{"id":"qld:sl-2017-0162","name":"Petroleum and Gas (General Provisions) Regulation 2017","slug":"petroleum-and-gas-general-provisions-regulation-2017","collection":"regulation","jurisdiction":"qld","status":"in_force","isInForce":true,"actNumber":"162 of 2017","makingDate":null,"administeringDepartment":null,"currentVersion":{"id":174938,"registerId":"qld-qld:sl-2017-0162-current","compilationNumber":null,"startDate":"2026-04-05","status":"InForce","reasons":null,"registeredAt":null},"sections":[{"sectionNumber":"pt.1","sectionType":"part","heading":"Preliminary","content":"# Preliminary","sortOrder":0},{"sectionNumber":"pt.1-div.1","sectionType":"division","heading":"Introduction","content":"## Introduction","sortOrder":1},{"sectionNumber":"sec.1","sectionType":"section","heading":"Short title","content":"### sec.1 Short title\n\nThis regulation may be cited as the Petroleum and Gas (General Provisions) Regulation 2017 .","sortOrder":2},{"sectionNumber":"sec.2","sectionType":"section","heading":"Commencement","content":"### sec.2 Commencement\n\nThis regulation commences on 1 September 2017.","sortOrder":3},{"sectionNumber":"pt.1-div.2","sectionType":"division","heading":"Interpretation","content":"## Interpretation","sortOrder":4},{"sectionNumber":"sec.3","sectionType":"section","heading":"Definitions","content":"### sec.3 Definitions\n\nThe dictionary in schedule 5 defines particular words used in this regulation.","sortOrder":5},{"sectionNumber":"sec.4","sectionType":"section","heading":"References to particular resource authorities and wells under this regulation","content":"### sec.4 References to particular resource authorities and wells under this regulation\n\nA reference in this regulation to an authority to prospect is a reference to—\nan authority to prospect under the 2004 Act ; and\nan authority to prospect under the 1923 Act .\nA reference in this regulation to a petroleum lease is a reference to—\na petroleum lease under the 2004 Act ; and\na lease under the 1923 Act .\nA reference in this regulation to a petroleum tenure is a reference to—\na 2004 Act petroleum tenure; and\nan authority to prospect and a lease under the 1923 Act .\nA reference in this regulation to a petroleum well includes a reference to a well under the 1923 Act .\n(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 .\n(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 .\n(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 .\n(sec.4-ssec.4) A reference in this regulation to a petroleum well includes a reference to a well under the 1923 Act .\n- (a) an authority to prospect under the 2004 Act ; and\n- (b) an authority to prospect under the 1923 Act .\n- (a) a petroleum lease under the 2004 Act ; and\n- (b) a lease under the 1923 Act .\n- (a) a 2004 Act petroleum tenure; and\n- (b) an authority to prospect and a lease under the 1923 Act .","sortOrder":6},{"sectionNumber":"pt.2","sectionType":"part","heading":"Substances prescribed for the 2004 Act","content":"# Substances prescribed for the 2004 Act","sortOrder":7},{"sectionNumber":"sec.5","sectionType":"section","heading":"Substances that are petroleum","content":"### sec.5 Substances that are petroleum\n\nFor the 2004 Act , section 10 (1) (d) , the following substances are prescribed—\nbiogas;\nbiomethane;\na substance that is a mixture of LPG and air, known as ‘synthetic natural gas’.\nHowever, subsection (1) applies only for the purposes of the following provisions of that Act—\nchapters 8 to 10; and\nchapters 11 to 14, to the extent they apply for chapters 8 to 10.\nFor the 2004 Act , section 10 (1) (e) , carbon dioxide is prescribed.\nHowever, subsection (3) applies only—\nto 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\nto 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—\nthe testing is carried out on a particular block of the authority within—\n2 years after the testing starts; or\na longer period decided by the Minister within the 2 years; and\nthe Minister approves the testing on the particular block; and\nthe holder complies with any conditions the Minister imposes on the approval.\ns 5 amd 2021 SL No. 75 s 21\n(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’.\n(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.\n(sec.5-ssec.3) For the 2004 Act , section 10 (1) (e) , carbon dioxide is prescribed.\n(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.\n- (a) biogas;\n- (b) biomethane;\n- (c) a substance that is a mixture of LPG and air, known as ‘synthetic natural gas’.\n- (a) chapters 8 to 10; and\n- (b) chapters 11 to 14, to the extent they apply for chapters 8 to 10.\n- (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\n- (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.\n- (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\n- (A) 2 years after the testing starts; or\n- (B) a longer period decided by the Minister within the 2 years; and\n- (ii) the Minister approves the testing on the particular block; and\n- (iii) the holder complies with any conditions the Minister imposes on the approval.\n- (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\n- (A) 2 years after the testing starts; or\n- (B) a longer period decided by the Minister within the 2 years; and\n- (ii) the Minister approves the testing on the particular block; and\n- (iii) the holder complies with any conditions the Minister imposes on the approval.\n- (A) 2 years after the testing starts; or\n- (B) a longer period decided by the Minister within the 2 years; and","sortOrder":8},{"sectionNumber":"sec.6","sectionType":"section","heading":"Substances that are fuel gas","content":"### sec.6 Substances that are fuel gas\n\nFor the 2004 Act , section 11 (2) (d) , the following substances are prescribed—\nbiogas;\nbiomethane;\nsynthetic methane;\na substance that is a mixture of LPG and air, known as ‘synthetic natural gas’.\nIn this section—\nsynthetic methane means a substance—\nthat is in a gaseous state at standard temperature and pressure; and\nthe principal constituent of which is methane; and\nthat is produced by the methanation of carbon dioxide; and\nthat is suitable for consumption.\ns 6 amd 2021 SL No. 75 s 22\nsub 2024 SL No. 32 s 4\n(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’.\n(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.\n- (a) biogas;\n- (b) biomethane;\n- (c) synthetic methane;\n- (d) a substance that is a mixture of LPG and air, known as ‘synthetic natural gas’.\n- (a) that is in a gaseous state at standard temperature and pressure; and\n- (b) the principal constituent of which is methane; and\n- (c) that is produced by the methanation of carbon dioxide; and\n- (d) that is suitable for consumption.","sortOrder":9},{"sectionNumber":"sec.6A","sectionType":"section","heading":"Substances that are regulated hydrogen","content":"### sec.6A Substances that are regulated hydrogen\n\nFor the 2004 Act , section 11A (c) , the following substances are prescribed—\nammonia;\ndimethyl-ether;\nmethanol;\nmethyl-cyclohexane (MCH);\ntoluene.\ns 6A ins 2024 SL No. 32 s 4\n- (a) ammonia;\n- (b) dimethyl-ether;\n- (c) methanol;\n- (d) methyl-cyclohexane (MCH);\n- (e) toluene.","sortOrder":10},{"sectionNumber":"sec.7","sectionType":"section","heading":"Substance that may be transported under condition of pipeline licence","content":"### sec.7 Substance that may be transported under condition of pipeline licence\n\nFor the 2004 Act , section 402 (1) (b) , a distilled petroleum substance is prescribed.\nIn this section—\ndistilled petroleum substance means a substance—\nproduced by distilling crude oil; and\nthat consists of, or includes, hydrocarbons.\ndiesel, petrol, kerosene\n(sec.7-ssec.1) For the 2004 Act , section 402 (1) (b) , a distilled petroleum substance is prescribed.\n(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\n- (a) produced by distilling crude oil; and\n- (b) that consists of, or includes, hydrocarbons.","sortOrder":11},{"sectionNumber":"pt.3","sectionType":"part","heading":"Reporting","content":"# Reporting","sortOrder":12},{"sectionNumber":"pt.3-div.1","sectionType":"division","heading":"Exploring for and producing petroleum","content":"## Exploring for and producing petroleum","sortOrder":13},{"sectionNumber":"sec.8","sectionType":"section","heading":"Authority to prospect—proposed work program","content":"### sec.8 Authority to prospect—proposed work program\n\nFor 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—\na description of the geological model for the area of the authority to prospect; and\nan assessment of the potential for petroleum discovery in the area; and\nthe rationale, in relation to the geological model for the area, for the activities proposed to be carried out under the authority to prospect.\ns 8 amd 2022 SL No. 191 s 5\n- (a) a description of the geological model for the area of the authority to prospect; and\n- (b) an assessment of the potential for petroleum discovery in the area; and\n- (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.","sortOrder":14},{"sectionNumber":"sec.9","sectionType":"section","heading":"Petroleum lease—proposed development plan","content":"### sec.9 Petroleum lease—proposed development plan\n\nFor 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—\nfor each natural underground reservoir within the area of the lease of which the applicant is aware, the location of the boundaries of—\nthe proved and probable reserves of petroleum in the reservoir; or\nthe reserves of petroleum in the reservoir worked out in another way approved by the chief executive; and\ndetails, including the location, type and size, of any planned infrastructure intended to be located within the area of the lease or proposed lease.\nplant or works, including, for example, communication systems, compressors, powerlines, pumping stations, reservoirs, roads, evaporation or storage ponds and tanks\ntemporary structures or structures of an industrial or technical nature, including, for example, mobile and temporary camps\n- (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\n- (i) the proved and probable reserves of petroleum in the reservoir; or\n- (ii) the reserves of petroleum in the reservoir worked out in another way approved by the chief executive; and\n- (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\n- 1 plant or works, including, for example, communication systems, compressors, powerlines, pumping stations, reservoirs, roads, evaporation or storage ponds and tanks\n- 2 temporary structures or structures of an industrial or technical nature, including, for example, mobile and temporary camps\n- (i) the proved and probable reserves of petroleum in the reservoir; or\n- (ii) the reserves of petroleum in the reservoir worked out in another way approved by the chief executive; and\n- 1 plant or works, including, for example, communication systems, compressors, powerlines, pumping stations, reservoirs, roads, evaporation or storage ponds and tanks\n- 2 temporary structures or structures of an industrial or technical nature, including, for example, mobile and temporary camps","sortOrder":15},{"sectionNumber":"sec.10","sectionType":"section","heading":"Shorter period to change production commencement day","content":"### sec.10 Shorter period to change production commencement day\n\nFor the 2004 Act , section 175AA (b) , the shorter period is 3 months.","sortOrder":16},{"sectionNumber":"sec.11","sectionType":"section","heading":"Notice about conversion of petroleum well to bore","content":"### sec.11 Notice about conversion of petroleum well to bore\n\nFor the 2004 Act , section 284 and the 1923 Act , section 75M , the information is—\na description of the location of the bore; and\nthe day on which the petroleum well was converted to a bore.\n- (a) a description of the location of the bore; and\n- (b) the day on which the petroleum well was converted to a bore.","sortOrder":17},{"sectionNumber":"sec.12","sectionType":"section","heading":"Notice about bore to Water Act regulator","content":"### sec.12 Notice about bore to Water Act regulator\n\nFor the 2004 Act , section 543A (2) and the 1923 Act , section 75XA (2) , the following information about a bore is prescribed—\nthe name and postal address of the holder of the petroleum tenure or water monitoring authority for the area containing the bore;\nthe identifying name of the bore;\na description of the location of the bore;\nthe purpose of the bore;\nthe diameter and depth in metres of the bore;\nthe following days—\nthe day the drilling of the bore started;\nthe last day the drilling rig was used to drill the bore;\nthe drilling method used to drill the bore;\ndetails of the casing, centralisers and equipment installed in the bore, including the type and location of centralisers;\nthe 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;\ndetails 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;\na geological interpretation of the bore, including the stratigraphy of the rock units it intersects;\ndetails of the water produced by each stratum of rock, including—\nthe quality and supply rate of the water; and\nthe depth at which the water is struck; and\nthe depth to which the water naturally rises;\nif, on completion, the bore is a subartesian bore—\nthe depth in metres to the standing water level, and either the pump suction inlet or bottom of the drill stem; and\ndetails of the test used to estimate the groundwater supply rate;\nif, on completion, the bore is an artesian bore—\nthe rate of flow of unimpeded water from the bore at the surface; and\nthe pressure head of the water mentioned in subparagraph (i) ; and\nthe temperature of the groundwater.\nThe information mentioned in subsection (1) must be given to the Water Act regulator in the approved form.\n(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.\n(sec.12-ssec.2) The information mentioned in subsection (1) must be given to the Water Act regulator in the approved form.\n- (a) the name and postal address of the holder of the petroleum tenure or water monitoring authority for the area containing the bore;\n- (b) the identifying name of the bore;\n- (c) a description of the location of the bore;\n- (d) the purpose of the bore;\n- (e) the diameter and depth in metres of the bore;\n- (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;\n- (i) the day the drilling of the bore started;\n- (ii) the last day the drilling rig was used to drill the bore;\n- (g) the drilling method used to drill the bore;\n- (h) details of the casing, centralisers and equipment installed in the bore, including the type and location of centralisers;\n- (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;\n- (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;\n- (k) a geological interpretation of the bore, including the stratigraphy of the rock units it intersects;\n- (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;\n- (i) the quality and supply rate of the water; and\n- (ii) the depth at which the water is struck; and\n- (iii) the depth to which the water naturally rises;\n- (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;\n- (i) the depth in metres to the standing water level, and either the pump suction inlet or bottom of the drill stem; and\n- (ii) details of the test used to estimate the groundwater supply rate;\n- (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.\n- (i) the rate of flow of unimpeded water from the bore at the surface; and\n- (ii) the pressure head of the water mentioned in subparagraph (i) ; and\n- (iii) the temperature of the groundwater.\n- (i) the day the drilling of the bore started;\n- (ii) the last day the drilling rig was used to drill the bore;\n- (i) the quality and supply rate of the water; and\n- (ii) the depth at which the water is struck; and\n- (iii) the depth to which the water naturally rises;\n- (i) the depth in metres to the standing water level, and either the pump suction inlet or bottom of the drill stem; and\n- (ii) details of the test used to estimate the groundwater supply rate;\n- (i) the rate of flow of unimpeded water from the bore at the surface; and\n- (ii) the pressure head of the water mentioned in subparagraph (i) ; and\n- (iii) the temperature of the groundwater.","sortOrder":18},{"sectionNumber":"sec.13","sectionType":"section","heading":"Pipeline licence or petroleum facility licence—annual report","content":"### sec.13 Pipeline licence or petroleum facility licence—annual report\n\nFor the 2004 Act , section 552 (2) , the following information is prescribed—\nthe authorised activities for the pipeline licence or petroleum facility licence carried out during the period to which the report relates;\na statement of the authorised activities proposed to be carried out under the licence during the next 12 months.\n- (a) the authorised activities for the pipeline licence or petroleum facility licence carried out during the period to which the report relates;\n- (b) a statement of the authorised activities proposed to be carried out under the licence during the next 12 months.","sortOrder":19},{"sectionNumber":"pt.3-div.2","sectionType":"division","heading":"Testing","content":"## Testing","sortOrder":20},{"sectionNumber":"sec.14","sectionType":"section","heading":"Notice about ATP production testing or PL production testing","content":"### sec.14 Notice about ATP production testing or PL production testing\n\nFor the 2004 Act , sections 71A (2) (a) and 150A (2) (a) , the following information is prescribed—\nthe identifying number of the authority to prospect or petroleum lease;\nthe day the testing started;\nthe identifying name of the petroleum well for which the testing is being carried out;\nfor each natural underground reservoir from which the testing is being carried out—\nan identification of the reservoir including, for example, a description of the geological features of the reservoir; and\nthe type of reservoir; and\nthe depth in metres of the top and bottom of the reservoir;\ndetails of any stimulation to be carried out during the testing;\nSee sections 33 and 34 for notice requirements relating to hydraulic fracturing activities.\ndetails of the use, or intended use, of petroleum in a gaseous state produced during the testing.\nfor an authorised activity for the petroleum tenure, flaring, venting, processing\n- (a) the identifying number of the authority to prospect or petroleum lease;\n- (b) the day the testing started;\n- (c) the identifying name of the petroleum well for which the testing is being carried out;\n- (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;\n- (i) an identification of the reservoir including, for example, a description of the geological features of the reservoir; and\n- (ii) the type of reservoir; and\n- (iii) the depth in metres of the top and bottom of the reservoir;\n- (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.\n- (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\n- (i) an identification of the reservoir including, for example, a description of the geological features of the reservoir; and\n- (ii) the type of reservoir; and\n- (iii) the depth in metres of the top and bottom of the reservoir;","sortOrder":21},{"sectionNumber":"sec.15","sectionType":"section","heading":"Notice about ATP storage testing or PL storage testing","content":"### sec.15 Notice about ATP storage testing or PL storage testing\n\nFor the 2004 Act , sections 71B (2) (a) and 150C (2) (a) , the following information is prescribed—\nthe identifying number of the authority to prospect or petroleum lease;\nthe day the testing started;\nthe identifying name of the petroleum well for which the testing is being carried out;\nfor each natural underground reservoir from which the testing is being carried out—\nan identification of the reservoir including, for example, a description of the geological features of the reservoir; and\nthe type of reservoir; and\nthe depth in metres of the top and bottom of the reservoir;\ndetails of substances to be used to carry out the testing.\n- (a) the identifying number of the authority to prospect or petroleum lease;\n- (b) the day the testing started;\n- (c) the identifying name of the petroleum well for which the testing is being carried out;\n- (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;\n- (i) an identification of the reservoir including, for example, a description of the geological features of the reservoir; and\n- (ii) the type of reservoir; and\n- (iii) the depth in metres of the top and bottom of the reservoir;\n- (e) details of substances to be used to carry out the testing.\n- (i) an identification of the reservoir including, for example, a description of the geological features of the reservoir; and\n- (ii) the type of reservoir; and\n- (iii) the depth in metres of the top and bottom of the reservoir;","sortOrder":22},{"sectionNumber":"sec.16","sectionType":"section","heading":"Notice about stopping of testing","content":"### sec.16 Notice about stopping of testing\n\nFor the 2004 Act , sections 71C and 150E the following information is prescribed—\nthe identifying number of the authority to prospect or petroleum lease;\nthe identifying name of the petroleum well for which the testing was carried out;\nthe day the testing started;\nthe day the testing stopped;\nthe reason the testing stopped.\n- (a) the identifying number of the authority to prospect or petroleum lease;\n- (b) the identifying name of the petroleum well for which the testing was carried out;\n- (c) the day the testing started;\n- (d) the day the testing stopped;\n- (e) the reason the testing stopped.","sortOrder":23},{"sectionNumber":"pt.3-div.3","sectionType":"division","heading":"Relinquishment, surrender, end of tenure and end of authority","content":"## Relinquishment, surrender, end of tenure and end of authority","sortOrder":24},{"sectionNumber":"sec.17","sectionType":"section","heading":"Definitions for division","content":"### sec.17 Definitions for division\n\nIn this division—\ngeneral area information , for a relinquishment report or surrender report for a petroleum tenure, see section 18 .\nhazard information , for a relinquishment report or surrender report for a petroleum tenure, see section 19 .\nrelinquished area , for a relinquishment report for a petroleum tenure, means the part of the area of the tenure that is relinquished.\nrelinquishment report means a report required to be lodged—\nunder the 2004 Act , section 545 if part of the area of a petroleum tenure is relinquished under that Act; or\nunder the 1923 Act , section 75Z if part of the area of a petroleum tenure is relinquished under that Act.\nsurrendered area , for a surrender report for a petroleum tenure or pipeline licence, means the part of the area of the tenure or licence—\nto be surrendered; and\nfor which approval of surrender is sought under the application.\nsurrender report means a report—\nrequired 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\nrequired 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.\ns 17 def surrender report amd 2019 SL No. 53 s 18\ntenure information , for a relinquishment report for a petroleum tenure, see section 20 .\n- (a) under the 2004 Act , section 545 if part of the area of a petroleum tenure is relinquished under that Act; or\n- (b) under the 1923 Act , section 75Z if part of the area of a petroleum tenure is relinquished under that Act.\n- (a) to be surrendered; and\n- (b) for which approval of surrender is sought under the application.\n- (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\n- (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.","sortOrder":25},{"sectionNumber":"sec.18","sectionType":"section","heading":"Meaning of general area information","content":"### sec.18 Meaning of general area information\n\nThe following information is general area information for a relinquishment report or surrender report for a petroleum tenure—\nspatial information showing the location of—\nthe area of the tenure immediately before the relinquishment or surrender (the previous tenure area ); and\nthe relinquished area or surrendered area;\nspatial information showing the leads and prospects in the relinquished area or surrendered area;\nany other data or information for the report required under the practice direction.\ns 18 amd 2020 SL No. 208 s 4\n- (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;\n- (i) the area of the tenure immediately before the relinquishment or surrender (the previous tenure area ); and\n- (ii) the relinquished area or surrendered area;\n- (b) spatial information showing the leads and prospects in the relinquished area or surrendered area;\n- (c) any other data or information for the report required under the practice direction.\n- (i) the area of the tenure immediately before the relinquishment or surrender (the previous tenure area ); and\n- (ii) the relinquished area or surrendered area;","sortOrder":26},{"sectionNumber":"sec.19","sectionType":"section","heading":"Meaning of hazard information","content":"### sec.19 Meaning of hazard information\n\nIn 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—\nthe nature of the hazard;\nthe cause, or reasons for existence, of the hazard;\nthe location of the hazard;\nmeasures taken to prevent or reduce the risk of the hazard to mitigate the effects of the hazard.\ns 19 amd 2019 SL No. 89 s 6\nsub 2020 SL No. 208 s 5\n- (a) the nature of the hazard;\n- (b) the cause, or reasons for existence, of the hazard;\n- (c) the location of the hazard;\n- (d) measures taken to prevent or reduce the risk of the hazard to mitigate the effects of the hazard.","sortOrder":27},{"sectionNumber":"sec.20","sectionType":"section","heading":"Meaning of tenure information","content":"### sec.20 Meaning of tenure information\n\nThe following information is tenure information for a relinquishment report for a petroleum tenure—\nthe day the relinquishment takes effect;\nthe period of the work program or development plan for the tenure;\nthe blocks or sub-blocks comprising the relinquished area.\ns 20 amd 2020 SL No. 208 s 6\n- (a) the day the relinquishment takes effect;\n- (b) the period of the work program or development plan for the tenure;\n- (c) the blocks or sub-blocks comprising the relinquished area.","sortOrder":28},{"sectionNumber":"sec.21","sectionType":"section","heading":"Authority to prospect—relinquishment or surrender report","content":"### sec.21 Authority to prospect—relinquishment or surrender report\n\nThis section prescribes—\nother 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\ninformation for a surrender report for an authority to prospect for the 1923 Act , section 21 (4) (b) (ii) .\nThe information is each of the following—\nthe tenure information for the report;\nthe general area information for the report;\na 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;\nthe hazard information for the report;\nfor each year since the authority took effect—\nfor a relinquishment report—the volume of petroleum or water produced from each petroleum well or bore in the relinquished area; or\nfor 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;\nthe reason the holder has relinquished the relinquished area or is applying to surrender the surrendered area;\nany other data or information for the report required under the practice direction.\ns 21 amd 2020 SL No. 208 s 7\n(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) .\n(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.\n- (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\n- (b) information for a surrender report for an authority to prospect for the 1923 Act , section 21 (4) (b) (ii) .\n- (a) the tenure information for the report;\n- (b) the general area information for the report;\n- (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;\n- (d) the hazard information for the report;\n- (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;\n- (i) for a relinquishment report—the volume of petroleum or water produced from each petroleum well or bore in the relinquished area; or\n- (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;\n- (f) the reason the holder has relinquished the relinquished area or is applying to surrender the surrendered area;\n- (g) any other data or information for the report required under the practice direction.\n- (i) for a relinquishment report—the volume of petroleum or water produced from each petroleum well or bore in the relinquished area; or\n- (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;","sortOrder":29},{"sectionNumber":"sec.22","sectionType":"section","heading":"Petroleum lease—relinquishment report","content":"### sec.22 Petroleum lease—relinquishment report\n\nThis 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) .\nThe information is each of the following—\nthe tenure information for the report;\nthe general area information for the report;\nfor each year since the lease took effect—\nthe volume of petroleum produced under the lease from each petroleum well in the relinquished area; and\nthe volume of water produced from each bore in the relinquished area;\nthe geological model of the natural underground reservoirs in the relinquished area;\na 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;\nthe hazard information for the report;\nthe reason the holder has relinquished the area;\nany other data or information for the report required under the practice direction.\ns 22 amd 2020 SL No. 208 s 8\n(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) .\n(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.\n- (a) the tenure information for the report;\n- (b) the general area information for the report;\n- (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;\n- (i) the volume of petroleum produced under the lease from each petroleum well in the relinquished area; and\n- (ii) the volume of water produced from each bore in the relinquished area;\n- (d) the geological model of the natural underground reservoirs in the relinquished area;\n- (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;\n- (f) the hazard information for the report;\n- (g) the reason the holder has relinquished the area;\n- (h) any other data or information for the report required under the practice direction.\n- (i) the volume of petroleum produced under the lease from each petroleum well in the relinquished area; and\n- (ii) the volume of water produced from each bore in the relinquished area;","sortOrder":30},{"sectionNumber":"sec.23","sectionType":"section","heading":"Petroleum lease—surrender report","content":"### sec.23 Petroleum lease—surrender report\n\nFor the 2004 Act , section 576 (2) , the following information is prescribed for a surrender report for a petroleum lease—\nthe hazard information for the report;\nspatial information showing the location in the surrendered area of—\neach petroleum well and bore drilled under the lease; and\neach seismic line used for a seismic survey carried out under the lease;\nstructure contour spatial information showing the seismic horizons (seismic reflectors) in the surrendered area;\nspatial information showing the leads and prospects in the surrendered area;\nthe reason the holder has applied to surrender the part of the area of the lease;\nany other data or information for the report required under the practice direction.\ns 23 amd 2020 SL No. 208 s 9\n- (a) the hazard information for the report;\n- (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;\n- (i) each petroleum well and bore drilled under the lease; and\n- (ii) each seismic line used for a seismic survey carried out under the lease;\n- (c) structure contour spatial information showing the seismic horizons (seismic reflectors) in the surrendered area;\n- (d) spatial information showing the leads and prospects in the surrendered area;\n- (e) the reason the holder has applied to surrender the part of the area of the lease;\n- (f) any other data or information for the report required under the practice direction.\n- (i) each petroleum well and bore drilled under the lease; and\n- (ii) each seismic line used for a seismic survey carried out under the lease;","sortOrder":31},{"sectionNumber":"sec.24","sectionType":"section","heading":"Pipeline licence—surrender report","content":"### sec.24 Pipeline licence—surrender report\n\nFor the 2004 Act , section 576 (2) , the following information is prescribed for a surrender report for a pipeline licence—\nin relation to the licence—\nthe day the licence was granted; and\nthe term of the licence; and\na description of the surrendered area;\na description of, and spatial information showing, the location of the pipeline in the surrendered area, including access to the pipeline;\na summary of the methods used to decommission the pipeline;\ndetails of all maintenance carried out on the pipeline during the term of the licence;\nthe hazard information for the licence;\nany other data or information for the report required under the practice direction.\ns 24 amd 2020 SL No. 208 s 10\n- (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;\n- (i) the day the licence was granted; and\n- (ii) the term of the licence; and\n- (iii) a description of the surrendered area;\n- (b) a description of, and spatial information showing, the location of the pipeline in the surrendered area, including access to the pipeline;\n- (c) a summary of the methods used to decommission the pipeline;\n- (d) details of all maintenance carried out on the pipeline during the term of the licence;\n- (e) the hazard information for the licence;\n- (f) any other data or information for the report required under the practice direction.\n- (i) the day the licence was granted; and\n- (ii) the term of the licence; and\n- (iii) a description of the surrendered area;","sortOrder":32},{"sectionNumber":"sec.25","sectionType":"section","heading":"End of tenure report","content":"### sec.25 End of tenure report\n\nThis 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) .\nThe 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) —\nsections 21 and 22 ;\nfor an end of tenure report for a petroleum lease— section 23 .\nFor 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.\nSubsection (2) does not apply to the extent the information has been included in a relinquishment report or surrender report lodged for the tenure.\n(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) .\n(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 .\n(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.\n(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.\n- (a) sections 21 and 22 ;\n- (b) for an end of tenure report for a petroleum lease— section 23 .","sortOrder":33},{"sectionNumber":"sec.26","sectionType":"section","heading":"End of authority report","content":"### sec.26 End of authority report\n\nFor the 2004 Act , section 546A (2) , the following matters are prescribed—\nthe authorised activities for the data acquisition authority or survey licence carried out during the term of the authority or licence;\nspatial information about each authorised activity carried out under the authority or licence;\nany other data or information for the report required under the practice direction.\ns 26 amd 2020 SL No. 208 s 11\n- (a) the authorised activities for the data acquisition authority or survey licence carried out during the term of the authority or licence;\n- (b) spatial information about each authorised activity carried out under the authority or licence;\n- (c) any other data or information for the report required under the practice direction.","sortOrder":34},{"sectionNumber":"pt.3-div.4","sectionType":"division","heading":"Prescribed notices and reports","content":"## Prescribed notices and reports","sortOrder":35},{"sectionNumber":"sec.27","sectionType":"section","heading":"Purpose of division","content":"### sec.27 Purpose of division\n\nThis division prescribes the notices and reports required to be kept or lodged—\nunder the 2004 Act , section 553 (1) (b) by the holder of a petroleum authority; and\nunder the 1923 Act , section 76G (1) (b) by the holder of a 1923 Act petroleum tenure.\n- (a) under the 2004 Act , section 553 (1) (b) by the holder of a petroleum authority; and\n- (b) under the 1923 Act , section 76G (1) (b) by the holder of a 1923 Act petroleum tenure.","sortOrder":36},{"sectionNumber":"sec.28","sectionType":"section","heading":"Owners and occupiers to be given copy of notices","content":"### sec.28 Owners and occupiers to be given copy of notices\n\nIf the holder of a petroleum tenure is required to lodge a notice under this subdivision, the holder must give a copy of the notice—\nto 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\nby the time the notice is required to be lodged under this subdivision.\nThe requirement under subsection (1) does not apply to the extent the holder is an owner or an occupier of the land.\n(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.\n(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.\n- (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\n- (b) by the time the notice is required to be lodged under this subdivision.","sortOrder":37},{"sectionNumber":"sec.29","sectionType":"section","heading":"Notice about intention to drill a petroleum well or bore","content":"### sec.29 Notice about intention to drill a petroleum well or bore\n\nIf the holder of a petroleum tenure intends to drill a petroleum well or bore, the holder must lodge a notice about the intended drilling.\nThe notice must—\nbe lodged at least 10 business days before the drilling starts; and\nbe in the digital form made or approved by the chief executive; and\nfor a notice about a petroleum well—state a proposed identifying name for the petroleum well.\nThe 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.\n(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.\n(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.\n(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.\n- (a) be lodged at least 10 business days before the drilling starts; and\n- (b) be in the digital form made or approved by the chief executive; and\n- (c) for a notice about a petroleum well—state a proposed identifying name for the petroleum well.","sortOrder":38},{"sectionNumber":"sec.30","sectionType":"section","heading":"Notice about completion, alteration or abandonment of petroleum well or bore","content":"### sec.30 Notice about completion, alteration or abandonment of petroleum well or bore\n\nIf any of the following events happens, the relevant holder must lodge a notice about the event—\ndrilling of a petroleum well or bore is completed;\nthe completion configuration of a petroleum well changes;\na petroleum well or bore is abandoned.\nFor subsection (1) (a) , drilling of a petroleum well or bore is completed if—\nthe drilling rig last used to drill the well or bore is moved so it is no longer above the well or bore; and\nthe relevant holder intends no further drilling of the well or bore to occur.\nFor subsection (1) (b) , the completion configuration of a petroleum well changes if, after drilling of the well is completed—\nadditional casing is installed in the well; or\nany part of the well is plugged, other than for decommissioning the well; or\nan interval in the well is altered in any other way.\nThe notice must be—\nlodged within 10 business days after the event happens; and\nin the digital form made or approved by the chief executive.\nIn this section—\nrelevant holder means—\nif the bore was drilled under a water monitoring authority under the 2004 Act —the holder of the water monitoring authority; or\notherwise—the holder of the petroleum tenure under which the petroleum well or bore was drilled.\n(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.\n(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.\n(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.\n(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.\n(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.\n- (a) drilling of a petroleum well or bore is completed;\n- (b) the completion configuration of a petroleum well changes;\n- (c) a petroleum well or bore is abandoned.\n- (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\n- (b) the relevant holder intends no further drilling of the well or bore to occur.\n- (a) additional casing is installed in the well; or\n- (b) any part of the well is plugged, other than for decommissioning the well; or\n- (c) an interval in the well is altered in any other way.\n- (a) lodged within 10 business days after the event happens; and\n- (b) in the digital form made or approved by the chief executive.\n- (a) if the bore was drilled under a water monitoring authority under the 2004 Act —the holder of the water monitoring authority; or\n- (b) otherwise—the holder of the petroleum tenure under which the petroleum well or bore was drilled.","sortOrder":39},{"sectionNumber":"sec.31","sectionType":"section","heading":"Notice about intention to carry out seismic survey or scientific or technical survey","content":"### sec.31 Notice about intention to carry out seismic survey or scientific or technical survey\n\nIf 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—\nthe area of a petroleum tenure; or\nthe area subject to a data acquisition authority that relates to a 2004 Act petroleum tenure.\nThe notice must state the following matters—\nan identifying name for the survey;\nthe type of survey to be carried out;\nseismic, geophysical, geochemical, geotechnical\na description of the area to be surveyed;\nthe day the surveying will start;\nthe expected duration of the surveying.\nThe 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.\nThe notice must be—\nlodged at least 10 business days before the survey starts; and\nin the approved form; and\naccompanied by spatial information showing the location of the area to be surveyed.\n(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.\n(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.\n(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.\n(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.\n- (a) the area of a petroleum tenure; or\n- (b) the area subject to a data acquisition authority that relates to a 2004 Act petroleum tenure.\n- (a) an identifying name for the survey;\n- (b) the type of survey to be carried out; Examples— seismic, geophysical, geochemical, geotechnical\n- (c) a description of the area to be surveyed;\n- (d) the day the surveying will start;\n- (e) the expected duration of the surveying.\n- (a) lodged at least 10 business days before the survey starts; and\n- (b) in the approved form; and\n- (c) accompanied by spatial information showing the location of the area to be surveyed.","sortOrder":40},{"sectionNumber":"sec.32","sectionType":"section","heading":"Notice about completion of seismic survey or scientific or technical survey","content":"### sec.32 Notice about completion of seismic survey or scientific or technical survey\n\nThis section applies if a seismic survey or scientific or technical survey is completed in either of the following areas—\nthe area of a petroleum tenure; or\nthe area subject to a data acquisition authority that relates to a 2004 Act petroleum tenure.\nThe holder of the petroleum tenure must lodge a notice about the completion of the survey.\nThe notice must be—\nlodged within 10 business days after the survey is completed; and\nin the approved form.\nFor subsection (2) , a survey is completed as soon as all of the raw data for the survey has been recorded or recovered.\n(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.\n(sec.32-ssec.2) The holder of the petroleum tenure must lodge a notice about the completion of the survey.\n(sec.32-ssec.3) The notice must be— lodged within 10 business days after the survey is completed; and in the approved form.\n(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.\n- (a) the area of a petroleum tenure; or\n- (b) the area subject to a data acquisition authority that relates to a 2004 Act petroleum tenure.\n- (a) lodged within 10 business days after the survey is completed; and\n- (b) in the approved form.","sortOrder":41},{"sectionNumber":"sec.33","sectionType":"section","heading":"Notice about intention to carry out hydraulic fracturing activities","content":"### sec.33 Notice about intention to carry out hydraulic fracturing activities\n\nIf 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.\nThe notice must be—\nlodged at least 10 business days before the hydraulic fracturing activities start being carried out; and\nin the digital form made or approved by the chief executive.\n(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.\n(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.\n- (a) lodged at least 10 business days before the hydraulic fracturing activities start being carried out; and\n- (b) in the digital form made or approved by the chief executive.","sortOrder":42},{"sectionNumber":"sec.34","sectionType":"section","heading":"Notice about completion of hydraulic fracturing activities","content":"### sec.34 Notice about completion of hydraulic fracturing activities\n\nIf 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.\nThe notice must state—\nthe days the hydraulic fracturing activities started and ended; and\nthe name of the operator of the drilling project involving the activities; and\nthe name of the contractor who carried out the activities for the operator of the drilling project; and\ndetails of the composition of the hydraulic fracturing fluid pumped into the petroleum well used for the activities.\nThe notice must be—\nlodged within 10 business days after the hydraulic fracturing activities are completed; and\nin the digital form made or approved by the chief executive.\n(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.\n(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.\n(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.\n- (a) the days the hydraulic fracturing activities started and ended; and\n- (b) the name of the operator of the drilling project involving the activities; and\n- (c) the name of the contractor who carried out the activities for the operator of the drilling project; and\n- (d) details of the composition of the hydraulic fracturing fluid pumped into the petroleum well used for the activities.\n- (a) lodged within 10 business days after the hydraulic fracturing activities are completed; and\n- (b) in the digital form made or approved by the chief executive.","sortOrder":43},{"sectionNumber":"sec.35","sectionType":"section","heading":"Daily drilling report","content":"### sec.35 Daily drilling report\n\nThe 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.\nA copy of each daily drilling report must be lodged with the petroleum well or bore completion report lodged for the well.\nAlso, a copy of a daily drilling report must be lodged if the chief executive asks for the report to be lodged.\nA 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—\nthe identifying name of the well;\nthe tenure holder’s name and the tenure under which the well was drilled;\nthe type of drilling rig used;\na summary of the drilling operations carried out;\nthe depth in metres of the well at the end of the day’s drilling;\nthe size and type of drill bit used;\nthe drilling fluids and additives used;\nthe size and depth in metres of any casing inserted in the well;\nthe depth in metres of the top and bottom of each cemented interval in the well;\nthe results of any deviation surveys carried out in the well;\na description of any drill stem tests or other tests carried out in the well;\nthe 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;\nthe type of any perforations in the well and the depth in metres of the top and bottom of the perforated intervals;\ndetails of any stimulation carried out;\ndetails of any squeeze cementing or cement plugging carried out;\na description of any cores or cutting samples taken;\nany other data or information for the report required under the practice direction.\nIn this section—\ndeviation survey means a survey of the path of a petroleum well that measures its direction in 3 dimensions.\ns 35 amd 2020 SL No. 208 s 12\n(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.\n(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.\n(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.\n(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.\n(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.\n- (a) the identifying name of the well;\n- (b) the tenure holder’s name and the tenure under which the well was drilled;\n- (c) the type of drilling rig used;\n- (d) a summary of the drilling operations carried out;\n- (e) the depth in metres of the well at the end of the day’s drilling;\n- (f) the size and type of drill bit used;\n- (g) the drilling fluids and additives used;\n- (h) the size and depth in metres of any casing inserted in the well;\n- (i) the depth in metres of the top and bottom of each cemented interval in the well;\n- (j) the results of any deviation surveys carried out in the well;\n- (k) a description of any drill stem tests or other tests carried out in the well;\n- (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;\n- (m) the type of any perforations in the well and the depth in metres of the top and bottom of the perforated intervals;\n- (n) details of any stimulation carried out;\n- (o) details of any squeeze cementing or cement plugging carried out;\n- (p) a description of any cores or cutting samples taken;\n- (q) any other data or information for the report required under the practice direction.","sortOrder":44},{"sectionNumber":"sec.36","sectionType":"section","heading":"Petroleum well or bore completion report","content":"### sec.36 Petroleum well or bore completion report\n\nIf 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 ).\nThe report must be lodged within 12 months after the rig release day for the well or bore.\nThe report must contain the following information—\nthe type and number of the petroleum tenure;\nthe name and postal address of the operator of the well or bore;\nthe identifying name of the well or bore;\na summary of the well or bore including the information for the well or bore required under the practice direction;\nspatial information showing the location of the well or bore;\nthe height reference in metres for the drilling rig used to drill the well or bore;\nthe total depth in metres of the well or bore;\nthe following days—\nthe day the drilling of the well or bore started;\nthe day the total depth of the well or bore was reached;\nthe rig release day for the well or bore;\ndetails of the drilling rig, the number and type of drill bits, and the drilling fluids, used in the well or bore;\nthe status of the well or bore on the rig release day;\nthe surveyed path of the well or bore;\ndetails of the casing and equipment installed in the well or bore, with a diagram showing their location in the well or bore;\nthe 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;\ndetails 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;\na 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;\na geological interpretation of the well or bore, including the stratigraphy of the rock units it intersects;\nan identification of the intervals in the well that have the potential to produce petroleum;\nthe tenure holder’s reasons for choosing the location of the well or bore;\nany other data or information for the report required under the practice direction.\nFor a directional well, the report must also state the position of each of the following—\nthe stratigraphic units intersected by the well;\nthe bottom of the well;\nany intersection of the well with another petroleum well.\nFor subsection (4) , the position must be expressed in relation to—\ntotal vertical depth in metres; and\nthe horizontal plane.\nThe report must be accompanied by each of the following—\na digital image of the cores taken during the drilling of the well or bore;\nthe raw data, in digital form, of each geophysical (or wireline) log that has been run in the well or bore;\na digital image of the graphic representations of the raw data mentioned in paragraph (b) .\nIf 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) .\ns 36 amd 2020 SL No. 208 s 13\n(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 ).\n(sec.36-ssec.2) The report must be lodged within 12 months after the rig release day for the well or bore.\n(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.\n(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.\n(sec.36-ssec.5) For subsection (4) , the position must be expressed in relation to— total vertical depth in metres; and the horizontal plane.\n(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) .\n(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) .\n- (a) the type and number of the petroleum tenure;\n- (b) the name and postal address of the operator of the well or bore;\n- (c) the identifying name of the well or bore;\n- (d) a summary of the well or bore including the information for the well or bore required under the practice direction;\n- (e) spatial information showing the location of the well or bore;\n- (f) the height reference in metres for the drilling rig used to drill the well or bore;\n- (g) the total depth in metres of the well or bore;\n- (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;\n- (i) the day the drilling of the well or bore started;\n- (ii) the day the total depth of the well or bore was reached;\n- (iii) the rig release day for the well or bore;\n- (i) details of the drilling rig, the number and type of drill bits, and the drilling fluids, used in the well or bore;\n- (j) the status of the well or bore on the rig release day;\n- (k) the surveyed path of the well or bore;\n- (l) details of the casing and equipment installed in the well or bore, with a diagram showing their location in the well or bore;\n- (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- (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;\n- (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;\n- (p) a geological interpretation of the well or bore, including the stratigraphy of the rock units it intersects;\n- (q) an identification of the intervals in the well that have the potential to produce petroleum;\n- (r) the tenure holder’s reasons for choosing the location of the well or bore;\n- (s) any other data or information for the report required under the practice direction.\n- (i) the day the drilling of the well or bore started;\n- (ii) the day the total depth of the well or bore was reached;\n- (iii) the rig release day for the well or bore;\n- (a) the stratigraphic units intersected by the well;\n- (b) the bottom of the well;\n- (c) any intersection of the well with another petroleum well.\n- (a) total vertical depth in metres; and\n- (b) the horizontal plane.\n- (a) a digital image of the cores taken during the drilling of the well or bore;\n- (b) the raw data, in digital form, of each geophysical (or wireline) log that has been run in the well or bore;\n- (c) a digital image of the graphic representations of the raw data mentioned in paragraph (b) .","sortOrder":45},{"sectionNumber":"sec.37","sectionType":"section","heading":"Petroleum well or bore abandonment report","content":"### sec.37 Petroleum well or bore abandonment report\n\nThis section applies to a petroleum well or bore drilled under a petroleum tenure or water monitoring authority under the 2004 Act .\nIf 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 ).\nThe report must be lodged within 6 months after the day the plugging and abandoning of the well or bore is completed.\nThe report must contain the following information—\nthe type and number of the tenure or authority;\nthe identifying name of the well or bore;\nthe name of the author of the report;\nthe name of the tenure or authority holder;\nthe name of the operator of the well or bore;\na summary of the well or bore including the information for the well or bore required under the practice direction;\nthe following information in relation to the completion or abandonment of the well or bore—\na 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;\naluminium, electronics or batteries\nthe surveyed location of any prescribed equipment;\nthe 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;\nthe method, materials and volume of cement used to cement voids;\na description of procedures or activities undertaken for abandonment of the well or bore;\nany other data or information for the report required under the practice direction.\nIn this section—\ncoal mining operations see the Coal Mining Safety and Health Act 1999 , schedule 3 .\nprescribed equipment means—\nmetal equipment, other than casing; and\nother equipment that may create a hazard to coal mining operations.\ndrilling equipment and geophysical logging tools\ns 37 amd 2018 SL No. 135 s 183 ; 2020 SL No. 208 s 14\n(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 .\n(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 ).\n(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.\n(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.\n(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\n- (a) the type and number of the tenure or authority;\n- (b) the identifying name of the well or bore;\n- (c) the name of the author of the report;\n- (d) the name of the tenure or authority holder;\n- (e) the name of the operator of the well or bore;\n- (f) a summary of the well or bore including the information for the well or bore required under the practice direction;\n- (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;\n- (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\n- (ii) the surveyed location of any prescribed equipment;\n- (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;\n- (iv) the method, materials and volume of cement used to cement voids;\n- (v) a description of procedures or activities undertaken for abandonment of the well or bore;\n- (h) any other data or information for the report required under the practice direction.\n- (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\n- (ii) the surveyed location of any prescribed equipment;\n- (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;\n- (iv) the method, materials and volume of cement used to cement voids;\n- (v) a description of procedures or activities undertaken for abandonment of the well or bore;\n- (a) metal equipment, other than casing; and\n- (b) other equipment that may create a hazard to coal mining operations.","sortOrder":46},{"sectionNumber":"sec.38","sectionType":"section","heading":"Seismic survey reports","content":"### sec.38 Seismic survey reports\n\nThis section applies if the holder of a petroleum tenure—\ncarries out a seismic survey of an area of the tenure; or\nfor 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\nreprocesses raw data obtained from a survey mentioned in paragraph (a) or (b) .\nThe tenure holder must lodge a seismic survey report within—\nfor a survey mentioned subsection (1) (a) or (b) —2 years after the completion day for the survey; or\nif the tenure holder reprocesses raw data obtained as mentioned in subsection (1) (c) —2 years after the day the reprocessing is completed.\nThe report must contain the following information—\na description of the location of the area surveyed;\nthe objectives of the survey;\nthe 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;\na description of each method used to acquire raw data, including—\nthe equipment used for positioning, surveying, navigation or other purposes; and\nthe techniques and equipment used for recording and testing the data;\na description of how the raw data was processed or reprocessed;\nan evaluation of the processed or reprocessed data;\nany other data or information for the report required under the practice direction.\nThe report must be accompanied by—\neach of the following in digital form—\nthe raw data obtained in relation to the survey and the record made as the data was recorded (commonly known as the ‘observer’s logs’);\na list of the seismic lines used and the range of the numbered stations on each line;\nthe surveyed location, including the elevation, of each seismic source and receiver point;\nthe processed or reprocessed data derived from each seismic line used for the survey; and\nif 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\nspatial information showing the location of the seismic lines used for the survey.\ns 38 amd 2019 SL No. 53 s 19 ; 2020 SL No. 208 s 15\n(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) .\n(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.\n(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.\n(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.\n- (a) carries out a seismic survey of an area of the tenure; or\n- (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\n- (c) reprocesses raw data obtained from a survey mentioned in paragraph (a) or (b) .\n- (a) for a survey mentioned subsection (1) (a) or (b) —2 years after the completion day for the survey; or\n- (b) if the tenure holder reprocesses raw data obtained as mentioned in subsection (1) (c) —2 years after the day the reprocessing is completed.\n- (a) a description of the location of the area surveyed;\n- (b) the objectives of the survey;\n- (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;\n- (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;\n- (i) the equipment used for positioning, surveying, navigation or other purposes; and\n- (ii) the techniques and equipment used for recording and testing the data;\n- (e) a description of how the raw data was processed or reprocessed;\n- (f) an evaluation of the processed or reprocessed data;\n- (g) any other data or information for the report required under the practice direction.\n- (i) the equipment used for positioning, surveying, navigation or other purposes; and\n- (ii) the techniques and equipment used for recording and testing the data;\n- (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\n- (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’);\n- (ii) a list of the seismic lines used and the range of the numbered stations on each line;\n- (iii) the surveyed location, including the elevation, of each seismic source and receiver point;\n- (iv) the processed or reprocessed data derived from each seismic line used for the survey; and\n- (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\n- (c) spatial information showing the location of the seismic lines used for the survey.\n- (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’);\n- (ii) a list of the seismic lines used and the range of the numbered stations on each line;\n- (iii) the surveyed location, including the elevation, of each seismic source and receiver point;\n- (iv) the processed or reprocessed data derived from each seismic line used for the survey; and","sortOrder":47},{"sectionNumber":"sec.39","sectionType":"section","heading":"Scientific or technical survey report","content":"### sec.39 Scientific or technical survey report\n\nThis section applies if the holder of a petroleum tenure—\ncarries out a scientific or technical survey of an area of the tenure; or\nfor 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\nreprocesses raw data obtained from a survey mentioned in paragraph (a) or (b) .\nThe tenure holder must lodge a scientific or technical survey report within—\nfor a survey mentioned subsection (1) (a) or (b) —2 years after the completion day for the survey; or\nif the tenure holder reprocesses raw data as mentioned in subsection (1) (c) —2 years after the day the reprocessing is completed.\nThe report must contain the following information—\na description of the location of the area surveyed;\nthe type of survey carried out;\nthe objectives of the survey;\nthe activities carried out for the survey, including, for example, the days on which the activities were carried out;\nthe methods and equipment used for acquiring and processing, or reprocessing, data;\nan interpretation of the processed or reprocessed data derived from the survey;\nspatial information showing the location of—\nthe area surveyed; and\nwhere any measurements were made or samples were taken in connection with the survey;\nany other data or information for the report required under the practice direction.\nThe report must be accompanied by each of the following in digital form—\nthe raw data obtained in relation to the survey;\nthe processed or reprocessed data derived from the survey.\ns 39 amd 2019 SL No. 53 s 20; 2020 SL No. 208 s 16\n(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) .\n(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.\n(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.\n(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.\n- (a) carries out a scientific or technical survey of an area of the tenure; or\n- (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\n- (c) reprocesses raw data obtained from a survey mentioned in paragraph (a) or (b) .\n- (a) for a survey mentioned subsection (1) (a) or (b) —2 years after the completion day for the survey; or\n- (b) if the tenure holder reprocesses raw data as mentioned in subsection (1) (c) —2 years after the day the reprocessing is completed.\n- (a) a description of the location of the area surveyed;\n- (b) the type of survey carried out;\n- (c) the objectives of the survey;\n- (d) the activities carried out for the survey, including, for example, the days on which the activities were carried out;\n- (e) the methods and equipment used for acquiring and processing, or reprocessing, data;\n- (f) an interpretation of the processed or reprocessed data derived from the survey;\n- (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;\n- (i) the area surveyed; and\n- (ii) where any measurements were made or samples were taken in connection with the survey;\n- (h) any other data or information for the report required under the practice direction.\n- (i) the area surveyed; and\n- (ii) where any measurements were made or samples were taken in connection with the survey;\n- (a) the raw data obtained in relation to the survey;\n- (b) the processed or reprocessed data derived from the survey.","sortOrder":48},{"sectionNumber":"sec.40","sectionType":"section","heading":"Definition for subdivision","content":"### sec.40 Definition for subdivision\n\nIn this subdivision—\n6-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—\n1 January to 30 June;\n1 July to 31 December.\n- (a) 1 January to 30 June;\n- (b) 1 July to 31 December.","sortOrder":49},{"sectionNumber":"sec.41","sectionType":"section","heading":"How particular measurements must be stated in reports","content":"### sec.41 How particular measurements must be stated in reports\n\nThis section applies if this subdivision requires a measurement to be stated in a report.\nThe measurement of a volume or mass must be stated in—\nfor water—megalitres; or\nfor gas—million cubic metres (Mm3); or\nfor LPG—kilotonnes; or\nfor crude oil or condensate—million barrels (also known as MMbbl).\nThe measurement of energy must be stated in—\nfor petroleum, a prescribed storage gas or substance prescribed under the 2004 Act , section 402 (1) , including coal seam gas—petajoules; or\nfor crude oil or condensate—energy of oil in million barrels of oil equivalent (also known as MMBOE).\nThe measurement of a depth, length or other distance must be stated in metres.\ns 41 sub 2020 SL No. 208 s 17\n(sec.41-ssec.1) This section applies if this subdivision requires a measurement to be stated in a report.\n(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).\n(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).\n(sec.41-ssec.4) The measurement of a depth, length or other distance must be stated in metres.\n- (a) for water—megalitres; or\n- (b) for gas—million cubic metres (Mm3); or\n- (c) for LPG—kilotonnes; or\n- (d) for crude oil or condensate—million barrels (also known as MMbbl).\n- (a) for petroleum, a prescribed storage gas or substance prescribed under the 2004 Act , section 402 (1) , including coal seam gas—petajoules; or\n- (b) for crude oil or condensate—energy of oil in million barrels of oil equivalent (also known as MMBOE).","sortOrder":50},{"sectionNumber":"sec.42","sectionType":"section","heading":"Petroleum production report","content":"### sec.42 Petroleum production report\n\nThe holder of a petroleum lease must lodge a petroleum production report for the lease for each 6-month period.\nThe report must be lodged within 60 business days after the 6-month period ends.\nThe report must contain the following information—\nthe number of the lease;\nan identification of each production interval or geological unit from which first-produced petroleum is produced under the lease during the 6-month period;\nthe volume of each of the following produced under the lease during the 6-month period—\neach petroleum product derived from first-produced petroleum;\nfirst-produced petroleum that was flared or vented in a gaseous state;\nfirst-produced petroleum that was used to produce other petroleum;\nthe volume, or estimated volume, of associated water taken from each natural underground reservoir during the 6-month period and the lease period;\nfor each natural underground reservoir from which petroleum is produced under the lease—the number of petroleum wells producing petroleum from the reservoir;\nfor 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;\nif 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;\nany other data or information for the report required under the practice direction.\nIn this section—\nfirst-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.\nlease period means—\nfor 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\nfor 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.\ns 42 amd 2020 SL No. 208 s 18\n(sec.42-ssec.1) The holder of a petroleum lease must lodge a petroleum production report for the lease for each 6-month period.\n(sec.42-ssec.2) The report must be lodged within 60 business days after the 6-month period ends.\n(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.\n(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.\n- (a) the number of the lease;\n- (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;\n- (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;\n- (i) each petroleum product derived from first-produced petroleum;\n- (ii) first-produced petroleum that was flared or vented in a gaseous state;\n- (iii) first-produced petroleum that was used to produce other petroleum;\n- (d) the volume, or estimated volume, of associated water taken from each natural underground reservoir during the 6-month period and the lease period;\n- (e) for each natural underground reservoir from which petroleum is produced under the lease—the number of petroleum wells producing petroleum from the reservoir;\n- (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;\n- (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;\n- (h) any other data or information for the report required under the practice direction.\n- (i) each petroleum product derived from first-produced petroleum;\n- (ii) first-produced petroleum that was flared or vented in a gaseous state;\n- (iii) first-produced petroleum that was used to produce other petroleum;\n- (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\n- (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.","sortOrder":51},{"sectionNumber":"sec.43","sectionType":"section","heading":"Petroleum resources and reserves report","content":"### sec.43 Petroleum resources and reserves report\n\nA petroleum tenure holder must lodge a petroleum resources and reserves report for the tenure for each calendar year.\nThe report must be lodged within 60 business days after the calendar year ends.\nThe report must contain the following information—\nthe type and number of the tenure;\nan 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;\nthe 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;\ndetails 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;\nany 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;\nany other data or information for the report required under the practice direction.\nIn this section—\nPRMS means the document called ‘Petroleum Resources Management System’, also referred to as the SPE Code, published in 2018 by the Society of Petroleum Engineers.\nproject maturity subclass means a sub-classification of activities for a project mentioned in the PRMS , part 2.1.3.5 .\ns 43 amd 2020 SL No. 208 s 19\n(sec.43-ssec.1) A petroleum tenure holder must lodge a petroleum resources and reserves report for the tenure for each calendar year.\n(sec.43-ssec.2) The report must be lodged within 60 business days after the calendar year ends.\n(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.\n(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 .\n- (a) the type and number of the tenure;\n- (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;\n- (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;\n- (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;\n- (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;\n- (f) any other data or information for the report required under the practice direction.","sortOrder":52},{"sectionNumber":"sec.44","sectionType":"section","heading":"Production testing report","content":"### sec.44 Production testing report\n\nThis section applies if production testing for a petroleum well is carried out under a petroleum tenure.\nThe tenure holder must lodge a production testing report for the relevant testing period.\nThe report must be lodged within 60 business days after the relevant testing period ends.\nThe report must contain the following information—\nthe type and number of the tenure;\nthe identifying name of the petroleum well;\nan identification of each natural underground reservoir and the reservoir formation (or geological unit) from which petroleum was produced as part of the production testing;\nthe duration of the production testing carried out during the period;\nthe type of any perforations in the well and the depth in metres of the top and bottom of the perforated intervals;\nthe volumes, or estimated volumes, of gas, oil and water produced from the testing during the period;\nthe choke size used for the well;\nthe 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;\nthe 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;\nif petroleum in a gaseous state was produced during the testing—\ndetails of the use, or intended use, of the petroleum; and\nfor an authorised activity for the petroleum tenure, flaring, venting, processing\nthe volume, or estimated volume, of the petroleum used, or intended to be used, other than by flaring or venting;\ndata in relation to samples, and the analysis of the samples, taken from the area of the tenure;\nany other data or information for the report required under the practice direction.\nIn this section—\nend day , for production testing for a petroleum well, means—\nif 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\notherwise—the day that is 6 months after the testing starts.\nproduction testing means testing for petroleum production from a petroleum well within the area of the petroleum tenure.\nrelevant testing period means—\nthe period starting on the first day production testing for the petroleum well is carried out and ending on the earlier of—\nthe end day; or\nthe last day the testing is carried out; and\nif 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.\ns 44 amd 2020 SL No. 208 s 20\n(sec.44-ssec.1) This section applies if production testing for a petroleum well is carried out under a petroleum tenure.\n(sec.44-ssec.2) The tenure holder must lodge a production testing report for the relevant testing period.\n(sec.44-ssec.3) The report must be lodged within 60 business days after the relevant testing period ends.\n(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.\n(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.\n- (a) the type and number of the tenure;\n- (b) the identifying name of the petroleum well;\n- (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;\n- (d) the duration of the production testing carried out during the period;\n- (e) the type of any perforations in the well and the depth in metres of the top and bottom of the perforated intervals;\n- (f) the volumes, or estimated volumes, of gas, oil and water produced from the testing during the period;\n- (g) the choke size used for the well;\n- (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;\n- (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;\n- (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;\n- (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\n- (ii) the volume, or estimated volume, of the petroleum used, or intended to be used, other than by flaring or venting;\n- (k) data in relation to samples, and the analysis of the samples, taken from the area of the tenure;\n- (l) any other data or information for the report required under the practice direction.\n- (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\n- (ii) the volume, or estimated volume, of the petroleum used, or intended to be used, other than by flaring or venting;\n- (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\n- (b) otherwise—the day that is 6 months after the testing starts.\n- (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\n- (i) the end day; or\n- (ii) the last day the testing is carried out; and\n- (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.\n- (i) the end day; or\n- (ii) the last day the testing is carried out; and","sortOrder":53},{"sectionNumber":"sec.45","sectionType":"section","heading":"Hydraulic fracturing activities completion report","content":"### sec.45 Hydraulic fracturing activities completion report\n\nAfter 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.\nThe report must be lodged within 6 months after the hydraulic fracturing activities are completed.\nThe report must contain the following information—\nthe type and number of the tenure;\nthe name and postal address of the contractor who carried out the hydraulic fracturing activities on behalf of the operator of the drilling project;\nthe identifying name of each treatment well or observation well for which the activities were carried out;\nthe days the activities for each petroleum well started and ended;\na description of each method of activities carried out;\nthe depth in metres of the top and bottom of—\neach stage over which the activities were carried out; and\neach geological interval over which activities were carried out and the name of each geological interval;\na summary of the operations performed at each stage in carrying out the activities, including the volume and type of chemical used at each stage;\nan 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—\ncasing pressure with time;\ncalculated bottom hole pressure with time;\ncalculated bottom hole concentration with time;\nthe rate at which the hydraulic fracturing fluid is pumped into the well used for the activities with time;\nthe concentration of proppant in the hydraulic fracturing fluid with time;\nmaximum surface treatment pressure reached during each stage of the activities;\nthe estimated targeted fracture pressure over the geological interval during each stage of the activities;\ndetails of—\nthe equipment used to carry out and monitor the activities; and\nthe diagnostic techniques used to monitor the activities;\nif known, details of—\nany geological connection between a geological interval over which activities were carried out and an aquifer; and\nIn 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.\nthe distance separating a geological interval over which activities were carried out from an aquifer;\ndetails of the total volume of hydraulic fracturing fluid, in kilolitres, pumped into each petroleum well during each stage of the activities;\nif 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;\nif 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;\nany other data or information for the report required under the practice direction.\nThe 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—\nthe quantity of each component of the hydraulic fracturing fluid; and\nthe concentration of each component in the hydraulic fracturing fluid; and\nthe name of any chemical compound contained in the hydraulic fracturing fluid.\nMaximum penalty for subsection (4) —20 penalty units.\ns 45 amd 2020 SL No. 208 s 21\n(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.\n(sec.45-ssec.2) The report must be lodged within 6 months after the hydraulic fracturing activities are completed.\n(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.\n(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.\n- (a) the type and number of the tenure;\n- (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;\n- (c) the identifying name of each treatment well or observation well for which the activities were carried out;\n- (d) the days the activities for each petroleum well started and ended;\n- (e) a description of each method of activities carried out;\n- (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;\n- (i) each stage over which the activities were carried out; and\n- (ii) each geological interval over which activities were carried out and the name of each geological interval;\n- (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;\n- (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;\n- (i) casing pressure with time;\n- (ii) calculated bottom hole pressure with time;\n- (iii) calculated bottom hole concentration with time;\n- (iv) the rate at which the hydraulic fracturing fluid is pumped into the well used for the activities with time;\n- (v) the concentration of proppant in the hydraulic fracturing fluid with time;\n- (vi) maximum surface treatment pressure reached during each stage of the activities;\n- (vii) the estimated targeted fracture pressure over the geological interval during each stage of the activities;\n- (i) details of— (i) the equipment used to carry out and monitor the activities; and (ii) the diagnostic techniques used to monitor the activities;\n- (i) the equipment used to carry out and monitor the activities; and\n- (ii) the diagnostic techniques used to monitor the activities;\n- (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;\n- (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.\n- (ii) the distance separating a geological interval over which activities were carried out from an aquifer;\n- (k) details of the total volume of hydraulic fracturing fluid, in kilolitres, pumped into each petroleum well during each stage of the activities;\n- (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;\n- (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- (n) any other data or information for the report required under the practice direction.\n- (i) each stage over which the activities were carried out; and\n- (ii) each geological interval over which activities were carried out and the name of each geological interval;\n- (i) casing pressure with time;\n- (ii) calculated bottom hole pressure with time;\n- (iii) calculated bottom hole concentration with time;\n- (iv) the rate at which the hydraulic fracturing fluid is pumped into the well used for the activities with time;\n- (v) the concentration of proppant in the hydraulic fracturing fluid with time;\n- (vi) maximum surface treatment pressure reached during each stage of the activities;\n- (vii) the estimated targeted fracture pressure over the geological interval during each stage of the activities;\n- (i) the equipment used to carry out and monitor the activities; and\n- (ii) the diagnostic techniques used to monitor the activities;\n- (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.\n- (ii) the distance separating a geological interval over which activities were carried out from an aquifer;\n- (a) the quantity of each component of the hydraulic fracturing fluid; and\n- (b) the concentration of each component in the hydraulic fracturing fluid; and\n- (c) the name of any chemical compound contained in the hydraulic fracturing fluid.","sortOrder":54},{"sectionNumber":"pt.4","sectionType":"part","heading":"Matters relating to records, samples and required information","content":"# Matters relating to records, samples and required information","sortOrder":55},{"sectionNumber":"pt.4-div.1","sectionType":"division","heading":"Records","content":"## Records","sortOrder":56},{"sectionNumber":"sec.46","sectionType":"section","heading":"Record of supply of gas from PGPLR land","content":"### sec.46 Record of supply of gas from PGPLR land\n\nFor the 2004 Act , section 175H (2) , a record of the following information must be kept—\ndetails of the petroleum lease for the PGPLR land, including its number and the area of the lease;\nthe entity to whom the gas was supplied;\nthe volume of gas supplied to the entity.\nEach record must be kept—\nfor at least 7 years after the day the record was made; and\nin 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) .\nhard copy or electronic format\n(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.\n(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\n- (a) details of the petroleum lease for the PGPLR land, including its number and the area of the lease;\n- (b) the entity to whom the gas was supplied;\n- (c) the volume of gas supplied to the entity.\n- (a) for at least 7 years after the day the record was made; and\n- (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","sortOrder":57},{"sectionNumber":"pt.4-div.2","sectionType":"division","heading":"Samples","content":"## Samples","sortOrder":58},{"sectionNumber":"sec.47","sectionType":"section","heading":"Purpose of division","content":"### sec.47 Purpose of division\n\nThis division prescribes matters for the 2004 Act , section 547 (1) and the 1923 Act , section 76A (1) .","sortOrder":59},{"sectionNumber":"sec.48","sectionType":"section","heading":"Keeping samples","content":"### sec.48 Keeping samples\n\nA sample must be kept until the later of the following—\nthe end of the term of the petroleum tenure;\nthe sample, or part of the sample, is lodged under the 2004 Act , section 548 or the 1923 Act , section 76B .\nA sample must be kept in a way that prevents unnecessary deterioration or loss of the sample.\ns 48 amd 2020 SL No. 70 s 9\n(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 .\n(sec.48-ssec.2) A sample must be kept in a way that prevents unnecessary deterioration or loss of the sample.\n- (a) the end of the term of the petroleum tenure;\n- (b) the sample, or part of the sample, is lodged under the 2004 Act , section 548 or the 1923 Act , section 76B .","sortOrder":60},{"sectionNumber":"sec.49","sectionType":"section","heading":"Cutting samples","content":"### sec.49 Cutting samples\n\nEach cutting sample of geological formations taken as follows must be kept—\nwhen the formations are penetrated making a petroleum well under a petroleum tenure;\nat each interval stated in subsection (2) .\nFor subsection (1) (b) , the intervals are—\nfor 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\neach 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.\nHowever, 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.\nThe part of the sample lodged under the 2004 Act , section 548 (1) or the 1923 Act , section 76B (1) must be—\nat least 250g, but not more than 500g; and\nwashed and dried; and\nin a container that is suitable for long-term storage and handling, and is labelled with—\nthe identifying name of the well from which the sample was taken; and\nthe depth in metres of the top and bottom of the interval from which the sample was taken.\nIn this section—\ncutting sample means a sample of the cuttings produced making the well.\n(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) .\n(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.\n(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.\n(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.\n(sec.49-ssec.5) In this section— cutting sample means a sample of the cuttings produced making the well.\n- (a) when the formations are penetrated making a petroleum well under a petroleum tenure;\n- (b) at each interval stated in subsection (2) .\n- (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\n- (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.\n- (a) at least 250g, but not more than 500g; and\n- (b) washed and dried; and\n- (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.\n- (i) the identifying name of the well from which the sample was taken; and\n- (ii) the depth in metres of the top and bottom of the interval from which the sample was taken.\n- (i) the identifying name of the well from which the sample was taken; and\n- (ii) the depth in metres of the top and bottom of the interval from which the sample was taken.","sortOrder":61},{"sectionNumber":"sec.50","sectionType":"section","heading":"Cores","content":"### sec.50 Cores\n\nEach core recovered from a petroleum well under a petroleum tenure must be kept.\nHowever, subsection (1) applies in relation to a core from a petroleum well made solely for coal seam gas exploration or production only if—\nthe holder gives the chief executive notice, in the approved form, offering to give the chief executive a sample of the core; and\nthe notice is received within 5 months after the day the core is recovered; and\nwithin 20 business days after receiving the notice, the chief executive gives the holder notice that the sample must be kept.\nThe part of the core lodged under the 2004 Act , section 548 (1) or the 1923 Act , section 76B (1) must—\nbe at least 50% of the core recovered; and\nhave as complete a vertical face as is practicable; and\nbe lodged in a box or other suitable container that is suitable for long-term storage and handling, and is labelled with—\nthe identifying name of the well from which the core was recovered; and\nif more than 1 core is recovered from the well—the number of the core; and\nthe depth in metres of the top and bottom of the interval cored; and\nthe length in metres of the core recovered.\n(sec.50-ssec.1) Each core recovered from a petroleum well under a petroleum tenure must be kept.\n(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.\n(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.\n- (a) the holder gives the chief executive notice, in the approved form, offering to give the chief executive a sample of the core; and\n- (b) the notice is received within 5 months after the day the core is recovered; and\n- (c) within 20 business days after receiving the notice, the chief executive gives the holder notice that the sample must be kept.\n- (a) be at least 50% of the core recovered; and\n- (b) have as complete a vertical face as is practicable; and\n- (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.\n- (i) the identifying name of the well from which the core was recovered; and\n- (ii) if more than 1 core is recovered from the well—the number of the core; and\n- (iii) the depth in metres of the top and bottom of the interval cored; and\n- (iv) the length in metres of the core recovered.\n- (i) the identifying name of the well from which the core was recovered; and\n- (ii) if more than 1 core is recovered from the well—the number of the core; and\n- (iii) the depth in metres of the top and bottom of the interval cored; and\n- (iv) the length in metres of the core recovered.","sortOrder":62},{"sectionNumber":"sec.51","sectionType":"section","heading":"Fluid samples","content":"### sec.51 Fluid samples\n\nA sample (a fluid sample ) of liquid petroleum recovered from a petroleum well under a petroleum tenure must be kept if—\nthe sample is more than 10l; and\nwithin 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.\nFor the 2004 Act , section 548 (1) and the 1923 Act , section 76B (1) , the part of the fluid sample lodged must be—\nat least 500ml of the fluid sample recovered; and\nin a glass bottle that is teflon sealed with a screw top; and\nlabelled with at least—\nthe identifying name of the well; and\nthe depth in metres of the top and bottom of the interval from which the sample was recovered; and\nthe day on which the sample was recovered; and\nthe method by which the fluid sample was recovered.\ndrill stem tests, production tests\n(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.\n(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\n- (a) the sample is more than 10l; and\n- (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.\n- (a) at least 500ml of the fluid sample recovered; and\n- (b) in a glass bottle that is teflon sealed with a screw top; and\n- (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\n- (i) the identifying name of the well; and\n- (ii) the depth in metres of the top and bottom of the interval from which the sample was recovered; and\n- (iii) the day on which the sample was recovered; and\n- (iv) the method by which the fluid sample was recovered. Examples— drill stem tests, production tests\n- (i) the identifying name of the well; and\n- (ii) the depth in metres of the top and bottom of the interval from which the sample was recovered; and\n- (iii) the day on which the sample was recovered; and\n- (iv) the method by which the fluid sample was recovered. Examples— drill stem tests, production tests","sortOrder":63},{"sectionNumber":"pt.4-div.3","sectionType":"division","heading":"Releasing required information","content":"## Releasing required information","sortOrder":64},{"sectionNumber":"sec.52","sectionType":"section","heading":"Confidentiality periods for required information for petroleum tenures","content":"### sec.52 Confidentiality periods for required information for petroleum tenures\n\nThis 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.\nThe 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.\nHowever, there is no confidentiality period for a petroleum well or bore abandonment report under section 37 if—\nthe 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\nthe person is the holder of a coal or oil shale mining tenement; and\nthe well or bore was drilled in the area of the person’s coal or oil shale mining tenement.\nAlso, there is no confidentiality period for required information not mentioned in subsection (2) .\ns 52 sub 2020 SL No. 208 s 22\namd 2022 SL No. 191 s 6 ; 2025 SL No. 48 s 14 sch 1\n(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.\n(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.\n(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.\n(sec.52-ssec.4) Also, there is no confidentiality period for required information not mentioned in subsection (2) .\n- (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\n- (b) the person is the holder of a coal or oil shale mining tenement; and\n- (c) the well or bore was drilled in the area of the person’s coal or oil shale mining tenement.","sortOrder":65},{"sectionNumber":"sec.53","sectionType":"section","heading":"Publication of required information","content":"### sec.53 Publication of required information\n\nFor 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—\nin a journal published by the department or under the Minister’s authority;\nin another publication considered appropriate by the chief executive;\non the department’s website;\nin a publicly available database;\non a map that is made available to the public for inspection or purchase;\nin digital or electronic form, including, for example, on a disc or tape;\nby displaying it on a notice that is available to the public for inspection at—\nthe department’s head office; and\nother places the chief executive considers appropriate;\nby telling it to another person or presenting it to the person in a visual form.\n- (a) in a journal published by the department or under the Minister’s authority;\n- (b) in another publication considered appropriate by the chief executive;\n- (c) on the department’s website;\n- (d) in a publicly available database;\n- (e) on a map that is made available to the public for inspection or purchase;\n- (f) in digital or electronic form, including, for example, on a disc or tape;\n- (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;\n- (i) the department’s head office; and\n- (ii) other places the chief executive considers appropriate;\n- (h) by telling it to another person or presenting it to the person in a visual form.\n- (i) the department’s head office; and\n- (ii) other places the chief executive considers appropriate;","sortOrder":66},{"sectionNumber":"pt.5","sectionType":"part","heading":"Matters relating to taking non-associated water","content":"# Matters relating to taking non-associated water","sortOrder":67},{"sectionNumber":"sec.54","sectionType":"section","heading":"Definition for part","content":"### sec.54 Definition for part\n\nIn this part—\nreporting period , for a petroleum tenure, means each period—\nthat starts on 1 January and ends on—\n30 June; or\nif the tenure expires or is surrendered on a day falling between 1 January and 30 June—that day; or\nthat starts on 1 July and ends on—\n31 December; or\nif the tenure expires or is surrendered on a day falling between 1 July and 31 December—that day.\n- (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\n- (i) 30 June; or\n- (ii) if the tenure expires or is surrendered on a day falling between 1 January and 30 June—that day; or\n- (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.\n- (i) 31 December; or\n- (ii) if the tenure expires or is surrendered on a day falling between 1 July and 31 December—that day.\n- (i) 30 June; or\n- (ii) if the tenure expires or is surrendered on a day falling between 1 January and 30 June—that day; or\n- (i) 31 December; or\n- (ii) if the tenure expires or is surrendered on a day falling between 1 July and 31 December—that day.","sortOrder":68},{"sectionNumber":"sec.55","sectionType":"section","heading":"Requirements for measuring the taking of non-associated water","content":"### sec.55 Requirements for measuring the taking of non-associated water\n\nThis section prescribes, for the 2004 Act , section 186 (4) , the requirements for measuring the volume of non-associated water taken by a holder of a 2004 Act petroleum tenure.\nThe volume of non-associated water taken must be calculated by—\nmeasuring the volume of non-associated water taken, in the area of the tenure, using a meter complying with AS 4747-2013 (Meters for non-urban water supply); or\nif non-associated water taken in the area of the tenure is transported by one or more vehicles—\nmultiplying the maximum water storage capacity of each vehicle by the number of loads of water (whether part or full) transported by the vehicle (the per vehicle volume ); and\nif more than one vehicle is used—adding the per vehicle volume for each vehicle.\nDespite subsection (2) , the holder may calculate, in whole or in part, the volume of non-associated water taken in the area of the tenure using an alternative method—\nsubmitted to the chief executive in writing with—\ninformation supporting the reliability and accuracy of the method; and\nan explanation of why the alternative method is being used instead of a method mentioned in subsection (2) ; and\napproved by the chief executive.\n(sec.55-ssec.1) This section prescribes, for the 2004 Act , section 186 (4) , the requirements for measuring the volume of non-associated water taken by a holder of a 2004 Act petroleum tenure.\n(sec.55-ssec.2) The volume of non-associated water taken must be calculated by— measuring the volume of non-associated water taken, in the area of the tenure, using a meter complying with AS 4747-2013 (Meters for non-urban water supply); or if non-associated water taken in the area of the tenure is transported by one or more vehicles— multiplying the maximum water storage capacity of each vehicle by the number of loads of water (whether part or full) transported by the vehicle (the per vehicle volume ); and if more than one vehicle is used—adding the per vehicle volume for each vehicle.\n(sec.55-ssec.3) Despite subsection (2) , the holder may calculate, in whole or in part, the volume of non-associated water taken in the area of the tenure using an alternative method— submitted to the chief executive in writing with— information supporting the reliability and accuracy of the method; and an explanation of why the alternative method is being used instead of a method mentioned in subsection (2) ; and approved by the chief executive.\n- (a) measuring the volume of non-associated water taken, in the area of the tenure, using a meter complying with AS 4747-2013 (Meters for non-urban water supply); or\n- (b) if non-associated water taken in the area of the tenure is transported by one or more vehicles— (i) multiplying the maximum water storage capacity of each vehicle by the number of loads of water (whether part or full) transported by the vehicle (the per vehicle volume ); and (ii) if more than one vehicle is used—adding the per vehicle volume for each vehicle.\n- (i) multiplying the maximum water storage capacity of each vehicle by the number of loads of water (whether part or full) transported by the vehicle (the per vehicle volume ); and\n- (ii) if more than one vehicle is used—adding the per vehicle volume for each vehicle.\n- (i) multiplying the maximum water storage capacity of each vehicle by the number of loads of water (whether part or full) transported by the vehicle (the per vehicle volume ); and\n- (ii) if more than one vehicle is used—adding the per vehicle volume for each vehicle.\n- (a) submitted to the chief executive in writing with— (i) information supporting the reliability and accuracy of the method; and (ii) an explanation of why the alternative method is being used instead of a method mentioned in subsection (2) ; and\n- (i) information supporting the reliability and accuracy of the method; and\n- (ii) an explanation of why the alternative method is being used instead of a method mentioned in subsection (2) ; and\n- (b) approved by the chief executive.\n- (i) information supporting the reliability and accuracy of the method; and\n- (ii) an explanation of why the alternative method is being used instead of a method mentioned in subsection (2) ; and","sortOrder":69},{"sectionNumber":"sec.56","sectionType":"section","heading":"Requirements for reporting the taking of non-associated water","content":"### sec.56 Requirements for reporting the taking of non-associated water\n\nThis section prescribes, for the 2004 Act , section 186 (4) , the requirements for reporting the volume of non-associated water taken by a holder of a 2004 Act petroleum tenure.\nFor each reporting period, the holder must report—\nthe total volume of non-associated water taken in the area of the tenure during the reporting period; and\nfor non-associated water extracted from a bore in the area of the tenure—\nthe volume of non-associated water extracted from the bore during the reporting period; and\nthe source geological formation from which the non-associated water was taken; and\nwhether the source geological formation is artesian or subartesian; and\nthe authorised activity for the tenure for which the non-associated water was used; and\nif, during the reporting period, the holder uses an alternative method under section 55 (3) for the first time—an explanation of the alternative method.\nReporting must be lodged by the holder under this section—\nif the reporting period ends on 30 June or 31 December—within 20 business days after the end of the reporting period; or\notherwise—on the day the tenure expires or is surrendered.\ns 56 amd 2020 SL No. 208 s 23\n(sec.56-ssec.1) This section prescribes, for the 2004 Act , section 186 (4) , the requirements for reporting the volume of non-associated water taken by a holder of a 2004 Act petroleum tenure.\n(sec.56-ssec.2) For each reporting period, the holder must report— the total volume of non-associated water taken in the area of the tenure during the reporting period; and for non-associated water extracted from a bore in the area of the tenure— the volume of non-associated water extracted from the bore during the reporting period; and the source geological formation from which the non-associated water was taken; and whether the source geological formation is artesian or subartesian; and the authorised activity for the tenure for which the non-associated water was used; and if, during the reporting period, the holder uses an alternative method under section 55 (3) for the first time—an explanation of the alternative method.\n(sec.56-ssec.3) Reporting must be lodged by the holder under this section— if the reporting period ends on 30 June or 31 December—within 20 business days after the end of the reporting period; or otherwise—on the day the tenure expires or is surrendered.\n- (a) the total volume of non-associated water taken in the area of the tenure during the reporting period; and\n- (b) for non-associated water extracted from a bore in the area of the tenure— (i) the volume of non-associated water extracted from the bore during the reporting period; and (ii) the source geological formation from which the non-associated water was taken; and (iii) whether the source geological formation is artesian or subartesian; and\n- (i) the volume of non-associated water extracted from the bore during the reporting period; and\n- (ii) the source geological formation from which the non-associated water was taken; and\n- (iii) whether the source geological formation is artesian or subartesian; and\n- (c) the authorised activity for the tenure for which the non-associated water was used; and\n- (d) if, during the reporting period, the holder uses an alternative method under section 55 (3) for the first time—an explanation of the alternative method.\n- (i) the volume of non-associated water extracted from the bore during the reporting period; and\n- (ii) the source geological formation from which the non-associated water was taken; and\n- (iii) whether the source geological formation is artesian or subartesian; and\n- (a) if the reporting period ends on 30 June or 31 December—within 20 business days after the end of the reporting period; or\n- (b) otherwise—on the day the tenure expires or is surrendered.","sortOrder":70},{"sectionNumber":"sec.57","sectionType":"section","heading":"Chief executive may review alternative method","content":"### sec.57 Chief executive may review alternative method\n\nThis section applies if the holder uses an alternative method under section 55 (3) for calculating a volume of non-associated water taken by the holder instead of a method mentioned in section 55 (2) .\nThe chief executive may, at any time, review the alternative method to assess the reliability and accuracy of the method.\nIf, as a result of the review, the chief executive no longer considers the alternative method to be reliable or accurate—\nthe chief executive must, as soon as practicable, give the holder notice of the result of the review; and\nfor the next reporting period, the holder must use—\na method mentioned in section 55 (2) ; or\nanother alternative method that complies with section 55 (3) .\n(sec.57-ssec.1) This section applies if the holder uses an alternative method under section 55 (3) for calculating a volume of non-associated water taken by the holder instead of a method mentioned in section 55 (2) .\n(sec.57-ssec.2) The chief executive may, at any time, review the alternative method to assess the reliability and accuracy of the method.\n(sec.57-ssec.3) If, as a result of the review, the chief executive no longer considers the alternative method to be reliable or accurate— the chief executive must, as soon as practicable, give the holder notice of the result of the review; and for the next reporting period, the holder must use— a method mentioned in section 55 (2) ; or another alternative method that complies with section 55 (3) .\n- (a) the chief executive must, as soon as practicable, give the holder notice of the result of the review; and\n- (b) for the next reporting period, the holder must use— (i) a method mentioned in section 55 (2) ; or (ii) another alternative method that complies with section 55 (3) .\n- (i) a method mentioned in section 55 (2) ; or\n- (ii) another alternative method that complies with section 55 (3) .\n- (i) a method mentioned in section 55 (2) ; or\n- (ii) another alternative method that complies with section 55 (3) .","sortOrder":71},{"sectionNumber":"pt.6","sectionType":"part","heading":"Metering parameters","content":"# Metering parameters","sortOrder":72},{"sectionNumber":"sec.58","sectionType":"section","heading":"Tolerance for error for a meter","content":"### sec.58 Tolerance for error for a meter\n\nThis section prescribes, for the 2004 Act , section 635 (a) , the tolerance for error in accuracy for a meter.\nIf the meter measures not more than 25m 3 of petroleum or fuel gas in an hour, the tolerance is—\nfor a meter installed before 31 December 2004—plus 2% or minus 3%; or\notherwise—plus or minus 1.5%.\nFor a meter not mentioned in subsection (2) , the tolerance is plus or minus 1%.\nThis section is subject to sections 59 and 60 .\n(sec.58-ssec.1) This section prescribes, for the 2004 Act , section 635 (a) , the tolerance for error in accuracy for a meter.\n(sec.58-ssec.2) If the meter measures not more than 25m 3 of petroleum or fuel gas in an hour, the tolerance is— for a meter installed before 31 December 2004—plus 2% or minus 3%; or otherwise—plus or minus 1.5%.\n(sec.58-ssec.3) For a meter not mentioned in subsection (2) , the tolerance is plus or minus 1%.\n(sec.58-ssec.4) This section is subject to sections 59 and 60 .\n- (a) for a meter installed before 31 December 2004—plus 2% or minus 3%; or\n- (b) otherwise—plus or minus 1.5%.","sortOrder":73},{"sectionNumber":"sec.59","sectionType":"section","heading":"Other requirements for accuracy of meter—100TJ to 1PJ","content":"### sec.59 Other requirements for accuracy of meter—100TJ to 1PJ\n\nThis section applies in relation to a meter that measures 100TJ or more, but not more than 1PJ, a year.\nThe controller of the meter must ensure the meter is installed with a device to correct the meter’s readings to standard temperature and pressure.\nThe overall tolerance for error for the meter, including the correcting device, is plus or minus 1%.\nThe accuracy of the meter must be checked at least once in each 6-month period.\ns 59 amd 2024 SL No. 32 s 5\n(sec.59-ssec.1) This section applies in relation to a meter that measures 100TJ or more, but not more than 1PJ, a year.\n(sec.59-ssec.2) The controller of the meter must ensure the meter is installed with a device to correct the meter’s readings to standard temperature and pressure.\n(sec.59-ssec.3) The overall tolerance for error for the meter, including the correcting device, is plus or minus 1%.\n(sec.59-ssec.4) The accuracy of the meter must be checked at least once in each 6-month period.","sortOrder":74},{"sectionNumber":"sec.60","sectionType":"section","heading":"Other requirements for accuracy of meter—over 1PJ","content":"### sec.60 Other requirements for accuracy of meter—over 1PJ\n\nThis section applies in relation to a meter that measures more than 1PJ a year.\nThe controller of the meter must ensure the meter is installed with a flow computer to calculate the energy of the petroleum or fuel gas flowing through the meter.\nThe overall tolerance for error for the meter, including the flow computer, is plus or minus 1%.\nThe accuracy of the meter must be checked at least once in every 3-month period.\n(sec.60-ssec.1) This section applies in relation to a meter that measures more than 1PJ a year.\n(sec.60-ssec.2) The controller of the meter must ensure the meter is installed with a flow computer to calculate the energy of the petroleum or fuel gas flowing through the meter.\n(sec.60-ssec.3) The overall tolerance for error for the meter, including the flow computer, is plus or minus 1%.\n(sec.60-ssec.4) The accuracy of the meter must be checked at least once in every 3-month period.","sortOrder":75},{"sectionNumber":"sec.61","sectionType":"section","heading":"Requirements for measurement scheme","content":"### sec.61 Requirements for measurement scheme\n\nFor the 2004 Act , section 637 (1) (d) , a meter that measures more than 25m 3 of petroleum or fuel gas in an hour must be replaced or tested at least once every 10 years.\nFor the 2004 Act , section 637 (1) (k) , if a measurement of petroleum or fuel gas is to be converted into another form of measurement under a measurement scheme, the scheme must state the method for converting the measurement.\nFor this section—\nform of measurement means any of the following—\na measurement of the energy of the petroleum or fuel gas;\na measurement of the mass of the petroleum or fuel gas;\na measurement of the volume of the petroleum or fuel gas.\n(sec.61-ssec.1) For the 2004 Act , section 637 (1) (d) , a meter that measures more than 25m 3 of petroleum or fuel gas in an hour must be replaced or tested at least once every 10 years.\n(sec.61-ssec.2) For the 2004 Act , section 637 (1) (k) , if a measurement of petroleum or fuel gas is to be converted into another form of measurement under a measurement scheme, the scheme must state the method for converting the measurement.\n(sec.61-ssec.3) For this section— form of measurement means any of the following— a measurement of the energy of the petroleum or fuel gas; a measurement of the mass of the petroleum or fuel gas; a measurement of the volume of the petroleum or fuel gas.\n- (a) a measurement of the energy of the petroleum or fuel gas;\n- (b) a measurement of the mass of the petroleum or fuel gas;\n- (c) a measurement of the volume of the petroleum or fuel gas.","sortOrder":76},{"sectionNumber":"sec.62","sectionType":"section","heading":"Requirement for gas pressure regulator","content":"### sec.62 Requirement for gas pressure regulator\n\nThe controller of a meter must ensure the addition of a gas pressure regulator to the meter does not disadvantage a consumer.\nexcessive regulator droop that could result in incorrect billing\nMaximum penalty—20 penalty units.","sortOrder":77},{"sectionNumber":"sec.63","sectionType":"section","heading":"Metering factors","content":"### sec.63 Metering factors\n\nIf there is a correction factor for calculating the price of gas flowing through a meter, the controller of the meter must ensure the pressure at which the meter must be operated is clearly marked on, or in the immediate vicinity of, the meter.\nMaximum penalty—20 penalty units.","sortOrder":78},{"sectionNumber":"pt.7","sectionType":"part","heading":"Financial provisions","content":"# Financial provisions","sortOrder":79},{"sectionNumber":"pt.7-div.1","sectionType":"division","heading":"Fees and rents payable","content":"## Fees and rents payable","sortOrder":80},{"sectionNumber":"sec.64","sectionType":"section","heading":"Fees generally","content":"### sec.64 Fees generally\n\nThe fees payable under the 2004 Act are—\nas worked out under section 66A ; and\nstated in schedule 2 .\nThe fees payable under the 1923 Act are stated in schedule 3 .\nSee also the Petroleum and Gas (Royalty) Regulation 2021 , section 39 and the Petroleum and Gas (Safety) Regulation 2018 , section 152 and schedule 6 .\ns 64 amd 2018 SL No. 135 s 184 ; 2021 SL No. 124 s 101 sch 2 ; 2022 SL No. 47 s 25 ; 2024 SL No. 68 s 3\n(sec.64-ssec.1) The fees payable under the 2004 Act are— as worked out under section 66A ; and stated in schedule 2 .\n(sec.64-ssec.2) The fees payable under the 1923 Act are stated in schedule 3 .\n- (a) as worked out under section 66A ; and\n- (b) stated in schedule 2 .","sortOrder":81},{"sectionNumber":"sec.64A","sectionType":"section","heading":null,"content":"### Section sec.64A\n\ns 64A orig s 64A ins 2020 SL No. 70 s 10\nexp 30 September 2020 (see prev s 64A(4))\nprev s 64A ins 2020 SL No. 253 s 6 (retro)\nexp 31 March 2021 (see s 64A(4))","sortOrder":82},{"sectionNumber":"sec.65","sectionType":"section","heading":"Annual rent","content":"### sec.65 Annual rent\n\nThe annual rent payable for each of the following resource authorities is stated in schedule 4 , part 1 —\na petroleum tenure;\na data acquisition authority;\na water monitoring authority.\n- (a) a petroleum tenure;\n- (b) a data acquisition authority;\n- (c) a water monitoring authority.","sortOrder":83},{"sectionNumber":"sec.65A","sectionType":"section","heading":null,"content":"### Section sec.65A\n\ns 65A orig s 65A ins 2020 SL No. 70 s 11\nexp 30 September 2020 (see prev s 65A(6))\nprev s 65A ins 2020 SL No. 253 s 7 (retro)\nexp 31 March 2021 (see s 65A(6))","sortOrder":84},{"sectionNumber":"sec.66","sectionType":"section","heading":"Storage rent payable by owner of stored petroleum or prescribed storage gas","content":"### sec.66 Storage rent payable by owner of stored petroleum or prescribed storage gas\n\nFor the 2004 Act , section 227 (3) , the rate at which rent is payable is stated in schedule 4 , part 2 .","sortOrder":85},{"sectionNumber":"sec.66A","sectionType":"section","heading":"Annual fee for pipeline licence holder","content":"### sec.66A Annual fee for pipeline licence holder\n\nThis section prescribes, for the 2004 Act , section 423 (3) , the annual fee payable by a pipeline licence holder for a financial year.\nThe annual fee is the amount worked out using the following formula, rounded down to the nearest cent—\nwhere—\nA means the annual fee payable by the pipeline licence holder for the financial year.\nB means the amount, expressed in dollars, of the cost of the State’s funding commitments to combined energy market regulation for the financial year, decided by the MCE.\nC means the proportion of B, expressed as a percentage, that is attributable to the cost of national energy market regulation for the financial year, decided by the AEMC.\nD means the number of kilometres of scheme pipeline situated in Queensland at the start of the financial year.\nE means the number of kilometres of scheme pipeline the subject of the holder’s licence at the start of the financial year.\nIn this section—\ncombined energy market regulation means the functions of the AEMC under the Australian Energy Market Commission Establishment Act 2004 (SA) , section 6 .\nMCE see the National Gas (Queensland) Law , section 2 .\ns 66A ins 2022 SL No. 47 s 26\namd 2022 SL No. 84 s 6\nsub 2024 SL No. 68 s 4\n(sec.66A-ssec.1) This section prescribes, for the 2004 Act , section 423 (3) , the annual fee payable by a pipeline licence holder for a financial year.\n(sec.66A-ssec.2) The annual fee is the amount worked out using the following formula, rounded down to the nearest cent— where— A means the annual fee payable by the pipeline licence holder for the financial year. B means the amount, expressed in dollars, of the cost of the State’s funding commitments to combined energy market regulation for the financial year, decided by the MCE. C means the proportion of B, expressed as a percentage, that is attributable to the cost of national energy market regulation for the financial year, decided by the AEMC. D means the number of kilometres of scheme pipeline situated in Queensland at the start of the financial year. E means the number of kilometres of scheme pipeline the subject of the holder’s licence at the start of the financial year.\n(sec.66A-ssec.3) In this section— combined energy market regulation means the functions of the AEMC under the Australian Energy Market Commission Establishment Act 2004 (SA) , section 6 . MCE see the National Gas (Queensland) Law , section 2 .","sortOrder":86},{"sectionNumber":"pt.7-div.2","sectionType":"division","heading":"Payment of annual fees and rents","content":"## Payment of annual fees and rents","sortOrder":87},{"sectionNumber":"sec.67","sectionType":"section","heading":"Application of division","content":"### sec.67 Application of division\n\nThis division applies for the payment of—\nthe following fees (each an annual fee )—\nan annual fee payable by a pipeline licence holder under the 2004 Act , section 423 (3) that is a proportion of the cost of the State’s funding commitments to national energy market regulation;\nan annual fee stated in schedule 2 for a pipeline licence or petroleum facility licence; and\nannual rent payable for a resource authority mentioned in section 65 ; and\nrent for storing petroleum or a prescribed storage gas payable under the 2004 Act , section 227 .\ns 67 amd 2022 SL No. 47 s 27\n- (a) the following fees (each an annual fee )— (i) an annual fee payable by a pipeline licence holder under the 2004 Act , section 423 (3) that is a proportion of the cost of the State’s funding commitments to national energy market regulation; (ii) an annual fee stated in schedule 2 for a pipeline licence or petroleum facility licence; and\n- (i) an annual fee payable by a pipeline licence holder under the 2004 Act , section 423 (3) that is a proportion of the cost of the State’s funding commitments to national energy market regulation;\n- (ii) an annual fee stated in schedule 2 for a pipeline licence or petroleum facility licence; and\n- (b) annual rent payable for a resource authority mentioned in section 65 ; and\n- (c) rent for storing petroleum or a prescribed storage gas payable under the 2004 Act , section 227 .\n- (i) an annual fee payable by a pipeline licence holder under the 2004 Act , section 423 (3) that is a proportion of the cost of the State’s funding commitments to national energy market regulation;\n- (ii) an annual fee stated in schedule 2 for a pipeline licence or petroleum facility licence; and","sortOrder":88},{"sectionNumber":"sec.68","sectionType":"section","heading":"When annual fee or rent must be paid","content":"### sec.68 When annual fee or rent must be paid\n\nAn annual fee or rent must be paid on or before 31 August each year.\nHowever, an annual fee or rent must be paid within 20 business days after—\non the grant of a pipeline licence or petroleum facility licence—the licence takes effect; or\non the grant of a resource authority for which annual rent is payable—the authority takes effect; or\nfor the first payment of rent for storing petroleum or a prescribed storage gas payable by a person—\nif a notice has been lodged under the 2004 Act , section 219 for the petroleum or prescribed storage gas—the day the person becomes the owner of the petroleum or prescribed storage gas; or\notherwise—the day the Minister decides, under the 2004 Act , section 215 , the person is the owner of the petroleum or prescribed storage gas.\nSubsection (2) does not apply on the grant of a pipeline licence, petroleum facility licence or resource authority if the Minister has already required payment of an annual fee or rent.\nSee the 2004 Act , sections 40 (1) , 410 (1) and 446 (1) for examples of when the Minister may require payment of rent or payment of an annual fee for a pipeline licence or petroleum facility licence.\n(sec.68-ssec.1) An annual fee or rent must be paid on or before 31 August each year.\n(sec.68-ssec.2) However, an annual fee or rent must be paid within 20 business days after— on the grant of a pipeline licence or petroleum facility licence—the licence takes effect; or on the grant of a resource authority for which annual rent is payable—the authority takes effect; or for the first payment of rent for storing petroleum or a prescribed storage gas payable by a person— if a notice has been lodged under the 2004 Act , section 219 for the petroleum or prescribed storage gas—the day the person becomes the owner of the petroleum or prescribed storage gas; or otherwise—the day the Minister decides, under the 2004 Act , section 215 , the person is the owner of the petroleum or prescribed storage gas.\n(sec.68-ssec.3) Subsection (2) does not apply on the grant of a pipeline licence, petroleum facility licence or resource authority if the Minister has already required payment of an annual fee or rent. See the 2004 Act , sections 40 (1) , 410 (1) and 446 (1) for examples of when the Minister may require payment of rent or payment of an annual fee for a pipeline licence or petroleum facility licence.\n- (a) on the grant of a pipeline licence or petroleum facility licence—the licence takes effect; or\n- (b) on the grant of a resource authority for which annual rent is payable—the authority takes effect; or\n- (c) for the first payment of rent for storing petroleum or a prescribed storage gas payable by a person— (i) if a notice has been lodged under the 2004 Act , section 219 for the petroleum or prescribed storage gas—the day the person becomes the owner of the petroleum or prescribed storage gas; or (ii) otherwise—the day the Minister decides, under the 2004 Act , section 215 , the person is the owner of the petroleum or prescribed storage gas.\n- (i) if a notice has been lodged under the 2004 Act , section 219 for the petroleum or prescribed storage gas—the day the person becomes the owner of the petroleum or prescribed storage gas; or\n- (ii) otherwise—the day the Minister decides, under the 2004 Act , section 215 , the person is the owner of the petroleum or prescribed storage gas.\n- (i) if a notice has been lodged under the 2004 Act , section 219 for the petroleum or prescribed storage gas—the day the person becomes the owner of the petroleum or prescribed storage gas; or\n- (ii) otherwise—the day the Minister decides, under the 2004 Act , section 215 , the person is the owner of the petroleum or prescribed storage gas.","sortOrder":89},{"sectionNumber":"sec.69","sectionType":"section","heading":"Prescribed way for paying annual fee or rent","content":"### sec.69 Prescribed way for paying annual fee or rent\n\nAn annual fee or rent must be paid by cash or electronic transfer of funds.","sortOrder":90},{"sectionNumber":"sec.70","sectionType":"section","heading":"Reduced annual fee or annual rent for part of a year","content":"### sec.70 Reduced annual fee or annual rent for part of a year\n\nIf the period to which an annual fee or rent relates is less than a year, a pro-rata amount of the fee or rent is payable for the year.\nIf an annual fee or rent is paid for a year and any of the following happens during the year, the proportion of the fee or rent for the remainder of the year may be refunded—\nthe licence for which the annual fee was paid ends;\nthe resource authority for which the rent was paid ends;\nthe petroleum or prescribed storage gas stops being stored.\n(sec.70-ssec.1) If the period to which an annual fee or rent relates is less than a year, a pro-rata amount of the fee or rent is payable for the year.\n(sec.70-ssec.2) If an annual fee or rent is paid for a year and any of the following happens during the year, the proportion of the fee or rent for the remainder of the year may be refunded— the licence for which the annual fee was paid ends; the resource authority for which the rent was paid ends; the petroleum or prescribed storage gas stops being stored.\n- (a) the licence for which the annual fee was paid ends;\n- (b) the resource authority for which the rent was paid ends;\n- (c) the petroleum or prescribed storage gas stops being stored.","sortOrder":91},{"sectionNumber":"pt.7-div.3","sectionType":"division","heading":"Other matters","content":"## Other matters","sortOrder":92},{"sectionNumber":"sec.71","sectionType":"section","heading":"Security for petroleum authorities","content":"### sec.71 Security for petroleum authorities\n\nFor the 2004 Act , section 488 (2) (a) and the 1923 Act , section 78E (2) (a) , the following forms of security are prescribed—\ncash;\nelectronic transfer of funds;\nan unconditional security issued by a financial institution that—\nis in favour of the ‘State of Queensland’ and is payable on demand; and\nhas no expiry day; and\nstates the type and number of—\nthe petroleum authority or 1923 petroleum tenure; or\nthe proposed petroleum authority or proposed 1923 petroleum tenure; and\nstates the address of the financial institution; and\nis signed for the financial institution by an officer who has authority to sign the security;\na combination of the forms mentioned in paragraphs (a) to (c) .\nFor the 2004 Act , section 488 (2) (b) and the 1923 Act , section 78E (2) (b) , the following amounts are prescribed—\nfor an authority to prospect or proposed authority to prospect—$12,000;\nfor a data acquisition authority or proposed data acquisition authority—$10,500;\nfor a petroleum lease or proposed petroleum lease—$35,000;\nfor a water monitoring authority or proposed water monitoring authority—$10,500.\ns 71 amd 2019 SL No. 53 s 21\n(sec.71-ssec.1) For the 2004 Act , section 488 (2) (a) and the 1923 Act , section 78E (2) (a) , the following forms of security are prescribed— cash; electronic transfer of funds; an unconditional security issued by a financial institution that— is in favour of the ‘State of Queensland’ and is payable on demand; and has no expiry day; and states the type and number of— the petroleum authority or 1923 petroleum tenure; or the proposed petroleum authority or proposed 1923 petroleum tenure; and states the address of the financial institution; and is signed for the financial institution by an officer who has authority to sign the security; a combination of the forms mentioned in paragraphs (a) to (c) .\n(sec.71-ssec.2) For the 2004 Act , section 488 (2) (b) and the 1923 Act , section 78E (2) (b) , the following amounts are prescribed— for an authority to prospect or proposed authority to prospect—$12,000; for a data acquisition authority or proposed data acquisition authority—$10,500; for a petroleum lease or proposed petroleum lease—$35,000; for a water monitoring authority or proposed water monitoring authority—$10,500.\n- (a) cash;\n- (b) electronic transfer of funds;\n- (c) an unconditional security issued by a financial institution that— (i) is in favour of the ‘State of Queensland’ and is payable on demand; and (ii) has no expiry day; and (iii) states the type and number of— (A) the petroleum authority or 1923 petroleum tenure; or (B) the proposed petroleum authority or proposed 1923 petroleum tenure; and (iv) states the address of the financial institution; and (v) is signed for the financial institution by an officer who has authority to sign the security;\n- (i) is in favour of the ‘State of Queensland’ and is payable on demand; and\n- (ii) has no expiry day; and\n- (iii) states the type and number of— (A) the petroleum authority or 1923 petroleum tenure; or (B) the proposed petroleum authority or proposed 1923 petroleum tenure; and\n- (A) the petroleum authority or 1923 petroleum tenure; or\n- (B) the proposed petroleum authority or proposed 1923 petroleum tenure; and\n- (iv) states the address of the financial institution; and\n- (v) is signed for the financial institution by an officer who has authority to sign the security;\n- (d) a combination of the forms mentioned in paragraphs (a) to (c) .\n- (i) is in favour of the ‘State of Queensland’ and is payable on demand; and\n- (ii) has no expiry day; and\n- (iii) states the type and number of— (A) the petroleum authority or 1923 petroleum tenure; or (B) the proposed petroleum authority or proposed 1923 petroleum tenure; and\n- (A) the petroleum authority or 1923 petroleum tenure; or\n- (B) the proposed petroleum authority or proposed 1923 petroleum tenure; and\n- (iv) states the address of the financial institution; and\n- (v) is signed for the financial institution by an officer who has authority to sign the security;\n- (A) the petroleum authority or 1923 petroleum tenure; or\n- (B) the proposed petroleum authority or proposed 1923 petroleum tenure; and\n- (a) for an authority to prospect or proposed authority to prospect—$12,000;\n- (b) for a data acquisition authority or proposed data acquisition authority—$10,500;\n- (c) for a petroleum lease or proposed petroleum lease—$35,000;\n- (d) for a water monitoring authority or proposed water monitoring authority—$10,500.","sortOrder":93},{"sectionNumber":"sec.72","sectionType":"section","heading":"Prescribed interest rate for amounts owing to the State","content":"### sec.72 Prescribed interest rate for amounts owing to the State\n\nFor the 2004 Act , section 588 (3) and the 1923 Act , section 102 (2) , the rate of interest is 15% a year.\ns 72 amd 2025 SL No. 48 s 14 sch 1","sortOrder":94},{"sectionNumber":"pt.8","sectionType":"part","heading":"Miscellaneous","content":"# Miscellaneous","sortOrder":95},{"sectionNumber":"sec.73","sectionType":"section","heading":"Required level of knowledge for a deposit of coal or oil shale","content":"### sec.73 Required level of knowledge for a deposit of coal or oil shale\n\nFor the 2004 Act , section 318 (1) (c) , the level of knowledge about a deposit of coal or oil shale in the land is—\nat least 20% of the area of the deposit must be a reserve under the relevant code; and\nthe remainder of the deposit must be an indicated or measured resource under the relevant code.\nSee the 2004 Act , section 318 (4) for the meaning of relevant code .\nThe estimate of reserves and resources made for subsection (1) must comply with the relevant code.\nThe document called ‘Australian guidelines for the estimation and classification of coal resources’ (2014) published by the Coalfields Geology Council of New South Wales and the Queensland Resources Council must be considered for determining the amount of data required to make the estimate for a deposit of coal.\nThis document may be inspected free of charge at the office of the department notified on the department’s website.\n(sec.73-ssec.1) For the 2004 Act , section 318 (1) (c) , the level of knowledge about a deposit of coal or oil shale in the land is— at least 20% of the area of the deposit must be a reserve under the relevant code; and the remainder of the deposit must be an indicated or measured resource under the relevant code. See the 2004 Act , section 318 (4) for the meaning of relevant code .\n(sec.73-ssec.2) The estimate of reserves and resources made for subsection (1) must comply with the relevant code.\n(sec.73-ssec.3) The document called ‘Australian guidelines for the estimation and classification of coal resources’ (2014) published by the Coalfields Geology Council of New South Wales and the Queensland Resources Council must be considered for determining the amount of data required to make the estimate for a deposit of coal. This document may be inspected free of charge at the office of the department notified on the department’s website.\n- (a) at least 20% of the area of the deposit must be a reserve under the relevant code; and\n- (b) the remainder of the deposit must be an indicated or measured resource under the relevant code.","sortOrder":96},{"sectionNumber":"sec.74","sectionType":"section","heading":"Prescribed way for making applications, giving or lodging documents or making submissions","content":"### sec.74 Prescribed way for making applications, giving or lodging documents or making submissions\n\nThis section prescribes, for the 2004 Act , section 851AA (2) (b) , and the 1923 Act , section 124AA (2) (b) , ways for doing any of the following—\nmaking an application or submission;\ngiving a document to the Minister, chief executive or chief inspector;\nlodging a document.\nFor subsection (1) , the ways are—\nelectronically using the online system provided for the purpose and accessible from a Queensland Government website; or\nif the department’s website states a postal address or facsimile number for making a particular type of application or submission, or giving or lodging a particular type of document—by sending it to the stated address or number.\nAlso, the chief executive may, by a notice given to a person making an application or submission, or giving or lodging a document, require the person to lodge a hard copy of the application, submission or document at the place required under the 2004 Act , section 851AA (2) (a) or the 1923 Act , section 124AA (2) (a) .\nAn application or submission made, or document (other than a safety and health fee return) given or lodged electronically under subsection (2) (a) after 4.30p.m. on a working day and before 8.30a.m. on the next working day (the later day ) is taken to have been lodged at 8.30a.m. on the later day.\nIn this section—\nQueensland Government website means a website with a URL that contains ‘qld.gov.au’, other than the website of a local government.\nsafety and health fee return see the Petroleum and Gas (Safety) Regulation 2018 , section 157 (1) .\ns 74 amd 2018 SL No. 135 s 185\n(sec.74-ssec.1) This section prescribes, for the 2004 Act , section 851AA (2) (b) , and the 1923 Act , section 124AA (2) (b) , ways for doing any of the following— making an application or submission; giving a document to the Minister, chief executive or chief inspector; lodging a document.\n(sec.74-ssec.2) For subsection (1) , the ways are— electronically using the online system provided for the purpose and accessible from a Queensland Government website; or if the department’s website states a postal address or facsimile number for making a particular type of application or submission, or giving or lodging a particular type of document—by sending it to the stated address or number.\n(sec.74-ssec.3) Also, the chief executive may, by a notice given to a person making an application or submission, or giving or lodging a document, require the person to lodge a hard copy of the application, submission or document at the place required under the 2004 Act , section 851AA (2) (a) or the 1923 Act , section 124AA (2) (a) .\n(sec.74-ssec.4) An application or submission made, or document (other than a safety and health fee return) given or lodged electronically under subsection (2) (a) after 4.30p.m. on a working day and before 8.30a.m. on the next working day (the later day ) is taken to have been lodged at 8.30a.m. on the later day.\n(sec.74-ssec.5) In this section— Queensland Government website means a website with a URL that contains ‘qld.gov.au’, other than the website of a local government. safety and health fee return see the Petroleum and Gas (Safety) Regulation 2018 , section 157 (1) .\n- (a) making an application or submission;\n- (b) giving a document to the Minister, chief executive or chief inspector;\n- (c) lodging a document.\n- (a) electronically using the online system provided for the purpose and accessible from a Queensland Government website; or\n- (b) if the department’s website states a postal address or facsimile number for making a particular type of application or submission, or giving or lodging a particular type of document—by sending it to the stated address or number.","sortOrder":97},{"sectionNumber":"pt.9","sectionType":"part","heading":"Transitional provision for SL No. 162 of 2017","content":"# Transitional provision for SL No. 162 of 2017","sortOrder":98},{"sectionNumber":"sec.75","sectionType":"section","heading":"Notice or report given under repealed provision","content":"### sec.75 Notice or report given under repealed provision\n\nA person is taken to have given or lodged a document mentioned in the following table, column 1, under the relevant provision of this regulation if, before the commencement, the person gave or lodged the document under the relevant repealed or expired provision.\nColumn 1\nDocument\nColumn 2\nProvision of this regulation\nColumn 3\nRepealed or expired provision\na copy of a notice to the owner or occupier of land\nsection 28\nP&G Regulation , section 30A\nPetroleum Regulation , section 15A\na notice about intention to drill a petroleum well or bore\nsection 29\nP&G Regulation , section 31\nPetroleum Regulation , section 16\na notice about completion, alteration or abandonment of petroleum well or bore\nsection 30\nP&G Regulation , section 32\nPetroleum Regulation , section 17\na notice about intention to carry out survey\nsection 31\nP&G Regulation , section 33\nPetroleum Regulation , section 18\na notice about completion of survey\nsection 32\nP&G Regulation , section 34\nPetroleum Regulation , section 19\na notice about intention to carry out hydraulic fracturing activities\nsection 33\nP&G Regulation , section 35\nPetroleum Regulation , section 20\na notice about completion of hydraulic fracturing activities\nsection 34\nP&G Regulation , section 35A\nPetroleum Regulation , section 20A\na daily drilling report\nsection 35\nP&G Regulation , section 36\nPetroleum Regulation , section 21\na petroleum well or bore completion report\nsection 36\nP&G Regulation , section 37\nPetroleum Regulation , section 22\na petroleum well or bore abandonment report\nsection 37\nP&G Regulation , section 38\nPetroleum Regulation , section 23\na seismic survey report\nsection 38\nP&G Regulation , section 39\nPetroleum Regulation , section 24\na scientific or technical survey report\nsection 39\nP&G Regulation , section 40\nPetroleum Regulation , section 25\na petroleum production report for a 6-month period\nsection 42\nP&G Regulation , section 43\nPetroleum Regulation , section 28\na petroleum reserves report for a 6-month period\nsection 43\nP&G Regulation , section 44\nPetroleum Regulation , section 29\na production testing report for a relevant testing period\nsection 44\nP&G Regulation , section 45\nPetroleum Regulation , section 30\na hydraulic fracturing activities completion report\nsection 45\nP&G Regulation , section 46A\nPetroleum Regulation , section 30A\nIn this section—\nP&G Regulation means the Petroleum and Gas (Production and Safety) Regulation 2004 as in force before the commencement.\nPetroleum Regulation means the expired Petroleum Regulation 2004 .\nrelevant provision of this regulation , for a document mentioned in the table in subsection (1), means the provision of this regulation stated in column 2 opposite the document in the table.\nrelevant repealed or expired provision , for a document mentioned in the table in subsection (1), means a provision of the Petroleum and Gas Regulation or Petroleum Regulation stated in column 3 opposite the document in the table.\n(sec.75-ssec.1) A person is taken to have given or lodged a document mentioned in the following table, column 1, under the relevant provision of this regulation if, before the commencement, the person gave or lodged the document under the relevant repealed or expired provision. Column 1 Document Column 2 Provision of this regulation Column 3 Repealed or expired provision a copy of a notice to the owner or occupier of land section 28 P&G Regulation , section 30A Petroleum Regulation , section 15A a notice about intention to drill a petroleum well or bore section 29 P&G Regulation , section 31 Petroleum Regulation , section 16 a notice about completion, alteration or abandonment of petroleum well or bore section 30 P&G Regulation , section 32 Petroleum Regulation , section 17 a notice about intention to carry out survey section 31 P&G Regulation , section 33 Petroleum Regulation , section 18 a notice about completion of survey section 32 P&G Regulation , section 34 Petroleum Regulation , section 19 a notice about intention to carry out hydraulic fracturing activities section 33 P&G Regulation , section 35 Petroleum Regulation , section 20 a notice about completion of hydraulic fracturing activities section 34 P&G Regulation , section 35A Petroleum Regulation , section 20A a daily drilling report section 35 P&G Regulation , section 36 Petroleum Regulation , section 21 a petroleum well or bore completion report section 36 P&G Regulation , section 37 Petroleum Regulation , section 22 a petroleum well or bore abandonment report section 37 P&G Regulation , section 38 Petroleum Regulation , section 23 a seismic survey report section 38 P&G Regulation , section 39 Petroleum Regulation , section 24 a scientific or technical survey report section 39 P&G Regulation , section 40 Petroleum Regulation , section 25 a petroleum production report for a 6-month period section 42 P&G Regulation , section 43 Petroleum Regulation , section 28 a petroleum reserves report for a 6-month period section 43 P&G Regulation , section 44 Petroleum Regulation , section 29 a production testing report for a relevant testing period section 44 P&G Regulation , section 45 Petroleum Regulation , section 30 a hydraulic fracturing activities completion report section 45 P&G Regulation , section 46A Petroleum Regulation , section 30A\n(sec.75-ssec.2) In this section— P&G Regulation means the Petroleum and Gas (Production and Safety) Regulation 2004 as in force before the commencement. Petroleum Regulation means the expired Petroleum Regulation 2004 . relevant provision of this regulation , for a document mentioned in the table in subsection (1), means the provision of this regulation stated in column 2 opposite the document in the table. relevant repealed or expired provision , for a document mentioned in the table in subsection (1), means a provision of the Petroleum and Gas Regulation or Petroleum Regulation stated in column 3 opposite the document in the table.","sortOrder":99},{"sectionNumber":"pt.10","sectionType":"part","heading":"Transitional provisions for Petroleum and Gas (General Provisions) (Reporting Requirements) Amendment Regulation 2020","content":"# Transitional provisions for Petroleum and Gas (General Provisions) (Reporting Requirements) Amendment Regulation 2020","sortOrder":100},{"sectionNumber":"sec.76","sectionType":"section","heading":"Time for lodgement of reports","content":"### sec.76 Time for lodgement of reports\n\nThis section applies if a person would, other than for this section, be required to lodge a report under a relevant section on or after the commencement but before 30 June 2021.\nThe day the person is required to lodge the report under the relevant section is taken to be 30 June 2021.\nIn this section—\nrelevant section means section 21, 22, 23, 24, 26, 36, 37, 38, 39, 42, 43, 44 or 45.\ns 76 ins 2020 SL No. 208 s 26\n(sec.76-ssec.1) This section applies if a person would, other than for this section, be required to lodge a report under a relevant section on or after the commencement but before 30 June 2021.\n(sec.76-ssec.2) The day the person is required to lodge the report under the relevant section is taken to be 30 June 2021.\n(sec.76-ssec.3) In this section— relevant section means section 21, 22, 23, 24, 26, 36, 37, 38, 39, 42, 43, 44 or 45.","sortOrder":101},{"sectionNumber":"sec.77","sectionType":"section","heading":"Required information lodged before commencement","content":"### sec.77 Required information lodged before commencement\n\nThis section applies if—\nbefore the commencement, required information for a petroleum tenure was lodged under the 2004 Act or the 1923 Act ; and\non the commencement, the required information has not been publicly released under the 2004 Act , section 550 or the 1923 Act , section 76D .\nOn the commencement, schedule 1 as amended by the Petroleum and Gas (General Provisions) (Reporting Requirements) Amendment Regulation 2020 , applies in relation to the required information.\ns 77 ins 2020 SL No. 208 s 26\n(sec.77-ssec.1) This section applies if— before the commencement, required information for a petroleum tenure was lodged under the 2004 Act or the 1923 Act ; and on the commencement, the required information has not been publicly released under the 2004 Act , section 550 or the 1923 Act , section 76D .\n(sec.77-ssec.2) On the commencement, schedule 1 as amended by the Petroleum and Gas (General Provisions) (Reporting Requirements) Amendment Regulation 2020 , applies in relation to the required information.\n- (a) before the commencement, required information for a petroleum tenure was lodged under the 2004 Act or the 1923 Act ; and\n- (b) on the commencement, the required information has not been publicly released under the 2004 Act , section 550 or the 1923 Act , section 76D .","sortOrder":102},{"sectionNumber":"sch.2-pt.1","sectionType":"part","heading":"Petroleum tenure fees","content":"# Petroleum tenure fees","sortOrder":103},{"sectionNumber":"sch.2-pt.2","sectionType":"part","heading":"Data acquisition authority and water monitoring authority fees","content":"# Data acquisition authority and water monitoring authority fees","sortOrder":104},{"sectionNumber":"sch.2-pt.3","sectionType":"part","heading":"Transfer fees","content":"# Transfer fees","sortOrder":105},{"sectionNumber":"sch.2-pt.4","sectionType":"part","heading":"Survey licence, pipeline licence and petroleum facility licence fees","content":"# Survey licence, pipeline licence and petroleum facility licence fees","sortOrder":106},{"sectionNumber":"sch.2-pt.5","sectionType":"part","heading":"General petroleum authority fees","content":"# General petroleum authority fees","sortOrder":107},{"sectionNumber":"sch.3-pt.1","sectionType":"part","heading":"Petroleum tenure fees","content":"# Petroleum tenure fees","sortOrder":108},{"sectionNumber":"sch.3-pt.2","sectionType":"part","heading":"Transfer fees","content":"# Transfer fees","sortOrder":109},{"sectionNumber":"sch.3-pt.3","sectionType":"part","heading":"Other fees","content":"# Other fees","sortOrder":110},{"sectionNumber":"sch.4-pt.1","sectionType":"part","heading":"Annual rent","content":"# Annual rent","sortOrder":111},{"sectionNumber":"sch.4-pt.2","sectionType":"part","heading":"Storage rent","content":"# Storage rent","sortOrder":112}],"analysis":{"kimi_summary":{"_metrics":{"completionTokens":892},"content_quality":"ok","complexity_score":8,"scope_assessment":{"changed":true,"description":"The regulation has expanded significantly from its original 2017 scope. The 2021 amendments added carbon dioxide and renewable gases (biogas, biomethane) to petroleum definitions. The 2024 amendments added 'regulated hydrogen' substances including ammonia, methanol, and methyl-cyclohexane—materially expanding coverage beyond traditional petroleum to hydrogen economy fuels. Reporting requirements have also been progressively strengthened, particularly around hydraulic fracturing and water management."},"complexity_factors":["Dual statutory framework requiring cross-referencing between the 2004 Act and 1923 Act throughout","Extensive defined terms and measurement units (petajoules, terajoules, million cubic metres, API gravity, etc.)","Nested conditional logic with multiple exceptions (e.g., section 5 has four subsections with 'however' limitations)","Detailed technical specifications (e.g., section 36 requires 19+ specific data points for well completion reports)","Multiple amendment references showing evolving regulatory requirements (2020, 2021, 2022, 2024 amendments)","Cross-references to external standards (AS 4747-2013, PRMS 2018, Australian guidelines for coal resources)","Formula-based fee calculations with multiple variables (section 66A)","Schedule-dependent confidentiality periods with exceptions (section 52)","Temporal conditions and deadlines throughout (e.g., 'within 60 business days', 'at least 10 business days before')","Practice direction references that incorporate external documents not contained in the regulation itself"],"plain_english_summary":"This Queensland regulation sets out detailed administrative and technical rules for the petroleum and gas industry. It covers five main areas:\n\n**1. What counts as petroleum and fuel gas**\n- Expands the definition of \"petroleum\" to include biogas, biomethane, synthetic natural gas, and carbon dioxide (for specific purposes like pipeline surveying and reservoir storage testing)\n- Expands \"fuel gas\" to include synthetic methane (made from carbon dioxide) and other renewable gases\n- Adds \"regulated hydrogen\" substances including ammonia, methanol, and methyl-cyclohexane\n\n**2. Reporting requirements for exploration and production**\n- Companies must submit detailed work programs before exploring, and development plans before producing\n- Extensive reporting required for: drilling wells, completing wells, abandoning wells, seismic surveys, production testing, and hydraulic fracturing (\"fracking\")\n- Daily drilling reports must be kept with 18+ specific data points including depth, casing details, fluids used, and geological information\n- Production reports required every 6 months with volumes of gas, oil, water, and how they were used\n\n**3. Physical samples and records**\n- Companies must preserve rock cuttings (250-500g samples every 3-10 metres of drilling) and cores (at least 50% of material recovered)\n- Fluid samples over 10 litres must be kept if requested\n- Records must be kept for 7+ years\n\n**4. Water management**\n- Strict rules for measuring \"non-associated water\" (water extracted during petroleum operations that isn't part of the oil/gas reservoir)\n- Must use approved meters or vehicle-load counting, with alternative methods requiring approval\n- Reports due every 6 months on water volumes, sources, and uses\n\n**5. Fees, rents and metering**\n- Sets security deposits ($10,500-$35,000 depending on authority type)\n- Annual fees for pipeline licences calculated by a formula based on national energy market regulation costs\n- Metering tolerances: ±1.5% for small meters, ±1% for large meters measuring 100+ terajoules per year\n- Meters over 25 cubic metres/hour must be tested every 10 years\n\n**Who it affects:** Petroleum companies holding exploration authorities, production leases, pipeline licences, and related permits in Queensland; also landowners and water regulators who receive notices and reports.\n\n**Why it matters:** This is the operational rulebook that ensures petroleum activities are properly documented, environmental impacts tracked (especially water use and fracking), and the government can monitor resource extraction. The 2024 amendments added hydrogen-related substances, showing the regulation evolving for the energy transition."},"issue_detection":{"absurdities":[{"type":"retroactive_impossibility","section":"sec.5(ssec.4)(b)(i)(A)-(B)","severity":"medium","reasoning":"Section 5(4)(b) states the subsection (3) applies 'if' three conditions are met conjunctively: (i) testing is carried out within 2 years; (ii) the Minister approves the testing; and (iii) the holder complies with conditions of approval. However, conditions are only imposed upon approval, which may occur after testing has already started or concluded. A holder cannot comply with conditions that don't yet exist at the time testing begins, yet compliance is a prerequisite for the section to apply at all.","confidence":0.72,"description":"The 2-year testing period for ATP storage testing creates a temporal paradox: the Minister must decide to extend the period 'within the 2 years', but the provision also requires the Minister to approve the testing on the particular block. There is no requirement that approval precede the commencement of testing, creating the absurdity that testing could be carried out before it is approved, with approval being a condition of the provision applying retroactively."},{"type":"impossible_compliance","section":"sec.30(ssec.2)","severity":"medium","reasoning":"Section 30(2)(b) requires the relevant holder to 'intend no further drilling'. Intent is subjective and unverifiable. A tenure holder could argue drilling is never 'completed' while they retain any intention (however remote) to re-drill. This creates an exploitable gap that could indefinitely delay the notice obligation under s30(1)(a), which is triggered only upon completion as defined.","confidence":0.65,"description":"The definition of 'completed' drilling requires both a physical act (rig moved) AND a mental element (holder intends no further drilling). The mental element creates an impossible compliance scenario: a holder could indefinitely defer 'completion' by simply maintaining an intention to drill further, regardless of whether the rig has been removed, potentially evading the obligation to lodge notices under section 30."},{"type":"self_contradicting","section":"sec.36(ssec.7) read with sec.37","severity":"low","reasoning":"Section 37(1) limits its application to wells drilled 'under a petroleum tenure or water monitoring authority under the 2004 Act'. Section 36 applies to all petroleum tenures including 1923 Act tenures. Section 36(7) requires s37(4) information to be included in completion reports for all tenures, but s37's standalone abandonment report obligation does not apply to 1923 Act tenures. This creates an asymmetric regime where 1923 Act holders must include abandonment content in completion reports via s36(7) but face no separate abandonment report obligation under s37.","confidence":0.6,"description":"Section 36(7) states that if a well is plugged and abandoned on or before the rig release day, the completion report must also contain the information in section 37(4). However, section 37(2) only requires a separate abandonment report if plugging and abandoning occurs 'after' the rig release day. This creates an asymmetry where wells abandoned before rig release have their abandonment information subsumed into the completion report, but wells abandoned after rig release require a separate report with a 6-month deadline. This is not inherently absurd but creates a gap: section 37 explicitly applies only to the 2004 Act, while section 36 applies to all petroleum tenures, meaning the cross-reference in s36(7) to s37(4) content applies across both Acts but the standalone obligation in s37 only applies under the 2004 Act."},{"type":"other","section":"sec.41(ssec.2)(d) and sec.41(ssec.3)(b)","severity":"low","reasoning":"The regulation attempts to prescribe separate measurement units for volume/mass and energy, but for crude oil and condensate the 'energy' unit (MMBOE) is derived from the volume unit (MMbbl) by applying a calorific conversion factor. While industry-standard, it means the two measurement categories collapse into the same underlying metric for this substance, undermining the conceptual distinction the section is trying to draw.","confidence":0.55,"description":"Crude oil or condensate is required to be measured by volume in 'million barrels' under s41(2)(d) AND by energy in 'million barrels of oil equivalent (MMBOE)' under s41(3)(b). MMBOE is a unit of energy equivalence, not a distinct energy unit, meaning the 'energy' measurement for crude oil is expressed in the same barrel-based metric as the volume measurement, effectively conflating volume and energy measurements for the same substance."},{"type":"impossible_compliance","section":"sec.35(ssec.1) and sec.35(ssec.2)","severity":"low","reasoning":"The obligation to lodge daily reports is contingent on lodging the completion report. If the completion report is never lodged (e.g. due to tenure expiry), the daily reports may never be lodged either. The regulation does not create a standalone obligation to lodge daily drilling reports independent of the completion report, despite s35(3) allowing the chief executive to request them.","confidence":0.58,"description":"Section 35(1) requires the holder to 'keep' a daily drilling report for each day drilling occurs. Section 35(2) requires a copy to be 'lodged' with the well completion report. However, section 36(2) requires the completion report to be lodged within 12 months of the rig release day. This means daily drilling reports kept during drilling must be retained and lodged up to 12 months later. If the tenure lapses or is surrendered before the completion report is lodged, there is no clear obligation on any party to lodge the daily drilling reports, creating a potential data loss scenario contrary to the regulation's evident purpose."},{"type":"other","section":"sec.29(ssec.3)","severity":"low","reasoning":"Technical well names are typically constructed from location codes, numerical sequences and letter suffixes. Applying a 'substantially the same' test without definition creates uncertainty about whether minor variations in alphanumeric well names satisfy or violate the requirement. Unlike with business names or trademarks, there is no body of law or interpretive guidance to resolve this for drilling identifiers.","confidence":0.5,"description":"The proposed identifying name for a petroleum well 'must not be the same, or substantially the same, as an identifying name for another well recorded in the register'. The concept of 'substantially the same' as applied to well names (which are typically alphanumeric identifiers) is undefined and potentially impossible to assess objectively, as there is no standard for what constitutes substantial similarity between technical identifiers such as 'Well-1A' and 'Well-1B'."}],"contradictions":[{"severity":"low","section_a":"sec.28(ssec.1)","section_b":"sec.27","confidence":0.55,"description":"Section 27 states that Division 3-4 prescribes notices and reports required under the 2004 Act s553(1)(b) and the 1923 Act s76G(1)(b) by holders of petroleum authorities and 1923 Act petroleum tenures respectively. Section 28(1) then requires the holder of a 'petroleum tenure' to give copies of notices to landowners and occupiers. However, 'petroleum tenure' under s4(3) includes both 2004 Act petroleum tenures and 1923 Act authorities/leases, while 'petroleum authority' under the 2004 Act is a broader concept that includes pipeline licences and petroleum facility licences. Section 28 imposes the landowner-notice obligation only on petroleum tenure holders, potentially excluding holders of pipeline licences or petroleum facility licences who may also be required to lodge notices under this division."},{"severity":"low","section_a":"sec.33(ssec.1)","section_b":"sec.14(e)","confidence":0.63,"description":"Section 14(e) requires a notice about ATP or PL production testing to include 'details of any stimulation to be carried out during the testing', with a note directing readers to sections 33 and 34 for notice requirements relating to hydraulic fracturing activities. Section 33(1) separately requires a notice to be lodged at least 10 business days before hydraulic fracturing activities start. This creates a situation where a single hydraulic fracturing event during production testing requires two separate pre-activity notices (one under s14, one under s33), but the timeframes are not coordinated. The s14 notice must be lodged before testing starts while the s33 notice must be lodged at least 10 business days before the fracturing starts, which may be mid-testing, creating potential duplication and inconsistency between the two notices."},{"severity":"low","section_a":"sec.36(ssec.2)","section_b":"sec.37(ssec.3)","confidence":0.6,"description":"Section 36(2) requires the petroleum well or bore completion report to be lodged within 12 months of the rig release day. Section 37(3) requires the abandonment report (for wells abandoned after the rig release day) to be lodged within 6 months of the plugging and abandonment being completed. If a well is abandoned shortly after the rig release day, the abandonment report (due within 6 months of abandonment) could fall due before the completion report (due within 12 months of rig release). Section 36(7) requires the completion report to include the s37(4) abandonment information if the well is abandoned on or before rig release, but there is no provision coordinating the two report deadlines where abandonment occurs after rig release but the abandonment report deadline falls earlier than the completion report deadline."},{"severity":"low","section_a":"sec.21(ssec.1)(a)","section_b":"sec.21(ssec.1)(b)","confidence":0.48,"description":"Section 21(1)(a) prescribes the section as providing 'other information' for a relinquishment report for an authority to prospect under both the 2004 Act s545(b) and the 1923 Act s75Z(b). Section 21(1)(b) prescribes it as providing 'information' (not 'other information') for a surrender report for an authority to prospect under the 1923 Act s21(4)(b)(ii). The asymmetry between 'other information' and 'information' reflects the structure of the parent Acts, but within this regulation the same section 21(2) list of information items applies to both relinquishment and surrender reports without distinction, potentially requiring information under (b) that duplicates what the parent Act already requires under its primary provisions for surrender reports."},{"severity":"medium","section_a":"sec.6(ssec.1)(c)","section_b":"sec.5(ssec.1)(c)","confidence":0.7,"description":"Section 5(1)(c) prescribes 'a substance that is a mixture of LPG and air, known as synthetic natural gas' as petroleum for limited purposes under the 2004 Act. Section 6(1)(d) prescribes the same substance as a fuel gas under the 2004 Act s11(2)(d). Section 6(1)(c) additionally prescribes 'synthetic methane' as a fuel gas. The overlap between synthetic natural gas (prescribed as both petroleum and fuel gas) could create regulatory uncertainty about which regime applies to holders dealing with that substance, particularly given that s5(2) limits the petroleum prescription to specific chapters while the fuel gas prescription under s6 carries no equivalent limitation."}]},"flash_summary_failed":{"failed":true,"reason":"A positive credit balance is required for all requests, including BYOK, so fallback providers remain available. Add credits at https://vercel.com/d?to=%2F%5Bteam%5D%2F%7E%2Fai%3Fmodal%3Dtop-up to continue.","source":"analysis-cron"},"flash_summary":{"complexity_score":7,"scope_assessment":{"changed":true,"description":"Since first framed, the regulation has been extended and amended to cover new substances, additional technical reporting and measurement detail, and new fee mechanisms. Notable scope extensions include: prescriptive treatment of synthetic gases and a class of hydrogen carrier substances (secs 5, 6, 6A), detailed hydraulic fracturing reporting and fluid disclosure obligations (secs 33–45), expanded metering and accuracy regimes for large gas flows (secs 58–61), and a new pipeline licence annual fee formula tying part of the fee to State funding commitments to national energy market regulation (sec 66A). The regulation also increases data transparency through publication rules and revised confidentiality periods (secs 52–53). These changes broadened the regulation from procedural reporting and safety matters to include modern fuel types, detailed environmental/operational disclosure requirements and allocation of market‑regulation costs to licence holders."},"complexity_factors":["Wide scope with many report types and timings (sections 29–46, 38–45, 42–45)","Numerous cross-references to 2004 Act and 1923 Act throughout, requiring reading of primary Acts to interpret effect","Multiple defined terms and a dictionary in schedule 5 (sec 3) referenced across provisions","Nested conditional rules and exceptions (examples: sec 5 limited application for carbon dioxide; sec 50 cores exception for coal seam gas)","Technical standards and external references (AS 4747‑2013, PRMS/SPE Code) create technical complexity (secs 55, 43)","Measurement and metering rules with tiered requirements by volume and different checking intervals (secs 58–61)","Confidentiality periods and publication methods set in schedules with exceptions (secs 52–53 and schedule 1)","Financial provisions with formulas and external bodies (pipeline fee formula referencing MCE and AEMC — sec 66A)","Multiple transitional and consequential amendment provisions (secs 75–77)","Discretionary approvals and practice directions referenced repeatedly, adding administrative complexity and implementation variability (secs 5(3), 55(3), 57, multiple practice direction references)"],"plain_english_summary":"**What this regulation does (mechanically)**\n\n- Sets detailed administrative and technical rules that apply to petroleum and gas activities in Queensland under the Petroleum and Gas (Production and Safety) Act 2004 and the Petroleum Act 1923. It does not create primary rights or licences itself; it prescribes what licence/tenure holders must do to comply with those Acts.\n\n- Prescribes what counts as ‘‘petroleum’’, ‘‘fuel gas’’ and certain other transported or stored substances (including prescribed synthetic gases and—recently—certain hydrogen carrier substances) for purposes of the 2004 Act (see sections 5, 6 and 6A).\n\n- Specifies notification and reporting obligations for tenure and licence holders: pre‑drill notices, survey notices, testing notices, completion and abandonment reports for wells and bores, seismic and scientific survey reports, production and reserves reports, hydraulic fracturing notifications and detailed hydraulic fracturing completion reports, and many other prescribed reports and data lodgements (see sections 29–46, 38–45). Timing and formats (digital/approved forms) are set out for each report.\n\n- Prescribes how samples (cuttings, cores, fluid samples) must be kept, the size/label/storage requirements and how long they must be retained (see sections 48–51).\n\n- Sets rules for measurement and metering: how to measure non‑associated water taken (meter standard AS 4747‑2013 or approved alternative), metering accuracy tolerances, checks intervals, requirements for flow computers or temperature/pressure correction for large‑volume gas meters, and meter replacement/testing cycles (see sections 55–61).\n\n- Establishes confidentiality periods for specific classes of required information and how the chief executive may publish required information (see sections 52–53 and relevant schedules).\n\n- Prescribes financial rules: what fees and rents apply, annual rent amounts, a formula for an annual fee for pipeline licence holders that allocates part of the State’s funding for national energy market regulation (see sections 64–66A and schedules), payment dates and accepted payment methods, security (financial guarantee) forms and amounts, and a prescribed interest rate for amounts owing to the State (see sections 67–72).\n\n- Provides administrative details about how to make applications, lodge documents and transitional rules for earlier versions of the regulations (see sections 74–77, 75).\n\n\n**Who is principally affected**\n\n- Holders of petroleum tenures and licences (authorities to prospect, petroleum leases, pipeline licences, petroleum facility licences, data acquisition authorities, water monitoring authorities).\n- Contractors and operators who carry out activities (drillers, hydraulic fracturing contractors) because reports must identify contractors and the operator (see section 34, 45).\n- Owners and occupiers of land where authorised activities occur (entitled to a copy of notices — section 28).\n- State regulators: the chief executive and the Minister, who have approval and publication powers, and responsibility to review alternative measurement methods (see sections 55–57, 52–53).\n- Entities using or storing petroleum or prescribed storage gases (storage rent and reporting — sections 66, 70).\n\n\n**Why it matters (practical effects and what behaviour it changes)**\n\n- Increases administrative, technical and record‑keeping demands on industry. Licence/tenure holders must provide frequent, structured information (drilling daily reports, completion and abandonment reports, production and reserves data, hydraulic fracturing disclosures), keep samples to specific standards, and maintain metering to prescribed accuracy and checking intervals (e.g. sections 35–37, 42–45, 48–51, 58–61). Those are direct compliance costs (staff time, data systems, storage, testing and calibration equipment).\n\n- Raises transparency of exploration, production and hydraulic fracturing activities by prescribing reporting content and publication mechanisms, and by limiting confidentiality periods for certain data (sections 52–53). That can reduce the exclusivity of commercial geological information held by companies.\n\n- Imposes technical controls that affect capital decisions: meters must meet accuracy tolerances, be fitted with flow computers or correcting devices for large volumes, and be tested or replaced on mandated cycles (sections 58–61). Companies will need to budget for metering hardware, calibration and verification services.\n\n- Allocates some regulatory costs to industry: pipeline licence holders may pay an annual fee calculated as their share of the State’s commitment to national energy market regulation (section 66A). Annual fees, rents and securities (section 71) are also prescribed and must be paid by certain dates (sections 67–70).\n\n- Gives regulatory discretion to the chief executive and the Minister (approvals of alternative measurement methods, approval of carbon dioxide testing on particular blocks, decisions about publication and practice directions). That discretion creates implementation risk and variability in compliance expectations (see sections 5(3), 55(3), 57, 53).\n\n\n**Costs, incentives and trade‑offs**\n\n- Who pays: licence and tenure holders bear most direct costs — monitoring and metering upgrades, sample storage and handling, staff to prepare and lodge reports, fees/rents and security deposits (see sections 35–51, 64–71). The State bears the administrative cost to process, store and (where applicable) publish the data.\n\n- Concentrated benefits vs diffuse costs: some regulatory features (e.g. publication of seismic and reservoir data) redistribute private information from individual firms to public or other market participants (sections 38, 39, 43). Benefits from data reuse (planning, safety, research) are diffuse; compliance costs are concentrated on producing companies.\n\n- Compliance burden and operational constraints: frequent reports with technical detail (daily drilling reports, hydraulic fracturing completion reports and fluid composition statements) create ongoing operational reporting obligations and a need for high‑quality recordkeeping systems (sections 35, 45). Failure to provide specified items can attract penalties (e.g. 20 penalty units for failing to supply hydraulic fracturing fluid statement—section 45(4)).\n\n- Regulatory approval and review functions (chief executive and Minister) introduce gatekeeping steps that can delay or condition activities (e.g. approval of alternative measurement methods, Minister’s approval for certain CO2 testing — sections 55(3), 5(3)). Those approvals can be used to ensure technical quality but add time and uncertainty.\n\n- Data confidentiality: prescribed confidentiality periods balance commercial protection against public disclosure. Certain abandonment reports are exempted from confidentiality when coal or oil shale mining tenement holders need access for safety reasons (section 52). That reduces withholding of safety‑relevant information to third parties with operational need.\n\n\n**Implementation and compliance risks**\n\n- Much of the regulation refers applicants/holders to ‘‘the practice direction’’ or approved digital forms. Those instruments are administratively controlled by the department and create ongoing compliance dependencies (multiple provisions refer to practice directions and approved forms).\n\n- Alternatives to standard measurement methods require approval and are subject to review; if the chief executive withdraws approval, operators must change methods for the next reporting period (sections 55–57). This creates operational risk for firms using novel measurement approaches.\n\n- The chief executive and Minister retain significant discretionary powers (approvals, publication, review), which can create variability in how the rules are applied across tenures and sites (sections 5(3), 53, 55(3), 57).\n\n\n**Key concrete provisions to note**\n\n- Prescribed substances: sec 5 (biogas, biomethane, synthetic natural gas) and sec 6 (fuel gas, synthetic methane), and sec 6A (regulated hydrogen carrier substances such as ammonia, methanol and others).\n- Extensive hydraulic fracturing reporting: pre‑notice (sec 33), completion notice (sec 34) and detailed completion report with fluid composition statement and a penalty for non‑compliance (sec 45).\n- Metering and measurement: AS standard for water meters, acceptable alternatives subject to approval (sec 55); metering accuracy, checking intervals and flow computer or temperature/pressure correction requirements for large volumes (secs 58–61).\n- Data publication and confidentiality: confidentiality periods set in schedule 1 and publication methods in sec 53; exceptions for coal and oil shale mining tenement holders (sec 52).\n- Financial regime: fee and rent schedules, security forms/amounts (sec 71), formula for pipeline licence annual fee tied to State funding commitments to energy market regulation (sec 66A), and a prescribed 15% interest rate on amounts owing to the State (sec 72).\n\n\n**Bottom line**\n\nThis regulation operationalises how petroleum and gas tenure and licence holders must measure, report, retain samples, pay fees, and meet metering standards in Queensland. It increases technical and administrative compliance requirements (detailed reports, metering accuracy, sample retention), sets publication/confidentiality rules for much of the data, and allocates certain regulatory costs to industry through fees, rents and security. Many obligations are technical and recurring; companies should budget for measurement hardware, data management systems and qualified personnel, and expect regulatory approvals and practice directions to shape ongoing compliance.\n\n(References in parentheses indicate the principal sections used above.)"},"summary":{"complexity_score":8,"scope_assessment":{"changed":true,"description":"The regulation's scope has expanded beyond its original 2017 intent. Amendments in 2021 and 2024 added new categories of regulated substances including synthetic methane and a suite of hydrogen carrier substances (ammonia, dimethyl-ether, methanol, methyl-cyclohexane, toluene), reflecting the emerging hydrogen economy. This extends the regulatory framework into energy transition technologies that were not part of the original petroleum regulation context, broadening scope from conventional petroleum and gas operations to encompass emerging clean energy carriers and carbon capture and storage activities."},"complexity_factors":["Operates across two separate legislative frameworks simultaneously (the 2004 Act and the 1923 Act), requiring constant cross-referencing between instruments","Deeply technical subject matter requiring specialist knowledge of petroleum geology, drilling operations, hydrogeology, and chemical processes","Extensive and granular reporting obligations with different timeframes, formats, and content requirements for each type of report or notice","Multiple defined terms that reference other defined terms, creating chains of definition that are difficult to navigate without reading the entire instrument","Intersects with multiple other regulatory regimes (Water Act, Coal Mining Safety and Health Act, pipeline licensing) creating overlapping obligations","Expanding definitions of 'petroleum' and related substances to cover emerging energy technologies (biogas, hydrogen carriers, synthetic methane, CO₂ storage) adds interpretive uncertainty","Conditional provisions — particularly around carbon dioxide and storage testing — with time limits, Ministerial discretions, and layered approval requirements","Different rules apply depending on the type of tenure, the type of activity, and the stage of the activity lifecycle, requiring careful identification of which obligations apply in each situation","Has been amended multiple times since 2017, meaning readers must track amendments to understand current obligations"],"plain_english_summary":"The regulation sets out practical rules for exploring, producing and transporting petroleum in Queensland, affecting licence-holders, pipeline operators, landowners and regulators. It specifies detailed notice, data‑reporting and safety obligations for petroleum activities and expands legal definitions to include modern gases and hydrogen carrier substances.\n\nWhy it matters: the rules create transparency and accountability for resource use, protect groundwater and mining safety, ensure landowners are informed, and bring regulatory detail up to date with emerging low‑carbon fuels."}},"importantCases":[],"_links":{"self":"/api/acts/petroleum-and-gas-general-provisions-regulation-2017","history":"/api/acts/petroleum-and-gas-general-provisions-regulation-2017/history","analysis":"/api/acts/petroleum-and-gas-general-provisions-regulation-2017/analysis","conflicts":"/api/acts/petroleum-and-gas-general-provisions-regulation-2017/conflicts","importantCases":"/api/acts/petroleum-and-gas-general-provisions-regulation-2017/important-cases","documents":"/api/acts/petroleum-and-gas-general-provisions-regulation-2017/documents"}}