Petroleum Regulations 2021

Part 1—Preliminary matters

1 Objectives

The objectives of these Regulations are—

(a) to provide for the elimination and minimisation, so far as is reasonably practicable, of hazards and risks to the environment, public amenity and public safety involved in undertaking petroleum operations over the life of those operations; and

(b) to provide for the elimination and minimisation, so far as is reasonably practicable, of impacts from petroleum operations on local communities; and

(c) to ensure effective engagement by authority holders with the community over the life of an authority; and

(d) to provide for the effective management of petroleum reservoirs and petroleum storage reservoirs; and

(e) to prescribe requirements for operation plans, storage development plans and petroleum production development plans; and

(f) to prescribe requirements for applications for, and notices of applications for, an authority; and

(g) to prescribe reporting requirements, including the information and samples, that an authority holder must provide to the Minister; and

(h) to provide for various administrative matters, fees and other requirements of the Act.

2 Authorising provision

These Regulations are made under section 252 of the Petroleum Act 1998.

3 Commencement

These Regulations come into operation on 22 November 2021.

4 Revocation

The Petroleum Interim Regulations 2021[1] are revoked.

5 Definitions

In these Regulations—

ancillary equipment, in relation to a well, includes—

(a) equipment located downhole; and

(b) pressure control equipment; and

(c) a well-head;

authority number means the unique identification number designated by the Minister for an authority;

environmental legislation means an Act of the State or the Commonwealth or any instrument made or issued under or for the purpose of those Acts that relates to the protection of the environment;

facility means a structure that—

(a) is used or constructed for the purpose of recovering or storing petroleum; or

(b) is used or constructed for the purpose of monitoring impacts from production or storage wells; or

(c) carries, contains or includes—

(i) equipment for the drilling, modification, maintenance or repair of a well or ancillary equipment; and

(ii) gas plants; and

(iii) compression plants; and

(iv) metering stations; and

(v) gathering lines; and

(vi) survey equipment;

hydrocarbon gas emissions means gaseous emissions from leaks, flaring or venting of hydrocarbons;

impact means a negative effect of a petroleum operation that is reasonably predictable at the time that the application for the authority under which the operation is carried out is made;

practicable, in relation to eliminating or minimising hazards and risks, means practicable having regard to—

(a) the severity of the hazard or risk; and

(b) the state of knowledge about the hazard or risk; and

(c) the availability and suitability of ways to eliminate or minimise that hazard or risk; and

(d) the cost of eliminating or minimising that hazard or risk;

relevant person or organisation means—

(a) in relation to an operation plan that is proposed to be varied—

(i) any person or organisation that may be affected by an activity carried out under the operation plan as proposed to be varied; and

(ii) any person or organisation that has interests that may be affected by an activity carried out under the operation plan as proposed to be varied; or

(b) in relation to any other operation plan—

(i) any person or organisation that may be affected by an activity carried out under the operation plan; and

(ii) any person or organisation that has interests that may be affected by an activity carried out under the operation plan;

rig release date, in relation to a well, means the date on which the drilling rig that was last used to drill the well is moved so that it is no longer above the well, if no further drilling of the well is to occur;

risk means the likelihood and consequence of a specific, undesired event occurring;

the Act means the Petroleum Act 1998;

well activity, in relation to a well, means an activity carried out during the life of the well;

well integrity, in relation to a well, means that the entire length of the well, for the life of the well—

(a) is under control, in accordance with an operation plan accepted under section 161 of the Act; and

(b) is able to contain reservoir fluid; and

(c) is not the subject of any unforeseen risks;

well integrity hazard means, for the life of the well, an event—

(a) that—

(i) may compromise the well integrity of a well; or

(ii) may cause loss of a well barrier control; and

(b) that may, if it occurred, cause harm or present a risk to individuals, public safety, public amenity, the environment or a petroleum reservoir.

Part 2—Exploration permits

6 Assessment of risks etc.

An application under section 20 of the Act must contain the following information in relation to the proposed work program submitted with the application over the life of the permit—

(a) the likely regional economic, social and environmental risks and impacts of the program;

(b) the likely regional benefits of the program relative to its likely risks and impacts;

(c) the extent to which these risks and impacts can be managed at the regional level and how the applicant proposes to do this.

7 Prescribed factors in relation to an application for an exploration permit

For the purposes of sections 20B(2)(c) and 21(2)(c) of the Act, the following are prescribed factors—

(a) the likely regional economic, social and environmental risks and impacts of the work program;

(b) the likely regional benefits of the work program relative to its likely risk and impacts;

(c) the extent to which these risks and impacts can be managed at the regional level and how the applicant proposes to do this.

Part 3—Retention leases

8 Assessment of risks etc.

(1) An application under section 38 of the Act must contain the following information in relation to the proposed work program submitted with the application over the life of the lease—

(a) the likely regional economic, social and environmental risks and impacts of the program;

(b) the likely regional benefits of the program relative to its likely risks and impacts;

(c) the extent to which these risks and impacts can be managed at the regional level and how the applicant proposes to do this.

(2) An application under section 38 of the Act must contain the following—

(a) the certificate of any insurance policy maintained by the applicant in accordance with section 171 of the Act in respect of the exploration permit held by the applicant;

(b) the adequacy, as at the date of the application, of that insurance to cover any expenses or liabilities arising from a petroleum operation carried out under the exploration permit held by the applicant;

(c) the amount of the rehabilitation bond obtained by the applicant in accordance with section 173 of the Act in respect of a petroleum operation carried out under the exploration permit held by the applicant;

(d) the sufficiency of the amount secured by a rehabilitation bond described in paragraph (c), as at the date of the application, to cover any costs of rehabilitation work necessary as a result of the relevant petroleum operation.

9 Prescribed factors in relation to an application for a retention lease

For the purposes of section 40(1)(e) of the Act, the following are prescribed factors—

(a) the likely regional economic, social and environmental risks and impacts of the work program;

(b) the likely regional benefits of the work program relative to its likely risks;

(c) the extent to which these risks and impacts can be managed at the regional level and how the applicant proposes to do this.

Part 4—Production licences

Division 1—Prescribed factors

10 Assessment of risks etc.

(1) An application under section 47 of the Act must contain the following information in relation to the proposed work program submitted with the application over the life of the licence—

(a) the likely regional economic, social and environmental risks and impacts of the program;

(b) the likely regional benefits of the program relative to its likely risks and impacts;

(c) the extent to which these risks and impacts can be managed at the regional level and how the applicant proposes to do this.

(2) An application under section 47 of the Act must contain the following—

(a) the certificate of any insurance policy maintained by the applicant in accordance with section 171 of the Act in respect of the exploration permit held by the applicant;

(b) the adequacy, as at the date of the application, of that insurance to cover any expenses or liabilities arising from a petroleum operation carried out under the exploration permit held by the applicant;

(c) the amount of the rehabilitation bond obtained by the applicant in accordance with section 173 of the Act in respect of a petroleum operation carried out under the exploration permit or retention lease held by the applicant;

(d) the sufficiency of the amount secured by a rehabilitation bond described in paragraph (c), as at the date of the application, to cover any costs of rehabilitation work necessary as a result of the relevant petroleum operation.

11 Prescribed factors—determining grant of application for a production licence

For the purposes of section 49(1)(d) of the Act, the following are prescribed factors—

(a) the likely regional economic, social and environmental risks and impacts of the proposed work program submitted with the application;

(b) the likely regional benefits of the work program relative to its likely risks;

(c) the extent to which these risks and impacts can be managed at the regional level and how the applicant proposes to do this.

12 Prescribed factors—granting of production licences following tender

For the purposes of sections 52(3) and 52A(3) of the Act, the following are prescribed factors—

(a) the likely regional economic, social and environmental risks and impacts of the proposed work program submitted with the application;

(b) the likely regional benefits of the work program relative to its likely risks;

(c) the extent to which these risks and impacts can be managed at the regional level and how the applicant proposes to do this.

Division 2—Petroleum production development plans

13 Matters to be included in petroleum production development plan

(1) For the purposes of section 63(2) of the Act, a petroleum production development plan must include

(a) a description of each stage of the petroleum operation, including equipment or facilities to be used; and

(b) a description of the relevant existing geological and reservoir data and interpretations of that data; and

(c) details of proposed further data acquisition and studies to enhance geological and reservoir understanding; and

(d) a reservoir management plan that

(i) describes how the reservoir will be produced; and

(ii) provides the reasons for adopting the proposed approach; and

(iii) estimates the future petroleum to be recovered from the reservoir; and

(iv) specifies the proposed rate of recovery of petroleum.

(2) The holder of the authority must ensure that the petroleum production development plan is reviewed within 12 months after initial petroleum production and then at intervals not exceeding one year.

(3) For the purposes of subregulation (1)(d)(iv), the proposed rate of recovery of petroleum may be expressed as a range.

14 Storage development plan

(1) For the purposes of section 68(2) of the Act, a storage development plan must include

(a) a description of each stage of the petroleum operation, including equipment or facilities to be used; and

(b) a description of the reservoir using geological data and interpretations of that data; and

(c) a reservoir management plan that

(i) estimates the recoverable petroleum reserve, owned by the Crown pursuant to section 13 of the Act located in the reservoir before the commencement of underground petroleum storage activities; and

(ii) evaluates the suitability of the reservoir and seal for storage purposes; and

(iii) specifies the proposed storage operating volume; and

(iv) specifies the proposed rates of injection and recovery of petroleum; and

(v) details the methods to monitor and verify containment of injected gas and the petroleum-water contact; and

(vi) provides information about how storage operations interact with storage operations at nearby petroleum fields; and

(d) a description of the measures to be used to ensure containment of the stored petroleum.

(2) The holder of the authority must ensure that the storage development plan is reviewed within 12 months after initial petroleum production and storage operations and then at intervals not exceeding one year.

15 Additional information

(1) If a petroleum production development plan or a storage development plan has been submitted by the holder of an authority for the purposes of section 64 or 69 of the Act, the Minister may, by notice in writing, require the holder to provide any additional information that the Minister considers to be relevant to the approval of the plan.

(2) The Minister may, by notice in writing, require the holder of an authority to submit a revised petroleum production development plan or a storage development plan incorporating the additional information referred to in subregulation (1).

Part 5—Provisions applying to authorities generally

Division 1—Applications

16 Other details in work program

(1) For the purposes of section 97(e) of the Act, a work program must contain details regarding how the authority holder intends to engage, over the term of the authority, with the community and, if relevant, traditional owner groups within the meaning of the Traditional Owner Settlement Act 2010.

(2) For the purposes of section 97(d) and (e) of the Act, a work program in relation to an exploration permit must set out the annual estimated expenditure for each year of the term of the permit, in the form of a table.

Division 2—Surrender or cancellation of authorities

17 Surrender of authority

For the purposes of section 111(2)(f) of the Act, the following are prescribed factors—

(a) that the requirements of any plan required under the Act or these Regulations have been met;

(b) that any reporting obligations under the Act or these Regulations have been met;

(c) that the relevant land in the authority area has been rehabilitated for the purposes of section 170 of the Act.

Division 3—Miscellaneous matters

18 Prescribed period for certain notices

For the purposes of sections 39A(2)(b) and 48A(2)(b) of the Act, the prescribed period is 21 days from the day on which the notice is published.

19 Prescribed information for certain notices

(1) For the purposes of sections 39A(2)(c) and 48A(2)(c) of the Act, the following is prescribed information—

(a) the proposed work program submitted with the application;

(b) the contact details of a representative of the Minister, for any queries about the application;

(c) the contact name, telephone number, address and email address of a representative of the applicant;

(d) the location at which a copy of the application can be inspected by members of the public within business hours;

(e) in the case of an application for a retention lease, a statement that subject to other statutory requirements being satisfied, the lease, if granted—

(i) will entitle the holder to retain rights to a petroleum discovery that is not commercially viable to develop; and

(ii) will entitle the holder to carry out further petroleum exploration and work incidental to that purpose; and

(iii) will not entitle the holder to undertake petroleum production;

(f) in the case of an application for a production licence, a statement that, subject to other statutory requirements being satisfied, the licence, if granted, will entitle the holder—

(i) to carry out petroleum production; and

(ii) to explore for petroleum; and

(iii) to do anything in the licence area that is necessary for, or incidental to, those purposes;

(g) a statement that further information is available on the Department's Internet site regarding the statutory requirements that the applicant must comply with before work is undertaken in the authority area, if the authority is granted;

(h) the Internet address of the Department at which the information set out in paragraph (g) can be accessed.

(2) A notice must be in a form approved by the Minister.

Part 6—Royalties and rent

20 Time of payment of royalties

(1) Subject to subregulation (5), for the purposes of section 154(2) of the Act, a royalty for a production licence must be paid—

(a) for each period of 6 months ending on 30 June and 31 December in each year; and

(b) within 30 days of the expiry of the period for which it is payable.

(2) Unless otherwise specified in a production licence, the royalty payment for the period must be accompanied by a copy of records of the quantity of petroleum extracted or recovered in that period from any well within the licence area as measured by an approved measuring device.

(3) For the purposes of section 179(b) of the Act, the holder of a production licence must retain a copy of records of petroleum extracted or recovered for inspection purposes for 5 years.

Note

Under section 179 of the Act, a person who contravenes this subregulation may be liable to a penalty not exceeding 60 penalty units.

(4) Subregulations (2) and (3) do not apply in relation to a well in any period in which the quantity of petroleum extracted or recovered from that well in that period was determined by the Minister in accordance with section 153(3) of the Act.

(5) The Minister, by notice in writing to the holder of the authority, may vary the period set out in subregulation (1) in respect of which royalties for a production licence are payable.

(6) In this regulation—

approved measuring device has the same meaning as in section 153 of the Act.

21 Rent for occupancy of Crown Land

(1) For the purposes of section 160(3) of the Act, the amount of rent payable is the current market value for occupying the land, having regard to the use of the land permitted by the authority, as determined by a valuer nominated by the valuer-general.

(2) The holder of the authority is liable for the costs incurred in obtaining the determination.

(3) The rent must be reviewed by a valuer nominated by the valuer-general at intervals not exceeding 3 years but not less than one year.

(4) Rent must be paid for each period of 6 months ending on 30 June and 31 December in each year and must be paid within 10 days of the commencement of the period for which the rent is payable.

(5) In this regulation—

valuer-general means the valuer-general referred to in section 3(1) of the Valuation of Land Act 1960.

Part 7—Conduct of operations etc.

Division 1—Operation plan

22 Content of operation plan

(1) For the purposes of section 161(1)(d) of the Act, an operation plan—

(a) must set out—

(i) a comprehensive description of the equipment and facilities to be used in the petroleum operation; and

(ii) a comprehensive description of the petroleum operation, including details of each of the proposed stages of the petroleum operation that must include, if appropriate, the following stages—

(A) construction;

(B) operation;

(C) decommissioning;

(D) rehabilitation; and

(iii) details of the proposed process to ensure that the Minister is notified prior to commencement of each stage of the petroleum operation; and

(iv) an environment management plan; and

(v) if the petroleum operation involves petroleum exploration, a statement of the activities referred to in section 7 of the Act that are proposed to be carried out; and

(vi) if the petroleum operation includes the making of a new well, carrying out activities on an existing well or decommissioning a well, a well operation management plan in accordance with Division 3; and

(b) must provide for—

(i) a review of the operation plan by the holder of the authority before the holder commences each stage of the petroleum operation; and

(ii) a review by the holder of the authority of the risks identified in the operation plan whenever there is a significant change in the risks that the petroleum operation may pose; and

(iii) a review of the operation plan by the holder of the authority at least once every 5 years; and

(iv) the submission of a report by the holder of the authority, within 7 days of each review being finalised, to the Minister setting out the findings of that review; and

(c) must include, in relation to any facility proposed to be used in connection with the petroleum operation—

(i) a map of the location of the facility, and

(ii) a description of the location; and

(iii) details of all the sites related to the petroleum operation (including, but not limited to, accommodation camps), the activities to be undertaken at those sites and their location on the map referred to in subparagraph (i); and

(iv) details of the proposed design, construction, installation and maintenance of the facility; and

(v) if the facility is to be modified, details of the proposed modifications; and

(vi) details of the proposals for the decommissioning of the facility.

(2) The details provided under subregulation (1)(a)(ii) must enable the Minister to assess whether the facility is adequate for the proposed petroleum operation.

(3) The operation plan must—

(a) be appropriate for the nature and scale of the activities to be carried out during the petroleum operation; and

(b) include a rehabilitation plan.

(4) If an operation plan has been submitted by the holder of an authority, the Minister may, by notice in writing, require the holder to provide any additional information that the Minister considers to be relevant to acceptance of the plan.

(5) The Minister may, by notice in writing, require the holder to submit a revised operation plan incorporating the additional information referred to in subregulation (4).

23 Notice of operation plan

For the purposes of section 161(1B)(c) of the Act, the following is prescribed information—

(a) the name and postal address of the holder of the authority;

(b) a contact name, telephone number and email address of a representative of the holder of the authority to which requests for further information may be made;

(c) the form in which written submissions must be made, and the physical address or email address to which any submission may be conveyed or submitted;

(d) the date on which the holder of the authority proposes to commence considering the submissions;

(e) a description of the petroleum operation;

(f) a summary of the environmental and social risks and impacts of the petroleum operation and the measures that will be adopted to mitigate those risks over the life of the petroleum operation;

(g) a summary of the public safety risks and impacts of the petroleum operation, including risks relating to any wells, and the measures that will be in place to mitigate those risks over the life of the petroleum operation;

(h) a summary of the proposed measures to rehabilitate land affected by the petroleum operation;

(i) a summary of how the authority holder proposes to ensure any relevant persons or organisations are consulted over the life of the petroleum operation.

24 Prescribed factors for accepting or varying an operation plan

(1) For the purposes of section 161(1D) of the Act, the following are prescribed factors—

(a) whether the Minister is satisfied that the holder of the authority will implement effective rehabilitation measures for the petroleum operation;

(b) whether the Minister is satisfied that the holder of the authority will consult effectively with any relevant persons or organisations over the life of the petroleum operation;

(c) whether the Minister is satisfied that the holder of the authority has identified the key risks and impacts of the petroleum operation;

(d) whether the Minister is satisfied that the risks and impacts of the petroleum operation will be adequately mitigated.

(2) For the purposes of section 163(3) of the Act, the Minister must take into account the following factors in considering an application to vary an operation plan—

(a) whether the Minister is satisfied that the holder of the authority will implement effective rehabilitation measures for the petroleum operation;

(b) whether the Minister is satisfied that the holder of the authority will consult effectively with any relevant persons or organisations over the life of the petroleum operation;

(c) whether the Minister is satisfied that the holder of the authority has identified the key risks and impacts of the petroleum operation;

(d) whether the Minister is satisfied that the risks and impacts of the petroleum operation will be adequately mitigated.

25 Prescribed form for evidence regarding notice and submissions for operation plan

(1) For the purposes of section 161(3)(a) of the Act, evidence regarding notice of an operation plan is in the prescribed form if it—

(a) is in writing (whether or not it is in electronic form); and

(b) contains a copy of the notice given by the holder of the authority under section 161(1A) of the Act; and

(c) contains a list of the relevant persons or organisations to whom the notice has been given.

(2) For the purposes of section 161(3)(b) of the Act, evidence regarding submissions on an operation plan is in the prescribed form if it—

(a) is in writing (whether or not it is in electronic form); and

(b) contains a copy of all submissions received or, if no submissions are received, a statement to this effect; and

(c) contains a summary of the submissions (if any) that sets out the substantive matters raised by the submissions, how each matter has been considered and, for each relevant matter, how it has been addressed in the operation plan.

26 Notice regarding variation to operation plan

For the purposes of section 163(5)(c) of the Act, the following is prescribed information—

(a) the name and postal address of the holder of the authority;

(b) a contact name, telephone number and email address of a representative of the holder of the authority to which requests for further information may be made;

(c) the form in which written submissions must be made, and the physical address or email address to which any submission may be conveyed or submitted;

(d) the date on which the holder of the authority proposes to commence considering the submissions;

(e) a description of the petroleum operation;

(f) a summary of the environmental and social risks and impacts of the petroleum operation and the measures that will be adopted to mitigate those risks over the life of the petroleum operation;

(g) a summary of the public safety risks and impacts of the petroleum operation, including risks relating to any wells, and the measures that will be in place to mitigate those risks over the life of the petroleum operation;

(h) a summary of the proposed measures to rehabilitate land affected by the petroleum operation;

(i) a summary of how the authority holder proposes to ensure any relevant persons or organisations are consulted over the life of the petroleum operation.

27 Prescribed form of evidence required to be submitted for the variation of an operation plan

(1) For the purposes of section 163(6)(a) of the Act, evidence is in the prescribed form if it—

(a) is in writing (whether or not it is in electronic form); and

(b) contains a copy of the notice given by the holder of the authority under section 163(4) of the Act; and

(c) contains a list of the relevant persons or organisations to whom the notice has been given.

(2) For the purposes of section 163(6)(b) of the Act, evidence is in the prescribed form if it—

(a) is in writing (whether or not it is in electronic form); and

(b) contains a copy of all submissions received or, if no submissions are received, a statement to this effect; and

(c) contains a summary of the submissions (if any) that sets out the substantive matters raised by the submissions, how each matter has been considered and, if relevant, how each matter has been addressed in the variation.

28 Consent to conduct production tests or well tests

(1) The holder of an authority must not conduct a production test or well test in a well except with, and in accordance with, the written consent of the Minister.

Penalty: 20 penalty units.

(2) An application for consent under subregulation (1) must include a plan setting out—

(a) the equipment to be used; and

(b) the timeframe for the testing; and

(c) how 2 verified well barriers will be maintained in the well at all times or, if this cannot be achieved, the alternative measures that will be in place to maintain well integrity; and

(d) the controls that will be in place to manage any potential well integrity hazards; and

(e) details regarding the suitably qualified or experienced person who designed the well testing; and

(f) details regarding the suitably qualified or experienced person who will be onsite to supervise the testing; and

(g) details of how any owner or occupier of the land on which the proposed test is to be conducted will be notified of the proposed test.

29 Consent to suspend or decommission a well

(1) The holder of an authority must ensure that a well is not suspended except with, and in accordance with, the written consent of the Minister.

Penalty: 20 penalty units.

(2) The holder of an authority must ensure that a well is not decommissioned except with, and in accordance with, the written consent of the Minister.

Penalty: 20 penalty units.

(3) An application for consent to suspend or decommission a well must include—

(a) the name and number of the well; and

(b) the reasons for the proposed suspension or decommissioning; and

(c) a plan setting out details of the proposed suspension or decommissioning program, including the method by which the well will be made safe after it is suspended or decommissioned.

(4) The plan under subregulation (3)(c) must set out—

(a) the authority holder's proposed measures for care and maintenance of the well, if proposed to be suspended; and

(b) the equipment to be used; and

(c) the timeframe for the suspension or decommissioning; and

(d) how 2 verified well barriers will be maintained in the well at all times or, if this cannot be achieved, the alternative measures that will be in place to maintain well integrity; and

(e) the controls that will be in place to manage any potential well integrity hazards; and

(f) the controls that will be in place to maintain well integrity while the well is suspended (including but not limited to the period in which suspension activity is occurring); and

(g) details of the suitably qualified or experienced person who will be responsible for designing the suspension or decommissioning of the well; and

(h) details of the suitably qualified or experienced person who will be responsible for supervising the suspension or decommissioning of the well; and

(i) details of how any owner or occupier of the land on which the well is located will be notified of the proposed suspension or decommissioning of that well.

Division 2—Environment management plan

30 Description of the environment

An environment management plan included in an operation plan under regulation 22(1)(a)(iv) must—

(a) describe the environment, including any relevant values and sensitivities; and

(b) describe any relevant cultural, historical, aesthetic, social, recreational, ecological, biological, landscape and economic aspects of the environment that may be affected by the petroleum operation; and

(c) identify any communities, land or property in the vicinity of the operation and any petroleum operation or petroleum resources that the petroleum operation might affect.

31 Description of environmental risks and impacts

An environment management plan must include an assessment of the environmental risks and impacts of the petroleum operation that—

(a) identifies and evaluates the environmental risks and impacts that may arise directly or indirectly from the normal activities of the petroleum operation (including construction if applicable); and

(b) assesses the environmental risks and impacts resulting from—

(i) reasonably possible activities in relation to the petroleum operation; and

(ii) incidents or events (whether planned or unplanned) that are not normal activities, incidents or events in relation to the operation including emergencies and foreseeable but unwanted events; and

(c) specifies the methodology used for the assessment.

32 Environmental performance objectives and standards

An environment management plan must—

(a) define environmental performance objectives, and set environmental performance standards, against which performance by the holder of the authority in protecting the environment from the petroleum operation is to be measured; and

(b) include measurement methods for determining whether the objectives and standards have been met.

33 Implementation strategy for the environment management plan

An environment management plan must contain an implementation strategy that—

(a) identifies the controls, specific systems, practices and procedures to be used to ensure that—

(i) any potential environmental risks and impacts arising from the petroleum operation are eliminated or minimised as far as is reasonably practicable; and

(ii) the environmental performance objectives and standards in the environment management plan are met; and

(b) specifies why the controls, specific systems, practices and procedures to eliminate or minimise risks and impacts have been adopted, whether other measures were considered but not adopted and the reasons why; and

(c) establishes a clear chain of command, setting out the roles and responsibilities of personnel in relation to the implementation, management and review of the environment management plan; and

(d) includes measures to ensure that each employee or contractor working in connection with the petroleum operation—

(i) is aware of the employee's or contractor's responsibilities in relation to the environment; and

(ii) has the appropriate skills and training to be able to fulfil those responsibilities; and

(e) provides for the monitoring, audit and review of the environmental performance and implementation strategy of the holder of the authority; and

(f) provides for the maintenance of a quantitative record of emissions and discharges into the air, or onto the land surface environment, or below the land surface environment that is accurate and that can be monitored and audited against the environmental performance standards; and

(g) includes arrangements for recording, monitoring and reporting information about the petroleum operation (including information required to be recorded under the Act, these Regulations and any other environmental legislation applying to the activity) sufficient to enable the Minister to determine whether the holder of the authority is complying with the environment management plan; and

(h) provides for appropriate consultation, ongoing for the life of the petroleum operation, about the authority holder's environmental performance with—

(i) relevant agencies of the Commonwealth and the State; and

(ii) other relevant persons or organisations; and

(i) provides for the maintenance of an up-to-date emergency response manual prepared for the petroleum operation that includes detailed response arrangements for—

(i) dealing with any threat to individuals, public safety, public amenity or the environment in the vicinity of the petroleum operation; and

(ii) ensuring that the threat does not harm individuals, public safety, public amenity or the environment; and

(iii) dealing with any unwanted event that occurs that is harming individuals, public safety, public amenity or the environment; and

(j) in relation to hydrocarbon gas emissions from the petroleum operation, includes—

(i) the measures in place to ensure any hydrocarbon gas emissions will be minimised as far as reasonably practicable; and

(ii) the measures in place to identify any hydrocarbon gas emissions as they occur; and

(iii) an estimate of the hydrocarbon gas emissions that will be generated by the petroleum operation; and

(k) in relation to any groundwater impacts of a well activity carried out during a petroleum operation—

(i) assesses the risks and impacts to the groundwater environment from the well activity; and

(ii) identifies how these risks and impacts to the groundwater environment will be mitigated; and

(iii) if the operation is a petroleum production operation—

(A) identifies the method by which the holder of the authority will establish the baseline water quality before petroleum production commences; and

(B) identifies the groundwater monitoring methodology, including the frequency of the monitoring and the parameters to be monitored prior to and during petroleum production; and

(C) identifies a reporting schedule for the holder of the authority to report to the Minister in relation to any monitoring identified in sub-subparagraph (B).

34 Other information in the environment management plan

The environment management plan must contain the following—

(a) a statement of the corporate environmental policy of the holder of the authority;

(b) a list of all environmental legislation of the Commonwealth or the State that may apply to the petroleum operation;

(c) the strategy of the holder of the authority to ensure compliance with the environmental legislation referred to in paragraph (b);

(d) details of how the holder of the authority will consult with any relevant persons or organisations during the petroleum operation.

35 Information on consultation with relevant persons or organisations

For the purposes of regulation 34(d), the environment management plan must—

(a) identify any relevant persons or organisations; and

(b) set out how the holder of the authority will share information with relevant persons or organisations; and

(c) set out how the holder of the authority will receive feedback from relevant persons or organisations; and

(d) set out how the holder of the authority will manage complaints and other communications from relevant persons or organisations; and

(e) set out how the holder of the authority will ensure that, while the operation plan is in effect, the holder of an authority will engage a suitably qualified or experienced person to be responsible for ensuring that the measures relating to consultation with relevant persons or organisations under the operation plan for the petroleum operation are implemented; and

(f) in the case of an environment management plan for a production licence, set out how the holder of the authority will—

(i) identify concerns and expectations of relevant persons or organisations; and

(ii) analyse feedback from relevant persons or organisations, taking into account those concerns or expectations.

Division 3—Well operation management plan

36 Well operation management plan

(1) The well operation management plan included in an operation plan under regulation 22(1)(a)(vi) must, in relation to each well to which it relates—

(a) contain the name and number of the well; and

(b) set out the elevation, easting and northing coordinates of the well and the basin and sub-basin (if applicable) in which the well is located; and

(c) describe each of the proposed stages of any well activity carried out during the petroleum operation including, if appropriate, the design, construction, operation, suspension, care, maintenance and decommissioning of the well; and

(d) be appropriate for the nature and scale of each well activity to be carried out under the operation plan; and

(e) include details of the design of the well and ancillary equipment, including details of how the well is to protect petroleum resources and aquifers; and

(f) set out the authority holder's proposed timetable for carrying out each well activity; and

(g) describe how the holder of the authority is to keep records and conduct inspections, including but not limited to leak detections, well-head inspections, well-head maintenance, workovers, and downhole inspections; and

(h) describe the process by which a connection is to be made between the well and a petroleum reservoir so that fluids can be produced from, or injected into, the reservoir; and

(i) include details of how modifications, maintenance and repairs to the well and ancillary equipment are to be managed; and

(j) include details of how any suspension or decommissioning of the well is to be managed, including specifications for all materials that are to be used to maintain well integrity, including but not limited to casings, tubing, mud, cement, and well‑heads; and

(k) describe the equipment and facilities to be used in connection with the well and ancillary equipment; and

(l) identify the risks associated with each well activity during each stage and state how the holder of the authority proposes to eliminate or minimise those risks as far as is reasonably practicable; and

(m) include details of when and how the holder of the authority is to give the Minister reports and information about—

(i) each well activity; and

(ii) any well integrity hazards; and

(iii) progression from one stage to another during the well operation; and

(iv) significant increases in existing risks in relation to the well; and

(v) other matters relevant to the conduct of each well activity; and

(n) demonstrate that the holder of the authority has a well integrity management system in place, or a process for managing well integrity during the life of the well that complies with relevant industry standards.

(2) The well operation management plan must include the following details, unless the Minister gives the holder of the authority written permission for any details specified in that permission not to be included—

(a) information about the conduct of each well activity;

(b) an explanation of the philosophy of and criteria for the design, construction, operational activity and management of the well and ancillary equipment;

(c) the possible petroleum production and storage activities of the well;

(d) details of—

(i) which logs will be run; and

(ii) how those logs will be run;

(e) proposals for testing of the well and ancillary equipment;

(f) proposed sampling and testing methods for petroleum;

(g) performance objectives against which the performance of each well activity is to be measured;

(h) measurement methods for determining whether the performance objectives have been met;

(i) the controls, systems, practices and procedures to be used to deal with—

(i) a well integrity hazard; and

(ii) a significant increase in an existing risk in relation to the well, including if an activity must continue to be carried out for the purpose of dealing with the risk; and

(iii) the protection of any aquifers;

(j) how the holder of the authority will ensure that the design of the well is verified by a person suitably qualified or experienced to verify the well design;

(k) the qualifications or experience of the person referred to in paragraph (j), and that person's work telephone number, email and postal address;

(l) how the holder of the authority will ensure that the construction of the well is supervised by a person suitably qualified or experienced to verify that the well construction—

(i) is completed in accordance with the design of the well; and

(ii) complies with any relevant requirements and standards;

(m) how the holder of the authority will ensure that the decommissioning of the well is supervised by a person suitably qualified or experienced to verify that the well decommissioning—

(i) is completed in accordance with the design of the well; and

(ii) complies with any relevant requirements and standards;

(n) details of how the holder of the authority will ensure well integrity;

(o) how the holder of the authority will ensure that any contractors or subcontractors involved in managing the operation of the well are suitably qualified or experienced;

(p) how the holder of the authority will, during the life of the well—

(i) maintain 2 verified well barriers at all times; and

(ii) keep records containing details of any well interventions, well-head maintenance activities, workovers and well testing.

(3) The holder of the authority must give the following details to the Minister at least 10 days before construction of the well commences—

(a) the qualifications or experience of the person referred to in subregulation (2)(l);

(b) the work telephone number, email address and postal address of the person referred to in subregulation (2)(l).

(4) The holder of the authority must give the following details to the Minister at least 10 days before the well is decommissioned—

(a) the qualifications or experience of the person referred to in subregulation (2)(m);

(b) the work telephone number, email address and postal address of the person referred to in subregulation (2)(m).

Division 4—Rehabilitation plans

37 Rehabilitation plan

(1) For the purposes of regulation 22(3)(b), a rehabilitation plan must include—

(a) details of the proposed rehabilitation of surface areas of land proposed to be affected by the petroleum operation including, but not limited to, facilities and accommodation camps; and

(b) proposed measures for revegetation of that land.

(2) A rehabilitation plan must—

(a) set out rehabilitation performance objectives and rehabilitation performance standards against which the authority holder's performance in rehabilitating the land is to be measured; and

(b) include measurement methods for determining whether those objectives and standards have been met.

Note

Under regulation 39(2)(g), the holder of an authority must give a report to the Minister in respect of each financial year that includes a summary of any rehabilitation undertaken on land on which a petroleum operation is carried out under the authority during that year.

Part 8—Information to be given to the Minister

Division 1—Notification of activities in respect of petroleum operation

38 Notifying start and end of petroleum operation

(1) For the purposes of section 179(c) of the Act, the holder of an authority must notify the Minister of the proposed commencement date of a petroleum operation carried out under the authority at least 10 days before the petroleum operation is to commence.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) For the purposes of section 179(c) of the Act, the holder of an authority must notify the Minister of the completion date of a petroleum operation carried out under the authority within 10 days after that completion.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

Division 2—Periodic reports

39 Annual report

(1) For the purposes of section 179(c) of the Act, the holder of an authority must give the Minister a report, in respect of each financial year, setting out—

(a) any petroleum operation carried out under the authority during that year; and

(b) any new petroleum reservoir detected from the petroleum operation identified in a manner that conforms with the prevailing industry standard if reasonably possible; and

(c) test results and conclusions derived from the petroleum operation; and

(d) reports and studies relating to the petroleum operation.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) A report under subregulation (1) must include—

(a) details of the expenditure by the holder of the authority on each petroleum operation undertaken during the year; and

(b) the date the report was completed; and

(c) an outline of progress against the work program; and

(d) an outline of the proposed work to be completed during the year following the year to which the report relates (if any), including the estimated costs to complete the proposed work and any anticipated change in risk; and

(e) the findings and outcomes of any review undertaken during the year in relation to the operation plan, petroleum production development plan or storage development plan (if applicable); and

(f) if the authority holder's expenses or liabilities, in relation to which insurance is required to be maintained under section 171 of the Act, have changed during the year, a summary of any changes including any reasons for those changes; and

(g) a summary of any rehabilitation undertaken on land on which the petroleum operation is carried out under the authority during that year; and

(h) if the estimated total costs for rehabilitating the land on which the petroleum operation is carried out have changed during the year, details of the current estimated costs for rehabilitating the land, including any reasons for the changes; and

(i) a summary of the outcomes of any monitoring activities undertaken during the year in accordance with the operation plan, including but not limited to groundwater monitoring; and

(j) a summary of any consultation with the community and relevant persons or organisations undertaken during the year, any issues identified through that consultation, and how those issues were addressed; and

(k) a summary of actions taken to monitor, measure, eliminate or minimise hydrocarbon gas emissions from petroleum operations as far as reasonably practicable.

(3) The holder of the authority must give a report under subregulation (1) to the Minister—

(a) within 60 days after the end of the financial year to which it relates; or

(b) if the authority ceased to have effect during a financial year, within 60 days after the authority ceased to have effect.

(4) The Minister may, on a request from the holder of the authority, extend the period for the submission of a report.

(5) If the Minister extends the period of time under subregulation (4), the holder of the authority must give the report to the Minister within the extended period of time.

(6) For the purposes of this regulation, a holder of an authority includes a person who was the holder of an authority in the financial year to which the report relates.

40 Report by holder of production licence

(1) For the purposes of section 179(c) of the Act, the holder of a production licence must, every 6 months, give to the Minister within 30 days of the end of that period a report of any petroleum production carried out under the licence.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) The report must include—

(a) details of the amount of hydrocarbons, water and other substances produced from, or injected into, each well in the licence area during the 6 month period to which the report relates; and

(b) details of petroleum reserves in the licence area, expressed in billion cubic feet, as assessed at the end of that 6 month period.

Division 3—Reports of certain activities

41 Requirement for weekly survey report

(1) For the purposes of section 179(c) of the Act, the holder of an authority who undertakes a geophysical, geological or geochemical survey in the authority area must give the Minister a weekly survey report as soon as reasonably practicable after the end of each week of the survey.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) A weekly survey report under subregulation (1) must include—

(a) the name of the survey; and

(b) the authority under which the survey is being conducted; and

(c) the name of the authority holder; and

(d) the name of the contractor conducting the survey; and

(e) the name and number of the vehicle or aircraft conducting the survey; and

(f) a map showing where the survey was conducted during the week; and

(g) the number of kilometres or square kilometres for which data was acquired during the week; and

(h) the number of points at which data was acquired during the week; and

(i) the number of lines of data acquired during the week; and

(j) the amount of downtime during the week due to equipment problems, bad weather or other circumstances; and

(k) the percentage of the survey completed at the end of the week.

(3) In this regulation—

week of the survey means—

(a) the week starting on the first day of data acquisition for the survey; and

(b) each subsequent week.

42 Requirement for survey acquisition report and data

(1) For the purposes of section 179(c) of the Act, the holder of an authority who undertakes a geophysical, geological or geochemical survey in the authority area must give the Minister a survey acquisition report and all survey acquisition data within—

(a) in the case of a 2-dimensional seismic survey—12 months after the day on which the acquisition of the data is completed; or

(b) in the case of a 3-dimensional seismic survey—18 months after the day on which the acquisition of the data is completed; or

(c) if the Minister authorises the holder of the authority to give the report and data within another period—that other period; or

(d) in any other case—6 months after the day on which the acquisition of the data is completed.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) A survey acquisition report under subregulation (1) must include—

(a) the name of the survey; and

(b) the authority under which the survey was conducted; and

(c) the name of the holder of the authority; and

(d) the name of the contractor that conducted the survey; and

(e) the name and number of the vehicle or aircraft that conducted the survey; and

(f) a map of where the survey was conducted; and

(g) the dates on which the survey started and ended; and

(h) details of all data acquisition equipment and systems used; and

(i) details of all positions and navigation equipment and systems used; and

(j) the number of lines of data acquired in the survey and the number of data acquisition points along each line; and

(k) navigation data for the survey, in the form of—

(i) in the case of a 2-dimensional survey—line ends and bends; or

(ii) in the case of a 3-dimensional seismic survey—a full fold polygon outline; or

(iii) in the case of any other 3-dimensional survey—a polygon outline; and

(l) the geometry of the acquisition parameters; and

(m) the results of any onboard data processing; and

(n) the results of any system tests, calibrations or diagnostics.

(3) In this regulation—

survey acquisition data means each of the following types of data in a form approved by the Minister—

(a) in the case of a seismic survey—

(i) raw navigation data; and

(ii) seismic field data; and

(iii) seismic support data; and

(iv) an itemised field tape listing showing—

(A) tape number; and

(B) survey name; and

(C) line number; and

(D) shotpoint range; and

(E) data type;

(b) field data;

(c) field support and navigation data.

43 Requirement for survey processing report and data

(1) For the purposes of section 179(c) of the Act, the holder of an authority who undertakes a geophysical, geological or geochemical survey in the authority area must give the Minister a survey processing report and all processed survey data within—

(a) in the case of a 2-dimensional seismic survey—12 months after the day on which the acquisition of the data is completed; or

(b) in the case of a 3-dimensional seismic survey—18 months after the day on which the acquisition of the data is completed; or

(c) if the Minister authorises the holder of the authority to give the report and data within another period—that other period; or

(d) in any other case—6 months after the day on which the acquisition of the data is completed.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) A survey processing report under subregulation (1) must include—

(a) the name of the survey; and

(b) the authority under which the survey was conducted; and

(c) the name of the holder of the authority; and

(d) the dates on which processing of the survey started and ended; and

(e) the name of the processing contractor; and

(f) the purpose of the processing; and

(g) a summary of the data acquisition parameters; and

(h) details of all the processing sequences and techniques used; and

(i) a sample Extended Binary Coded Decimal Interchange Code header from the final data set; and

(j) listings of all processed data; and

(k) in the case of a 3-dimensional survey—

(i) a description of the position of the survey polygon; and

(ii) a calculation for the 3-dimensional line numbering convention.

(3) A survey processing report under subregulation (1) must—

(a) be in the form approved by the Minister; and

(b) in the case of a 2-dimensional seismic survey—include each type of the following data—

(i) raw and final stacked data, including near, mid and far sub stacks if generated;

(ii) raw and final migrated data, including—

(A) pre-stack time migration; and

(B) pre-stack depth migration; and

(C) near, mid and far sub stacks;

(iii) final processed navigation and elevation data;

(iv) shotpoint to common depth point relationship;

(v) data for both stacked and migrated velocities, including—

(A) line number; and

(B) shotpoint; and

(C) time versus root mean square pairs;

(vi) an itemised process tape listing showing—

(A) tape number; and

(B) survey name; and

(C) line number; and

(D) shotpoint range; and

(E) common depth points; and

(F) data type; and

(c) in the case of a 3-dimensional seismic survey—include each type of the following data—

(i) raw and final stacked data, including near, mid and far sub stacks if generated;

(ii) raw and final migrated data, including—

(A) pre-stack time migration; and

(B) pre-stack depth migration; and

(C) near, mid and far sub stacks;

(iii) final processed navigation, elevation and bathymetry data;

(iv) final navigation data in the form of—

(A) final processed grid bin coordinates; and

(B) polygonal position data, being an outline of the full fold area;

(v) data for both stacked and migrated velocities, including—

(A) bin number; and

(B) time versus root mean square pairs;

(vi) 2D data subset, if production is required as a condition of the grant of an authority;

(vii) an itemised process tape listing showing—

(A) tape number; and

(B) survey name; and

(C) in-lines and crosslines; and

(D) data type; and

(d) in the case of any other survey—include each type of the following data—

(i) final processed data;

(ii) final processed images;

(iii) final geological or geochemical survey analysis data.

44 Requirement for survey interpretation report and data

(1) For the purposes of section 179(c) of the Act, the holder of an authority who undertakes a geophysical, geological or geochemical survey in the authority area must give the Minister a survey interpretation report and interpretative survey data within—

(a) in the case of a seismic survey—18 months after the day on which the acquisition of the data is completed; or

(b) in the case of any other type of survey—12 months after the day on which the acquisition of the data is completed; or

(c) if the Minister authorises the holder of the authority to give the report and data within another period—that other period.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) A survey interpretation report must include—

(a) the name of the survey; and

(b) the authority under which the survey was conducted; and

(c) the name of the holder of the authority; and

(d) a description of the objectives of the interpretation; and

(e) in the case of a seismic survey—

(i) a list of the surfaces interpreted; and

(ii) a justification of the surfaces interpreted, including synthetic seismograms if available; and

(iii) the velocity field used to convert time to depth (including ASCII data) and the basis for the velocity field; and

(iv) if available, time slices to describe the environment of deposition; and

(f) an elevation map of the survey area; and

(g) an index of the maps created during the interpretation; and

(h) in the case of a geological or geochemical survey, any interpretations formed after the conclusion of the survey; and

(i) all digital images of interpretation maps, in a form approved by the Minister.

45 Incident reporting

(1) For the purposes of this regulation, a reportable incident means an incident arising directly out of a petroleum operation that is reasonably likely to cause significant harm or damage to individuals, the environment, the integrity of the petroleum operation or the immediate area (whether above or below ground).

(2) The holder of an authority under which a petroleum operation is carried out must notify the Minister of a reportable incident within 2 hours—

(a) after the reportable incident occurs; or

(b) if the holder of the authority is not initially aware of the reportable incident, after the holder becomes aware that it occurred.

Penalty: 20 penalty units.

(3) A notification under subregulation (2) must—

(a) be given orally; and

(b) contain any information that is available at the time of the notification regarding—

(i) the material facts and circumstances of the reportable incident that the holder of the authority knows or is able, by reasonable search or enquiry, to find out; and

(ii) any action taken by the holder of the authority to avoid or mitigate any impacts to individuals, public safety, public amenity or the environment of the reportable incident; and

(iii) any immediate corrective action taken, or proposed to be taken, by the holder of the authority to stop, control or remedy the reportable incident.

(4) Within 3 days after the holder of an authority has notified the Minister of a reportable incident under subregulation (2), the holder must give a written report to the Minister containing the information specified in subregulation (3)(b).

Penalty: 20 penalty units.

(5) Within 30 days after the holder of an authority has notified the Minister of a reportable incident under subregulation (2), the holder must give the Minister a written report that contains—

(a) the date, time and place of the reportable incident; and

(b) a description of the reportable incident; and

(c) any known or suspected causes of the reportable incident; and

(d) a root cause analysis of the reportable incident; and

(e) a description of the steps taken by the holder to minimise the impacts of the reportable incident; and

(f) a description of the steps taken or proposed to be taken by the holder to prevent a recurrence of the reportable incident.

Penalty: 20 penalty units.

Division 4—Reports about drilling wells

46 Requirement for daily drilling report

(1) For the purposes of section 179(c) of the Act, the holder of an authority who undertakes drilling in the authority area must give the Minister a daily drilling report, prepared by a suitably qualified or experienced person, before midday on the day after the day of drilling to which the report relates.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) A daily drilling report under subregulation (1) must include—

(a) the authority number; and

(b) the name of the well in which the drilling was undertaken; and

(c) the location of the well using easting and northing coordinates; and

(d) the elevation of the well; and

(e) the drilled depth; and

(f) the work carried out; and

(g) the lithology of formations penetrated; and

(h) details of any indication of petroleum; and

(i) a summary of the material used; and

(j) any drilling fluid losses; and

(k) a leak off test summary; and

(l) the geometry of the well bore; and

(m) the results of surveys made in the well bore; and

(n) details of—

(i) any works undertaken in relation to drilling activities that were not within the scope of the operation plan but were carried out to avoid or manage an emergency situation or to overcome an unforeseen circumstance; and

(ii) details of the reasons for those works, any risks and how the risks were eliminated or minimised.

47 Requirement for initial well completion report and data

(1) For the purposes of section 179(c) of the Act, the holder of an authority who undertakes drilling activities in the authority area must give the Minister an initial well completion report as soon as reasonably practicable, but no later than 6 months, after the rig release date.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) The Minister may, in writing, extend the period within which the holder of an authority must give an initial well completion report under subregulation (1).

(3) An initial well completion report under subregulation (1) must contain the following data in relation to the well in a form and manner approved by the Minister—

(a) raw data, edited field data and processed data for all wireline logs, tools used for measurements while drilling (MWD tools) and tools used for logging while drilling (LWD tools);

(b) log displays;

(c) edited field data and processed data for borehole deviation surveys;

(d) mudlogging data;

(e) mudlog displays;

(f) if generated, data from velocity surveys including—

(i) raw data; and

(ii) processed data; and

(iii) checkshot data and a time and depth analysis;

(g) velocity survey displays;

(h) photography of the core and sidewall core, in both natural and UV light.

(4) An initial well completion report under subregulation (1) must include the following information—

(a) the name of the well;

(b) the name of the authority area in which the well is located;

(c) the location of the well in the form of—

(i) latitude and longitude; and

(ii) map sheet name and graticular block number; and

(iii) seismic line location and shotpoint number;

(d) the results of a check survey of the location of the well-head or the top of the casing supporting the blow-out preventer;

(e) if the well is a sidetrack—the name of the parent well;

(f) the names of the rig contractor and rig operator;

(g) the name of the rig used to drill the well;

(h) the make and model of the rig;

(i) the names of the contractors for—

(i) cementing; and

(ii) wireline logging; and

(iii) measurements while drilling; and

(iv) logging while drilling; and

(v) mudlogging;

(j) the names of any MWD tools and LWD tools used;

(k) a list of log runs for wireline logging and velocity surveys;

(l) the purpose of the well;

Examples

Appraisal, exploration, production or storage.

(m) the outcome of the well operation;

Examples

Completion of the well as a producer, suspension of the well or decommissioning of the well.

(n) raw pressure-time listings for any formation fluid sample tests and production tests;

(o) the spud date;

(p) the rig release date;

(q) the reference point from which the depth of the well is measured;

Examples

Kelly bushing or the rig floor.

(r) the height of the depth reference above sea level;

(s) the measured depth of the well;

(t) the true vertical depth of the well;

(u) if applicable, the depth of perforation in the petroleum reservoir;

(v) the date on which the total depth was reached;

(w) if the well is deviated or horizontal—

(i) the surveyed path of the well; and

(ii) the coordinates of the bottom of the well bore; and

(iii) if applicable, the coordinates and true vertical depth of the intersection of the well with the reservoir horizon;

(x) details of equipment and casing installed on or in the well, including schematics;

(y) if applicable, schematics of decommissioning;

(z) information on cementing operations;

(za) bit records;

(zb) drilling fluids used;

(zc) any drilling fluid losses;

(zd) a list of cores, cuttings and samples taken, and their depths and intervals;

48 Requirement for final well completion report and data

(1) For the purposes of section 179(c) of the Act, the holder of an authority who undertakes drilling activities in the authority area must give the Minister a final well completion report as soon as reasonably practicable, but no later than 12 months, after the rig release date.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) The Minister may, in writing, extend the period within which the holder of an authority must give a final well completion report under subregulation (1).

(3) A final well completion report under subregulation (1) must contain the following data in relation to the well in a form and manner approved by the Minister—

(a) an interpretative log analysis;

(b) a composite well log;

(c) a well index sheet;

(d) petrophysical, geochemical or other sample analyses.

(4) A final well completion report under subregulation (1) must include the following information—

(a) the name of the well;

(b) the name of the authority area in which the well is located;

(c) the location of the well using easting and northing coordinates;

(d) if the well is a sidetrack—the name of the parent well;

(e) the names of the rig contractor and rig operator;

(f) the name of the rig used to drill the well;

(g) the make and model of the rig;

(h) the names of the contractors for—

(i) cementing; and

(ii) wireline logging; and

(iii) measurements while drilling; and

(iv) logging while drilling; and

(v) mudlogging;

(i) the purpose of the well;

Examples

Appraisal, exploration, production or storage.

(j) the outcome of the well operation;

Examples

Completion of the well as a producer, suspension of the well or decommissioning of the well.

(k) raw pressure-time listings for any formation fluid sample tests and production tests;

(l) the spud date;

(m) the height of the depth reference above sea level;

(n) the measured depth of the well;

(o) the true vertical depth of the well;

(p) if applicable, the depth of perforation in the petroleum reservoir;

(q) the date on which the total depth was reached;

(r) if the well is deviated or horizontal—

(i) the surveyed path of the well; and

(ii) the coordinates of the bottom of the well bore; and

(iii) if applicable, the coordinates and true vertical depth of the intersection of the well with the reservoir horizon;

(s) details of equipment and casing installed on or in the well, including schematics;

(t) bit records;

(u) drilling fluids used;

(v) any drilling fluid losses;

(w) a list of cores, cuttings and samples taken, and their depths and intervals;

(x) a list of logs acquired;

(y) details of any petroleum indications;

(z) the measured depth and true vertical depth of marker horizons or formation tops;

(za) geological interpretations of the observations made as a result of drilling the well, including—

(i) lithology; and

(ii) stratigraphy; and

(iii) reservoir properties and quality; and

(iv) geochemistry of source rocks if available; and

(v) environment of deposition if available;

(zb) wireline formation test results;

(zc) production test results;

(zd) a core analysis;

(ze) if the well is an exploration well—the relevance of the observations and interpretations to the evaluation of the petroleum potential of the area.

Division 5—Reports regarding decommissioning

49 Well decommissioning report

(1) For the purposes of section 179(c) of the Act, the holder of an authority who plugs and decommissions a well under the authority must give the Minister a well decommissioning report, prepared by a suitably qualified or experienced person.

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) A well decommissioning report under subregulation (1) must be given to the Minister within 2 months after the day on which the plugging and decommissioning of the well is completed.

(3) A well decommissioning report under subregulation (1) must contain the following information—

(a) the authority number and type of authority;

(b) the name of the well;

(c) the name of the author of the report;

(d) the name of the holder of the authority;

(e) the name of the operator of the well;

(f) the name of the person giving the report;

(g) the date of the report;

(h) a summary and history of the well, including—

(i) spatial information showing its location; and

(ii) if a final well completion report in relation to the well has been lodged, the day on which that final well completion report was lodged;

(i) the following details about the well—

(i) its total depth in metres;

(ii) the top position and bottom position of any natural underground reservoir or aquifer intersected by the well, identified in accordance with subregulation (4);

(iii) the depth in metres of any perforations in the casing of the well;

(iv) the type of drilling rig used to drill the well;

(v) the basis for decommissioning the well;

(j) all surveys conducted and measurements made in relation to the well, including any detailed interpretation of the surveys or measurements;

(k) the following information in relation to the decommissioning of the well—

(i) details of any casing and equipment installed in the well, including diagrams showing the major dimensions and features of the casing and equipment;

(ii) a description of any equipment that has been retained in the well, including the size and nature of the equipment and any features of the equipment that may cause a hazard;

(iii) the surveyed location of any equipment retained in the well;

(iv) details of any cementing operations carried out in or on the well, including—

(A) the location and type of plugs; and

(B) the compressive strength of the cement; and

(C) time graphs; and

(D) the intervals covered; and

(E) the volume and type of cement used; and

(F) any losses of cement due to voids or permeable strata and the methods used to overcome those losses of cement;

(v) a description of any other decommissioning procedures used for the well;

(vi) details of any other activities undertaken in the course of drilling, completing, plugging and decommissioning the well, and an assessment of the possible impacts of those activities.

(4) For the purposes of subregulation (3)(i)(ii), the top position and bottom position of the natural underground reservoir or aquifer must be identified in relation to—

(a) in the case of a directional well—

(i) the total vertical depth in metres; and

(ii) the horizontal plane; or

(b) in any other case, the depth in metres.

Division 6—Retention and submission of samples

50 Requirement to retain core, cutting or sample

The holder of an authority must retain any core, cutting or sample that the holder collects in relation to a petroleum operation that the holder carries out under the authority.

Penalty: 20 penalty units.

51 Requirement to give core, cutting or sample

(1) This regulation applies if the holder of an authority—

(a) drills a well or conducts any other petroleum operation in a well under the authority; and

(b) during that operation, collects a core, cutting or sample of a type set out in column 2 of the Table to subregulation (2).

(2) For the purposes of section 179(c) of the Act, the holder of the authority must give the core, cutting or sample to the Minister—

(a) before the corresponding day set out in column 4 of the Table; and

(b) subject to subregulation (3), in the corresponding quantity set out in column 3 of the Table.

Table

Note

Under section 179 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(3) If the corresponding quantity is not available for the core, cutting or sample before the corresponding day, the holder of the authority must provide details of the following to the Minister—

(a) the reasons the corresponding quantity was not available;

(b) the quantity of the core, cutting or sample collected before that day.

Part 9—Administrative matters

Division 1—Pecuniary interests

52 Duty of disclosure of pecuniary interest

(1) For the purposes of section 243 of the Act, a person employed in the administration of the Act must disclose a pecuniary interest, in accordance with the procedures for declaring conflicts of interest approved by the Minister.

Note

Under section 243 of the Act, a person who contravenes this subregulation is liable to a penalty not exceeding 60 penalty units.

(2) A person who is required to disclose an interest under subregulation (1) must not perform or exercise any function or power under the Act in relation to the matter to which the interest relates unless the Minister authorises the person to do so.

Division 2—Compensation

53 Period before a disputed claim can go to the Tribunal or Supreme Court

Unless otherwise agreed by the owner or occupier of land and the holder of an authority, for the purposes of section 134(2) of the Act, the period of time during which an application may be made in relation to a claim is—

(a) if the claim relates to petroleum exploration—14 days after the claim is made; or

(b) if the claim relates to petroleum production—30 days after the claim is made.

Pt 10 (Heading and regs 54–61) substituted by S.R. No. 64/2024 reg. 4.

Part 10—Miscellaneous matters

Reg. 54 substituted by S.R. No. 64/2024 reg. 4.

54 Application fees

(1) The fee for an application for an exploration permit is—

(a) in the case of an application made before 1 July 2025, 2932 fee units; or

(b) in the case of an application made on or after 1 July 2025, 3905 fee units.

(2) The fee for an application for a retention lease is—

(a) in the case of an application made before 1 July 2025, 2094 fee units; or

(b) in the case of an application made on or after 1 July 2025, 2789 fee units.

(3) The fee for an application for a production licence is—

(a) in the case of an application made before 1 July 2025, 2094 fee units; or

(b) in the case of an application made on or after 1 July 2025, 2789 fee units.

(4) The fee for an application for a special access authorisation is—

(a) in the case of an application made before 1 July 2025, 1047 fee units; or

(b) in the case of an application made on or after 1 July 2025, 1395 fee units.

Reg. 55 substituted by S.R. No. 64/2024 reg. 4.

55 Fee for renewal of exploration permit

For the purposes of section 30(1)(b) of the Act, the fee for the renewal of an exploration permit is—

(a) in the case of an application for renewal made before 1 July 2025, 1047 fee units; or

(b) in the case of an application for renewal made on or after 1 July 2025, 1395 fee units.

Reg. 56 substituted by S.R. No. 64/2024 reg. 4.

56 Annual fees for exploration permit, retention lease or production licence

(1) The annual fee for an exploration permit is—

(a) in the case of an exploration permit granted before 1 July 2025, 2094 fee units; or

(b) in the case of an exploration permit granted on or after 1 July 2025, 2789 fee units.

(2) The annual fee for a retention lease is—

(a) in the case of a retention lease granted before 1 July 2025, 2932 fee units; or

(b) in the case of a retention lease granted on or after 1 July 2025, 3905 fee units.

(3) The annual fee for a production licence is—

(a) in the case of a production licence granted before 1 July 2025, 2932 fee units; or

(b) in the case of a production licence granted on or after 1 July 2025, 3905 fee units.

(4) The annual fee payable in respect of the first year after the grant of an exploration permit, retention lease or production licence must be paid within 7 days after the permit, lease or licence is granted.

Example

For an exploration permit granted on 1 August 2025—

(a) the annual fee for the first year must be paid on or before 8 August 2025; and

(b) the period for which the first annual fee applies is 1 August 2025 to 31 July 2026.

(5) The annual fee payable in respect of the second year and each subsequent year of an exploration permit, retention lease or production licence must be paid before the anniversary of the grant of the permit, lease or licence.

Example

For an exploration permit granted on 1 August 2025, the annual fee for the second year and each subsequent year must be paid before 1 August of that year.

Reg. 57 substituted by S.R. No. 64/2024 reg. 4.

57 Fees for transfer of exploration permit, retention lease or production licence

(1) The fee for the transfer or partial transfer of an exploration permit is—

(a) in the case of an application for transfer made before 1 July 2025, 1047 fee units; or

(b) in the case of an application for transfer made on or after 1 July 2025, 1395 fee units.

(2) The fee for the transfer of a retention lease is—

(a) in the case of an application for transfer made before 1 July 2025, 628 fee units; or

(b) in the case of an application for transfer made on or after 1 July 2025, 837 fee units.

(3) The fee for the transfer or partial transfer of a production licence is—

(a) in the case of an application for transfer made before 1 July 2025, 1047 fee units; or

(b) in the case of an application for transfer made on or after 1 July 2025, 1395 fee units.

Reg. 58 substituted by S.R. No. 64/2024 reg. 4.

58 Fees for suspension or variation of conditions of exploration permit, retention lease or production licence

(1) The fee for the suspension or variation of conditions of an exploration permit is—

(a) in the case of an application for suspension or variation made before 1 July 2025, 628 fee units; or

(b) in the case of a variation made under section 102 or 104 of the Act before 1 July 2025, 628 fee units; or

(c) in the case of an application for suspension or variation made on or after 1 July 2025, 837 fee units; or

(d) in the case of a variation made under section 102 or 104 of the Act on or after 1 July 2025, 837 fee units.

(2) The fee for the suspension or variation of conditions of a retention lease is—

(a) in the case of an application for suspension or variation made before 1 July 2025, 628 fee units; or

(b) in the case of a variation made under section 102 or 104 of the Act before 1 July 2025, 628 fee units; or

(c) in the case of an application for suspension or variation made on or after 1 July 2025, 837 fee units; or

(d) in the case of a variation made under section 102 or 104 of the Act on or after 1 July 2025, 837 fee units.

(3) The fee for the suspension or variation of conditions of a production licence is—

(a) in the case of an application for suspension or variation made before 1 July 2025, 628 fee units; or

(b) in the case of a variation made under section 102 or 104 of the Act before 1 July 2025, 628 fee units; or

(c) in the case of an application for suspension or variation made on or after 1 July 2025, 837 fee units; or

(d) in the case of a variation made under section 102 or 104 of the Act on or after 1 July 2025, 837 fee units.

Reg. 59 substituted by S.R. No. 64/2024 reg. 4.

59 Fee for registration of documents

The fee for the registration of a document in the petroleum register is—

(a) in the case of a document to be registered before 1 July 2025, 21 fee units; or

(b) in the case of a document to be registered on or after 1 July 2025, 28 fee units.

Reg. 60 substituted by S.R. No. 64/2024 reg. 4.

60 Fees for inspection of, or copy of document in, petroleum register

(1) For the purposes of section 236(1) of the Act, the fee for inspection of the petroleum register and any documents that form part of the register is—

(a) in the case of an inspection before 1 July 2025, 8 fee units; or

(b) in the case of an inspection on or after 1 July 2025, 11 fee units.

(2) For the purposes of section 236(2) of the Act, the fee for a copy of any entry or document in the petroleum register is—

(a) for each page of a copy of an entry or document to be obtained before 1 July 2025, 1 fee unit; or

(b) for each page of a copy of an entry or document to be obtained on or after 1 July 2025, 1⋅4 fee units.

Reg. 61 substituted by S.R. No. 64/2024 reg. 4.

61 Fee for Minister's certificate

For the purposes of section 237(2) of the Act, the fee for a certificate is—

(a) in the case of an application for a certificate made before 1 July 2025, 21 fee units; or

(b) in the case of an application for a certificate made on or after 1 July 2025, 28 fee units.

Part 11—Transitional regulations

62 Definitions

In this Part—

accepted exempt operation plan means an operation plan that applies to an exempt authority that was, before or during the moratorium period—

(a) accepted by the Minister in accordance with section 161 of the Act; or

(b) the subject of a significant change report;

exempt authority means—

(a) a production licence specified in section 17A(3) of the Act; or

(b) any authority in force immediately before the moratorium period other than a relevant authority;

moratorium period has the same meaning as in section 17A(5) of the Act;

relevant authority has the same meaning as in section 257 of the Act;

significant change report means a report required to be submitted to the Minister in relation to an operation plan under (as applicable)—

(a) regulation 6(1)(b)(iii) of the Petroleum Regulations 2011[2], as in force immediately before the commencement of the Petroleum Interim Regulations 2021; or

(b) regulation 6(1)(b)(iii) of the Petroleum Interim Regulations 2021, as in force immediately before the commencement of these Regulations.

Note

Regulation 6(1)(b) of the Petroleum Regulations 2011 and regulation 6(1)(b) of the Petroleum Interim Regulations 2021 required operation plans to provide for review and reporting to the Minister in the case of a significant change in the risks posed by a petroleum operation.

63 Prescribed circumstances—Minister may require variation of accepted operation plan

For the purposes of section 163A(2)(e) of the Act, the prescribed circumstances are that—

(a) at least 5 years has elapsed after the date on which either—

(i) the Minister accepted the accepted exempt operation plan; or

(ii) a significant change report was submitted to the Minister in relation to the accepted exempt operation plan; and

(b) the accepted exempt operation plan has not been varied under section 163 or 163A of the Act.

64 Modified reporting requirements for holders of exempt authorities

(1) This regulation applies if an accepted exempt operation plan is in force that has not been varied under section 163 or 163A of the Act on or after the commencement of these Regulations.

(2) Regulation 39(1)(b) and (2)(c), (f), (g), (h), (i) and (k) do not apply to the holder of an exempt authority.

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Endnotes

1 General information

See www.legislation.vic.gov.au for Victorian Bills, Acts and current Versions of legislation and up-to-date legislative information.

The Petroleum Regulations 2021, S.R. No. 139/2021 were made on 16 November 2021 by the Governor in Council under section 252 of the Petroleum Act 1998, No. 96/1998 and came into operation on 22 November 2021: regulation 3.

The Petroleum Regulations 2021 will sunset 10 years after the day of making on 16 November 2031 (see section 5 of the Subordinate Legislation Act 1994).

INTERPRETATION OF LEGISLATION ACT 1984 (ILA)

Style changes

Section 54A of the ILA authorises the making of the style changes set out in Schedule 1 to that Act.

References to ILA s. 39B

Sidenotes which cite ILA s. 39B refer to section 39B of the ILA which provides that where an undivided regulation, rule or clause of a Schedule is amended by the insertion of one or more subregulations, subrules or subclauses the original regulation, rule or clause becomes subregulation, subrule or subclause (1) and is amended by the insertion of the expression "(1)" at the beginning of the original regulation, rule or clause.

Interpretation

As from 1 January 2001, amendments to section 36 of the ILA have the following effects:

• Headings

All headings included in a Statutory Rule which is made on or after
1 January 2001 form part of that Statutory Rule. Any heading inserted in a Statutory Rule which was made before 1 January 2001, by a Statutory Rule made on or after 1 January 2001, forms part of that Statutory Rule.
This includes headings to Parts, Divisions or Subdivisions in a Schedule; Orders; Parts into which an Order is divided; clauses; regulations; rules; items; tables; columns; examples; diagrams; notes or forms.
See section 36(1A)(2A)(2B).

• Examples, diagrams or notes

All examples, diagrams or notes included in a Statutory Rule which is made on or after 1 January 2001 form part of that Statutory Rule. Any examples, diagrams or notes inserted in a Statutory Rule which was made before 1 January 2001, by a Statutory Rule made on or after 1 January 2001, form part of that Statutory Rule. See section 36(3A).

• Punctuation

All punctuation included in a Statutory Rule which is made on or after
1 January 2001 forms part of that Statutory Rule. Any punctuation inserted in a Statutory Rule which was made before 1 January 2001, by a Statutory Rule made on or after 1 January 2001, forms part of that Statutory Rule.
See section 36(3B).

• Provision numbers

All provision numbers included in a Statutory Rule form part of that Statutory Rule, whether inserted in the Statutory Rule before, on or after
1 January 2001. Provision numbers include regulation numbers, rule numbers, subregulation numbers, subrule numbers, paragraphs and subparagraphs. See section 36(3C).

• Location of "legislative items"

A "legislative item" is a penalty, an example or a note. As from 13 October 2004, a legislative item relating to a provision of a Statutory Rule is taken to be at the foot of that provision even if it is preceded or followed by another legislative item that relates to that provision. For example, if a penalty at the foot of a provision is followed by a note, both of these legislative items will be regarded as being at the foot of that provision. See section 36B.

• Other material

Any explanatory memorandum, table of provisions, endnotes, index and other material printed after the Endnotes does not form part of a Statutory Rule. See section 36(3)(3D)(3E).

2 Table of Amendments

This publication incorporates amendments made to the Petroleum Regulations 2021 by statutory rules, subordinate instruments and Acts.

–––––––––––––––––––––––––––––––––––––––––––––––––––––––––––––

Petroleum Amendment Regulations 2024, S.R. No. 64/2024

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3 Explanatory details

1. Reg. 4: S.R. No. 45/2021. ↑

2. Reg. 62 def. of significant change report: S.R. No. 30/2011. Revoked by S.R. No. 45/2021.

——

Fee Units

These Regulations provide for fees by reference to fee units within the meaning of the Monetary Units Act 2004.

The amount of the fee is to be calculated, in accordance with section 7 of that Act, by multiplying the number of fee units applicable by the value of a fee unit.

The value of a fee unit for the financial year commencing 1 July 2024 is $16.33. The amount of the calculated fee may be rounded to the nearest 10 cents.

The value of a fee unit for future financial years is to be fixed by the Treasurer under section 5 of the Monetary Units Act 2004. The value of a fee unit for a financial year must be published in the Government Gazette and a Victorian newspaper before 1 June in the preceding financial year.

Penalty Units

These Regulations provide for penalties by reference to penalty units within the meaning of section 110 of the Sentencing Act 1991. The amount of the penalty is to be calculated, in accordance with section 7 of the Monetary Units Act 2004, by multiplying the number of penalty units applicable by the value of a penalty unit.

The value of a penalty unit for the financial year commencing 1 July 2024 is $197.59.

The amount of the calculated penalty may be rounded to the nearest dollar.

The value of a penalty unit for future financial years is to be fixed by the Treasurer under section 5 of the Monetary Units Act 2004. The value of a penalty unit for a financial year must be published in the Government Gazette and a Victorian newspaper before 1 June in the preceding financial year. ↑