Preliminary

Introduction

sec.1 Short title

This regulation may be cited as the Petroleum and Gas (General Provisions) Regulation 2017 .

sec.2 Commencement

This regulation commences on 1 September 2017.

Interpretation

sec.3 Definitions

The dictionary in schedule 5 defines particular words used in this regulation.

sec.4 References to particular resource authorities and wells under this regulation

A reference in this regulation to an authority to prospect is a reference to— an authority to prospect under the 2004 Act ; and an authority to prospect under the 1923 Act . A reference in this regulation to a petroleum lease is a reference to— a petroleum lease under the 2004 Act ; and a lease under the 1923 Act . A reference in this regulation to a petroleum tenure is a reference to— a 2004 Act petroleum tenure; and an authority to prospect and a lease under the 1923 Act . A reference in this regulation to a petroleum well includes a reference to a well under the 1923 Act . (sec.4-ssec.1) A reference in this regulation to an authority to prospect is a reference to— an authority to prospect under the 2004 Act ; and an authority to prospect under the 1923 Act . (sec.4-ssec.2) A reference in this regulation to a petroleum lease is a reference to— a petroleum lease under the 2004 Act ; and a lease under the 1923 Act . (sec.4-ssec.3) A reference in this regulation to a petroleum tenure is a reference to— a 2004 Act petroleum tenure; and an authority to prospect and a lease under the 1923 Act . (sec.4-ssec.4) A reference in this regulation to a petroleum well includes a reference to a well under the 1923 Act .

• (a) an authority to prospect under the 2004 Act ; and
• (b) an authority to prospect under the 1923 Act .
• (a) a petroleum lease under the 2004 Act ; and
• (b) a lease under the 1923 Act .
• (a) a 2004 Act petroleum tenure; and
• (b) an authority to prospect and a lease under the 1923 Act .

Substances prescribed for the 2004 Act

sec.5 Substances that are petroleum

For the 2004 Act , section 10 (1) (d) , the following substances are prescribed— biogas; biomethane; a substance that is a mixture of LPG and air, known as ‘synthetic natural gas’. However, subsection (1) applies only for the purposes of the following provisions of that Act— chapters 8 to 10; and chapters 11 to 14, to the extent they apply for chapters 8 to 10. For the 2004 Act , section 10 (1) (e) , carbon dioxide is prescribed. However, subsection (3) applies only— to a survey licence holder investigating and surveying an area for its potential and suitability for the construction and operation of pipelines for transporting carbon dioxide; or to an authority to prospect holder evaluating or testing natural underground reservoirs for the storage of petroleum under the 2004 Act , section 32 (1) (d) if— the testing is carried out on a particular block of the authority within— 2 years after the testing starts; or a longer period decided by the Minister within the 2 years; and the Minister approves the testing on the particular block; and the holder complies with any conditions the Minister imposes on the approval. s 5 amd 2021 SL No. 75 s 21 (sec.5-ssec.1) For the 2004 Act , section 10 (1) (d) , the following substances are prescribed— biogas; biomethane; a substance that is a mixture of LPG and air, known as ‘synthetic natural gas’. (sec.5-ssec.2) However, subsection (1) applies only for the purposes of the following provisions of that Act— chapters 8 to 10; and chapters 11 to 14, to the extent they apply for chapters 8 to 10. (sec.5-ssec.3) For the 2004 Act , section 10 (1) (e) , carbon dioxide is prescribed. (sec.5-ssec.4) However, subsection (3) applies only— to a survey licence holder investigating and surveying an area for its potential and suitability for the construction and operation of pipelines for transporting carbon dioxide; or to an authority to prospect holder evaluating or testing natural underground reservoirs for the storage of petroleum under the 2004 Act , section 32 (1) (d) if— the testing is carried out on a particular block of the authority within— 2 years after the testing starts; or a longer period decided by the Minister within the 2 years; and the Minister approves the testing on the particular block; and the holder complies with any conditions the Minister imposes on the approval.

• (a) biogas;
• (b) biomethane;
• (c) a substance that is a mixture of LPG and air, known as ‘synthetic natural gas’.
• (a) chapters 8 to 10; and
• (b) chapters 11 to 14, to the extent they apply for chapters 8 to 10.
• (a) to a survey licence holder investigating and surveying an area for its potential and suitability for the construction and operation of pipelines for transporting carbon dioxide; or
• (b) to an authority to prospect holder evaluating or testing natural underground reservoirs for the storage of petroleum under the 2004 Act , section 32 (1) (d) if— (i) the testing is carried out on a particular block of the authority within— (A) 2 years after the testing starts; or (B) a longer period decided by the Minister within the 2 years; and (ii) the Minister approves the testing on the particular block; and (iii) the holder complies with any conditions the Minister imposes on the approval.
• (i) the testing is carried out on a particular block of the authority within— (A) 2 years after the testing starts; or (B) a longer period decided by the Minister within the 2 years; and
• (A) 2 years after the testing starts; or
• (B) a longer period decided by the Minister within the 2 years; and
• (ii) the Minister approves the testing on the particular block; and
• (iii) the holder complies with any conditions the Minister imposes on the approval.
• (i) the testing is carried out on a particular block of the authority within— (A) 2 years after the testing starts; or (B) a longer period decided by the Minister within the 2 years; and
• (A) 2 years after the testing starts; or
• (B) a longer period decided by the Minister within the 2 years; and
• (ii) the Minister approves the testing on the particular block; and
• (iii) the holder complies with any conditions the Minister imposes on the approval.
• (A) 2 years after the testing starts; or
• (B) a longer period decided by the Minister within the 2 years; and

sec.6 Substances that are fuel gas

For the 2004 Act , section 11 (2) (d) , the following substances are prescribed— biogas; biomethane; synthetic methane; a substance that is a mixture of LPG and air, known as ‘synthetic natural gas’. In this section— synthetic methane means a substance— that is in a gaseous state at standard temperature and pressure; and the principal constituent of which is methane; and that is produced by the methanation of carbon dioxide; and that is suitable for consumption. s 6 amd 2021 SL No. 75 s 22 sub 2024 SL No. 32 s 4 (sec.6-ssec.1) For the 2004 Act , section 11 (2) (d) , the following substances are prescribed— biogas; biomethane; synthetic methane; a substance that is a mixture of LPG and air, known as ‘synthetic natural gas’. (sec.6-ssec.2) In this section— synthetic methane means a substance— that is in a gaseous state at standard temperature and pressure; and the principal constituent of which is methane; and that is produced by the methanation of carbon dioxide; and that is suitable for consumption.

• (a) biogas;
• (b) biomethane;
• (c) synthetic methane;
• (d) a substance that is a mixture of LPG and air, known as ‘synthetic natural gas’.
• (a) that is in a gaseous state at standard temperature and pressure; and
• (b) the principal constituent of which is methane; and
• (c) that is produced by the methanation of carbon dioxide; and
• (d) that is suitable for consumption.

sec.6A Substances that are regulated hydrogen

For the 2004 Act , section 11A (c) , the following substances are prescribed— ammonia; dimethyl-ether; methanol; methyl-cyclohexane (MCH); toluene. s 6A ins 2024 SL No. 32 s 4

• (a) ammonia;
• (b) dimethyl-ether;
• (c) methanol;
• (d) methyl-cyclohexane (MCH);
• (e) toluene.

sec.7 Substance that may be transported under condition of pipeline licence

For the 2004 Act , section 402 (1) (b) , a distilled petroleum substance is prescribed. In this section— distilled petroleum substance means a substance— produced by distilling crude oil; and that consists of, or includes, hydrocarbons. diesel, petrol, kerosene (sec.7-ssec.1) For the 2004 Act , section 402 (1) (b) , a distilled petroleum substance is prescribed. (sec.7-ssec.2) In this section— distilled petroleum substance means a substance— produced by distilling crude oil; and that consists of, or includes, hydrocarbons. diesel, petrol, kerosene

• (a) produced by distilling crude oil; and
• (b) that consists of, or includes, hydrocarbons.

Reporting

Exploring for and producing petroleum

sec.8 Authority to prospect—proposed work program

For the 2004 Act , section 48 (2) (d) and the 1923 Act , section 25A (1) (i) , the matters prescribed in relation to an authority to prospect are— a description of the geological model for the area of the authority to prospect; and an assessment of the potential for petroleum discovery in the area; and the rationale, in relation to the geological model for the area, for the activities proposed to be carried out under the authority to prospect. s 8 amd 2022 SL No. 191 s 5

• (a) a description of the geological model for the area of the authority to prospect; and
• (b) an assessment of the potential for petroleum discovery in the area; and
• (c) the rationale, in relation to the geological model for the area, for the activities proposed to be carried out under the authority to prospect.

sec.9 Petroleum lease—proposed development plan

For the 2004 Act , section 138 (1) (g) and the 1923 Act , section 53A (1) (g) , the matters prescribed in relation to a petroleum lease are— for each natural underground reservoir within the area of the lease of which the applicant is aware, the location of the boundaries of— the proved and probable reserves of petroleum in the reservoir; or the reserves of petroleum in the reservoir worked out in another way approved by the chief executive; and details, including the location, type and size, of any planned infrastructure intended to be located within the area of the lease or proposed lease. plant or works, including, for example, communication systems, compressors, powerlines, pumping stations, reservoirs, roads, evaporation or storage ponds and tanks temporary structures or structures of an industrial or technical nature, including, for example, mobile and temporary camps

• (a) for each natural underground reservoir within the area of the lease of which the applicant is aware, the location of the boundaries of— (i) the proved and probable reserves of petroleum in the reservoir; or (ii) the reserves of petroleum in the reservoir worked out in another way approved by the chief executive; and
• (i) the proved and probable reserves of petroleum in the reservoir; or
• (ii) the reserves of petroleum in the reservoir worked out in another way approved by the chief executive; and
• (b) details, including the location, type and size, of any planned infrastructure intended to be located within the area of the lease or proposed lease. Examples of infrastructure— 1 plant or works, including, for example, communication systems, compressors, powerlines, pumping stations, reservoirs, roads, evaporation or storage ponds and tanks 2 temporary structures or structures of an industrial or technical nature, including, for example, mobile and temporary camps
• 1 plant or works, including, for example, communication systems, compressors, powerlines, pumping stations, reservoirs, roads, evaporation or storage ponds and tanks
• 2 temporary structures or structures of an industrial or technical nature, including, for example, mobile and temporary camps
• (i) the proved and probable reserves of petroleum in the reservoir; or
• (ii) the reserves of petroleum in the reservoir worked out in another way approved by the chief executive; and
• 1 plant or works, including, for example, communication systems, compressors, powerlines, pumping stations, reservoirs, roads, evaporation or storage ponds and tanks
• 2 temporary structures or structures of an industrial or technical nature, including, for example, mobile and temporary camps

sec.10 Shorter period to change production commencement day

For the 2004 Act , section 175AA (b) , the shorter period is 3 months.

sec.11 Notice about conversion of petroleum well to bore

For the 2004 Act , section 284 and the 1923 Act , section 75M , the information is— a description of the location of the bore; and the day on which the petroleum well was converted to a bore.

• (a) a description of the location of the bore; and
• (b) the day on which the petroleum well was converted to a bore.

sec.12 Notice about bore to Water Act regulator

For the 2004 Act , section 543A (2) and the 1923 Act , section 75XA (2) , the following information about a bore is prescribed— the name and postal address of the holder of the petroleum tenure or water monitoring authority for the area containing the bore; the identifying name of the bore; a description of the location of the bore; the purpose of the bore; the diameter and depth in metres of the bore; the following days— the day the drilling of the bore started; the last day the drilling rig was used to drill the bore; the drilling method used to drill the bore; details of the casing, centralisers and equipment installed in the bore, including the type and location of centralisers; the type of any slots or perforations in the casing, or screens installed, for water entry and the depth in metres of the top and bottom of the slots, perforations or screens; details of the cementing in the bore, including the type of cement used and the depth in metres of the top and bottom of each cemented interval; a geological interpretation of the bore, including the stratigraphy of the rock units it intersects; details of the water produced by each stratum of rock, including— the quality and supply rate of the water; and the depth at which the water is struck; and the depth to which the water naturally rises; if, on completion, the bore is a subartesian bore— the depth in metres to the standing water level, and either the pump suction inlet or bottom of the drill stem; and details of the test used to estimate the groundwater supply rate; if, on completion, the bore is an artesian bore— the rate of flow of unimpeded water from the bore at the surface; and the pressure head of the water mentioned in subparagraph (i) ; and the temperature of the groundwater. The information mentioned in subsection (1) must be given to the Water Act regulator in the approved form. (sec.12-ssec.1) For the 2004 Act , section 543A (2) and the 1923 Act , section 75XA (2) , the following information about a bore is prescribed— the name and postal address of the holder of the petroleum tenure or water monitoring authority for the area containing the bore; the identifying name of the bore; a description of the location of the bore; the purpose of the bore; the diameter and depth in metres of the bore; the following days— the day the drilling of the bore started; the last day the drilling rig was used to drill the bore; the drilling method used to drill the bore; details of the casing, centralisers and equipment installed in the bore, including the type and location of centralisers; the type of any slots or perforations in the casing, or screens installed, for water entry and the depth in metres of the top and bottom of the slots, perforations or screens; details of the cementing in the bore, including the type of cement used and the depth in metres of the top and bottom of each cemented interval; a geological interpretation of the bore, including the stratigraphy of the rock units it intersects; details of the water produced by each stratum of rock, including— the quality and supply rate of the water; and the depth at which the water is struck; and the depth to which the water naturally rises; if, on completion, the bore is a subartesian bore— the depth in metres to the standing water level, and either the pump suction inlet or bottom of the drill stem; and details of the test used to estimate the groundwater supply rate; if, on completion, the bore is an artesian bore— the rate of flow of unimpeded water from the bore at the surface; and the pressure head of the water mentioned in subparagraph (i) ; and the temperature of the groundwater. (sec.12-ssec.2) The information mentioned in subsection (1) must be given to the Water Act regulator in the approved form.

• (a) the name and postal address of the holder of the petroleum tenure or water monitoring authority for the area containing the bore;
• (b) the identifying name of the bore;
• (c) a description of the location of the bore;
• (d) the purpose of the bore;
• (e) the diameter and depth in metres of the bore;
• (f) the following days— (i) the day the drilling of the bore started; (ii) the last day the drilling rig was used to drill the bore;
• (i) the day the drilling of the bore started;
• (ii) the last day the drilling rig was used to drill the bore;
• (g) the drilling method used to drill the bore;
• (h) details of the casing, centralisers and equipment installed in the bore, including the type and location of centralisers;
• (i) the type of any slots or perforations in the casing, or screens installed, for water entry and the depth in metres of the top and bottom of the slots, perforations or screens;
• (j) details of the cementing in the bore, including the type of cement used and the depth in metres of the top and bottom of each cemented interval;
• (k) a geological interpretation of the bore, including the stratigraphy of the rock units it intersects;
• (l) details of the water produced by each stratum of rock, including— (i) the quality and supply rate of the water; and (ii) the depth at which the water is struck; and (iii) the depth to which the water naturally rises;
• (i) the quality and supply rate of the water; and
• (ii) the depth at which the water is struck; and
• (iii) the depth to which the water naturally rises;
• (m) if, on completion, the bore is a subartesian bore— (i) the depth in metres to the standing water level, and either the pump suction inlet or bottom of the drill stem; and (ii) details of the test used to estimate the groundwater supply rate;
• (i) the depth in metres to the standing water level, and either the pump suction inlet or bottom of the drill stem; and
• (ii) details of the test used to estimate the groundwater supply rate;
• (n) if, on completion, the bore is an artesian bore— (i) the rate of flow of unimpeded water from the bore at the surface; and (ii) the pressure head of the water mentioned in subparagraph (i) ; and (iii) the temperature of the groundwater.
• (i) the rate of flow of unimpeded water from the bore at the surface; and
• (ii) the pressure head of the water mentioned in subparagraph (i) ; and
• (iii) the temperature of the groundwater.
• (i) the day the drilling of the bore started;
• (ii) the last day the drilling rig was used to drill the bore;
• (i) the quality and supply rate of the water; and
• (ii) the depth at which the water is struck; and
• (iii) the depth to which the water naturally rises;
• (i) the depth in metres to the standing water level, and either the pump suction inlet or bottom of the drill stem; and
• (ii) details of the test used to estimate the groundwater supply rate;
• (i) the rate of flow of unimpeded water from the bore at the surface; and
• (ii) the pressure head of the water mentioned in subparagraph (i) ; and
• (iii) the temperature of the groundwater.

sec.13 Pipeline licence or petroleum facility licence—annual report

For the 2004 Act , section 552 (2) , the following information is prescribed— the authorised activities for the pipeline licence or petroleum facility licence carried out during the period to which the report relates; a statement of the authorised activities proposed to be carried out under the licence during the next 12 months.

• (a) the authorised activities for the pipeline licence or petroleum facility licence carried out during the period to which the report relates;
• (b) a statement of the authorised activities proposed to be carried out under the licence during the next 12 months.

Testing

sec.14 Notice about ATP production testing or PL production testing

For the 2004 Act , sections 71A (2) (a) and 150A (2) (a) , the following information is prescribed— the identifying number of the authority to prospect or petroleum lease; the day the testing started; the identifying name of the petroleum well for which the testing is being carried out; for each natural underground reservoir from which the testing is being carried out— an identification of the reservoir including, for example, a description of the geological features of the reservoir; and the type of reservoir; and the depth in metres of the top and bottom of the reservoir; details of any stimulation to be carried out during the testing; See sections 33 and 34 for notice requirements relating to hydraulic fracturing activities. details of the use, or intended use, of petroleum in a gaseous state produced during the testing. for an authorised activity for the petroleum tenure, flaring, venting, processing

• (a) the identifying number of the authority to prospect or petroleum lease;
• (b) the day the testing started;
• (c) the identifying name of the petroleum well for which the testing is being carried out;
• (d) for each natural underground reservoir from which the testing is being carried out— (i) an identification of the reservoir including, for example, a description of the geological features of the reservoir; and (ii) the type of reservoir; and (iii) the depth in metres of the top and bottom of the reservoir;
• (i) an identification of the reservoir including, for example, a description of the geological features of the reservoir; and
• (ii) the type of reservoir; and
• (iii) the depth in metres of the top and bottom of the reservoir;
• (e) details of any stimulation to be carried out during the testing; Note— See sections 33 and 34 for notice requirements relating to hydraulic fracturing activities.
• (f) details of the use, or intended use, of petroleum in a gaseous state produced during the testing. Examples of use, or intended use, of the petroleum— for an authorised activity for the petroleum tenure, flaring, venting, processing
• (i) an identification of the reservoir including, for example, a description of the geological features of the reservoir; and
• (ii) the type of reservoir; and
• (iii) the depth in metres of the top and bottom of the reservoir;

sec.15 Notice about ATP storage testing or PL storage testing

For the 2004 Act , sections 71B (2) (a) and 150C (2) (a) , the following information is prescribed— the identifying number of the authority to prospect or petroleum lease; the day the testing started; the identifying name of the petroleum well for which the testing is being carried out; for each natural underground reservoir from which the testing is being carried out— an identification of the reservoir including, for example, a description of the geological features of the reservoir; and the type of reservoir; and the depth in metres of the top and bottom of the reservoir; details of substances to be used to carry out the testing.

• (a) the identifying number of the authority to prospect or petroleum lease;
• (b) the day the testing started;
• (c) the identifying name of the petroleum well for which the testing is being carried out;
• (d) for each natural underground reservoir from which the testing is being carried out— (i) an identification of the reservoir including, for example, a description of the geological features of the reservoir; and (ii) the type of reservoir; and (iii) the depth in metres of the top and bottom of the reservoir;
• (i) an identification of the reservoir including, for example, a description of the geological features of the reservoir; and
• (ii) the type of reservoir; and
• (iii) the depth in metres of the top and bottom of the reservoir;
• (e) details of substances to be used to carry out the testing.
• (i) an identification of the reservoir including, for example, a description of the geological features of the reservoir; and
• (ii) the type of reservoir; and
• (iii) the depth in metres of the top and bottom of the reservoir;

sec.16 Notice about stopping of testing

For the 2004 Act , sections 71C and 150E the following information is prescribed— the identifying number of the authority to prospect or petroleum lease; the identifying name of the petroleum well for which the testing was carried out; the day the testing started; the day the testing stopped; the reason the testing stopped.

• (a) the identifying number of the authority to prospect or petroleum lease;
• (b) the identifying name of the petroleum well for which the testing was carried out;
• (c) the day the testing started;
• (d) the day the testing stopped;
• (e) the reason the testing stopped.

Relinquishment, surrender, end of tenure and end of authority

sec.17 Definitions for division

In this division— general area information , for a relinquishment report or surrender report for a petroleum tenure, see section 18 . hazard information , for a relinquishment report or surrender report for a petroleum tenure, see section 19 . relinquished area , for a relinquishment report for a petroleum tenure, means the part of the area of the tenure that is relinquished. relinquishment report means a report required to be lodged— under the 2004 Act , section 545 if part of the area of a petroleum tenure is relinquished under that Act; or under the 1923 Act , section 75Z if part of the area of a petroleum tenure is relinquished under that Act. surrendered area , for a surrender report for a petroleum tenure or pipeline licence, means the part of the area of the tenure or licence— to be surrendered; and for which approval of surrender is sought under the application. surrender report means a report— required under the 2004 Act , section 576 (2) to accompany an application, under that Act, for approval to surrender all or part of the area of a petroleum authority; or required under the 1923 Act , section 21 (4) (b) (ii) to accompany an application, under that Act, for approval to surrender all or part of the area of an authority to prospect. s 17 def surrender report amd 2019 SL No. 53 s 18 tenure information , for a relinquishment report for a petroleum tenure, see section 20 .

• (a) under the 2004 Act , section 545 if part of the area of a petroleum tenure is relinquished under that Act; or
• (b) under the 1923 Act , section 75Z if part of the area of a petroleum tenure is relinquished under that Act.
• (a) to be surrendered; and
• (b) for which approval of surrender is sought under the application.
• (a) required under the 2004 Act , section 576 (2) to accompany an application, under that Act, for approval to surrender all or part of the area of a petroleum authority; or
• (b) required under the 1923 Act , section 21 (4) (b) (ii) to accompany an application, under that Act, for approval to surrender all or part of the area of an authority to prospect.

sec.18 Meaning of general area information

The following information is general area information for a relinquishment report or surrender report for a petroleum tenure— spatial information showing the location of— the area of the tenure immediately before the relinquishment or surrender (the previous tenure area ); and the relinquished area or surrendered area; spatial information showing the leads and prospects in the relinquished area or surrendered area; any other data or information for the report required under the practice direction. s 18 amd 2020 SL No. 208 s 4

• (a) spatial information showing the location of— (i) the area of the tenure immediately before the relinquishment or surrender (the previous tenure area ); and (ii) the relinquished area or surrendered area;
• (i) the area of the tenure immediately before the relinquishment or surrender (the previous tenure area ); and
• (ii) the relinquished area or surrendered area;
• (b) spatial information showing the leads and prospects in the relinquished area or surrendered area;
• (c) any other data or information for the report required under the practice direction.
• (i) the area of the tenure immediately before the relinquishment or surrender (the previous tenure area ); and
• (ii) the relinquished area or surrendered area;

sec.19 Meaning of hazard information

In this division, hazard information for a relinquishment report or surrender report for a petroleum tenure means the following information for a hazard relating to activities carried out under the tenure— the nature of the hazard; the cause, or reasons for existence, of the hazard; the location of the hazard; measures taken to prevent or reduce the risk of the hazard to mitigate the effects of the hazard. s 19 amd 2019 SL No. 89 s 6 sub 2020 SL No. 208 s 5

• (a) the nature of the hazard;
• (b) the cause, or reasons for existence, of the hazard;
• (c) the location of the hazard;
• (d) measures taken to prevent or reduce the risk of the hazard to mitigate the effects of the hazard.

sec.20 Meaning of tenure information

The following information is tenure information for a relinquishment report for a petroleum tenure— the day the relinquishment takes effect; the period of the work program or development plan for the tenure; the blocks or sub-blocks comprising the relinquished area. s 20 amd 2020 SL No. 208 s 6

• (a) the day the relinquishment takes effect;
• (b) the period of the work program or development plan for the tenure;
• (c) the blocks or sub-blocks comprising the relinquished area.

sec.21 Authority to prospect—relinquishment or surrender report

This section prescribes— other information for a relinquishment report for an authority to prospect for the 2004 Act , section 545 (b) and the 1923 Act , section 75Z (b) ; and information for a surrender report for an authority to prospect for the 1923 Act , section 21 (4) (b) (ii) . The information is each of the following— the tenure information for the report; the general area information for the report; a summary of the results of all authorised activities for the authority carried out in the relinquished area or surrendered area since the authority took effect and the conclusions drawn by the holder based on the results, including any identified leads and prospects; the hazard information for the report; for each year since the authority took effect— for a relinquishment report—the volume of petroleum or water produced from each petroleum well or bore in the relinquished area; or for a surrender report—the location of each natural underground reservoir in the surrendered area and the volume of petroleum or water produced from each reservoir; the reason the holder has relinquished the relinquished area or is applying to surrender the surrendered area; any other data or information for the report required under the practice direction. s 21 amd 2020 SL No. 208 s 7 (sec.21-ssec.1) This section prescribes— other information for a relinquishment report for an authority to prospect for the 2004 Act , section 545 (b) and the 1923 Act , section 75Z (b) ; and information for a surrender report for an authority to prospect for the 1923 Act , section 21 (4) (b) (ii) . (sec.21-ssec.2) The information is each of the following— the tenure information for the report; the general area information for the report; a summary of the results of all authorised activities for the authority carried out in the relinquished area or surrendered area since the authority took effect and the conclusions drawn by the holder based on the results, including any identified leads and prospects; the hazard information for the report; for each year since the authority took effect— for a relinquishment report—the volume of petroleum or water produced from each petroleum well or bore in the relinquished area; or for a surrender report—the location of each natural underground reservoir in the surrendered area and the volume of petroleum or water produced from each reservoir; the reason the holder has relinquished the relinquished area or is applying to surrender the surrendered area; any other data or information for the report required under the practice direction.

• (a) other information for a relinquishment report for an authority to prospect for the 2004 Act , section 545 (b) and the 1923 Act , section 75Z (b) ; and
• (b) information for a surrender report for an authority to prospect for the 1923 Act , section 21 (4) (b) (ii) .
• (a) the tenure information for the report;
• (b) the general area information for the report;
• (c) a summary of the results of all authorised activities for the authority carried out in the relinquished area or surrendered area since the authority took effect and the conclusions drawn by the holder based on the results, including any identified leads and prospects;
• (d) the hazard information for the report;
• (e) for each year since the authority took effect— (i) for a relinquishment report—the volume of petroleum or water produced from each petroleum well or bore in the relinquished area; or (ii) for a surrender report—the location of each natural underground reservoir in the surrendered area and the volume of petroleum or water produced from each reservoir;
• (i) for a relinquishment report—the volume of petroleum or water produced from each petroleum well or bore in the relinquished area; or
• (ii) for a surrender report—the location of each natural underground reservoir in the surrendered area and the volume of petroleum or water produced from each reservoir;
• (f) the reason the holder has relinquished the relinquished area or is applying to surrender the surrendered area;
• (g) any other data or information for the report required under the practice direction.
• (i) for a relinquishment report—the volume of petroleum or water produced from each petroleum well or bore in the relinquished area; or
• (ii) for a surrender report—the location of each natural underground reservoir in the surrendered area and the volume of petroleum or water produced from each reservoir;

sec.22 Petroleum lease—relinquishment report

This section prescribes other information for a relinquishment report for a petroleum lease for the 2004 Act , section 545 (b) and the 1923 Act , section 75Z (b) . The information is each of the following— the tenure information for the report; the general area information for the report; for each year since the lease took effect— the volume of petroleum produced under the lease from each petroleum well in the relinquished area; and the volume of water produced from each bore in the relinquished area; the geological model of the natural underground reservoirs in the relinquished area; a summary of the results of all authorised activities for the lease carried out in the relinquished area since the lease took effect and the conclusions drawn by the holder based on the results, including any identified leads and prospects; the hazard information for the report; the reason the holder has relinquished the area; any other data or information for the report required under the practice direction. s 22 amd 2020 SL No. 208 s 8 (sec.22-ssec.1) This section prescribes other information for a relinquishment report for a petroleum lease for the 2004 Act , section 545 (b) and the 1923 Act , section 75Z (b) . (sec.22-ssec.2) The information is each of the following— the tenure information for the report; the general area information for the report; for each year since the lease took effect— the volume of petroleum produced under the lease from each petroleum well in the relinquished area; and the volume of water produced from each bore in the relinquished area; the geological model of the natural underground reservoirs in the relinquished area; a summary of the results of all authorised activities for the lease carried out in the relinquished area since the lease took effect and the conclusions drawn by the holder based on the results, including any identified leads and prospects; the hazard information for the report; the reason the holder has relinquished the area; any other data or information for the report required under the practice direction.

• (a) the tenure information for the report;
• (b) the general area information for the report;
• (c) for each year since the lease took effect— (i) the volume of petroleum produced under the lease from each petroleum well in the relinquished area; and (ii) the volume of water produced from each bore in the relinquished area;
• (i) the volume of petroleum produced under the lease from each petroleum well in the relinquished area; and
• (ii) the volume of water produced from each bore in the relinquished area;
• (d) the geological model of the natural underground reservoirs in the relinquished area;
• (e) a summary of the results of all authorised activities for the lease carried out in the relinquished area since the lease took effect and the conclusions drawn by the holder based on the results, including any identified leads and prospects;
• (f) the hazard information for the report;
• (g) the reason the holder has relinquished the area;
• (h) any other data or information for the report required under the practice direction.
• (i) the volume of petroleum produced under the lease from each petroleum well in the relinquished area; and
• (ii) the volume of water produced from each bore in the relinquished area;

sec.23 Petroleum lease—surrender report

For the 2004 Act , section 576 (2) , the following information is prescribed for a surrender report for a petroleum lease— the hazard information for the report; spatial information showing the location in the surrendered area of— each petroleum well and bore drilled under the lease; and each seismic line used for a seismic survey carried out under the lease; structure contour spatial information showing the seismic horizons (seismic reflectors) in the surrendered area; spatial information showing the leads and prospects in the surrendered area; the reason the holder has applied to surrender the part of the area of the lease; any other data or information for the report required under the practice direction. s 23 amd 2020 SL No. 208 s 9

• (a) the hazard information for the report;
• (b) spatial information showing the location in the surrendered area of— (i) each petroleum well and bore drilled under the lease; and (ii) each seismic line used for a seismic survey carried out under the lease;
• (i) each petroleum well and bore drilled under the lease; and
• (ii) each seismic line used for a seismic survey carried out under the lease;
• (c) structure contour spatial information showing the seismic horizons (seismic reflectors) in the surrendered area;
• (d) spatial information showing the leads and prospects in the surrendered area;
• (e) the reason the holder has applied to surrender the part of the area of the lease;
• (f) any other data or information for the report required under the practice direction.
• (i) each petroleum well and bore drilled under the lease; and
• (ii) each seismic line used for a seismic survey carried out under the lease;

sec.24 Pipeline licence—surrender report

For the 2004 Act , section 576 (2) , the following information is prescribed for a surrender report for a pipeline licence— in relation to the licence— the day the licence was granted; and the term of the licence; and a description of the surrendered area; a description of, and spatial information showing, the location of the pipeline in the surrendered area, including access to the pipeline; a summary of the methods used to decommission the pipeline; details of all maintenance carried out on the pipeline during the term of the licence; the hazard information for the licence; any other data or information for the report required under the practice direction. s 24 amd 2020 SL No. 208 s 10

• (a) in relation to the licence— (i) the day the licence was granted; and (ii) the term of the licence; and (iii) a description of the surrendered area;
• (i) the day the licence was granted; and
• (ii) the term of the licence; and
• (iii) a description of the surrendered area;
• (b) a description of, and spatial information showing, the location of the pipeline in the surrendered area, including access to the pipeline;
• (c) a summary of the methods used to decommission the pipeline;
• (d) details of all maintenance carried out on the pipeline during the term of the licence;
• (e) the hazard information for the licence;
• (f) any other data or information for the report required under the practice direction.
• (i) the day the licence was granted; and
• (ii) the term of the licence; and
• (iii) a description of the surrendered area;

sec.25 End of tenure report

This section prescribes other information for an end of tenure report for the 2004 Act , section 546 (b) and the 1923 Act , section 76 (1) (b) . The information is the information stated in the following sections that is not mentioned in the 2004 Act , section 546 (a) or the 1923 Act , section 76 (1) (a) — sections 21 and 22 ; for an end of tenure report for a petroleum lease— section 23 . For subsection (2) , a reference in section 21 , 22 or 23 to the relinquished area or surrendered area is taken to be a reference to the area of the tenure immediately before it ended. Subsection (2) does not apply to the extent the information has been included in a relinquishment report or surrender report lodged for the tenure. (sec.25-ssec.1) This section prescribes other information for an end of tenure report for the 2004 Act , section 546 (b) and the 1923 Act , section 76 (1) (b) . (sec.25-ssec.2) The information is the information stated in the following sections that is not mentioned in the 2004 Act , section 546 (a) or the 1923 Act , section 76 (1) (a) — sections 21 and 22 ; for an end of tenure report for a petroleum lease— section 23 . (sec.25-ssec.3) For subsection (2) , a reference in section 21 , 22 or 23 to the relinquished area or surrendered area is taken to be a reference to the area of the tenure immediately before it ended. (sec.25-ssec.4) Subsection (2) does not apply to the extent the information has been included in a relinquishment report or surrender report lodged for the tenure.

• (a) sections 21 and 22 ;
• (b) for an end of tenure report for a petroleum lease— section 23 .

sec.26 End of authority report

For the 2004 Act , section 546A (2) , the following matters are prescribed— the authorised activities for the data acquisition authority or survey licence carried out during the term of the authority or licence; spatial information about each authorised activity carried out under the authority or licence; any other data or information for the report required under the practice direction. s 26 amd 2020 SL No. 208 s 11

• (a) the authorised activities for the data acquisition authority or survey licence carried out during the term of the authority or licence;
• (b) spatial information about each authorised activity carried out under the authority or licence;
• (c) any other data or information for the report required under the practice direction.

Prescribed notices and reports

sec.27 Purpose of division

This division prescribes the notices and reports required to be kept or lodged— under the 2004 Act , section 553 (1) (b) by the holder of a petroleum authority; and under the 1923 Act , section 76G (1) (b) by the holder of a 1923 Act petroleum tenure.

• (a) under the 2004 Act , section 553 (1) (b) by the holder of a petroleum authority; and
• (b) under the 1923 Act , section 76G (1) (b) by the holder of a 1923 Act petroleum tenure.

sec.28 Owners and occupiers to be given copy of notices

If the holder of a petroleum tenure is required to lodge a notice under this subdivision, the holder must give a copy of the notice— to each owner and occupier of the land on which the authorised activities to which the notice relates have been or are to be carried out; and by the time the notice is required to be lodged under this subdivision. The requirement under subsection (1) does not apply to the extent the holder is an owner or an occupier of the land. (sec.28-ssec.1) If the holder of a petroleum tenure is required to lodge a notice under this subdivision, the holder must give a copy of the notice— to each owner and occupier of the land on which the authorised activities to which the notice relates have been or are to be carried out; and by the time the notice is required to be lodged under this subdivision. (sec.28-ssec.2) The requirement under subsection (1) does not apply to the extent the holder is an owner or an occupier of the land.

• (a) to each owner and occupier of the land on which the authorised activities to which the notice relates have been or are to be carried out; and
• (b) by the time the notice is required to be lodged under this subdivision.

sec.29 Notice about intention to drill a petroleum well or bore

If the holder of a petroleum tenure intends to drill a petroleum well or bore, the holder must lodge a notice about the intended drilling. The notice must— be lodged at least 10 business days before the drilling starts; and be in the digital form made or approved by the chief executive; and for a notice about a petroleum well—state a proposed identifying name for the petroleum well. The proposed identifying name for the petroleum well must not be the same, or substantially the same, as an identifying name for another well recorded in the register. (sec.29-ssec.1) If the holder of a petroleum tenure intends to drill a petroleum well or bore, the holder must lodge a notice about the intended drilling. (sec.29-ssec.2) The notice must— be lodged at least 10 business days before the drilling starts; and be in the digital form made or approved by the chief executive; and for a notice about a petroleum well—state a proposed identifying name for the petroleum well. (sec.29-ssec.3) The proposed identifying name for the petroleum well must not be the same, or substantially the same, as an identifying name for another well recorded in the register.

• (a) be lodged at least 10 business days before the drilling starts; and
• (b) be in the digital form made or approved by the chief executive; and
• (c) for a notice about a petroleum well—state a proposed identifying name for the petroleum well.

sec.30 Notice about completion, alteration or abandonment of petroleum well or bore

If any of the following events happens, the relevant holder must lodge a notice about the event— drilling of a petroleum well or bore is completed; the completion configuration of a petroleum well changes; a petroleum well or bore is abandoned. For subsection (1) (a) , drilling of a petroleum well or bore is completed if— the drilling rig last used to drill the well or bore is moved so it is no longer above the well or bore; and the relevant holder intends no further drilling of the well or bore to occur. For subsection (1) (b) , the completion configuration of a petroleum well changes if, after drilling of the well is completed— additional casing is installed in the well; or any part of the well is plugged, other than for decommissioning the well; or an interval in the well is altered in any other way. The notice must be— lodged within 10 business days after the event happens; and in the digital form made or approved by the chief executive. In this section— relevant holder means— if the bore was drilled under a water monitoring authority under the 2004 Act —the holder of the water monitoring authority; or otherwise—the holder of the petroleum tenure under which the petroleum well or bore was drilled. (sec.30-ssec.1) If any of the following events happens, the relevant holder must lodge a notice about the event— drilling of a petroleum well or bore is completed; the completion configuration of a petroleum well changes; a petroleum well or bore is abandoned. (sec.30-ssec.2) For subsection (1) (a) , drilling of a petroleum well or bore is completed if— the drilling rig last used to drill the well or bore is moved so it is no longer above the well or bore; and the relevant holder intends no further drilling of the well or bore to occur. (sec.30-ssec.3) For subsection (1) (b) , the completion configuration of a petroleum well changes if, after drilling of the well is completed— additional casing is installed in the well; or any part of the well is plugged, other than for decommissioning the well; or an interval in the well is altered in any other way. (sec.30-ssec.4) The notice must be— lodged within 10 business days after the event happens; and in the digital form made or approved by the chief executive. (sec.30-ssec.5) In this section— relevant holder means— if the bore was drilled under a water monitoring authority under the 2004 Act —the holder of the water monitoring authority; or otherwise—the holder of the petroleum tenure under which the petroleum well or bore was drilled.

• (a) drilling of a petroleum well or bore is completed;
• (b) the completion configuration of a petroleum well changes;
• (c) a petroleum well or bore is abandoned.
• (a) the drilling rig last used to drill the well or bore is moved so it is no longer above the well or bore; and
• (b) the relevant holder intends no further drilling of the well or bore to occur.
• (a) additional casing is installed in the well; or
• (b) any part of the well is plugged, other than for decommissioning the well; or
• (c) an interval in the well is altered in any other way.
• (a) lodged within 10 business days after the event happens; and
• (b) in the digital form made or approved by the chief executive.
• (a) if the bore was drilled under a water monitoring authority under the 2004 Act —the holder of the water monitoring authority; or
• (b) otherwise—the holder of the petroleum tenure under which the petroleum well or bore was drilled.

sec.31 Notice about intention to carry out seismic survey or scientific or technical survey

If the holder of a petroleum tenure intends to carry out a seismic survey or scientific or technical survey in either of the following areas, the tenure holder must lodge a notice about the survey— the area of a petroleum tenure; or the area subject to a data acquisition authority that relates to a 2004 Act petroleum tenure. The notice must state the following matters— an identifying name for the survey; the type of survey to be carried out; seismic, geophysical, geochemical, geotechnical a description of the area to be surveyed; the day the surveying will start; the expected duration of the surveying. The identifying name for the survey must not be the same, or substantially the same, as an identifying name for another survey recorded in the register. The notice must be— lodged at least 10 business days before the survey starts; and in the approved form; and accompanied by spatial information showing the location of the area to be surveyed. (sec.31-ssec.1) If the holder of a petroleum tenure intends to carry out a seismic survey or scientific or technical survey in either of the following areas, the tenure holder must lodge a notice about the survey— the area of a petroleum tenure; or the area subject to a data acquisition authority that relates to a 2004 Act petroleum tenure. (sec.31-ssec.2) The notice must state the following matters— an identifying name for the survey; the type of survey to be carried out; seismic, geophysical, geochemical, geotechnical a description of the area to be surveyed; the day the surveying will start; the expected duration of the surveying. (sec.31-ssec.3) The identifying name for the survey must not be the same, or substantially the same, as an identifying name for another survey recorded in the register. (sec.31-ssec.4) The notice must be— lodged at least 10 business days before the survey starts; and in the approved form; and accompanied by spatial information showing the location of the area to be surveyed.

• (a) the area of a petroleum tenure; or
• (b) the area subject to a data acquisition authority that relates to a 2004 Act petroleum tenure.
• (a) an identifying name for the survey;
• (b) the type of survey to be carried out; Examples— seismic, geophysical, geochemical, geotechnical
• (c) a description of the area to be surveyed;
• (d) the day the surveying will start;
• (e) the expected duration of the surveying.
• (a) lodged at least 10 business days before the survey starts; and
• (b) in the approved form; and
• (c) accompanied by spatial information showing the location of the area to be surveyed.

sec.32 Notice about completion of seismic survey or scientific or technical survey

This section applies if a seismic survey or scientific or technical survey is completed in either of the following areas— the area of a petroleum tenure; or the area subject to a data acquisition authority that relates to a 2004 Act petroleum tenure. The holder of the petroleum tenure must lodge a notice about the completion of the survey. The notice must be— lodged within 10 business days after the survey is completed; and in the approved form. For subsection (2) , a survey is completed as soon as all of the raw data for the survey has been recorded or recovered. (sec.32-ssec.1) This section applies if a seismic survey or scientific or technical survey is completed in either of the following areas— the area of a petroleum tenure; or the area subject to a data acquisition authority that relates to a 2004 Act petroleum tenure. (sec.32-ssec.2) The holder of the petroleum tenure must lodge a notice about the completion of the survey. (sec.32-ssec.3) The notice must be— lodged within 10 business days after the survey is completed; and in the approved form. (sec.32-ssec.4) For subsection (2) , a survey is completed as soon as all of the raw data for the survey has been recorded or recovered.

• (a) the area of a petroleum tenure; or
• (b) the area subject to a data acquisition authority that relates to a 2004 Act petroleum tenure.
• (a) lodged within 10 business days after the survey is completed; and
• (b) in the approved form.

sec.33 Notice about intention to carry out hydraulic fracturing activities

If the holder of a petroleum tenure intends to carry out hydraulic fracturing activities in the prescribed area for a petroleum tenure, the tenure holder must lodge a notice about the intended activities. The notice must be— lodged at least 10 business days before the hydraulic fracturing activities start being carried out; and in the digital form made or approved by the chief executive. (sec.33-ssec.1) If the holder of a petroleum tenure intends to carry out hydraulic fracturing activities in the prescribed area for a petroleum tenure, the tenure holder must lodge a notice about the intended activities. (sec.33-ssec.2) The notice must be— lodged at least 10 business days before the hydraulic fracturing activities start being carried out; and in the digital form made or approved by the chief executive.

• (a) lodged at least 10 business days before the hydraulic fracturing activities start being carried out; and
• (b) in the digital form made or approved by the chief executive.

sec.34 Notice about completion of hydraulic fracturing activities

If the holder of a petroleum tenure has finished carrying out hydraulic fracturing activities in the prescribed area for the tenure, the tenure holder must lodge a notice about the completion of the activities. The notice must state— the days the hydraulic fracturing activities started and ended; and the name of the operator of the drilling project involving the activities; and the name of the contractor who carried out the activities for the operator of the drilling project; and details of the composition of the hydraulic fracturing fluid pumped into the petroleum well used for the activities. The notice must be— lodged within 10 business days after the hydraulic fracturing activities are completed; and in the digital form made or approved by the chief executive. (sec.34-ssec.1) If the holder of a petroleum tenure has finished carrying out hydraulic fracturing activities in the prescribed area for the tenure, the tenure holder must lodge a notice about the completion of the activities. (sec.34-ssec.2) The notice must state— the days the hydraulic fracturing activities started and ended; and the name of the operator of the drilling project involving the activities; and the name of the contractor who carried out the activities for the operator of the drilling project; and details of the composition of the hydraulic fracturing fluid pumped into the petroleum well used for the activities. (sec.34-ssec.3) The notice must be— lodged within 10 business days after the hydraulic fracturing activities are completed; and in the digital form made or approved by the chief executive.

• (a) the days the hydraulic fracturing activities started and ended; and
• (b) the name of the operator of the drilling project involving the activities; and
• (c) the name of the contractor who carried out the activities for the operator of the drilling project; and
• (d) details of the composition of the hydraulic fracturing fluid pumped into the petroleum well used for the activities.
• (a) lodged within 10 business days after the hydraulic fracturing activities are completed; and
• (b) in the digital form made or approved by the chief executive.

sec.35 Daily drilling report

The holder of a petroleum tenure must keep a daily drilling report for each day on which drilling of a petroleum well is carried out under the tenure. A copy of each daily drilling report must be lodged with the petroleum well or bore completion report lodged for the well. Also, a copy of a daily drilling report must be lodged if the chief executive asks for the report to be lodged. A daily drilling report for a petroleum well must contain the following information about the drilling carried out on the day to which the report relates— the identifying name of the well; the tenure holder’s name and the tenure under which the well was drilled; the type of drilling rig used; a summary of the drilling operations carried out; the depth in metres of the well at the end of the day’s drilling; the size and type of drill bit used; the drilling fluids and additives used; the size and depth in metres of any casing inserted in the well; the depth in metres of the top and bottom of each cemented interval in the well; the results of any deviation surveys carried out in the well; a description of any drill stem tests or other tests carried out in the well; the depth in metres of the top and bottom of the hydrocarbon show intervals in the well and the type and description of any surface observations of each interval; the type of any perforations in the well and the depth in metres of the top and bottom of the perforated intervals; details of any stimulation carried out; details of any squeeze cementing or cement plugging carried out; a description of any cores or cutting samples taken; any other data or information for the report required under the practice direction. In this section— deviation survey means a survey of the path of a petroleum well that measures its direction in 3 dimensions. s 35 amd 2020 SL No. 208 s 12 (sec.35-ssec.1) The holder of a petroleum tenure must keep a daily drilling report for each day on which drilling of a petroleum well is carried out under the tenure. (sec.35-ssec.2) A copy of each daily drilling report must be lodged with the petroleum well or bore completion report lodged for the well. (sec.35-ssec.3) Also, a copy of a daily drilling report must be lodged if the chief executive asks for the report to be lodged. (sec.35-ssec.4) A daily drilling report for a petroleum well must contain the following information about the drilling carried out on the day to which the report relates— the identifying name of the well; the tenure holder’s name and the tenure under which the well was drilled; the type of drilling rig used; a summary of the drilling operations carried out; the depth in metres of the well at the end of the day’s drilling; the size and type of drill bit used; the drilling fluids and additives used; the size and depth in metres of any casing inserted in the well; the depth in metres of the top and bottom of each cemented interval in the well; the results of any deviation surveys carried out in the well; a description of any drill stem tests or other tests carried out in the well; the depth in metres of the top and bottom of the hydrocarbon show intervals in the well and the type and description of any surface observations of each interval; the type of any perforations in the well and the depth in metres of the top and bottom of the perforated intervals; details of any stimulation carried out; details of any squeeze cementing or cement plugging carried out; a description of any cores or cutting samples taken; any other data or information for the report required under the practice direction. (sec.35-ssec.5) In this section— deviation survey means a survey of the path of a petroleum well that measures its direction in 3 dimensions.

• (a) the identifying name of the well;
• (b) the tenure holder’s name and the tenure under which the well was drilled;
• (c) the type of drilling rig used;
• (d) a summary of the drilling operations carried out;
• (e) the depth in metres of the well at the end of the day’s drilling;
• (f) the size and type of drill bit used;
• (g) the drilling fluids and additives used;
• (h) the size and depth in metres of any casing inserted in the well;
• (i) the depth in metres of the top and bottom of each cemented interval in the well;
• (j) the results of any deviation surveys carried out in the well;
• (k) a description of any drill stem tests or other tests carried out in the well;
• (l) the depth in metres of the top and bottom of the hydrocarbon show intervals in the well and the type and description of any surface observations of each interval;
• (m) the type of any perforations in the well and the depth in metres of the top and bottom of the perforated intervals;
• (n) details of any stimulation carried out;
• (o) details of any squeeze cementing or cement plugging carried out;
• (p) a description of any cores or cutting samples taken;
• (q) any other data or information for the report required under the practice direction.

sec.36 Petroleum well or bore completion report

If the drilling of petroleum well or bore under a petroleum tenure is completed, the tenure holder must lodge a report about the completion of the well or bore (a petroleum well or bore completion report ). The report must be lodged within 12 months after the rig release day for the well or bore. The report must contain the following information— the type and number of the petroleum tenure; the name and postal address of the operator of the well or bore; the identifying name of the well or bore; a summary of the well or bore including the information for the well or bore required under the practice direction; spatial information showing the location of the well or bore; the height reference in metres for the drilling rig used to drill the well or bore; the total depth in metres of the well or bore; the following days— the day the drilling of the well or bore started; the day the total depth of the well or bore was reached; the rig release day for the well or bore; details of the drilling rig, the number and type of drill bits, and the drilling fluids, used in the well or bore; the status of the well or bore on the rig release day; the surveyed path of the well or bore; details of the casing and equipment installed in the well or bore, with a diagram showing their location in the well or bore; the type of any perforations in the well or bore, the depth in metres of the top and bottom of the perforated intervals and the perforation spacing in metres; details of the cementing in the well or bore, including its location, the type of cement used and the depth in metres of the top and bottom of each cemented interval; a description of all tests or surveys carried out in the well or bore, the depth in metres where each test was carried out and the distance in metres between the top and bottom of each testing interval; a geological interpretation of the well or bore, including the stratigraphy of the rock units it intersects; an identification of the intervals in the well that have the potential to produce petroleum; the tenure holder’s reasons for choosing the location of the well or bore; any other data or information for the report required under the practice direction. For a directional well, the report must also state the position of each of the following— the stratigraphic units intersected by the well; the bottom of the well; any intersection of the well with another petroleum well. For subsection (4) , the position must be expressed in relation to— total vertical depth in metres; and the horizontal plane. The report must be accompanied by each of the following— a digital image of the cores taken during the drilling of the well or bore; the raw data, in digital form, of each geophysical (or wireline) log that has been run in the well or bore; a digital image of the graphic representations of the raw data mentioned in paragraph (b) . If the petroleum well or bore is plugged and abandoned on or before the rig release day for the well or bore, the report must also contain the information stated in section 37 (4) . s 36 amd 2020 SL No. 208 s 13 (sec.36-ssec.1) If the drilling of petroleum well or bore under a petroleum tenure is completed, the tenure holder must lodge a report about the completion of the well or bore (a petroleum well or bore completion report ). (sec.36-ssec.2) The report must be lodged within 12 months after the rig release day for the well or bore. (sec.36-ssec.3) The report must contain the following information— the type and number of the petroleum tenure; the name and postal address of the operator of the well or bore; the identifying name of the well or bore; a summary of the well or bore including the information for the well or bore required under the practice direction; spatial information showing the location of the well or bore; the height reference in metres for the drilling rig used to drill the well or bore; the total depth in metres of the well or bore; the following days— the day the drilling of the well or bore started; the day the total depth of the well or bore was reached; the rig release day for the well or bore; details of the drilling rig, the number and type of drill bits, and the drilling fluids, used in the well or bore; the status of the well or bore on the rig release day; the surveyed path of the well or bore; details of the casing and equipment installed in the well or bore, with a diagram showing their location in the well or bore; the type of any perforations in the well or bore, the depth in metres of the top and bottom of the perforated intervals and the perforation spacing in metres; details of the cementing in the well or bore, including its location, the type of cement used and the depth in metres of the top and bottom of each cemented interval; a description of all tests or surveys carried out in the well or bore, the depth in metres where each test was carried out and the distance in metres between the top and bottom of each testing interval; a geological interpretation of the well or bore, including the stratigraphy of the rock units it intersects; an identification of the intervals in the well that have the potential to produce petroleum; the tenure holder’s reasons for choosing the location of the well or bore; any other data or information for the report required under the practice direction. (sec.36-ssec.4) For a directional well, the report must also state the position of each of the following— the stratigraphic units intersected by the well; the bottom of the well; any intersection of the well with another petroleum well. (sec.36-ssec.5) For subsection (4) , the position must be expressed in relation to— total vertical depth in metres; and the horizontal plane. (sec.36-ssec.6) The report must be accompanied by each of the following— a digital image of the cores taken during the drilling of the well or bore; the raw data, in digital form, of each geophysical (or wireline) log that has been run in the well or bore; a digital image of the graphic representations of the raw data mentioned in paragraph (b) . (sec.36-ssec.7) If the petroleum well or bore is plugged and abandoned on or before the rig release day for the well or bore, the report must also contain the information stated in section 37 (4) .

• (a) the type and number of the petroleum tenure;
• (b) the name and postal address of the operator of the well or bore;
• (c) the identifying name of the well or bore;
• (d) a summary of the well or bore including the information for the well or bore required under the practice direction;
• (e) spatial information showing the location of the well or bore;
• (f) the height reference in metres for the drilling rig used to drill the well or bore;
• (g) the total depth in metres of the well or bore;
• (h) the following days— (i) the day the drilling of the well or bore started; (ii) the day the total depth of the well or bore was reached; (iii) the rig release day for the well or bore;
• (i) the day the drilling of the well or bore started;
• (ii) the day the total depth of the well or bore was reached;
• (iii) the rig release day for the well or bore;
• (i) details of the drilling rig, the number and type of drill bits, and the drilling fluids, used in the well or bore;
• (j) the status of the well or bore on the rig release day;
• (k) the surveyed path of the well or bore;
• (l) details of the casing and equipment installed in the well or bore, with a diagram showing their location in the well or bore;
• (m) the type of any perforations in the well or bore, the depth in metres of the top and bottom of the perforated intervals and the perforation spacing in metres;
• (n) details of the cementing in the well or bore, including its location, the type of cement used and the depth in metres of the top and bottom of each cemented interval;
• (o) a description of all tests or surveys carried out in the well or bore, the depth in metres where each test was carried out and the distance in metres between the top and bottom of each testing interval;
• (p) a geological interpretation of the well or bore, including the stratigraphy of the rock units it intersects;
• (q) an identification of the intervals in the well that have the potential to produce petroleum;
• (r) the tenure holder’s reasons for choosing the location of the well or bore;
• (s) any other data or information for the report required under the practice direction.
• (i) the day the drilling of the well or bore started;
• (ii) the day the total depth of the well or bore was reached;
• (iii) the rig release day for the well or bore;
• (a) the stratigraphic units intersected by the well;
• (b) the bottom of the well;
• (c) any intersection of the well with another petroleum well.
• (a) total vertical depth in metres; and
• (b) the horizontal plane.
• (a) a digital image of the cores taken during the drilling of the well or bore;
• (b) the raw data, in digital form, of each geophysical (or wireline) log that has been run in the well or bore;
• (c) a digital image of the graphic representations of the raw data mentioned in paragraph (b) .

sec.37 Petroleum well or bore abandonment report

This section applies to a petroleum well or bore drilled under a petroleum tenure or water monitoring authority under the 2004 Act . If the tenure holder or authority holder plugs and abandons the petroleum well or bore after its rig release day, the tenure holder or authority holder must lodge a report about the abandonment (a petroleum well or bore abandonment report ). The report must be lodged within 6 months after the day the plugging and abandoning of the well or bore is completed. The report must contain the following information— the type and number of the tenure or authority; the identifying name of the well or bore; the name of the author of the report; the name of the tenure or authority holder; the name of the operator of the well or bore; a summary of the well or bore including the information for the well or bore required under the practice direction; the following information in relation to the completion or abandonment of the well or bore— a full description of all equipment, including prescribed equipment, left in the well or bore, including the size and nature of the equipment and any features of the equipment that may cause a hazard to coal mining operations; aluminium, electronics or batteries the surveyed location of any prescribed equipment; the method of the cementing operations carried out in or on the well or bore, including the location and type of plugs, the intervals covered by the operations, the volume and type of cement used, any losses of cement due to voids or permeable strata, and the methods used to overcome losses of cement; the method, materials and volume of cement used to cement voids; a description of procedures or activities undertaken for abandonment of the well or bore; any other data or information for the report required under the practice direction. In this section— coal mining operations see the Coal Mining Safety and Health Act 1999 , schedule 3 . prescribed equipment means— metal equipment, other than casing; and other equipment that may create a hazard to coal mining operations. drilling equipment and geophysical logging tools s 37 amd 2018 SL No. 135 s 183 ; 2020 SL No. 208 s 14 (sec.37-ssec.1) This section applies to a petroleum well or bore drilled under a petroleum tenure or water monitoring authority under the 2004 Act . (sec.37-ssec.2) If the tenure holder or authority holder plugs and abandons the petroleum well or bore after its rig release day, the tenure holder or authority holder must lodge a report about the abandonment (a petroleum well or bore abandonment report ). (sec.37-ssec.3) The report must be lodged within 6 months after the day the plugging and abandoning of the well or bore is completed. (sec.37-ssec.4) The report must contain the following information— the type and number of the tenure or authority; the identifying name of the well or bore; the name of the author of the report; the name of the tenure or authority holder; the name of the operator of the well or bore; a summary of the well or bore including the information for the well or bore required under the practice direction; the following information in relation to the completion or abandonment of the well or bore— a full description of all equipment, including prescribed equipment, left in the well or bore, including the size and nature of the equipment and any features of the equipment that may cause a hazard to coal mining operations; aluminium, electronics or batteries the surveyed location of any prescribed equipment; the method of the cementing operations carried out in or on the well or bore, including the location and type of plugs, the intervals covered by the operations, the volume and type of cement used, any losses of cement due to voids or permeable strata, and the methods used to overcome losses of cement; the method, materials and volume of cement used to cement voids; a description of procedures or activities undertaken for abandonment of the well or bore; any other data or information for the report required under the practice direction. (sec.37-ssec.5) In this section— coal mining operations see the Coal Mining Safety and Health Act 1999 , schedule 3 . prescribed equipment means— metal equipment, other than casing; and other equipment that may create a hazard to coal mining operations. drilling equipment and geophysical logging tools

• (a) the type and number of the tenure or authority;
• (b) the identifying name of the well or bore;
• (c) the name of the author of the report;
• (d) the name of the tenure or authority holder;
• (e) the name of the operator of the well or bore;
• (f) a summary of the well or bore including the information for the well or bore required under the practice direction;
• (g) the following information in relation to the completion or abandonment of the well or bore— (i) a full description of all equipment, including prescribed equipment, left in the well or bore, including the size and nature of the equipment and any features of the equipment that may cause a hazard to coal mining operations; Example of features that may cause a hazard to coal mining operations— aluminium, electronics or batteries (ii) the surveyed location of any prescribed equipment; (iii) the method of the cementing operations carried out in or on the well or bore, including the location and type of plugs, the intervals covered by the operations, the volume and type of cement used, any losses of cement due to voids or permeable strata, and the methods used to overcome losses of cement; (iv) the method, materials and volume of cement used to cement voids; (v) a description of procedures or activities undertaken for abandonment of the well or bore;
• (i) a full description of all equipment, including prescribed equipment, left in the well or bore, including the size and nature of the equipment and any features of the equipment that may cause a hazard to coal mining operations; Example of features that may cause a hazard to coal mining operations— aluminium, electronics or batteries
• (ii) the surveyed location of any prescribed equipment;
• (iii) the method of the cementing operations carried out in or on the well or bore, including the location and type of plugs, the intervals covered by the operations, the volume and type of cement used, any losses of cement due to voids or permeable strata, and the methods used to overcome losses of cement;
• (iv) the method, materials and volume of cement used to cement voids;
• (v) a description of procedures or activities undertaken for abandonment of the well or bore;
• (h) any other data or information for the report required under the practice direction.
• (i) a full description of all equipment, including prescribed equipment, left in the well or bore, including the size and nature of the equipment and any features of the equipment that may cause a hazard to coal mining operations; Example of features that may cause a hazard to coal mining operations— aluminium, electronics or batteries
• (ii) the surveyed location of any prescribed equipment;
• (iii) the method of the cementing operations carried out in or on the well or bore, including the location and type of plugs, the intervals covered by the operations, the volume and type of cement used, any losses of cement due to voids or permeable strata, and the methods used to overcome losses of cement;
• (iv) the method, materials and volume of cement used to cement voids;
• (v) a description of procedures or activities undertaken for abandonment of the well or bore;
• (a) metal equipment, other than casing; and
• (b) other equipment that may create a hazard to coal mining operations.

sec.38 Seismic survey reports

This section applies if the holder of a petroleum tenure— carries out a seismic survey of an area of the tenure; or for a 2004 Act petroleum tenure—carries out a seismic survey of an area subject to a data acquisition authority to which the tenure relates; or reprocesses raw data obtained from a survey mentioned in paragraph (a) or (b) . The tenure holder must lodge a seismic survey report within— for a survey mentioned subsection (1) (a) or (b) —2 years after the completion day for the survey; or if the tenure holder reprocesses raw data obtained as mentioned in subsection (1) (c) —2 years after the day the reprocessing is completed. The report must contain the following information— a description of the location of the area surveyed; the objectives of the survey; the activities carried out for the survey, including, for example, details of the seismic lines used and the days on which the activities were carried out; a description of each method used to acquire raw data, including— the equipment used for positioning, surveying, navigation or other purposes; and the techniques and equipment used for recording and testing the data; a description of how the raw data was processed or reprocessed; an evaluation of the processed or reprocessed data; any other data or information for the report required under the practice direction. The report must be accompanied by— each of the following in digital form— the raw data obtained in relation to the survey and the record made as the data was recorded (commonly known as the ‘observer’s logs’); a list of the seismic lines used and the range of the numbered stations on each line; the surveyed location, including the elevation, of each seismic source and receiver point; the processed or reprocessed data derived from each seismic line used for the survey; and if an activity for the survey was carried out by a contractor of the tenure holder, a copy of any report given to the holder by the contractor in relation to the activity; and spatial information showing the location of the seismic lines used for the survey. s 38 amd 2019 SL No. 53 s 19 ; 2020 SL No. 208 s 15 (sec.38-ssec.1) This section applies if the holder of a petroleum tenure— carries out a seismic survey of an area of the tenure; or for a 2004 Act petroleum tenure—carries out a seismic survey of an area subject to a data acquisition authority to which the tenure relates; or reprocesses raw data obtained from a survey mentioned in paragraph (a) or (b) . (sec.38-ssec.2) The tenure holder must lodge a seismic survey report within— for a survey mentioned subsection (1) (a) or (b) —2 years after the completion day for the survey; or if the tenure holder reprocesses raw data obtained as mentioned in subsection (1) (c) —2 years after the day the reprocessing is completed. (sec.38-ssec.3) The report must contain the following information— a description of the location of the area surveyed; the objectives of the survey; the activities carried out for the survey, including, for example, details of the seismic lines used and the days on which the activities were carried out; a description of each method used to acquire raw data, including— the equipment used for positioning, surveying, navigation or other purposes; and the techniques and equipment used for recording and testing the data; a description of how the raw data was processed or reprocessed; an evaluation of the processed or reprocessed data; any other data or information for the report required under the practice direction. (sec.38-ssec.4) The report must be accompanied by— each of the following in digital form— the raw data obtained in relation to the survey and the record made as the data was recorded (commonly known as the ‘observer’s logs’); a list of the seismic lines used and the range of the numbered stations on each line; the surveyed location, including the elevation, of each seismic source and receiver point; the processed or reprocessed data derived from each seismic line used for the survey; and if an activity for the survey was carried out by a contractor of the tenure holder, a copy of any report given to the holder by the contractor in relation to the activity; and spatial information showing the location of the seismic lines used for the survey.

• (a) carries out a seismic survey of an area of the tenure; or
• (b) for a 2004 Act petroleum tenure—carries out a seismic survey of an area subject to a data acquisition authority to which the tenure relates; or
• (c) reprocesses raw data obtained from a survey mentioned in paragraph (a) or (b) .
• (a) for a survey mentioned subsection (1) (a) or (b) —2 years after the completion day for the survey; or
• (b) if the tenure holder reprocesses raw data obtained as mentioned in subsection (1) (c) —2 years after the day the reprocessing is completed.
• (a) a description of the location of the area surveyed;
• (b) the objectives of the survey;
• (c) the activities carried out for the survey, including, for example, details of the seismic lines used and the days on which the activities were carried out;
• (d) a description of each method used to acquire raw data, including— (i) the equipment used for positioning, surveying, navigation or other purposes; and (ii) the techniques and equipment used for recording and testing the data;
• (i) the equipment used for positioning, surveying, navigation or other purposes; and
• (ii) the techniques and equipment used for recording and testing the data;
• (e) a description of how the raw data was processed or reprocessed;
• (f) an evaluation of the processed or reprocessed data;
• (g) any other data or information for the report required under the practice direction.
• (i) the equipment used for positioning, surveying, navigation or other purposes; and
• (ii) the techniques and equipment used for recording and testing the data;
• (a) each of the following in digital form— (i) the raw data obtained in relation to the survey and the record made as the data was recorded (commonly known as the ‘observer’s logs’); (ii) a list of the seismic lines used and the range of the numbered stations on each line; (iii) the surveyed location, including the elevation, of each seismic source and receiver point; (iv) the processed or reprocessed data derived from each seismic line used for the survey; and
• (i) the raw data obtained in relation to the survey and the record made as the data was recorded (commonly known as the ‘observer’s logs’);
• (ii) a list of the seismic lines used and the range of the numbered stations on each line;
• (iii) the surveyed location, including the elevation, of each seismic source and receiver point;
• (iv) the processed or reprocessed data derived from each seismic line used for the survey; and
• (b) if an activity for the survey was carried out by a contractor of the tenure holder, a copy of any report given to the holder by the contractor in relation to the activity; and
• (c) spatial information showing the location of the seismic lines used for the survey.
• (i) the raw data obtained in relation to the survey and the record made as the data was recorded (commonly known as the ‘observer’s logs’);
• (ii) a list of the seismic lines used and the range of the numbered stations on each line;
• (iii) the surveyed location, including the elevation, of each seismic source and receiver point;
• (iv) the processed or reprocessed data derived from each seismic line used for the survey; and

sec.39 Scientific or technical survey report

This section applies if the holder of a petroleum tenure— carries out a scientific or technical survey of an area of the tenure; or for a 2004 Act petroleum tenure—carries out a scientific or technical survey of an area subject to a data acquisition authority to which the tenure relates; or reprocesses raw data obtained from a survey mentioned in paragraph (a) or (b) . The tenure holder must lodge a scientific or technical survey report within— for a survey mentioned subsection (1) (a) or (b) —2 years after the completion day for the survey; or if the tenure holder reprocesses raw data as mentioned in subsection (1) (c) —2 years after the day the reprocessing is completed. The report must contain the following information— a description of the location of the area surveyed; the type of survey carried out; the objectives of the survey; the activities carried out for the survey, including, for example, the days on which the activities were carried out; the methods and equipment used for acquiring and processing, or reprocessing, data; an interpretation of the processed or reprocessed data derived from the survey; spatial information showing the location of— the area surveyed; and where any measurements were made or samples were taken in connection with the survey; any other data or information for the report required under the practice direction. The report must be accompanied by each of the following in digital form— the raw data obtained in relation to the survey; the processed or reprocessed data derived from the survey. s 39 amd 2019 SL No. 53 s 20; 2020 SL No. 208 s 16 (sec.39-ssec.1) This section applies if the holder of a petroleum tenure— carries out a scientific or technical survey of an area of the tenure; or for a 2004 Act petroleum tenure—carries out a scientific or technical survey of an area subject to a data acquisition authority to which the tenure relates; or reprocesses raw data obtained from a survey mentioned in paragraph (a) or (b) . (sec.39-ssec.2) The tenure holder must lodge a scientific or technical survey report within— for a survey mentioned subsection (1) (a) or (b) —2 years after the completion day for the survey; or if the tenure holder reprocesses raw data as mentioned in subsection (1) (c) —2 years after the day the reprocessing is completed. (sec.39-ssec.3) The report must contain the following information— a description of the location of the area surveyed; the type of survey carried out; the objectives of the survey; the activities carried out for the survey, including, for example, the days on which the activities were carried out; the methods and equipment used for acquiring and processing, or reprocessing, data; an interpretation of the processed or reprocessed data derived from the survey; spatial information showing the location of— the area surveyed; and where any measurements were made or samples were taken in connection with the survey; any other data or information for the report required under the practice direction. (sec.39-ssec.4) The report must be accompanied by each of the following in digital form— the raw data obtained in relation to the survey; the processed or reprocessed data derived from the survey.

• (a) carries out a scientific or technical survey of an area of the tenure; or
• (b) for a 2004 Act petroleum tenure—carries out a scientific or technical survey of an area subject to a data acquisition authority to which the tenure relates; or
• (c) reprocesses raw data obtained from a survey mentioned in paragraph (a) or (b) .
• (a) for a survey mentioned subsection (1) (a) or (b) —2 years after the completion day for the survey; or
• (b) if the tenure holder reprocesses raw data as mentioned in subsection (1) (c) —2 years after the day the reprocessing is completed.
• (a) a description of the location of the area surveyed;
• (b) the type of survey carried out;
• (c) the objectives of the survey;
• (d) the activities carried out for the survey, including, for example, the days on which the activities were carried out;
• (e) the methods and equipment used for acquiring and processing, or reprocessing, data;
• (f) an interpretation of the processed or reprocessed data derived from the survey;
• (g) spatial information showing the location of— (i) the area surveyed; and (ii) where any measurements were made or samples were taken in connection with the survey;
• (i) the area surveyed; and
• (ii) where any measurements were made or samples were taken in connection with the survey;
• (h) any other data or information for the report required under the practice direction.
• (i) the area surveyed; and
• (ii) where any measurements were made or samples were taken in connection with the survey;
• (a) the raw data obtained in relation to the survey;
• (b) the processed or reprocessed data derived from the survey.

sec.40 Definition for subdivision

In this subdivision— 6-month period , for a petroleum tenure, means a following period in a year during which, for all or part of the period, the tenure is in effect— 1 January to 30 June; 1 July to 31 December.

• (a) 1 January to 30 June;
• (b) 1 July to 31 December.

sec.41 How particular measurements must be stated in reports

This section applies if this subdivision requires a measurement to be stated in a report. The measurement of a volume or mass must be stated in— for water—megalitres; or for gas—million cubic metres (Mm3); or for LPG—kilotonnes; or for crude oil or condensate—million barrels (also known as MMbbl). The measurement of energy must be stated in— for petroleum, a prescribed storage gas or substance prescribed under the 2004 Act , section 402 (1) , including coal seam gas—petajoules; or for crude oil or condensate—energy of oil in million barrels of oil equivalent (also known as MMBOE). The measurement of a depth, length or other distance must be stated in metres. s 41 sub 2020 SL No. 208 s 17 (sec.41-ssec.1) This section applies if this subdivision requires a measurement to be stated in a report. (sec.41-ssec.2) The measurement of a volume or mass must be stated in— for water—megalitres; or for gas—million cubic metres (Mm3); or for LPG—kilotonnes; or for crude oil or condensate—million barrels (also known as MMbbl). (sec.41-ssec.3) The measurement of energy must be stated in— for petroleum, a prescribed storage gas or substance prescribed under the 2004 Act , section 402 (1) , including coal seam gas—petajoules; or for crude oil or condensate—energy of oil in million barrels of oil equivalent (also known as MMBOE). (sec.41-ssec.4) The measurement of a depth, length or other distance must be stated in metres.

• (a) for water—megalitres; or
• (b) for gas—million cubic metres (Mm3); or
• (c) for LPG—kilotonnes; or
• (d) for crude oil or condensate—million barrels (also known as MMbbl).
• (a) for petroleum, a prescribed storage gas or substance prescribed under the 2004 Act , section 402 (1) , including coal seam gas—petajoules; or
• (b) for crude oil or condensate—energy of oil in million barrels of oil equivalent (also known as MMBOE).

sec.42 Petroleum production report

The holder of a petroleum lease must lodge a petroleum production report for the lease for each 6-month period. The report must be lodged within 60 business days after the 6-month period ends. The report must contain the following information— the number of the lease; an identification of each production interval or geological unit from which first-produced petroleum is produced under the lease during the 6-month period; the volume of each of the following produced under the lease during the 6-month period— each petroleum product derived from first-produced petroleum; first-produced petroleum that was flared or vented in a gaseous state; first-produced petroleum that was used to produce other petroleum; the volume, or estimated volume, of associated water taken from each natural underground reservoir during the 6-month period and the lease period; for each natural underground reservoir from which petroleum is produced under the lease—the number of petroleum wells producing petroleum from the reservoir; for each petroleum well drilled for the purpose of producing coal seam gas within the area of the lease—the volume, or an estimate of the volume, of associated water taken from the well under the lease during the 6-month period; if a petroleum well within the area of the lease changes after a report for the well is lodged under section 36 —details of the casing and equipment installed in the well and a diagram showing the location of the casing and equipment; any other data or information for the report required under the practice direction. In this section— first-produced petroleum means petroleum extracted from a natural reservoir, other than petroleum that is stored, in a natural reservoir or otherwise, and later re-extracted. lease period means— for a volume of petroleum, or a petroleum product derived from petroleum, produced under a lease for a 6-month report—the period starting on the day petroleum was first produced under the lease and ending on the last day of the 6-month period; or for a volume or estimated volume of associated water taken under a lease for a 6-month report—the period starting on the day associated water was first taken under the lease and ending on the last day of the 6-month period. s 42 amd 2020 SL No. 208 s 18 (sec.42-ssec.1) The holder of a petroleum lease must lodge a petroleum production report for the lease for each 6-month period. (sec.42-ssec.2) The report must be lodged within 60 business days after the 6-month period ends. (sec.42-ssec.3) The report must contain the following information— the number of the lease; an identification of each production interval or geological unit from which first-produced petroleum is produced under the lease during the 6-month period; the volume of each of the following produced under the lease during the 6-month period— each petroleum product derived from first-produced petroleum; first-produced petroleum that was flared or vented in a gaseous state; first-produced petroleum that was used to produce other petroleum; the volume, or estimated volume, of associated water taken from each natural underground reservoir during the 6-month period and the lease period; for each natural underground reservoir from which petroleum is produced under the lease—the number of petroleum wells producing petroleum from the reservoir; for each petroleum well drilled for the purpose of producing coal seam gas within the area of the lease—the volume, or an estimate of the volume, of associated water taken from the well under the lease during the 6-month period; if a petroleum well within the area of the lease changes after a report for the well is lodged under section 36 —details of the casing and equipment installed in the well and a diagram showing the location of the casing and equipment; any other data or information for the report required under the practice direction. (sec.42-ssec.4) In this section— first-produced petroleum means petroleum extracted from a natural reservoir, other than petroleum that is stored, in a natural reservoir or otherwise, and later re-extracted. lease period means— for a volume of petroleum, or a petroleum product derived from petroleum, produced under a lease for a 6-month report—the period starting on the day petroleum was first produced under the lease and ending on the last day of the 6-month period; or for a volume or estimated volume of associated water taken under a lease for a 6-month report—the period starting on the day associated water was first taken under the lease and ending on the last day of the 6-month period.

• (a) the number of the lease;
• (b) an identification of each production interval or geological unit from which first-produced petroleum is produced under the lease during the 6-month period;
• (c) the volume of each of the following produced under the lease during the 6-month period— (i) each petroleum product derived from first-produced petroleum; (ii) first-produced petroleum that was flared or vented in a gaseous state; (iii) first-produced petroleum that was used to produce other petroleum;
• (i) each petroleum product derived from first-produced petroleum;
• (ii) first-produced petroleum that was flared or vented in a gaseous state;
• (iii) first-produced petroleum that was used to produce other petroleum;
• (d) the volume, or estimated volume, of associated water taken from each natural underground reservoir during the 6-month period and the lease period;
• (e) for each natural underground reservoir from which petroleum is produced under the lease—the number of petroleum wells producing petroleum from the reservoir;
• (f) for each petroleum well drilled for the purpose of producing coal seam gas within the area of the lease—the volume, or an estimate of the volume, of associated water taken from the well under the lease during the 6-month period;
• (g) if a petroleum well within the area of the lease changes after a report for the well is lodged under section 36 —details of the casing and equipment installed in the well and a diagram showing the location of the casing and equipment;
• (h) any other data or information for the report required under the practice direction.
• (i) each petroleum product derived from first-produced petroleum;
• (ii) first-produced petroleum that was flared or vented in a gaseous state;
• (iii) first-produced petroleum that was used to produce other petroleum;
• (a) for a volume of petroleum, or a petroleum product derived from petroleum, produced under a lease for a 6-month report—the period starting on the day petroleum was first produced under the lease and ending on the last day of the 6-month period; or
• (b) for a volume or estimated volume of associated water taken under a lease for a 6-month report—the period starting on the day associated water was first taken under the lease and ending on the last day of the 6-month period.

sec.43 Petroleum resources and reserves report

A petroleum tenure holder must lodge a petroleum resources and reserves report for the tenure for each calendar year. The report must be lodged within 60 business days after the calendar year ends. The report must contain the following information— the type and number of the tenure; an identification of each natural underground reservoir in which there were, during the period, any 2C contingent resources, 1P reserves, 2P reserves or 3P reserves under the PRMS; the amount of any 2C contingent resources, 1P reserves, 2P reserves or 3P reserves under the PRMS within the area of the tenure worked out on the last day of the period; details of project maturity subclasses for any 2P reserves or 2C contingent resources under the PRMS that relate to the tenure worked out on the last day of the period; any change not less than 10% for any 2P reserves under the PRMS within the area of the tenure at field-level or basin-level that occurred during the period; any other data or information for the report required under the practice direction. In this section— PRMS means the document called ‘Petroleum Resources Management System’, also referred to as the SPE Code, published in 2018 by the Society of Petroleum Engineers. project maturity subclass means a sub-classification of activities for a project mentioned in the PRMS , part 2.1.3.5 . s 43 amd 2020 SL No. 208 s 19 (sec.43-ssec.1) A petroleum tenure holder must lodge a petroleum resources and reserves report for the tenure for each calendar year. (sec.43-ssec.2) The report must be lodged within 60 business days after the calendar year ends. (sec.43-ssec.3) The report must contain the following information— the type and number of the tenure; an identification of each natural underground reservoir in which there were, during the period, any 2C contingent resources, 1P reserves, 2P reserves or 3P reserves under the PRMS; the amount of any 2C contingent resources, 1P reserves, 2P reserves or 3P reserves under the PRMS within the area of the tenure worked out on the last day of the period; details of project maturity subclasses for any 2P reserves or 2C contingent resources under the PRMS that relate to the tenure worked out on the last day of the period; any change not less than 10% for any 2P reserves under the PRMS within the area of the tenure at field-level or basin-level that occurred during the period; any other data or information for the report required under the practice direction. (sec.43-ssec.4) In this section— PRMS means the document called ‘Petroleum Resources Management System’, also referred to as the SPE Code, published in 2018 by the Society of Petroleum Engineers. project maturity subclass means a sub-classification of activities for a project mentioned in the PRMS , part 2.1.3.5 .

• (a) the type and number of the tenure;
• (b) an identification of each natural underground reservoir in which there were, during the period, any 2C contingent resources, 1P reserves, 2P reserves or 3P reserves under the PRMS;
• (c) the amount of any 2C contingent resources, 1P reserves, 2P reserves or 3P reserves under the PRMS within the area of the tenure worked out on the last day of the period;
• (d) details of project maturity subclasses for any 2P reserves or 2C contingent resources under the PRMS that relate to the tenure worked out on the last day of the period;
• (e) any change not less than 10% for any 2P reserves under the PRMS within the area of the tenure at field-level or basin-level that occurred during the period;
• (f) any other data or information for the report required under the practice direction.

sec.44 Production testing report

This section applies if production testing for a petroleum well is carried out under a petroleum tenure. The tenure holder must lodge a production testing report for the relevant testing period. The report must be lodged within 60 business days after the relevant testing period ends. The report must contain the following information— the type and number of the tenure; the identifying name of the petroleum well; an identification of each natural underground reservoir and the reservoir formation (or geological unit) from which petroleum was produced as part of the production testing; the duration of the production testing carried out during the period; the type of any perforations in the well and the depth in metres of the top and bottom of the perforated intervals; the volumes, or estimated volumes, of gas, oil and water produced from the testing during the period; the choke size used for the well; the density of any oil produced from the testing during the period, measured using the American Petroleum Institute’s scale of measuring the specific gravity of oil, commonly known as the ‘API gravity’ of the oil; the pressure in the well, measured during the period, at which petroleum can not escape from the wellhead, commonly known as the ‘shut-in pressure’ of the well; if petroleum in a gaseous state was produced during the testing— details of the use, or intended use, of the petroleum; and for an authorised activity for the petroleum tenure, flaring, venting, processing the volume, or estimated volume, of the petroleum used, or intended to be used, other than by flaring or venting; data in relation to samples, and the analysis of the samples, taken from the area of the tenure; any other data or information for the report required under the practice direction. In this section— end day , for production testing for a petroleum well, means— if the well intersects a natural underground reservoir containing coal seam gas, shale gas, tight gas or basin-centred gas and the testing relates to petroleum produced from the reservoir—the day that is 13 months after the testing starts; or otherwise—the day that is 6 months after the testing starts. production testing means testing for petroleum production from a petroleum well within the area of the petroleum tenure. relevant testing period means— the period starting on the first day production testing for the petroleum well is carried out and ending on the earlier of— the end day; or the last day the testing is carried out; and if the production testing is carried out after the end day with the Minister’s approval—the period starting on the day after the end day and ending on the last day the testing is carried out. s 44 amd 2020 SL No. 208 s 20 (sec.44-ssec.1) This section applies if production testing for a petroleum well is carried out under a petroleum tenure. (sec.44-ssec.2) The tenure holder must lodge a production testing report for the relevant testing period. (sec.44-ssec.3) The report must be lodged within 60 business days after the relevant testing period ends. (sec.44-ssec.4) The report must contain the following information— the type and number of the tenure; the identifying name of the petroleum well; an identification of each natural underground reservoir and the reservoir formation (or geological unit) from which petroleum was produced as part of the production testing; the duration of the production testing carried out during the period; the type of any perforations in the well and the depth in metres of the top and bottom of the perforated intervals; the volumes, or estimated volumes, of gas, oil and water produced from the testing during the period; the choke size used for the well; the density of any oil produced from the testing during the period, measured using the American Petroleum Institute’s scale of measuring the specific gravity of oil, commonly known as the ‘API gravity’ of the oil; the pressure in the well, measured during the period, at which petroleum can not escape from the wellhead, commonly known as the ‘shut-in pressure’ of the well; if petroleum in a gaseous state was produced during the testing— details of the use, or intended use, of the petroleum; and for an authorised activity for the petroleum tenure, flaring, venting, processing the volume, or estimated volume, of the petroleum used, or intended to be used, other than by flaring or venting; data in relation to samples, and the analysis of the samples, taken from the area of the tenure; any other data or information for the report required under the practice direction. (sec.44-ssec.5) In this section— end day , for production testing for a petroleum well, means— if the well intersects a natural underground reservoir containing coal seam gas, shale gas, tight gas or basin-centred gas and the testing relates to petroleum produced from the reservoir—the day that is 13 months after the testing starts; or otherwise—the day that is 6 months after the testing starts. production testing means testing for petroleum production from a petroleum well within the area of the petroleum tenure. relevant testing period means— the period starting on the first day production testing for the petroleum well is carried out and ending on the earlier of— the end day; or the last day the testing is carried out; and if the production testing is carried out after the end day with the Minister’s approval—the period starting on the day after the end day and ending on the last day the testing is carried out.

• (a) the type and number of the tenure;
• (b) the identifying name of the petroleum well;
• (c) an identification of each natural underground reservoir and the reservoir formation (or geological unit) from which petroleum was produced as part of the production testing;
• (d) the duration of the production testing carried out during the period;
• (e) the type of any perforations in the well and the depth in metres of the top and bottom of the perforated intervals;
• (f) the volumes, or estimated volumes, of gas, oil and water produced from the testing during the period;
• (g) the choke size used for the well;
• (h) the density of any oil produced from the testing during the period, measured using the American Petroleum Institute’s scale of measuring the specific gravity of oil, commonly known as the ‘API gravity’ of the oil;
• (i) the pressure in the well, measured during the period, at which petroleum can not escape from the wellhead, commonly known as the ‘shut-in pressure’ of the well;
• (j) if petroleum in a gaseous state was produced during the testing— (i) details of the use, or intended use, of the petroleum; and Examples of use, or intended use, of the petroleum— for an authorised activity for the petroleum tenure, flaring, venting, processing (ii) the volume, or estimated volume, of the petroleum used, or intended to be used, other than by flaring or venting;
• (i) details of the use, or intended use, of the petroleum; and Examples of use, or intended use, of the petroleum— for an authorised activity for the petroleum tenure, flaring, venting, processing
• (ii) the volume, or estimated volume, of the petroleum used, or intended to be used, other than by flaring or venting;
• (k) data in relation to samples, and the analysis of the samples, taken from the area of the tenure;
• (l) any other data or information for the report required under the practice direction.
• (i) details of the use, or intended use, of the petroleum; and Examples of use, or intended use, of the petroleum— for an authorised activity for the petroleum tenure, flaring, venting, processing
• (ii) the volume, or estimated volume, of the petroleum used, or intended to be used, other than by flaring or venting;
• (a) if the well intersects a natural underground reservoir containing coal seam gas, shale gas, tight gas or basin-centred gas and the testing relates to petroleum produced from the reservoir—the day that is 13 months after the testing starts; or
• (b) otherwise—the day that is 6 months after the testing starts.
• (a) the period starting on the first day production testing for the petroleum well is carried out and ending on the earlier of— (i) the end day; or (ii) the last day the testing is carried out; and
• (i) the end day; or
• (ii) the last day the testing is carried out; and
• (b) if the production testing is carried out after the end day with the Minister’s approval—the period starting on the day after the end day and ending on the last day the testing is carried out.
• (i) the end day; or
• (ii) the last day the testing is carried out; and

sec.45 Hydraulic fracturing activities completion report

After the holder of a petroleum tenure has finished carrying out hydraulic fracturing activities in the prescribed area for the tenure, the tenure holder must lodge a hydraulic fracturing activities completion report. The report must be lodged within 6 months after the hydraulic fracturing activities are completed. The report must contain the following information— the type and number of the tenure; the name and postal address of the contractor who carried out the hydraulic fracturing activities on behalf of the operator of the drilling project; the identifying name of each treatment well or observation well for which the activities were carried out; the days the activities for each petroleum well started and ended; a description of each method of activities carried out; the depth in metres of the top and bottom of— each stage over which the activities were carried out; and each geological interval over which activities were carried out and the name of each geological interval; a summary of the operations performed at each stage in carrying out the activities, including the volume and type of chemical used at each stage; an assessment of the implications of the activities for each petroleum well for the future management of the natural underground reservoir involved, including for each stage of the activities, over the geological interval, a graphic representation of the following— casing pressure with time; calculated bottom hole pressure with time; calculated bottom hole concentration with time; the rate at which the hydraulic fracturing fluid is pumped into the well used for the activities with time; the concentration of proppant in the hydraulic fracturing fluid with time; maximum surface treatment pressure reached during each stage of the activities; the estimated targeted fracture pressure over the geological interval during each stage of the activities; details of— the equipment used to carry out and monitor the activities; and the diagnostic techniques used to monitor the activities; if known, details of— any geological connection between a geological interval over which activities were carried out and an aquifer; and In the Surat Basin, if a Walloon subgroup geological interval hydraulic fracture treatment stage breaks through to the Upper Springbok Formation, the holder must include details of this event. the distance separating a geological interval over which activities were carried out from an aquifer; details of the total volume of hydraulic fracturing fluid, in kilolitres, pumped into each petroleum well during each stage of the activities; if activities were carried out on a coal seam—any other details about the activities that would assist a person to make a future assessment of the impact of the activities on the coal seam and any increased risk to safe and optimal mining of coal; if a known event related to the activities has caused material environmental harm or serious environmental harm under the Environmental Protection Act 1994 —details of each step taken to mitigate the harm; any other data or information for the report required under the practice direction. The holder must ensure the report is accompanied by a hydraulic fracturing fluid statement about the composition of the hydraulic fracturing fluid used in carrying out the activities, including— the quantity of each component of the hydraulic fracturing fluid; and the concentration of each component in the hydraulic fracturing fluid; and the name of any chemical compound contained in the hydraulic fracturing fluid. Maximum penalty for subsection (4) —20 penalty units. s 45 amd 2020 SL No. 208 s 21 (sec.45-ssec.1) After the holder of a petroleum tenure has finished carrying out hydraulic fracturing activities in the prescribed area for the tenure, the tenure holder must lodge a hydraulic fracturing activities completion report. (sec.45-ssec.2) The report must be lodged within 6 months after the hydraulic fracturing activities are completed. (sec.45-ssec.3) The report must contain the following information— the type and number of the tenure; the name and postal address of the contractor who carried out the hydraulic fracturing activities on behalf of the operator of the drilling project; the identifying name of each treatment well or observation well for which the activities were carried out; the days the activities for each petroleum well started and ended; a description of each method of activities carried out; the depth in metres of the top and bottom of— each stage over which the activities were carried out; and each geological interval over which activities were carried out and the name of each geological interval; a summary of the operations performed at each stage in carrying out the activities, including the volume and type of chemical used at each stage; an assessment of the implications of the activities for each petroleum well for the future management of the natural underground reservoir involved, including for each stage of the activities, over the geological interval, a graphic representation of the following— casing pressure with time; calculated bottom hole pressure with time; calculated bottom hole concentration with time; the rate at which the hydraulic fracturing fluid is pumped into the well used for the activities with time; the concentration of proppant in the hydraulic fracturing fluid with time; maximum surface treatment pressure reached during each stage of the activities; the estimated targeted fracture pressure over the geological interval during each stage of the activities; details of— the equipment used to carry out and monitor the activities; and the diagnostic techniques used to monitor the activities; if known, details of— any geological connection between a geological interval over which activities were carried out and an aquifer; and In the Surat Basin, if a Walloon subgroup geological interval hydraulic fracture treatment stage breaks through to the Upper Springbok Formation, the holder must include details of this event. the distance separating a geological interval over which activities were carried out from an aquifer; details of the total volume of hydraulic fracturing fluid, in kilolitres, pumped into each petroleum well during each stage of the activities; if activities were carried out on a coal seam—any other details about the activities that would assist a person to make a future assessment of the impact of the activities on the coal seam and any increased risk to safe and optimal mining of coal; if a known event related to the activities has caused material environmental harm or serious environmental harm under the Environmental Protection Act 1994 —details of each step taken to mitigate the harm; any other data or information for the report required under the practice direction. (sec.45-ssec.4) The holder must ensure the report is accompanied by a hydraulic fracturing fluid statement about the composition of the hydraulic fracturing fluid used in carrying out the activities, including— the quantity of each component of the hydraulic fracturing fluid; and the concentration of each component in the hydraulic fracturing fluid; and the name of any chemical compound contained in the hydraulic fracturing fluid. Maximum penalty for subsection (4) —20 penalty units.

• (a) the type and number of the tenure;
• (b) the name and postal address of the contractor who carried out the hydraulic fracturing activities on behalf of the operator of the drilling project;
• (c) the identifying name of each treatment well or observation well for which the activities were carried out;
• (d) the days the activities for each petroleum well started and ended;
• (e) a description of each method of activities carried out;
• (f) the depth in metres of the top and bottom of— (i) each stage over which the activities were carried out; and (ii) each geological interval over which activities were carried out and the name of each geological interval;
• (i) each stage over which the activities were carried out; and
• (ii) each geological interval over which activities were carried out and the name of each geological interval;
• (g) a summary of the operations performed at each stage in carrying out the activities, including the volume and type of chemical used at each stage;
• (h) an assessment of the implications of the activities for each petroleum well for the future management of the natural underground reservoir involved, including for each stage of the activities, over the geological interval, a graphic representation of the following— (i) casing pressure with time; (ii) calculated bottom hole pressure with time; (iii) calculated bottom hole concentration with time; (iv) the rate at which the hydraulic fracturing fluid is pumped into the well used for the activities with time; (v) the concentration of proppant in the hydraulic fracturing fluid with time; (vi) maximum surface treatment pressure reached during each stage of the activities; (vii) the estimated targeted fracture pressure over the geological interval during each stage of the activities;
• (i) casing pressure with time;
• (ii) calculated bottom hole pressure with time;
• (iii) calculated bottom hole concentration with time;
• (iv) the rate at which the hydraulic fracturing fluid is pumped into the well used for the activities with time;
• (v) the concentration of proppant in the hydraulic fracturing fluid with time;
• (vi) maximum surface treatment pressure reached during each stage of the activities;
• (vii) the estimated targeted fracture pressure over the geological interval during each stage of the activities;
• (i) details of— (i) the equipment used to carry out and monitor the activities; and (ii) the diagnostic techniques used to monitor the activities;
• (i) the equipment used to carry out and monitor the activities; and
• (ii) the diagnostic techniques used to monitor the activities;
• (j) if known, details of— (i) any geological connection between a geological interval over which activities were carried out and an aquifer; and Example— In the Surat Basin, if a Walloon subgroup geological interval hydraulic fracture treatment stage breaks through to the Upper Springbok Formation, the holder must include details of this event. (ii) the distance separating a geological interval over which activities were carried out from an aquifer;
• (i) any geological connection between a geological interval over which activities were carried out and an aquifer; and Example— In the Surat Basin, if a Walloon subgroup geological interval hydraulic fracture treatment stage breaks through to the Upper Springbok Formation, the holder must include details of this event.
• (ii) the distance separating a geological interval over which activities were carried out from an aquifer;
• (k) details of the total volume of hydraulic fracturing fluid, in kilolitres, pumped into each petroleum well during each stage of the activities;
• (l) if activities were carried out on a coal seam—any other details about the activities that would assist a person to make a future assessment of the impact of the activities on the coal seam and any increased risk to safe and optimal mining of coal;
• (m) if a known event related to the activities has caused material environmental harm or serious environmental harm under the Environmental Protection Act 1994 —details of each step taken to mitigate the harm;
• (n) any other data or information for the report required under the practice direction.
• (i) each stage over which the activities were carried out; and
• (ii) each geological interval over which activities were carried out and the name of each geological interval;
• (i) casing pressure with time;
• (ii) calculated bottom hole pressure with time;
• (iii) calculated bottom hole concentration with time;
• (iv) the rate at which the hydraulic fracturing fluid is pumped into the well used for the activities with time;
• (v) the concentration of proppant in the hydraulic fracturing fluid with time;
• (vi) maximum surface treatment pressure reached during each stage of the activities;
• (vii) the estimated targeted fracture pressure over the geological interval during each stage of the activities;
• (i) the equipment used to carry out and monitor the activities; and
• (ii) the diagnostic techniques used to monitor the activities;
• (i) any geological connection between a geological interval over which activities were carried out and an aquifer; and Example— In the Surat Basin, if a Walloon subgroup geological interval hydraulic fracture treatment stage breaks through to the Upper Springbok Formation, the holder must include details of this event.
• (ii) the distance separating a geological interval over which activities were carried out from an aquifer;
• (a) the quantity of each component of the hydraulic fracturing fluid; and
• (b) the concentration of each component in the hydraulic fracturing fluid; and
• (c) the name of any chemical compound contained in the hydraulic fracturing fluid.

Matters relating to records, samples and required information

Records

sec.46 Record of supply of gas from PGPLR land

For the 2004 Act , section 175H (2) , a record of the following information must be kept— details of the petroleum lease for the PGPLR land, including its number and the area of the lease; the entity to whom the gas was supplied; the volume of gas supplied to the entity. Each record must be kept— for at least 7 years after the day the record was made; and in a way that enables the selling entity to comply with a request for a copy of the record within the time stated in a notice given under the 2004 Act , section 175H (3) . hard copy or electronic format (sec.46-ssec.1) For the 2004 Act , section 175H (2) , a record of the following information must be kept— details of the petroleum lease for the PGPLR land, including its number and the area of the lease; the entity to whom the gas was supplied; the volume of gas supplied to the entity. (sec.46-ssec.2) Each record must be kept— for at least 7 years after the day the record was made; and in a way that enables the selling entity to comply with a request for a copy of the record within the time stated in a notice given under the 2004 Act , section 175H (3) . hard copy or electronic format

• (a) details of the petroleum lease for the PGPLR land, including its number and the area of the lease;
• (b) the entity to whom the gas was supplied;
• (c) the volume of gas supplied to the entity.
• (a) for at least 7 years after the day the record was made; and
• (b) in a way that enables the selling entity to comply with a request for a copy of the record within the time stated in a notice given under the 2004 Act , section 175H (3) . Examples of ways records may be kept— hard copy or electronic format

Samples

sec.47 Purpose of division

This division prescribes matters for the 2004 Act , section 547 (1) and the 1923 Act , section 76A (1) .

sec.48 Keeping samples

A sample must be kept until the later of the following— the end of the term of the petroleum tenure; the sample, or part of the sample, is lodged under the 2004 Act , section 548 or the 1923 Act , section 76B . A sample must be kept in a way that prevents unnecessary deterioration or loss of the sample. s 48 amd 2020 SL No. 70 s 9 (sec.48-ssec.1) A sample must be kept until the later of the following— the end of the term of the petroleum tenure; the sample, or part of the sample, is lodged under the 2004 Act , section 548 or the 1923 Act , section 76B . (sec.48-ssec.2) A sample must be kept in a way that prevents unnecessary deterioration or loss of the sample.

• (a) the end of the term of the petroleum tenure;
• (b) the sample, or part of the sample, is lodged under the 2004 Act , section 548 or the 1923 Act , section 76B .

sec.49 Cutting samples

Each cutting sample of geological formations taken as follows must be kept— when the formations are penetrated making a petroleum well under a petroleum tenure; at each interval stated in subsection (2) . For subsection (1) (b) , the intervals are— for a petroleum well other than a development well—each 10m interval, or part of a 10m interval, from the surface to as close as practicable to the top of the geological formation nearest to the surface that is likely to contain a natural underground reservoir; and each 3m interval, or part of a 3m interval, from as close as practicable to the top of the geological formation mentioned in paragraph (a) to the bottom of the well. However, subsection (1) applies to a cutting sample taken when making a petroleum well solely for coal seam gas exploration or production only if, before the well was made, the chief executive gave the tenure holder notice that the sample must be kept. The part of the sample lodged under the 2004 Act , section 548 (1) or the 1923 Act , section 76B (1) must be— at least 250g, but not more than 500g; and washed and dried; and in a container that is suitable for long-term storage and handling, and is labelled with— the identifying name of the well from which the sample was taken; and the depth in metres of the top and bottom of the interval from which the sample was taken. In this section— cutting sample means a sample of the cuttings produced making the well. (sec.49-ssec.1) Each cutting sample of geological formations taken as follows must be kept— when the formations are penetrated making a petroleum well under a petroleum tenure; at each interval stated in subsection (2) . (sec.49-ssec.2) For subsection (1) (b) , the intervals are— for a petroleum well other than a development well—each 10m interval, or part of a 10m interval, from the surface to as close as practicable to the top of the geological formation nearest to the surface that is likely to contain a natural underground reservoir; and each 3m interval, or part of a 3m interval, from as close as practicable to the top of the geological formation mentioned in paragraph (a) to the bottom of the well. (sec.49-ssec.3) However, subsection (1) applies to a cutting sample taken when making a petroleum well solely for coal seam gas exploration or production only if, before the well was made, the chief executive gave the tenure holder notice that the sample must be kept. (sec.49-ssec.4) The part of the sample lodged under the 2004 Act , section 548 (1) or the 1923 Act , section 76B (1) must be— at least 250g, but not more than 500g; and washed and dried; and in a container that is suitable for long-term storage and handling, and is labelled with— the identifying name of the well from which the sample was taken; and the depth in metres of the top and bottom of the interval from which the sample was taken. (sec.49-ssec.5) In this section— cutting sample means a sample of the cuttings produced making the well.

• (a) when the formations are penetrated making a petroleum well under a petroleum tenure;
• (b) at each interval stated in subsection (2) .
• (a) for a petroleum well other than a development well—each 10m interval, or part of a 10m interval, from the surface to as close as practicable to the top of the geological formation nearest to the surface that is likely to contain a natural underground reservoir; and
• (b) each 3m interval, or part of a 3m interval, from as close as practicable to the top of the geological formation mentioned in paragraph (a) to the bottom of the well.
• (a) at least 250g, but not more than 500g; and
• (b) washed and dried; and
• (c) in a container that is suitable for long-term storage and handling, and is labelled with— (i) the identifying name of the well from which the sample was taken; and (ii) the depth in metres of the top and bottom of the interval from which the sample was taken.
• (i) the identifying name of the well from which the sample was taken; and
• (ii) the depth in metres of the top and bottom of the interval from which the sample was taken.
• (i) the identifying name of the well from which the sample was taken; and
• (ii) the depth in metres of the top and bottom of the interval from which the sample was taken.

sec.50 Cores

Each core recovered from a petroleum well under a petroleum tenure must be kept. However, subsection (1) applies in relation to a core from a petroleum well made solely for coal seam gas exploration or production only if— the holder gives the chief executive notice, in the approved form, offering to give the chief executive a sample of the core; and the notice is received within 5 months after the day the core is recovered; and within 20 business days after receiving the notice, the chief executive gives the holder notice that the sample must be kept. The part of the core lodged under the 2004 Act , section 548 (1) or the 1923 Act , section 76B (1) must— be at least 50% of the core recovered; and have as complete a vertical face as is practicable; and be lodged in a box or other suitable container that is suitable for long-term storage and handling, and is labelled with— the identifying name of the well from which the core was recovered; and if more than 1 core is recovered from the well—the number of the core; and the depth in metres of the top and bottom of the interval cored; and the length in metres of the core recovered. (sec.50-ssec.1) Each core recovered from a petroleum well under a petroleum tenure must be kept. (sec.50-ssec.2) However, subsection (1) applies in relation to a core from a petroleum well made solely for coal seam gas exploration or production only if— the holder gives the chief executive notice, in the approved form, offering to give the chief executive a sample of the core; and the notice is received within 5 months after the day the core is recovered; and within 20 business days after receiving the notice, the chief executive gives the holder notice that the sample must be kept. (sec.50-ssec.3) The part of the core lodged under the 2004 Act , section 548 (1) or the 1923 Act , section 76B (1) must— be at least 50% of the core recovered; and have as complete a vertical face as is practicable; and be lodged in a box or other suitable container that is suitable for long-term storage and handling, and is labelled with— the identifying name of the well from which the core was recovered; and if more than 1 core is recovered from the well—the number of the core; and the depth in metres of the top and bottom of the interval cored; and the length in metres of the core recovered.

• (a) the holder gives the chief executive notice, in the approved form, offering to give the chief executive a sample of the core; and
• (b) the notice is received within 5 months after the day the core is recovered; and
• (c) within 20 business days after receiving the notice, the chief executive gives the holder notice that the sample must be kept.
• (a) be at least 50% of the core recovered; and
• (b) have as complete a vertical face as is practicable; and
• (c) be lodged in a box or other suitable container that is suitable for long-term storage and handling, and is labelled with— (i) the identifying name of the well from which the core was recovered; and (ii) if more than 1 core is recovered from the well—the number of the core; and (iii) the depth in metres of the top and bottom of the interval cored; and (iv) the length in metres of the core recovered.
• (i) the identifying name of the well from which the core was recovered; and
• (ii) if more than 1 core is recovered from the well—the number of the core; and
• (iii) the depth in metres of the top and bottom of the interval cored; and
• (iv) the length in metres of the core recovered.
• (i) the identifying name of the well from which the core was recovered; and
• (ii) if more than 1 core is recovered from the well—the number of the core; and
• (iii) the depth in metres of the top and bottom of the interval cored; and
• (iv) the length in metres of the core recovered.

sec.51 Fluid samples

A sample (a fluid sample ) of liquid petroleum recovered from a petroleum well under a petroleum tenure must be kept if— the sample is more than 10l; and within 5 months after the day the sample is recovered, the chief executive gives the holder of the petroleum tenure notice that the sample must be kept. For the 2004 Act , section 548 (1) and the 1923 Act , section 76B (1) , the part of the fluid sample lodged must be— at least 500ml of the fluid sample recovered; and in a glass bottle that is teflon sealed with a screw top; and labelled with at least— the identifying name of the well; and the depth in metres of the top and bottom of the interval from which the sample was recovered; and the day on which the sample was recovered; and the method by which the fluid sample was recovered. drill stem tests, production tests (sec.51-ssec.1) A sample (a fluid sample ) of liquid petroleum recovered from a petroleum well under a petroleum tenure must be kept if— the sample is more than 10l; and within 5 months after the day the sample is recovered, the chief executive gives the holder of the petroleum tenure notice that the sample must be kept. (sec.51-ssec.2) For the 2004 Act , section 548 (1) and the 1923 Act , section 76B (1) , the part of the fluid sample lodged must be— at least 500ml of the fluid sample recovered; and in a glass bottle that is teflon sealed with a screw top; and labelled with at least— the identifying name of the well; and the depth in metres of the top and bottom of the interval from which the sample was recovered; and the day on which the sample was recovered; and the method by which the fluid sample was recovered. drill stem tests, production tests

• (a) the sample is more than 10l; and
• (b) within 5 months after the day the sample is recovered, the chief executive gives the holder of the petroleum tenure notice that the sample must be kept.
• (a) at least 500ml of the fluid sample recovered; and
• (b) in a glass bottle that is teflon sealed with a screw top; and
• (c) labelled with at least— (i) the identifying name of the well; and (ii) the depth in metres of the top and bottom of the interval from which the sample was recovered; and (iii) the day on which the sample was recovered; and (iv) the method by which the fluid sample was recovered. Examples— drill stem tests, production tests
• (i) the identifying name of the well; and
• (ii) the depth in metres of the top and bottom of the interval from which the sample was recovered; and
• (iii) the day on which the sample was recovered; and
• (iv) the method by which the fluid sample was recovered. Examples— drill stem tests, production tests
• (i) the identifying name of the well; and
• (ii) the depth in metres of the top and bottom of the interval from which the sample was recovered; and
• (iii) the day on which the sample was recovered; and
• (iv) the method by which the fluid sample was recovered. Examples— drill stem tests, production tests

Releasing required information

sec.52 Confidentiality periods for required information for petroleum tenures

This section prescribes, for the 2004 Act , section 550 (2) and the 1923 Act , section 76D (2) , the confidentiality period for the required information stated in schedule 1 , column 1. The confidentiality period for the required information starts on the day the information is lodged and ends on the day stated in schedule 1 , column 2 opposite the required information. However, there is no confidentiality period for a petroleum well or bore abandonment report under section 37 if— the report is to be made available to a person under the 2004 Act , section 550 (1) (b) or the 1923 Act , section 76D (1) (b) ; and the person is the holder of a coal or oil shale mining tenement; and the well or bore was drilled in the area of the person’s coal or oil shale mining tenement. Also, there is no confidentiality period for required information not mentioned in subsection (2) . s 52 sub 2020 SL No. 208 s 22 amd 2022 SL No. 191 s 6 ; 2025 SL No. 48 s 14 sch 1 (sec.52-ssec.1) This section prescribes, for the 2004 Act , section 550 (2) and the 1923 Act , section 76D (2) , the confidentiality period for the required information stated in schedule 1 , column 1. (sec.52-ssec.2) The confidentiality period for the required information starts on the day the information is lodged and ends on the day stated in schedule 1 , column 2 opposite the required information. (sec.52-ssec.3) However, there is no confidentiality period for a petroleum well or bore abandonment report under section 37 if— the report is to be made available to a person under the 2004 Act , section 550 (1) (b) or the 1923 Act , section 76D (1) (b) ; and the person is the holder of a coal or oil shale mining tenement; and the well or bore was drilled in the area of the person’s coal or oil shale mining tenement. (sec.52-ssec.4) Also, there is no confidentiality period for required information not mentioned in subsection (2) .

• (a) the report is to be made available to a person under the 2004 Act , section 550 (1) (b) or the 1923 Act , section 76D (1) (b) ; and
• (b) the person is the holder of a coal or oil shale mining tenement; and
• (c) the well or bore was drilled in the area of the person’s coal or oil shale mining tenement.

sec.53 Publication of required information

For the 2004 Act , section 550 (1) (a) and the 1923 Act , section 76D (1) (a) , the chief executive may publish required information in the following ways— in a journal published by the department or under the Minister’s authority; in another publication considered appropriate by the chief executive; on the department’s website; in a publicly available database; on a map that is made available to the public for inspection or purchase; in digital or electronic form, including, for example, on a disc or tape; by displaying it on a notice that is available to the public for inspection at— the department’s head office; and other places the chief executive considers appropriate; by telling it to another person or presenting it to the person in a visual form.

• (a) in a journal published by the department or under the Minister’s authority;
• (b) in another publication considered appropriate by the chief executive;
• (c) on the department’s website;
• (d) in a publicly available database;
• (e) on a map that is made available to the public for inspection or purchase;
• (f) in digital or electronic form, including, for example, on a disc or tape;
• (g) by displaying it on a notice that is available to the public for inspection at— (i) the department’s head office; and (ii) other places the chief executive considers appropriate;
• (i) the department’s head office; and
• (ii) other places the chief executive considers appropriate;
• (h) by telling it to another person or presenting it to the person in a visual form.
• (i) the department’s head office; and
• (ii) other places the chief executive considers appropriate;

Matters relating to taking non-associated water

sec.54 Definition for part

In this part— reporting period , for a petroleum tenure, means each period— that starts on 1 January and ends on— 30 June; or if the tenure expires or is surrendered on a day falling between 1 January and 30 June—that day; or that starts on 1 July and ends on— 31 December; or if the tenure expires or is surrendered on a day falling between 1 July and 31 December—that day.

• (a) that starts on 1 January and ends on— (i) 30 June; or (ii) if the tenure expires or is surrendered on a day falling between 1 January and 30 June—that day; or
• (i) 30 June; or
• (ii) if the tenure expires or is surrendered on a day falling between 1 January and 30 June—that day; or
• (b) that starts on 1 July and ends on— (i) 31 December; or (ii) if the tenure expires or is surrendered on a day falling between 1 July and 31 December—that day.
• (i) 31 December; or
• (ii) if the tenure expires or is surrendered on a day falling between 1 July and 31 December—that day.
• (i) 30 June; or
• (ii) if the tenure expires or is surrendered on a day falling between 1 January and 30 June—that day; or
• (i) 31 December; or
• (ii) if the tenure expires or is surrendered on a day falling between 1 July and 31 December—that day.