbon dioxide from cubic metres at standard conditions of pressure and temperature to CO2‑e tonnes.

RCCSCO2 is carbon dioxide captured for permanent storage measured in cubic metres in accordance with Division 1.2.3.

[79]         Subsection 4.68 (1)

omit

method 1

insert

method 2 under section 4.67

[80]         Section 4.69

substitute

4.69        Application

         (1)   This Division applies to emissions of carbon dioxide from any of the following:

                (a)    the consumption of a fossil fuel reductant during the production of:

                          (i)    a ferroalloy; or

                         (ii)    silicomanganese; or

                         (iii)    silicon;

               (b)    the oxidation of a fossil fuel electrode in the production of:

                          (i)    a ferroalloy; or

                         (ii)    silicomanganese; or

                         (iii)    silicon.

         (2)   In this section:

ferroalloy means an alloy of 1 or more elements with iron including, but not limited to, any of the following:

                (a)    ferrochrome;

               (b)    ferromanganese;

                (c)    ferromolybdenum;

               (d)    ferronickel;

                (e)    ferrosilicon;

                (f)    ferrotitanium;

                (g)    ferrotungsten;

                (h)    ferrovanadium.

[81]         Subsection 4.70 (1)

omit

ferroalloy metal

insert

ferroalloy metal, silicomanganese or silicon

[82]         Subdivision 4.4.3.1, heading

substitute

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

[83]         Subsection 4.75 (1)

omit

baked

[84]         Section 4.76, heading

substitute

4.76        Method 1 — aluminium (carbon anode consumption)

[85]         Section 4.76

omit each mention of

baked

[86]         Section 4.77, heading

substitute

4.77        Method 2 — aluminium (carbon anode consumption)

[87]         Section 4.78, heading

substitute

4.78        Method 3 — aluminium (carbon anode consumption)

[88]         Section 4.92

substitute

4.92        Application

         (1)   This Division applies to emissions of carbon dioxide from any of the following:

                (a)    the consumption of a fossil fuel reductant;

               (b)    the oxidation of a fossil fuel electrode.

         (2)   This Division does not apply to the production of any of the following:

                (a)    aluminium;

               (b)    ferroalloys;

                (c)    iron;

               (d)    steel;

                (e)    any other metal produced using an integrated metalworks.

[89]         Subsection 5.25 (5), definition of CODsl

substitute

CODsl is the quantity of COD removed as sludge from wastewater and treated in the plant measured in tonnes of COD and worked out as follows:

where:

CODpsl is the quantity of COD removed as primary sludge from wastewater and treated in the plant measured in tonnes of COD and estimated under subsection (7).

CODwasl is the quantity of COD removed as waste activated sludge from wastewater and treated in the plant measured in tonnes of COD and estimated under subsection (8).

[90]         Subsection 5.25 (7)

substitute

         (7)   For subsection (5), CODpsl may be estimated using the following formula:

where:

VSpsl is the estimated volatile solids in the primary sludge.

         (8)   For subsection (5), CODwasl may be estimated using the following formula:

where:

VSwasl is the estimated volatile solids in the waste activated sludge.

         (9)   In this section:

primary sludge means sludge from the first major treatment process in a wastewater treatment facility that is designed primarily to remove a substantial amount of suspended matter but little or no colloidal or dissolved matter.

waste activated sludge means sludge from a secondary treatment process in a wastewater treatment facility involving aeration and active biological material.

[91]         Subsection 5.43 (3)

omit

is sections

insert

in sections

[92]         Section 5.52

omit

Subject

insert

         (1)   Subject

[93]         Section 5.52, after the note

insert

         (2)   For incidental emissions, another method may be used that is consistent with the principles in section 1.13.

[94]         After subsection 6.2 (1)

insert

      (1A)   For incidental energy production, another method may be used that is consistent with the principles in section 1.13.

[95]         Paragraph 8.6 (1) (c)

omit

subsection (2)

insert

subsection (3)

[96]         Subsection 8.7 (2)

omit

subsection 8.6 (2)

insert

subsection 8.6 (3)

[97]         Section 8.12, definitions of D1 → Dn and E1 → En

substitute

D1 → Dn are the percentage uncertainties associated with each emission estimate (E1 → En) for the source.

E1 → En are the estimated emissions from each source associated with the facility measured in CO2-e tonnes.

[98]         Section 8.13, formula

substitute

[99]         Section 8.13, definitions of D1 → Dn and E1 → En

substitute

F1 → Fn are the percentage uncertainties associated with each emission estimate (G1 → Gn) for the facility.

G1 → Gn are the estimated emissions from each facility under the operational control of the corporation measured in CO2-e tonnes.

[100]       Schedule 1, item 22, column 3

substitute

62.9 × 10-3

[101]       Schedule 1, item 68, column 3

substitute

Euro iv or higher

[102]       Schedule 1, Part 6, table

substitute


Item

State, Territory or grid description

Emission factor
kg CO2‑e/kWh

77

New South Wales and Australian Capital Territory

0.90

78

Victoria

1.23

79

Queensland

0.89

80

South Australia

0.72

81

South West Interconnected System in Western Australia

0.82

82

Tasmania

0.32

83

Northern Territory

0.68

[103]       Schedule 3, heading

substitute

Schedule 3        Carbon content factors

(subsection 2.61 (1), sections 3.65, 4.66 and subsections 4.67 (2) and 4.68 (2))

  

[104]       Schedule 3, item 22, column 3

substitute

9.70 × 10‑4

 [105]      Schedule 3, after Part 4

insert

Part 5          Carbonates

Item

Carbonate type

Carbon content factor (tC/t pure carbonate material unless otherwise specified)

63

Calcium carbonate

0.120

64

Magnesium carbonate

0.142

65

Sodium carbonate

0.113

66

Sodium bicarbonate

0.143

[106]       Further amendments — Chapter 2

                The following provisions are amended by omitting ‘Part 1’ and inserting ‘Chapter 2’:

·   subsection 4.7 (2)

·   subsection 4.8 (1), step 1, definition of EFij, paragraph (d)

·   subsection 4.10 (2)

·   subsection 4.16 (2)

·   section 4.22, step 1, definition of EFij, paragraph (d)

·   subsection 4.23 (1), step 1, definition of EFij, paragraph (d)

·   subsection 4.25 (2).


Note

1.       All legislative instruments and compilations are registered on the Federal Register of Legislative Instruments kept under the Legislative Instruments Act 2003. See http://www.frli.gov.au.