Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Regulations 2011 (Cth)

Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Regulations 2011

Select Legislative Instrument No. 54, 2011

made under the

Offshore Petroleum and Greenhouse Gas Storage Act 2006

Compilation No. 18

Compilation date: 12 June 2025

Includes amendments: F2024L01587

About this compilation

This compilation

This is a compilation of the Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Regulations 2011 that shows the text of the law as amended and in force on 12 June 2025 (the compilation date).

The notes at the end of this compilation (the endnotes) include information about amending laws and the amendment history of provisions of the compiled law.

Uncommenced amendments

The effect of uncommenced amendments is not shown in the text of the compiled law. Any uncommenced amendments affecting the law are accessible on the Register ( The details of amendments made up to, but not commenced at, the compilation date are underlined in the endnotes. For more information on any uncommenced amendments, see the Register for the compiled law.

Application, saving and transitional provisions for provisions and amendments

If the operation of a provision or amendment of the compiled law is affected by an application, saving or transitional provision that is not included in this compilation, details are included in the endnotes.

Editorial changes

For more information about any editorial changes made in this compilation, see the endnotes.

Modifications

If the compiled law is modified by another law, the compiled law operates as modified but the modification does not amend the text of the law. Accordingly, this compilation does not show the text of the compiled law as modified. For more information on any modifications, see the Register for the compiled law.

Self‑repealing provisions

If a provision of the compiled law has been repealed in accordance with a provision of the law, details are included in the endnotes.

Contents

Part 1Preliminary1.01Name of Regulations

These Regulations are the Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Regulations 2011.

1.04Objects of Parts 2 to 4 and 6 to 13

(1)
An object of Parts 2 to 4 and 6 to 13 of these Regulations is to ensure that operations in an offshore area are:
(a)
carried out in accordance with good oilfield practice; and
(b)
compatible with the optimum long‑term recovery of petroleum.
(2)
An object of Parts 2 to 4 and 6 to 13 of these Regulations is to ensure that the administrators of the Act are informed, in a timely and consistent manner, of:
(a)
exploration for petroleum and greenhouse gas storage formations; and
(b)
the discovery of petroleum and potential storage formations; and
(c)
the appraisal of discoveries; and
(d)
development and production operations in relation to petroleum, and injection operations in relation to greenhouse gas substances; and
(e)
the results of operations.
(3)
The other objects of Parts 2 to 4 and 6 to 13 of these Regulations are:
(a)
to provide a framework for encouraging the adequate collection, retention and timely dissemination of petroleum and greenhouse gas data; and
(b)
to assist in ensuring the adequacy of the data acquired; and
(c)
to allow for the efficient management of data confidentiality and the disclosure of data on completion of the relevant confidentiality periods.

1.04AObject of Part 5

The object of Part 5 of these Regulations is the maintenance of the integrity of offshore petroleum and greenhouse gas wells, by ensuring that risks to well integrity are reduced to as low as reasonably practicable.

1.05Definitions

In these Regulations:
accepted field development plan means a field development plan that has been accepted by the Joint Authority under regulation 4.05, as varied from time to time under regulation 4.10.
Act means the Offshore Petroleum and Greenhouse Gas Storage Act 2006.
commencement day means the day that these Regulations commence.
end of the operation means:
(a)
for a regulated operation related to the drilling of a well—the date on which the rig is released; and
(b)
for a regulated operation conducted on a well after the well is completed—the date on which the operation ceased; and
(c)
for a survey—the date on which the acquisition of the data is completed.
Energy Department has the meaning given by subregulation 8.13A(2).
excluded information has the meaning given by regulation 1.06.
greenhouse gas title means:
(a)
a greenhouse gas assessment permit; or
(b)
a greenhouse gas holding lease; or
(c)
a greenhouse gas injection licence; or
(d)
a greenhouse gas search authority; or
(e)
a greenhouse gas special authority; or
(f)
a greenhouse gas research consent.
greenhouse gas titleholder means:
(a)
a greenhouse gas assessment permittee; or
(b)
a greenhouse gas holding lessee; or
(c)
a greenhouse gas injection licensee; or
(d)
a registered holder of a greenhouse gas search authority; or
(e)
a registered holder of a greenhouse gas special authority; or
(f)
a holder of a greenhouse gas research consent.
named month means one of the 12 months of the calendar year.
non‑exclusive data means data that is made available for commercial sale or license.
open information about a survey means any of the following information:
(a)
the name of the survey;
(b)
the title under which the survey is being conducted;
(c)
the name of the titleholder;
(d)
the basin and sub‑basin (if applicable) in which the survey is being conducted;
(e)
the type of survey;
(f)
the size of the survey in:
(i)
for a 2‑dimensional survey—kilometres; or
(ii)
for a 3‑dimensional survey—square kilometres;
(g)
the name of the vessel or aircraft conducting the survey;
(h)
the name of the contractor conducting the survey;
(i)
the dates on which the survey starts and ends or is proposed to start and end;
(j)
whether the survey is exclusive or non‑exclusive;
(k)
navigation data for the survey, in the form of:
(i)
for a 2‑dimensional survey—line ends and bends; or
(ii)
for a 3‑dimensional seismic survey—a full fold polygon outline; or
(iii)
for other 3‑dimensional surveys—a polygon outline.
open information about a well means any of the following information:
(a)
the name of the well;
(b)
the offshore area in which the well is located;
(c)
the basin and sub‑basin (if applicable) in which the well is located;
(d)
the well’s latitude and longitude;
(e)
the name of the title area in which the well is located;
(f)
the name of the titleholder;
(g)
the purpose of the well (for example development, appraisal, exploration or stratigraphy);
(h)
if the well is a sidetrack—the name of the parent well;
(i)
the well’s spud date;
(j)
the water depth at the well;
(k)
what is being used as the depth reference for the well (for example the Kelly bushing or the rig floor);
(l)
the height of the depth reference above sea level;
(m)
the name of the rig drilling the well;
(n)
the rig’s make and model;
(o)
the name of the rig contractor;
(p)
the rig release date;
(q)
the status of the well (for example producing, suspended or abandoned).
petroleum title means:
(a)
a petroleum exploration permit; or
(b)
a petroleum retention lease; or
(c)
a petroleum production licence; or
(d)
a petroleum special prospecting authority; or
(e)
a petroleum access authority; or
(f)
a scientific investigation consent.
petroleum titleholder means:
(a)
a petroleum exploration permittee; or
(b)
a petroleum retention lessee; or
(c)
a petroleum production licensee; or
(d)
the registered holder of a petroleum special prospecting authority; or
(e)
the registered holder of a petroleum access authority; or
(f)
the holder of a scientific investigation consent.
riskmeans the likelihood of a specific, undesired, event occurring within a specific period or in specified circumstances.
Note: A risk may be understood as a frequency (the number of specified events occurring within a period) or a probability (the likelihood of a specific event following another event).
seismic extracted data grid means a series of vertical cross‑sections extracted from a 3‑dimensional seismic data volume that form a grid of which:
(a)
one direction is along the direction of seismic data acquisition; and
(b)
the other direction is at right angles to the direction of seismic data acquisition; and
(c)
the vertical cross‑sections are spaced 5 kilometres apart in both directions.
title means:
(a)
a greenhouse gas title; or
(b)
an infrastructure licence; or
(c)
a pipeline licence; or
(d)
a petroleum title.
title area means:
(a)
for a petroleum exploration permit or greenhouse gas assessment permit—the permit area; and
(b)
for a petroleum retention lease or greenhouse gas holding lease—the lease area; and
(c)
for a petroleum production licence, infrastructure licence, or greenhouse gas injection licence—the licence area; and
(d)
for a petroleum special prospecting authority, petroleum access authority, greenhouse gas search authority or greenhouse gas special authority—the authority area; and
(e)
for a scientific investigation consent or greenhouse gas research consent—the offshore area specified in the consent.
titleholder means:
(a)
a greenhouse gas titleholder; or
(b)
an infrastructure licensee; or
(c)
a pipeline licensee; or
(d)
a petroleum titleholder.
Titles Administrator means the National Offshore Petroleum Titles Administrator.

1.06Meaning of excluded information

(1)
This regulation sets out the type of information that is excluded information.
(2)
Information about the following is excluded information:
(a)
the technical qualifications of a titleholder or an applicant for a title;
(b)
the technical advice available to a titleholder or an applicant for a title;
(c)
the financial resources available to a titleholder or an applicant for a title.
(3)
Information contained in the following documents is excluded information:
(a)
an application for a petroleum exploration permit under section 104, 110 or 115 of the Act;
(b)
an application for renewal of a petroleum exploration permit under section 119 of the Act;
(c)
an application for a petroleum retention lease under section 141 or 147 of the Act;
(d)
an application for renewal of a petroleum retention lease under section 153 of the Act;
(e)
the results of a re‑evaluation of the commercial viability of petroleum production in a lease area under subsection 136(5) of the Act;
(f)
an application for a petroleum production licence under section 168, 170 or 178 of the Act or under clause 2 or 4 of Schedule 4 to the Act;
(g)
an application for renewal of a petroleum production licence under section 184 of the Act;
(h)
an application for a greenhouse gas assessment permit under section 296, 302A, 303 or 307A of the Act;
(i)
an application for renewal of a greenhouse gas assessment permit under section 308 or 311A of the Act;
(j)
an application for a greenhouse gas holding lease under section 324, 329A, 330, 335A, 336, 342A or 343 of the Act;
(k)
an application for renewal of a greenhouse gas holding lease under section 347 or 350A of the Act;
(l)
an application for a greenhouse gas injection licence under section 361, 368A or 369 of the Act;
(m)
a report given under Part 2 or Part 3 of these Regulations;
(n)
a field development plan submitted under regulation 4.04;
(o)
a variation of a field development plan submitted under regulation 4.08.
(4)
For subregulation (3), it does not matter whether a document was prepared or submitted before or after the commencement of these Regulations.
(5)
However, subregulation (3) does not apply to information that is also contained in a document not listed in subregulation (3) that is given to the Titles Administrator or responsible Commonwealth Minister.

Part 2Notification and reporting of discovery of petroleumDivision 1Petroleum titleholders2.01Application

This Division applies to a petroleum exploration permittee, petroleum retention lessee or petroleum production licensee who is required, under section 284 of the Act, to notify the Titles Administrator of a discovery of petroleum.
Note: Section 284 of the Act applies if petroleum is discovered in a petroleum exploration permit area, a petroleum retention lease area or a petroleum production licence area.

2.02Requirement to provide information with notification of discovery of petroleum

A petroleum titleholder must provide the following information when notifying the Titles Administrator:
(a) the title in which the discovery was made;
(b)
the name of the well through which the discovery was made;
(c)
the blocks in which the discovery is situated;
(d)
if the rate or quantity of production of petroleum and water from the discovery well has been determined—the rate or quantity;
(e)
the physical and chemical properties of the petroleum from the discovery well that have been determined;
(f)
if the physical properties of the pool from which the petroleum is recovered have been determined—the properties;
(g)
each preliminary estimate of the quantities of petroleum in place that has been made.

2.03Titles Administrator may request information to be included in discovery assessment report

(1)
The Titles Administrator may, within 7 days after being notified by a petroleum titleholder of a discovery of petroleum under section 284 of the Act, ask the titleholder in writing to include additional information about the discovery in the titleholder’s discovery assessment report under regulation 2.04.
Note: Section 284 of the Act requires notification of a discovery within 30 days after completion of the discovery well. Regulation 2.04 requires a further report about the discovery within 90 days after completion of the discovery well.
(2)
The request must specify the information sought and the reasons for the request.
(3)
After receiving the request, the titleholder may give the Titles Administrator a written statement that:
(a)
the information is not within the titleholder’s knowledge; or
(b)
the titleholder is unable to obtain the information.
(4)
If the Titles Administrator is satisfied (whether or not because of a statement under subregulation (3)) that the titleholder cannot comply with the request because:
(a)
the information is not within the titleholder’s knowledge; or
(b)
the titleholder is unable to obtain the information;
the Titles Administrator must, as soon as practicable, give the titleholder a notice in writing withdrawing the request.

2.04Requirement to provide discovery assessment report

(1)
A petroleum titleholder commits an offence if:
(a)
the titleholder has notified the Titles Administrator of a discovery of petroleum in accordance with section 284 of the Act; and
(b)
the titleholder does not give the Titles Administrator a discovery assessment report for the title area within:
(i)
90 days after completion of the well that resulted in the discovery; or
(ii)
if the Titles Administrator authorises the titleholder to give the report within another period—the other period.
Penalty: 60 penalty units.
(2)
An offence against subregulation (1) is an offence of strict liability.
Note: For strict liability, see section 6.1 of the Criminal Code.
(3)
In this regulation:
discovery assessment report means a report that includes the following information:
(a)
the title in which the discovery was made;
(b)
a preliminary estimate of the location and areal extent of the petroleum pool;
(c)
details of the geological structure in which the petroleum is located;
(d)
the results of all assessments of the discovery;
(e)
a preliminary estimate of the quantity of petroleum in the petroleum pool;
(f)
the data used to estimate the quantity of petroleum in the petroleum pool;
(g)
a preliminary estimate of the quantity of recoverable petroleum in the petroleum pool;
(h)
details of the petroleum titleholder’s plans for further evaluation of the discovery, including the work that the titleholder proposes to carry out in the title area in the next 12 months from the date of the report;
(i)
if the Titles Administrator has issued a notice to the petroleum titleholder under regulation 2.03 and the notice has not been withdrawn—the information specified in the notice.

Division 2Greenhouse gas titleholders2.05Application

This Division applies to a greenhouse gas assessment permittee, greenhouse gas holding lessee or greenhouse gas injection licensee who is required, under section 452 of the Act, to notify the responsible Commonwealth Minister of a discovery of petroleum.
Note: Section 452 of the Act applies if petroleum is discovered in a greenhouse gas assessment permit area, a greenhouse gas holding lease area or a greenhouse gas injection licence area.

2.06Requirement to provide petroleum discovery report

(1)
A greenhouse gas titleholder commits an offence if:
(a)
the titleholder has notified the responsible Commonwealth Minister of a discovery of petroleum in accordance with section 452 of the Act; and
(b)
the titleholder does not give the Minister, within 60 days after completion of the well that resulted in the discovery, a report that includes the information mentioned in subregulation (3).
Penalty: 60 penalty units.
(2)
An offence against subregulation (1) is an offence of strict liability.
Note: For strict liability, see section 6.1 of the Criminal Code.
(3)
For subregulation (1), the information that the report must include is:
(a)
the location of the petroleum discovery in the title area; and
(b)
if any production tests have been conducted on the discovered petroleum—the results of the tests.

2.07Information may be provided to responsible State Minister and responsible Northern Territory Minister

(1)
This regulation applies if:
(a)
petroleum is discovered in:
(i)
part of the permit area of a cross‑boundary greenhouse gas assessment permit that is in the coastal waters of a State or the coastal waters of the Northern Territory; or
(ii)
part of the lease area of a cross‑boundary greenhouse gas holding lease that is in the coastal waters of a State or the coastal waters of the Northern Territory; or
(iii)
part of the licence area of a cross‑boundary greenhouse gas injection licence that is in the coastal waters of a State or the coastal waters of the Northern Territory; and
(b)
a report of the discovery is provided to the responsible Commonwealth Minister under paragraph 2.06(1)(b).
(2)
Despite Parts 8 and 10, the responsible Commonwealth Minister may make information in the report available to the responsible State Minister or the responsible Northern Territory Minister, for the purpose of enabling or assisting the responsible State Minister or the responsible Northern Territory Minister to perform functions, or exercise powers, under a State PSLA or a Territory PSLA.

Part 3Title assessment reports3.01Application

This Part applies to the following titleholders:
(a)
a petroleum exploration permittee;
(b)
a petroleum retention lessee;
(c)
a petroleum production licensee;
(d)
a greenhouse gas assessment permittee;
(e)
a greenhouse gas holding lessee.

3.02Definition

In this Part:
Regulator means:
(a)
for a petroleum exploration permit, petroleum retention lease or petroleum production licence—the Titles Administrator; and
(b)
for a greenhouse gas assessment permit or greenhouse gas holding lease—the responsible Commonwealth Minister.

3.03Requirement to provide annual title assessment report

(1)
A titleholder commits an offence if the titleholder does not give an annual title assessment report, providing the required information for a year of the term of the title, to the Regulator within:
(a)
30 days after the day on which the year of the term ends; or
(b)
if the Regulator authorises the titleholder to give the report within another period—the other period.
Penalty: 60 penalty units.
Note: Year of the term is defined in section 10 of the Act. A year of the term of a title commences on the day that the title comes into force or on any anniversary of that day.
(2)
An offence against subregulation (1) is an offence of strict liability.
Note: For strict liability, see section 6.1 of the Criminal Code.
(3)
For subregulation (1), the required information is:
(a)
from a petroleum exploration permittee—the information mentioned in subregulation 3.06(1); or
(b)
from a petroleum retention lessee—the information mentioned in subregulation 3.07(1); or
(c)
from a petroleum production licensee—the information mentioned in subregulation 3.08(1); or

(d)
from a greenhouse gas assessment permittee—the information mentioned in subregulation 3.09(1); or
(e)
from a greenhouse gas holding lessee—the information mentioned in subregulation 3.10(1).

3.04Reports may be combined with permission

A titleholder with more than one title may combine the annual title assessment reports into a single document with the written agreement of the Regulator.

3.05Title assessment report for part of a year

(1)
This regulation applies if:
(a)
a title ceases to be in force (whether because the title has expired or because the title has been surrendered, cancelled, revoked or terminated); and
(b)
the term of the title was not a whole number of years.
Note: This regulation may apply when a title has been renewed. The renewal of a title is taken to be the grant of a new title on the day after the expiry of the previous title—see section 11 of the Act.
(2)
The Regulator may, by notice in writing, require the titleholder to give a title assessment report to the Regulator for the period at the end of the term that was not a year of the term.
(3)
The notice must specify:
(a)
the information that must be provided in the report; and
(b)
the date by which the report must be given.
(4)
For paragraph (3)(a), only information that would be required from the titleholder in an annual title assessment report under regulation 3.03 may be specified.
(5)
For paragraph (3)(b), the date must be at least 30 days after the day that the notice is given.
Offence – failure to give report when required
(6)
A titleholder commits an offence if:
(a)
the Regulator gives the titleholder a notice under subregulation (2); and
(b)
the titleholder does not comply with the notice.
Penalty: 60 penalty units.

3.06Information to be provided in annual title assessment report – petroleum exploration permit

(1)
For regulation 3.03, the required information from a petroleum exploration permittee is:
(a)
a description of work and expenditure commitments as detailed in the permit; and
(b)
for all work, evaluations and studies carried out in relation to the permit:
(i)
the total expenditure of the work, evaluation and studies; and
(ii)
the results of the work, evaluation and studies, including details about any leads and prospects identified; and
(c)
a list of the reports submitted to the Titles Administrator in accordance with these Regulations during the year; and
(d)
for the work, evaluations and studies expected to be carried out in relation to the permit during the next year of the permit:
(i)
a description of work commitments and expenditure estimates; and
(ii)
a description of the measures taken by the permittee to prepare for the work mentioned in subparagraph (i); and
(e)
any other information that is required to be included in the annual title assessment report by a condition of the permit.
(2)
An annual title assessment report may include any other information that the permittee believes is relevant to the petroleum exploration permit.

3.07Information to be provided in annual title assessment report – petroleum retention lease

(1)
For regulation 3.03, the required information from a petroleum retention lessee is:
(a)
a description of work and expenditure commitments as detailed in the lease; and
(b)
for all work, evaluations and studies carried out in relation to the lease:
(i)
the total expenditure of the work, evaluation and studies; and
(ii)
the results of the work, evaluation and studies, including details about any leads and prospects identified; and
(c)
a list of the reports submitted to the Titles Administrator in accordance with these Regulations during the year; and
(d)
details of the lessee’s plans for further evaluation of discoveries, including work that is to be carried out in the lease area; and
(e)
for the work, evaluations and studies expected to be carried out in relation to the lease during the next year of the lease:
(i)
a description of work commitments and expenditure estimates; and
(ii)
a description of the measures taken by the lessee to prepare for the work mentioned in subparagraph (i); and
(f)
for a year after the first year of the lease—the following information about each petroleum pool situated in the lease area:
(i)
a description of the pool;
(ii)
any new information relating to the evaluation of the pool;
(iii)
an estimate of the quantity of petroleum in the pool at the end of the previous year;
(iv)
an estimate of recoverable petroleum in the pool at the end of the previous year;
(v)
any new or revised data upon which the estimates in subparagraphs (iii) and (iv) are based, including a report of any study carried out that has resulted in a revised estimate;
(vi)
a table summarising the resource and reserve quantities mentioned in subparagraphs (iii) and (iv); and
(g)
any other information that is required to be included in the annual title assessment report by a condition of the lease.
(2)
An annual title assessment report may include any other information that the lessee believes is relevant to the petroleum retention lease.

3.08Information to be provided in annual title assessment report – petroleum production licence

(1)
For regulation 3.03, the required information from a petroleum production licensee is:
(a)
details of any activities the licensee plans to undertake in the licence area in compliance with a condition of the licence; and
(b)
a list of the reports submitted to the Titles Administrator in accordance with these Regulations during the year; and
(c)
details of the licensee’s plans for further evaluation of the licence area, including work that is to be carried out in the licence area and is not covered by paragraph (a); and
(d)
a production forecast for each producing or potential development project; and
(e)
a description of any leads and prospects in the licence area; and
(f)
for a year after the first year of the licence—the following information about each petroleum pool situated in the licence:
(i)
a description of the pool;
(ii)
any new information relating to the evaluation of the pool;
(iii)
an estimate of the quantity of petroleum in the pool at the end of the previous year;
(iv)
an estimate of recoverable petroleum in the pool at the end of the previous year;
(v)
any new or revised data upon which the estimates in subparagraphs (iii) and (iv) are based, including a report of any study carried out that has resulted in a revised estimate;
(vi)
a table summarising the resource and reserve quantities mentioned in subparagraphs (iii) and (iv); and
(g)
the total amount of petroleum produced during the year; and
(h)
the amount of each substance injected into a reservoir during the year; and
(i)
the amount of each substance flared or vented during the year; and
(j)
any other information that is required to be included in accordance with a condition of the petroleum production licence.
(2)
An annual title assessment report may include any other information that the licensee believes is relevant to the petroleum production licence.

3.09Information to be provided in annual title assessment report – greenhouse gas assessment permit

(1)
For regulation 3.03, the required information from a greenhouse gas assessment permittee is:
(a)
a description of work and expenditure commitments as detailed in the permit; and
(b)
for all work, evaluations and studies carried out in relation to the permit:
(i)
the total expenditure of the work, evaluation and studies; and
(ii)
the results of the work, evaluation and studies, including details about any leads and prospects identified; and
(c)
a list of the reports submitted to the responsible Commonwealth Minister in accordance with these Regulations during the year; and
(d)
for the work, evaluations and studies expected to be carried out in relation to the permit during the next year of the permit:
(i)
a description of work commitments and expenditure estimates; and
(ii)
a description of the measures taken by the permittee to prepare for the work mentioned in subparagraph (i); and
(e)
any other information that is required to be included in the annual title assessment report by a condition of the permit.
(2)
An annual title assessment report may include any other information that the permittee believes is relevant to the greenhouse gas assessment permit.

3.10Information to be provided in annual title assessment report – greenhouse gas holding lease

(1)
For regulation 3.03, the required information from a greenhouse gas holding lessee is:
(a)
a description of work and expenditure commitments as detailed in the lease; and
(b)
for all work, evaluations and studies carried out in relation to the lease:
(i)
the total expenditure of the work, evaluation and studies; and
(ii)
the results of the work, evaluation and studies; and
(c)
a list of the reports submitted to the responsible Commonwealth Minister in accordance with these Regulations during the year; and
(d)
details of the lessee’s plans for further evaluation work, including work that is to be carried out in the lease area; and
(e)
for the work, evaluations and studies expected to be carried out in relation to the lease during the next year of the lease:
(i)
a description of work commitments and expenditure estimates; and
(ii)
a description of the measures taken by the lessee to prepare for the work mentioned in subparagraph (i); and
(f)
any other information that is required to be included in the annual title assessment report by a condition of the lease.
(2)
An annual title assessment report may include any other information that the lessee believes is relevant to the greenhouse gas holding lease.

Part 4Field development plans and approvals of petroleum recoveryDivision 1Preliminary4.01Definitions

In this Part:
field, in relation to a field development plan, means an area within the licence area that is subject to the plan.
licence area, in relation to an applicant for a petroleum production licence, means the area constituted by the block or blocks that will be the subject of the petroleum production licence if the licence is granted.
major change, in relation to the recovery of petroleum from a field, includes the following:
(a)
the petroleum production licensee changes the development strategy or management strategy of a field or a petroleum pool;
(b)
the petroleum production licensee changes the plan for the development of additional pools in the field;
(c)
the petroleum production licensee ceases production, permanently or for the long term, before the date proposed in the field development plan;
(d)
the petroleum production licensee introduces new methods for the petroleum recovery, such as enhanced recovery and injection of fluids.
significant event includes the following:
(a)
a change in the understanding of the characteristics of the geology or reservoir that may have a significant impact on the optimum recovery of petroleum;
(b)
a new or increased risk to the recovery of petroleum within the licence area;
(c)
a new or increased risk to the recovery of petroleum outside the licence area caused by the development of pools in the licence area;
(d)
a new or increased risk of activities in the licence area causing effects outside the licence area (for example aquifer depletion caused by hydrocarbon extraction);
(e)
change to the proposed option for development of pools in the licence area, including any tie‑in opportunity with nearby licence areas.

Division 2Field development plan requirements for petroleum production licensees4.02Requirement to have an accepted field development plan

(1)
A petroleum production licensee commits an offence if:
(a)
the licensee undertakes the recovery of petroleum from a petroleum pool in the licence area; and
(b)
the recovery is not on an appraisal basis; and
(c)
at the time of the recovery of the petroleum, the licensee does not have:
(i)
an accepted field development plan in force for a field that includes the petroleum pool; or
(ii)
an approval, under regulation 4.15, to undertake the recovery of petroleum without an accepted field development plan; or
(iii)
an exemption under the transitional provisions of regulation 4.16.
Penalty: 80 penalty units.
Note 1: The Act also requires a licensee to undertake the recovery operation in accordance with good oilfield practice—see section 569.
Note 2: This offence applies to a petroleum production licensee. Recovery of petroleum in an offshore area without a petroleum production licence or other authorisation under the Act is an offence under section 160 of the Act.
(2)
An offence against subregulation (1) is an offence of strict liability.
Note: For strict liability, see section 6.1 of the Criminal Code.

4.03Requirement to undertake activities in accordance with accepted field development plan

A petroleum production licensee commits an offence if:
(a)
the licensee has an accepted field development plan in force for a field in the licence area; and
(b)
the licensee undertakes an activity in the licence area; and
(c)
the undertaking of the activity is not consistent with the field development plan.
Penalty: 80 penalty units.

Division 3Obtaining acceptance of field development plan4.04Application for acceptance of field development plan

(1)
A person who is a petroleum production licensee or an applicant for a petroleum production licence may apply to the Titles Administrator for the Joint Authority to accept a field development plan.
(2)
The application must be accompanied by the field development plan.

4.05Joint Authority decision on field development plan

(1)
As soon as practicable after a person gives a field development plan to the Titles Administrator under regulation 4.04, the Titles Administrator must give the plan to the Joint Authority.
(2)
After receiving the plan from the Titles Administrator, the Joint Authority must:
(a)
accept the plan; or
(b)
reject the plan; or
(c)
ask the Titles Administrator to notify the person in writing that the Joint Authority is unable to make a decision without further assessment of the plan.
Further assessment before decision
(3)
If the Joint Authority asks the Titles Administrator to issue a notice under paragraph (2)(c), the Joint Authority must specify for inclusion in the notice:
(a)
any further information the Joint Authority requires to be included in the plan; and
(b)
the date after which the Joint Authority will commence further assessment of the plan.
(4)
The date specified under paragraph (3)(b) must give the person a reasonable opportunity to modify or resubmit the plan.
(5)
If the Joint Authority undertakes further assessment of a field development plan, the Joint Authority must accept or reject the field development plan as soon as practicable.
Acceptance may be subject to conditions
(6)
The Joint Authority may accept the field development plan subject to conditions.
Notice of decision
(7)
The Titles Administrator must notify the person in writing of the following matters as soon as practicable after the Joint Authority has made a decision to accept or reject the field development plan:
(a)
the terms of the decision;
(b)
if the Joint Authority rejects the plan—the reasons for the decision;
(c)
if the Joint Authority accepts the plan—the date on which the plan commences;
(d)
if the Joint Authority accepts the plan subject to a condition—the condition and the reason for making the acceptance subject to a condition.
Date of effect
(8)
If the Joint Authority accepts the field development plan, the plan commences on the date notified under paragraph (7)(c).

4.06Criteria for acceptance of field development plan

(1)
The Joint Authority must accept a field development plan under paragraph 4.05(2)(a) or subregulation 4.05(5) if the Joint Authority is satisfied that:
(a)
the plan includes the matters mentioned in subregulation 4.07(1); and
(b)
the plan demonstrates that the person will conduct pool management in the field in a manner that is:
(i)
consistent with good oilfield practice; and
(ii)
compatible with optimum long‑term recovery of the petroleum.
(2)
The Joint Authority must not accept a field development plan if the Joint Authority is not satisfied that the plan meets the requirements of subregulation (1).

4.07Contents of field development plan

(1)
For paragraph 4.06(1)(a), the matters are:
(a)
evidence and data showing that the field contains petroleum, including details of the structure, extent and location of discovered petroleum pools; and
(b)
estimates of the volume of petroleum in place and recoverable petroleum, including data supporting the estimates; and
(c)
a description of:
(i)
the possible petroleum pools in the field; and
(ii)
the person’s plans (if any) to explore for petroleum pools; and
(iii)
how any petroleum pools of commercial quantity can be incorporated into the development of the licence area; and
(d)
a description of:
(i)
an appropriate strategy for the development of the field, management of the petroleum pool and optimum long‑term recovery; and
(ii)
any proposed and alternative development scenarios; and
(e)
a description of how the person intends to extract the petroleum over time, including the following information:
(i)
the estimated positions of wells;
(ii)
the potential timing of workovers;
(iii)
possible tie‑ins; and
(f)
the project schedule, including an estimated development timetable of production facilities such as wells, platforms and petroleum pipelines; and
(g)
the person’s operations or proposals for:
(i)
the enhanced recovery or recycling of petroleum; and
(ii)
the processing, storage or disposal of petroleum; and
(iii)
the injection of petroleum or water into an underground formation; and
(h)
arrangements for:
(i)
monitoring, recording in writing and reporting on the person’s conduct of pool management; and
(ii)
keeping records and other documents about the person’s conduct of pool management; and
(i)
details of:
(i)
the surface connections and equipment used by the person; and
(ii)
any production by a well that is from more than one petroleum pool; and
(iii)
any production from a petroleum pool that is through more than one well; and
(j)
the arrangements (if any) for the transport, injection and storage of greenhouse gas substances that have been obtained from a third party or other external source; and
(k)
arrangements for the maintenance of an accurate quantitative record of events, measurements and actions to which the plan relates.
(2)
A field development plan may include any other information that the person believes is relevant.

Division 4Variation of field development plan4.08Requirement to apply for variation of field development plan

(1)
A petroleum production licensee must apply to the Titles Administrator for the Joint Authority to accept a variation of a field development plan if:
(a)
the licensee intends to make a major change in relation to the recovery of petroleum from the field; or
(b)
there is a new licensee for the licence, unless the new licensee agrees in writing to continue operations in accordance with the current accepted field development plan; or
(c)
the Joint Authority has requested the licensee, under regulation 4.11, to vary the accepted field development plan.
(2)
The application must be accompanied by the proposed variation.

4.09Application must be made at least 90 days before major change

A petroleum production licensee commits an offence if:
(a)
the licensee undertakes the recovery of petroleum from a petroleum pool in the licence area; and
(b)
at the time of the recovery of the petroleum, the licensee has an accepted field development plan for a field that includes the petroleum pool; and
(c)
the licensee makes a major change in relation to the recovery of petroleum from the field; and
(d)
the licensee did not, at least 90 days before the occurrence of the major change, apply for a variation of the accepted field development plan.
Penalty: 60 penalty units.

4.10Joint Authority decision on variation of field development plan

(1)
As soon as practicable after a petroleum production licensee gives a variation of a field development plan to the Titles Administrator under regulation 4.08, the Titles Administrator must give the variation to the Joint Authority.
(2)
After receiving the variation from the Titles Administrator, the Joint Authority must:
(a)
accept the variation if the varied field development plan would meet the requirements of subregulation 4.06(1); or

(b)
reject the variation; or
(c)
ask the Titles Administrator to notify the licensee, in writing, that the Joint Authority is unable to make a decision without further assessment of the variation.
Further assessment before decision
(3)
If the Joint Authority asks the Titles Administrator to issue a notice under paragraph (2)(c), the Joint Authority must specify for inclusion in the notice:
(a)
any further information the Joint Authority requires to be included in the variation; and
(b)
the date after which the Joint Authority will commence further assessment of the plan.
(4)
The date specified under paragraph (3)(b) must give the licensee a reasonable opportunity to modify or resubmit the plan.
(5)
If the Joint Authority undertakes further assessment of a variation, the Joint Authority must accept or reject the variation as soon as practicable.
Acceptance may be subject to conditions
(6)
The Joint Authority may accept a variation of a field development plan subject to conditions.
Notice of decision
(7)
The Titles Administrator must notify the licensee in writing of the following matters as soon as practicable after the Joint Authority has made a decision to accept or reject a variation of a field development plan:
(a)
the terms of the decision;
(b)
if the Joint Authority rejects the variation—the reasons for the decision;
(c)
if the Joint Authority accepts the variation—the date on which the variation commences;
(d)
if the Joint Authority accepts the variation subject to a condition—the condition and the reason for making the acceptance subject to a condition.
Date of effect
(8)
If the Joint Authority accepts a variation of a field development plan, the plan as varied replaces the existing field development plan as the plan in force for the field on the date notified under paragraph (7)(c).

4.11Variation required by Joint Authority

The Titles Administrator may give a petroleum production licensee a notice in writing:
(a)
advising the licensee that the Joint Authority requires the licensee to vary a field development plan as set out in the notice; and
(b)
setting out the technical grounds for requiring the variation; and
(c)
identifying the proposed date of effect of the variation; and
(d)
identifying the proposed date by which the licensee must submit a variation of the plan to the Titles Administrator; and
(e)
advising the licensee of the effect of regulation 4.12.

4.12Objection to requirement to vary field development plan

(1) If the Titles Administrator gives a petroleum production licensee a notice under regulation 4.11, the licensee may give an objection, in writing, to the Titles Administrator:
(a)
stating one or more of the following:
(i)
that the variation should not occur;
(ii)
that the variation should be in terms different from the proposed terms;
(iii)
that the varied field development plan should take effect on a date later than the proposed date;
(iv)
that the date by which the licensee must submit a variation of the plan should be later than the proposed date; and
(b)
giving reasons for the objection.
(2) The licensee must make the objection within:
(a)
21 days after receiving the notice; or
(b)
if the Titles Administrator, in writing, allows a longer period—that period.

4.13Decision on objection

(1)
As soon as practicable after a petroleum production licensee gives an objection to the Titles Administrator under regulation 4.12, the Titles Administrator must give the objection to the Joint Authority.
(2)
After receiving the objection from the Titles Administrator, the Joint Authority must decide whether to accept or reject the objection.
(3) The Titles Administrator must notify the licensee, in writing, of the following matters as soon as practicable after the Joint Authority has made a decision:
(a)
the terms of the decision, including:
(i)
whether the original notice given under regulation 4.11 is varied or withdrawn; and
(ii)
if the original notice is varied—the new requirements;
(b)
if the decision is to reject the objection—the reasons for the decision.

Division 5Recovery of petroleum before field development plan is accepted4.14Application for approval to undertake recovery of petroleum without accepted field development plan

(1)
A petroleum production licensee may apply, in writing, to the Titles Administrator for permission to undertake recovery of petroleum from a petroleum pool in the licence area for a period of up to 3 months without having an accepted field development plan in force for a field that includes the pool.
(2)
The application must include:
(a)
the reason why it is necessary for the licensee to undertake recovery without having an accepted field development plan; and
(b)
details of any proposed extended production test; and
(c)
the period in respect of which the permission is sought; and
(d)
details of any proposed disposal or flaring of any produced hydrocarbons.

4.15Decision on application

(1)
As soon as practicable after the petroleum production licencee gives an application to the Titles Administrator under regulation 4.14, the Titles Administrator must:
(a)
consult the Joint Authority on the appropriateness or otherwise of approving the application; and
(b)
either:
(i)
approve the application; or
(ii)
reject the application; or
(iii)
notify the licensee, in writing, that the Titles Administrator is unable to make a decision without further information.
(2)
If the Titles Administrator issues a notice under subparagraph (1)(b)(iii), the Titles Administrator must specify the further information that it requires.
(3)
After receiving the information, the Titles Administrator must, as soon as practicable, do one of the things set out in paragraph (1)(b) in respect of the application.
(4)
The Titles Administrator may approve the application subject to conditions.
(5)
If the Titles Administrator approves the application, the maximum period for which the Titles Administrator may grant the permission is 3 months from the date of the Titles Administrator’s approval.
(6)
However, the Titles Administrator may, on written application by the licensee, extend the period by a maximum of 3 months after seeking the views of the Joint Authority on the appropriateness or otherwise of an extension.
(7)
The Titles Administrator may extend permission under subregulation (6) more than once.
(8)
The Titles Administrator must notify the licensee in writing of the following matters as soon as practicable after making a decision to approve or reject an application:
(a)
the terms of the decision;
(b)
if the Titles Administrator approves the application subject to a condition—the condition;
(c)
if the Titles Administrator rejects the application—the reasons for the decision.

Division 6Transitional provisions about field development plans4.16Events that occurred on or before the commencement of these Regulations

If a field development plan has been accepted before commencement day
(1)
If, on the commencement day, a petroleum production licensee has a field development plan for a field in the licence area that has been accepted by the Joint Authority, the field development plan is in force for the field.
If no decision made on acceptance before commencement day
(2)
A petroleum production licensee is taken to have made an application under regulation 4.04 on the commencement day if:
(a)
the licensee made an application for a field development plan to be accepted by the Joint Authority before the commencement day; and
(b)
the Joint Authority did not make a decision on the application before the commencement day.
If there is no accepted field development plan for recovery on commencement day
(3) If petroleum was being recovered in an area under a petroleum production licence on or before the commencement day (the recovery area)and the recovery after that day is not covered by a field development plan:
(a)
the licensee must make an application to the Titles Administrator under regulation 4.04 for acceptance of a field development plan for the recovery area before the end of:
(i)
2 years after the commencement day; or
(ii)
if the Titles Administrator gives the licensee written approval to extend the period to 4 years after the commencement day—that period; and
(b)
the licensee is exempt from regulation 4.02 until an accepted field development plan is in force for the recovery area.
(4)
If a licensee exempted by paragraph (3)(b) makes an application under regulation 4.04 and the plan is rejected by the Joint Authority, the licensee must make another application no later than 90 days after being given notice of the rejection.

Division 7Approval of rate of recovery of petroleum4.17Requirement to obtain approval of rate of recovery of petroleum

(1)
A petroleum production licensee commits an offence if:
(a)
the licensee undertakes the recovery of petroleum from a petroleum pool in a licence area; and
(b)
the licensee has not obtained from the Joint Authority written approval of the rate of recovery of petroleum from the pool; and
(c)
the rate of recovery of petroleum from the pool is not subject to a direction under section 190 of the Act.
Penalty: 60 penalty units.
(2)
An offence against subregulation (1) is an offence of strict liability.
Note: For strict liability, see section 6.1 of the Criminal Code.

4.18Application for approval of rate of recovery from pool in licence area

(1)
This regulation applies if a petroleum production licensee applies to the Joint Authority for written approval of the rate of recovery of petroleum from a petroleum pool in a licence area.
(2)
The Joint Authority must not approve the application unless the application includes the following information:
(a)
the proposed rate of recovery of petroleum from the pool;
(b)
the past performance (if any) and a prediction of future performance of production wells in the licence area;
(c)
an estimate of the ultimate recovery from the pool;
(d)
evidence that the equipment and procedures used to determine the quantity and composition of petroleum and water have been approved:
(i)
if the Royalty Act applies—under section 13 of that Act; or
(ii)
if that Act does not apply—by the Joint Authority.
(3)
In making a decision about the rate of recovery of petroleum from the pool, the Joint Authority must ensure that the rate is consistent with the accepted field development plan for the field that includes the pool.

Division 8Requirement to notify significant event4.19Requirement to notify significant event to Joint Authority

(1)
A petroleum production licensee commits an offence if:
(a)
a significant event occurs in, or in relation to, the licence area; and
(b)
the licensee becomes aware of the significant event; and
(c)
the licensee does not provide a written notification of the significant event to the Titles Administrator within 7 days after becoming aware of the event.
Penalty: 60 penalty units.
(2)
The notification must include:
(a)
all the material facts and circumstances about the significant event that the licensee is aware of or is able, by reasonable search and inquiry, to find out, including:
(i)
when the event occurred or was first detected; and
(ii)
the implications of the event for the reservoir and the optimum long‑term recovery of petroleum; and
(b)
the action the licensee proposes to take in response to the significant event.
(3)
The notification may include any other facts the licensee considers relevant.

Part 5Well operations management plans and well activitiesDivision 1Preliminary5.01Application

(1)
This Part applies to the following titleholders:
(a)
a petroleum exploration permittee;
(b)
a petroleum retention lessee;
(c)
a petroleum production licensee;
(d)
an infrastructure licensee;
(e)
a greenhouse gas assessment permittee;
(f)
a greenhouse gas holding lessee;
(g)
a greenhouse gas injection licensee.
(2)
This Part does not apply in relation to a well that is drilled for the purpose of geotechnical drilling or construction of a facility.

5.02Definitions

In this Part:
facility has the same meaning as in Schedule 3 to the Act.
in force, in relation to a well operations management plan (including any accepted revisions), means that:
(a)
the plan has been accepted; and
(b)
the acceptance of the plan has not been withdrawn; and
(c)
the operation of the plan has not ended.
integrity, in relation to a well, means the capacity of the well to contain petroleum, a greenhouse gas substance, or any other substance.
operator, in relation to a facility, has the same meaning as in Schedule 3 to the Act.
Regulator means NOPSEMA.
reportable incident, in relation to a well, means any of the following:
(a)
a loss of integrity of the well, including a well kick, resulting in a release of more than:
(i)
1 kilogram of gas; or
(ii)
80 litres of liquid;
(b)
a failure of hydrostatic pressure as a primary barrier, leading to:
(i)
a build‑up of pressure or a positive flow check; and
(ii)
the operation of a blow‑out prevention or diversion system;
(c)
damage to, or failure of, well‑related equipment that has led or could lead to a loss of integrity of the well;
(d)
any other unplanned occurrence that requires the titleholder to implement measures or arrangements to regain control of the well.
well has a meaning affected by regulation 5.03.
well activity means an activity relating to a well that is carried out during the life of the well.

5.03Well includes associated well‑related equipment

In this Part, a reference to a well includes a reference to the well‑related equipment associated with the well.
Note: For the definitions of well and well‑related equipment, see section 7 of the Act.

5.03AWell activity taken to occur if well is not operational

If there is a well in a title area that is not operational (but not permanently abandoned), the titleholder is taken for the purpose of these Regulations to be undertaking a well activity in relation to the well.

Division 2—Requirementswell operations management plan5.04Requirement to have well operations management plan in force

(1)
A titleholder commits an offence if:
(a)
the titleholder undertakes a well activity in a title area; and
(b)
there is not a well operations management plan in force for the well that applies to the well activity.
Penalty: 80 penalty units.
(2)
An offence against subregulation (1) is an offence of strict liability.
Note 1: For strict liability, see section 6.1 of the Criminal Code.
Note 2: NOPSEMA may give directions to titleholders that may relate to a well activity and must be complied with despite anything in these Regulations: see sections 574, 576B and 576C of the Act. NOPSEMA and the responsible Commonwealth Minister may also give remedial directions about plugging or closing off wells: see sections 586, 586A, 591B and 592 of the Act.

5.05Requirement to undertake activities in accordance with well operations management plan

(1)
A titleholder commits an offence if:
(a)
the titleholder undertakes a well activity in a title area; and
(b)
the well activity is regulated by:
(i)
one or more requirements of the well operations management plan in force for the well; or
(ii)
one or more conditions to which the acceptance of the plan was subject; or
(iii)
both requirements and conditions; and
(c)
the titleholder does not undertake the activity in accordance with the requirements, conditions or both that regulate the activity.
Penalty: 80 penalty units.
(1A)
A titleholder commits an offence if:
(a)
the well operations management plan in force for a well in the title area requires the titleholder to undertake an activity; and
(b)
the titleholder does not undertake the well activity.
Penalty: 80 penalty units.
(2)
An offence against subregulation (1) or (1A) is an offence of strict liability.
Note 1: For strict liability, see section 6.1 of the Criminal Code.
Note 2: NOPSEMA may give directions to titleholders that may relate to a well activity and must be complied with despite anything in these Regulations: see sections 574, 576B and 576C of the Act. NOPSEMA and the responsible Commonwealth Minister may also give remedial directions about plugging or closing off wells: see sections 586, 586A, 591B and 592 of the Act.
Exception to subregulation (1)—Regulator consents to undertaking activity in a specified manner
(3)
A titleholder may request, in writing, the consent of the Regulator to the titleholder undertaking a well activity in a specified manner.
(4)
The request must include sufficient information for the Regulator to assess whether or not undertaking the well activity in that manner would result in the integrity of the well becoming subject to a significant new risk or a significantly increased risk.
(5)
The Regulator may give consent only if there are reasonable grounds for believing that undertaking the well activity in that manner will not result in the integrity of the well becoming subject to a significant new risk or a significantly increased risk. The consent must be in writing.
(6)
Subregulation (1) does not apply in relation to a well activity if:
(a)
the Regulator has consented under subregulation (5) to the titleholder undertaking the activity in a specified manner; and
(b)
the titleholder undertakes the activity in that manner.
Note: A defendant bears an evidential burden in relation to the matter in subregulation (6): see subsection 13.3(3) of the Criminal Code.

Division 3Obtaining acceptance of well operations management plan5.06Application for acceptance of well operations management plan

(1)
A titleholder may apply to the Regulator for acceptance by the Regulator of a well operations management plan.
(2)
The titleholder must submit the plan to the Regulator:
(a)
at least 30 days before the proposed start of the first well activity to which the plan would apply; or
(b)
within the period approved by the Regulator in writing.
(3)
The plan:
(a)
must be in writing; and
(b)
may apply to more than one well if the integrity of each well is subject to similar risks; and
(c)
with the written approval of the Regulator—may be submitted in part.

5.07Decision on well operations management plan

Initial consideration
(1)
Within 30 days after a titleholder submits a well operations management plan to the Regulator:
(a)
if the Regulator is reasonably satisfied that the plan meets the criteria set out in regulation 5.08, the Regulator must accept the plan; or
(b)
if the Regulator is not reasonably satisfied that the plan meets the criteria set out in regulation 5.08, the Regulator must give the titleholder notice in writing under subregulation (2); or
(c)
if the Regulator is unable to make a decision on the plan within the 30 day period, the Regulator must give the titleholder notice in writing and set out a proposed timetable for consideration of the plan.
(2)
A notice to a titleholder under this subregulation must:
(a)
state that the Regulator is not reasonably satisfied that the well operations management plan submitted by the titleholder meets the criteria set out in regulation 5.08; and
(b)
identify the criteria set out in regulation 5.08 about which the Regulator is not reasonably satisfied; and
(c)
set a date by which the titleholder may resubmit the well operations management plan.
(3)
The date referred to in paragraph (2)(c) must give the titleholder a reasonable opportunity to modify and resubmit the plan.
Consideration after opportunity for resubmission
(4)
Within 30 days after the titleholder has resubmitted a modified well operations management plan:
(a)
if the Regulator is reasonably satisfied that the plan meets the criteria set out in regulation 5.08, the Regulator must accept the plan; or
(b)
if the Regulator is still not reasonably satisfied that the plan meets the criteria set out in regulation 5.08, the Regulator must:
(i)
give the titleholder a further notice under subregulation (2); or
(ii)
refuse to accept the plan; or
(iii)
act under subregulation (6); or
(c)
if the Regulator is unable to make a decision on the plan within the 30 day period, the Regulator must give the titleholder notice in writing and set out a proposed timetable for consideration of the plan.
(5)
If the titleholder does not resubmit a modified well operations management plan by the date referred to in paragraph (2)(c), or a later date agreed to by the Regulator, the Regulator must:
(a)
refuse to accept the plan; or
(b)
act under subregulation (6).

(6)
For subparagraph (4)(b)(iii) and paragraph (5)(b), the Regulator may do either or both of the following:
(a)
accept the plan in part;
(b)
accept the plan subject to conditions.
Validity of decision
(7)
A decision by the Regulator under subregulation (1) or (4) is not invalid only because the Regulator did not comply with the 30 day period in subregulation (1) or (4).
Notice of decision
(8)
The Regulator must give the titleholder notice in writing of a decision by the Regulator to:
(a)
accept the well operations management plan; or
(b)
refuse to accept the plan; or
(c)
accept the plan in part, or subject to conditions.
(9)
A notice of a decision mentioned in paragraph (8)(b) must set out the reasons for the decision.
(10)
A notice of a decision mentioned in paragraph (8)(c) must set out the terms of the decision and the reasons for the decision.

5.07AFurther information on submitted plan

(1)
If a titleholder submits a well operations management plan (including by resubmitting a plan in response to a notice under subregulation 5.07(2)), the Regulator may ask the titleholder to provide further written information about any matter that is required under subregulation 5.09(1) to be included in a well operations management plan.
(2)
The request must:
(a)
be in writing; and
(b)
set out each matter for which information is requested; and
(c)
specify a reasonable period within which the information is to be provided.
(3)
If a titleholder receives a request, and provides information requested by the Regulator within the period specified or within a longer period agreed to by the Regulator:
(a)
the information becomes part of the well operations management plan; and
(b)
the Regulator must have regard to the information as if it had been included in the well operations management plan when it was submitted.

5.08Criteria for acceptance of well operations management plan

For regulation 5.07, the criteria for acceptance of a well operations management plan for a well are:
(a)
that, subject to subregulation 5.09(2), the plan includes the matters mentioned in subregulation 5.09(1); and
(b)
that the plan is appropriate to the nature and scale of the well, and of the well activities relating to the well to which it applies; and
(c)
if the plan applies to more than one well—that the risks to the integrity of each well are similar; and
(d)
that the plan demonstrates how the risks to the integrity of the well will be reduced to as low as reasonably practicable; and
(e)
that the performance outcomes, performance standards and measurement criteria included in the plan are appropriate.

5.09Contents of well operations management plan

(1)
The matters that must be included in a well operations management plan are the following:
(a)
a description of the well, and the well activities relating to the well, to which the plan applies;
(b)
a description of the risk management process used to identify and assess risks to the integrity of the well;
(c)
a description and explanation of the design, construction, operation and management of the well, and conduct of well activities, showing how risks to the integrity of the well will be reduced to as low as reasonably practicable;
(d)
a description of the performance outcomes against which the performance of the titleholder in maintaining the integrity of the well is to be measured;
(e)
a description of the control measures that will be in place to ensure that risks to the integrity of the well will be reduced to as low as reasonably practicable throughout the life of the well, including periods when the well is not operational but has not been permanently abandoned;
(f)
a description of the performance standards for the control measures identified under paragraph (e);
(g)
the measurement criteria that will be used to determine whether the performance outcomes identified under paragraph (d) and the performance standards identified under paragraph (f) are being met;
(h)
a description of the monitoring, audit and well integrity assurance processes that will be implemented to ensure the performance outcomes and performance standards are being met throughout the life of the well, including periods when the well is not operational but has not been permanently abandoned;
(i)
a description of the arrangements that will be in place for suspension and abandonment of the well, showing:
(i)
how, during the process of suspending or abandoning the well, risks to the integrity of the well will be reduced to as low as reasonably practicable; and
(ii)
how the actions taken during that process will ensure that the integrity of the well is maintained while the well is suspended or abandoned;
(j)
a description of the measures that will be used to ensure that contractors and service providers undertaking well activities are aware of their responsibilities in relation to the maintenance of the integrity of the well, and have appropriate competencies and training;
(k)
a description of the measures and arrangements that will be used to regain control of the well if there is a loss of integrity;
(l)
a timetable for carrying out and completing the well activities to which the plan applies.
(2)
The Regulator may give a titleholder permission, notified in writing, not to include matters in a well operations management plan if those matters are regulated in the title.
(3)
A well operations management plan may include any other information that the titleholder believes is relevant.

Division 4Revision of well operations management plan5.10Revision based on circumstances

(1)
A titleholder must submit to the Regulator a proposed revision of the well operations management plan that is in force for a well in the title area, before the start of any well activity that the plan as currently in force does not apply to.
Note: A plan may have originally been submitted in part or only accepted in part: see regulations 5.06 and 5.07.
(2)
A titleholder must (except when the Regulator has consented under subregulation 5.05(5)) submit to the Regulator a proposed revision of a well operations management plan that is in force for a well in the title area, before making a significant change to the manner in which risks to the integrity of the well are reduced to as low as reasonably practicable.
Note: The titleholder must undertake activities in accordance with the well operations management plan in force for the well, except when the Regulator has consented to the titleholder undertaking an activity in a specified manner: see regulation 5.05.
(3)
A titleholder must submit to the Regulator a proposed revision of a well operations management plan that is in force for a well in the title area:
(a)
as soon as practicable after the integrity of the well becomes subject to a significant new risk or a significantly increased risk; or
(b)
if NOPSEMA gives the titleholder a direction under section 574, 576B, 579A, 586 or 591B of the Act that is inconsistent with the plan; or
(c)
if the responsible Commonwealth Minister has given the titleholder a direction under section 586A or 592 of the Act that is inconsistent with the plan.
Note: If paragraph (b) or (c) applies, the proposed revision will need to be consistent with the direction to be accepted—see subregulation 5.15(2).

5.11Revision required by Regulator

(1)
Subject to regulation 5.12, a titleholder must submit to the Regulator a proposed revision of the well operations management plan that is in force for a well in the title area if the Regulator notifies the titleholder under this regulation that the titleholder is required to do so.
(2)
The notice must be in writing and must set out the following:
(a)
the matters to be addressed by the revision;
(b)
the reasons for requiring the revision;
(c)
the proposed date by which the titleholder must submit the revision;
(d)
the effect of regulation 5.12.

5.12Revision required by Regulator – objection to requirement

(1)
If the Regulator gives a titleholder a notice under regulation 5.11, the titleholder may give an objection, in writing, to the Regulator:
(a)
stating one or more of the following:
(i)
that the revision should not occur;
(ii)
that the revision should not address the matters set out in the notice or should address different matters;
(iii)
that the date by which the titleholder must submit a revision should be later than the proposed date; and
(b)
giving reasons for the objection.
(2)
The titleholder must make the objection within 21 days after receiving the notice, or a longer period allowed by the Regulator.
(3)
The Regulator must, within 30 days after receiving the objection, decide whether to accept or reject the objection.
(4)
The Regulator must notify the titleholder, in writing, of the following matters as soon as practicable after making a decision:
(a)
the terms of the decision, including:
(i)
whether the original notice given under regulation 5.11 is varied or withdrawn; and
(ii)
if the original notice is varied—the new requirements;
(b)
if the decision is to reject the objection—the reasons for the decision.

5.13Revision at end of each 5 year period

(1)
A titleholder must submit to the Regulator a proposed revision of the well operations management plan that is in force for a well in the title area at least 14 days before the end of the period of 5 years that begins on the latest of the following days:
(a)
the day the Regulator first accepts the well operations management plan;
(b)
a day the Regulator accepts a proposed revision of the well operations management plan submitted under this regulation;
(d)
a day notified by the Regulator under subregulation (2).
(2)
For paragraph (1)(d), if the Regulator accepts a proposed revision of a well operations management plan that was submitted under regulation 5.10 or 5.11, the Regulator may notify the titleholder that the period of 5 years mentioned in subregulation (1) starts on the day specified in the notice.

5.14Form of proposed revision

A proposed revision must be in the form of a revised well operations management plan or, if the titleholder and the Regulator agree, a revised part of the well operations management plan.

5.15Acceptance of revised well operations management plan

(1)
Regulations 5.07, 5.07A and 5.08 apply to the proposed revision as if:
(a)
a reference in those regulations to the submission, acceptance or non‑acceptance of the well operations management plan were a reference to the submission, acceptance or non‑acceptance of the proposed revision; and
(b)
any other reference in those regulations to the well operations management plan were a reference to the plan as revised by the proposed revision.
Note: Those regulations deal with the consideration and acceptance of a well operations management plan.
(2)
If the proposed revision is required because NOPSEMA or the responsible Commonwealth Minister gave the titleholder a direction which is inconsistent with the well operations management plan that is in force, regulation 5.08 applies as if a criterion for the acceptance of the proposed revision is that it is consistent with the direction.

5.16Effect of non‑acceptance of proposed revision

If a proposed revision of a well operations management plan is not accepted, the provisions of the plan in force before the proposed revision was submitted remain in force, subject to the Act and this Part, as if the revision had not been proposed.

Division 5End of well operations management plan5.17Plan ends when well permanently abandoned

The operation of a well operations management plan ends when:
(a)
the titleholder has permanently abandoned the well or wells to which the plan applies; and
(b)
the titleholder has given the Regulator a written report of the process that was undertaken in abandoning the well or wells, and the outcome of that process; and
(c)
the Regulator notifies the titleholder in writing that the Regulator is reasonably satisfied that the process of abandoning the well or wells has been undertaken in accordance with the well operations management plan.

Division 6Withdrawal of acceptance of well operations management plan5.18Reasons for withdrawal of acceptance

The Regulator may withdraw its acceptance of a titleholder’s well operations management plan if:
(a)
the titleholder has not complied with the Act, this Part or a direction given under section 574, 576B, 579A, 586, 586A, 591B or 592 of the Act; or
(b)
the titleholder has not complied with the well operations management plan; or
(c)
the Regulator is satisfied for any other reason that its acceptance of the well operations management plan should be withdrawn.

5.19Notice of proposal to withdraw acceptance

(1)
If the Regulator believes it may be necessary to withdraw its acceptance of a well operations management plan, the Regulator must, at least 30 days before the Regulator would withdraw its acceptance:
(a)
notify the titleholder in writing that the Regulator is considering the withdrawal of the acceptance; and
(b)
include in the notification:
(i)
an explanation of the reasons why the Regulator is considering withdrawing the acceptance; and
(ii)
a date by which the titleholder may give the Regulator any information that the Regulator may take into account before deciding whether to withdraw the acceptance; and
(iii)
any other information that the Regulator considers appropriate.
(2)
The Regulator may give a copy of the notice to a person other than the titleholder if the Regulator considers it appropriate.

5.20Decision to withdraw acceptance

(1)
If the Regulator notifies a titleholder under subregulation 5.19(1), the Regulator must, as soon as practicable after the date mentioned in subparagraph 5.19(1)(b)(ii) has passed:
(a)
withdraw its acceptance of the well operations management plan; or
(b)
decide not to withdraw its acceptance.
(2)
The Regulator must not withdraw its acceptance unless the Regulator:
(a)
has taken any information given under subparagraph 5.19(1)(b)(ii) into account; and
(b)
is satisfied that a reason mentioned in regulation 5.18 exists.
(3)
The Regulator must notify the titleholder, in writing, of the following matters as soon as practicable after making a decision:
(a)
the terms of the decision;
(b)
if the decision is to withdraw its acceptance of the well operations management plan—the reasons for the decision.

5.20AWithdrawal decision has no effect in relation to well that is not operational

A decision by the Regulator to withdraw its acceptance of a well operations management plan has no effect in relation to a well that is not operational at the time of the decision, to the extent that the plan deals with the period that the well is not operational.

5.21Relationship between withdrawal and other provisions

(1)
The Regulator may withdraw its acceptance of a well operations management plan for the titleholder, even if the titleholder has been convicted of an offence, because of a failure to comply with a provision of the Act, these Regulations or other regulations made under the Act.
(2)
If the Regulator withdraws its acceptance of a well operations management plan, the withdrawal does not prevent the titleholder from being convicted of an offence because of a failure to comply with a provision of the Act, these Regulations or other regulations made under the Act.

Division 7Information about specific well activities5.22Well activities for which advance notice is required

Activities requiring 21 days notice
(1)
A titleholder must notify the Regulator about any of the following well activities in the title area before starting the well activity:
(a)
a well activity that involves drilling formation;
(b)
a well activity that involves running tubular goods into a well or recovering tubular goods from a well;
(c)
a well activity that involves removing a Christmas tree, tubing spool, casing spool or casing head from a well;
(d)
a well activity that involves the installation of a Christmas tree saver for use with downhole operations or well testing.
(2)
Notice of an activity mentioned in subregulation (1) must be given to the Regulator:
(a)
at least 21 days before the start of the well activity; or
(b)
if the Regulator agrees to a shorter period—at least the agreed number of days before the start of the well activity.
Activities requiring notice at any time before start of activity
(3)
A titleholder must notify the Regulator about any of the following well activities in the title area before starting the well activity:
(a)
a well activity, not mentioned in subregulation (1), that involves perforation or tubing punching;
(b)
a well activity, not mentioned in subregulation (1), that involves installation, removal or locking open of a downhole safety valve, storm choke valve, gas‑lift valve or injection valve;
(c)
a well activity, not mentioned in subregulation (1), that involves the installation of a Christmas tree saver for use during maintenance work on Christmas tree components.
Form of notice
(4)
Notice of a well activity must be in writing and must include the following information relating to the well activity:
(a)
a reference that identifies the well operations management plan for the well;
(b)
a description of the well, including the proposed or existing well name and number, the location of the well and the water depth;
(c)
the name of the facility from which the well activity will be carried out;
(d)
the name of the operator of the facility;
(e)
a description of the well activity, including the objective, key elements, milestones and programmed depths;
(f)
a list of any documents that have been prepared for the management, control or operation of the particular well activity;
(g)
the timetable for carrying out and completing the activity.

5.23Regulator may request more information

(1)
If a titleholder gives the Regulator a notice about a well activity under regulation 5.22, the Regulator may ask the titleholder to provide further written information about the well activity.
(2)
The request must be in writing and describe the information that is requested.

5.24Notice of change in activity or circumstances

(1)
If the information in a notice about a well activity given to the Regulator under regulation 5.22 is no longer accurate, the titleholder must provide the Regulator with updated information as soon as practicable.
(2)
Subregulation (1) does not apply if the reason why the information is no longer accurate is because the integrity of the well is subject to a significant new risk or a significantly increased risk.
Note: A significant new risk or a significantly increased risk requires a revision of the well operations management plan for the well—see subregulation 5.10(3).

5.25Notice that notified well activity has been completed

(1)
If a titleholder completes an activity for which notice was required under regulation 5.22, the titleholder must notify the Regulator that the activity has been completed.
(2)
The notice must be in writing and must be given to the Regulator no later than 10 days after the activity is completed.

Division 8Incidents, reports and records5.26Notifying reportable incident

(1)
A titleholder commits an offence if:
(a)
there is a reportable incident in relation to a well in the title area; and
(b)
the titleholder does not give notice of the reportable incident to the Regulator in accordance with subregulation (3).
Penalty: 80 penalty units.
(2)
An offence against subregulation (1) is an offence of strict liability.
Note: For strict liability, see section 6.1 of the Criminal Code.
(3)
The notice:
(a)
must be given to the Regulator as soon as practicable after:
(i)
the first occurrence of the reportable incident; or
(ii)
if the reportable incident was not detected by the titleholder at the time of the first occurrence—the time the titleholder becomes aware of the reportable incident; and
(b)
must be given orally; and
(c)
must contain:
(i)
all material facts and circumstances concerning the reportable incident that the titleholder knows or is able, by reasonable search or enquiry, to find out; and
(ii)
any action taken, or proposed to be taken, to stop, control or remedy the reportable incident.

5.26AWritten report of reportable incident

(1)
A titleholder commits an offence if:
(a)
there is a reportable incident in relation to a well in the title area; and

(4)
The nomination is in force, after the commencement of Schedule 1 to the Offshore Petroleum and Greenhouse Gas Storage Legislation Amendment (2013 Measures No. 2) Regulation 2013, as if it had been made under subregulation 11A.05(2).

Division 2Application provision relating to the Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Amendment (Fees) Regulation 201613.04Application provision – Amendments made by the Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Amendment (Fees) Regulation 2016

The amendments made to Schedule 6 of these Regulations by Schedule 1 to the Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Amendment (Fees) Regulation 2016 apply in relation to an application, nomination or request that is made on or after the day that Regulation commences.

Division 3Application provision relating to the Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Amendment (Fees) Regulations 202413.05Application provision – amendments made by the Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Amendment (Fees) Regulations 2024

The amendments of Schedule 6 to this instrument, made by the Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Amendment (Fees) Regulations 2024, apply in relation to an application, request or nomination (as the case requires) made on or after the day on which this regulation commences.

Schedule 1Initial well completion data

(regulations 7.13 and 9.13)

Item	Type of data	Standard media	Standard formats
1	Raw data, edited field data and processed data for all wireline logs, MWD or LWD tools	CD‑ROM, DVD or portable hard drive	LIS, DLIS or LAS
2	Log displays	CD‑ROM, DVD or portable hard drive	PDS, META, PDF or TIF
3	Edited field data and processed data for borehole deviation surveys	CD‑ROM, DVD or portable hard drive	LIS, DLIS, ASCII, LAS or XLS
4	Mudlogging data	CD‑ROM, DVD or portable hard drive	ASCII or LAS
5	Mudlog display	CD‑ROM, DVD or portable hard drive	TIF or PDF
6	If generated, data from velocity surveys including: (a) raw data; and (b) processed data; and (c) checkshot and time/depth analysis	CD‑ROM, DVD or portable hard drive	DLIS or SEG‑Y for raw data and processed data DLIS, SEG‑Y or ASCII for checkshot data
7	Velocity survey displays	CD‑ROM, DVD or portable hard drive	TIF, JPEG, PDF or PDS
8	Photography of the core and sidewall core, in both natural and UV light	CD‑ROM, DVD or portable hard drive	JPEG, PNG or TIF

Schedule 2Final well completion data

(regulations 7.14 and 9.14)

Item	Type of data	Standard media	Standard formats
1	Interpretative log analysis	CD‑ROM, DVD or portable hard drive	LIS, DLIS, ASCII, LAS or XLS
2	Composite well log	CD‑ROM, DVD or portable hard drive	TIF, JPEG or PDF
3	Well index sheet	CD‑ROM, DVD or portable hard drive	PDF
4	Petrophysical, geochemical or other sample analyses	CD‑ROM, DVD or portable hard drive	ASCII or XLS

Schedule 3Survey acquisition data

(regulations 7.16 and 9.16)

Part 1For seismic surveys

Item	Type of data	Standard media	Standard formats
101	Raw navigation data	CD‑ROM, DVD, portable hard drive or 3592 cartridge	UKOOA (P2/94 or later)
102	Seismic field data	3592 cartridge	SEG Standard
103	Seismic support data	CD‑ROM, DVD or portable hard drive	PDF
104	Itemised field tape listing showing: (a) tape number; and (b) survey name; and (c) line number; and (d) shotpoint range; and (e) data type	CD‑ROM, DVD or portable hard drive	ASCII

Part 2For other surveys

Item	Type of data	Standard media	Standard formats
201	Field data	CD‑ROM, DVD or portable hard drive	ASCII
202	Field support and navigation data	CD‑ROM, DVD or portable hard drive	ASCII

Schedule 4Processed survey data

(regulations 7.17 and 9.17)

Part 1For 2D seismic surveys

Item	Type of data	Standard media	Standard formats
101	Raw and final stacked data, including near/mid/far sub‑stacks if generated	3592 cartridge	SEG‑Y
102	Raw and final migrated data, including: (a) pre‑stack time migration (PSTM); and (b) pre‑stack depth migration (PSDM); and (c) near/mid/far sub‑stacks	3592 cartridge	SEG‑Y
103	Final processed navigation, elevation and bathymetry data	CD‑ROM, DVD or portable hard drive	UKOOA (P1/90 or later)
104	Shotpoint to common depth point (CDP) relationship	CD‑ROM, DVD or portable hard drive	ASCII
105	Data for both stacked and migrated velocities, including: (a) line number; and (b) shotpoint; and (c) time versus root mean square (RMS) pairs	CD‑ROM, DVD or portable hard drive	ASCII
106	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 (CDPs); and (f) data type	CD‑ROM, DVD or portable hard drive	ASCII

Part 2For 3D seismic surveys

Item	Type of data	Standard media	Standard formats
201	Raw and final stacked data, including near/mid/far sub‑stacks if generated	3592 cartridge	SEG‑Y
202	Raw and final migrated data, including: (a) pre‑stack time migration (PSTM); and (b) pre‑stack depth migration (PSDM); and (c) near/mid/far sub‑stacks	3592 cartridge	SEG‑Y
203	Final processed navigation, elevation and bathymetry data	CD‑ROM, DVD or portable hard drive	UKOOA (P1/90 or later)
204	Final navigation data in the form of: (a) final processed (grid) bin coordinates; and (b) polygonal position data (outline of the full fold area)	CD‑ROM, DVD or portable hard drive	UKOOA (P6/98 or later)
205	Data for both stacked and migrated velocities, including: (a) bin number; and (b) time versus root mean square (RMS) pairs	CD‑ROM, DVD or portable hard drive	ASCII
206	2D data subset, if production is required as a condition of the grant of a title	3592 cartridge	SEG‑Y
207	Itemised process tape listing showing: (a) tape number; and (b) survey name; and (c) in‑lines and crosslines; and (d) data type	CD‑ROM, DVD or portable hard drive	ASCII

Part 3For other surveys

Item	Type of data	Standard media	Standard formats
301	Final processed data	CD‑ROM, DVD or portable hard drive	ASCII or ASEG‑GDF2
302	Final processed images	CD‑ROM, DVD or portable hard drive	PDF

Schedule 5Interpretative survey data

(regulations 7.18 and 9.18)

Item	Type of data	Standard media	Standard formats
1	Digital images of interpretation maps	CD‑ROM, DVD or portable hard drive	Georeferenced TIF or PDF

Schedule 6Application fees etc.

Note: See regulation 11.01.

Part 1Fees in relation to applicationsDivision 1Fees payable under section 256 of the Act1Application fees payable under section 256 of the Act

The following table sets out the application fees payable under section 256 of the Act.

Item	Type of application	Fee ($)
101	Work‑bid petroleum exploration permit under section 104 of the Act	18,000
102	Special petroleum exploration permit under section 115 of the Act	18,000
103	Cash‑bid petroleum exploration permit under section 110 of the Act	18,000
104	Renewal of petroleum exploration permit (all types) under section 119 of the Act	18,000
105	Petroleum retention lease (all types) under section 141 or 147 of the Act	25,500
106	Renewal of petroleum retention lease (all types) under section 153 of the Act	25,500
107	Petroleum production licence over a surrendered block under section 178 of the Act	25,500
108	Petroleum production licence over an individual block under section 182 of the Act	25,500
109	Petroleum production licence (other than a licence in items 107 and 108)	25,500
110	Renewal of petroleum production licence (all types) under section 184 of the Act	25,500
111	Infrastructure licence under section 198 of the Act	25,500
111A	Variation of infrastructure licence under section 204 of the Act	25,500
112	Pipeline licence under section 217 of the Act	18,000
113	Variation of pipeline licence under section 226 of the Act	18,000
114	Petroleum special prospecting authority under section 234 of the Act	10,000

Division 2Fees payable under section 516A of the Act2Application fees payable under section 516A of the Act

The following table sets out the application fees payable under section 516A of the Act.

Fees payable under section 516A of the Act
Item	Type of application	Fee ($)
115	Approval of transfer of petroleum title under section 473 of the Act	10,000
116	Approval of dealing relating to petroleum title under section 488 of the Act	10,000
116AAA	Approval of a dealing relating to a title that may come into existence in the future under section 498 of the Act	10,000

Division 2AFees payable under section 566M of the Act2AApplication fees payable under section 566M of the Act

The following table sets out the application fees payable under section 566M of the Act.

Fees payable under section 566M of the Act
Item	Type of application	Fee ($)
116AA	Application for approval of change in control of a registered holder of a title	10,000

Division 3Fees payable under section 695L of the Act3Application etc. fees payable under section 695L of the Act

The following table sets out the fees payable under section 695L of the Act for processing an application, request or nomination.

Fees payable under section 695L of the Act
Item	Type of application, request or nomination	Fee ($)
116A	Request for variation of a declaration of location under subsection 133(1) of the Act	25,500
117	Application for a petroleum access authority under section 242 of the Act	10,000
118	Application for one or more of the following under item 1 of the table in subsection 264(1) of the Act in relation to a petroleum title: (a) variation of conditions of permit, lease or licence; (b) suspension of conditions and extension of the term of permit or lease; (c) exemption from conditions of permit, lease or licence; (d) suspension of conditions of licence, permit or lease	18,000
119	Nomination by permittee for declaration of a location in relation to a petroleum title under section 129 of the Act	25,500
120	Application for a consent to surrender a title under section 269 of the Act	18,000
120A	Application for approval to carry out one or more key greenhouse gas operations under a greenhouse gas assessment permit under section 292 or 292A of the Act	18,000
121	Application for a declaration of a part of a geological formation as an identified greenhouse gas storage formation under section 312 or 312A of the Act	40,000
122	Application for variation of a declaration of an identified greenhouse gas storage formation under section 313 of the Act	40,000
122A	Application for approval to carry out one or more key greenhouse gas operations under a greenhouse gas holding lease under section 321 or 321A of the Act	18,000
123	Application for a greenhouse gas special authority under section 415 of the Act	10,000
124	Application for one or more of the following under item 1 of the table in subsection 436(1) of the Act in relation to a greenhouse gas assessment permit, greenhouse gas holding lease or greenhouse gas injection licence: (a) variation or suspension of any of the conditions to which the permit, lease or licence is subject; (b) exemption from compliance with any of the conditions to which the permit, lease or licence is subject	18,000
124A	Application for one or more of the following under item 1 of the table in subsection 439A(1) of the Act in relation to a cross‑boundary greenhouse gas assessment permit, cross‑boundary greenhouse gas holding lease or cross‑boundary greenhouse gas injection licence: (a) variation or suspension of any of the conditions to which the permit, lease or licence is subject; (b) exemption from compliance with any of the conditions to which the permit, lease or licence is subject	18,000
124B	Application for a consent to surrender a title under section 441 of the Act	18,000
125	Application for acceptance of a field development plan under regulation 4.04	25,500
126	Application for variation of a field development plan under regulation 4.08	25,500
127	Application for permission to undertake recovery of petroleum from a petroleum pool in a licence area under regulation 4.14	25,500
128	Application for approval of the rate of recovery of petroleum from a petroleum pool in a licence area under regulation 4.18	25,500

Part 2Fees for greenhouse gas applicationsDivision 1Fees payable under section 427 of the Act4Application fees payable under section 427 of the Act

The following table sets out the application fees payable under section 427 of the Act.

Item	Type of application	Fee ($)
201	Work‑bid greenhouse gas assessment permit	18,000
201A	Cross‑boundary greenhouse gas assessment permit	18,000
202	Cash‑bid greenhouse gas assessment permit	18,000
203	Renewal of greenhouse gas assessment permit	18,000
204	Greenhouse gas holding lease (all types)	25,500
205	Renewal of greenhouse gas holding lease	25,500
206	Greenhouse gas injection licence	40,000
206A	Variation of greenhouse gas injection licence	40,000
207	Greenhouse gas search authority	10,000
208	Greenhouse gas site closing certificate	18,000

Division 2Fees payable under section 565A of the Act5Application fees payable under section 565A of the Act

The following table sets out the application fees payable under section 565A of the Act.

Item	Type of application	Fee ($)
209	Application for approval of transfer of greenhouse gas title under section 525 of the Act	10,000
210	Application for approval of dealing relating to greenhouse gas title under section 539 of the Act	10,000
211	Provisional application for approval of dealing in future interest relating to greenhouse gas title under section 548 of the Act	10,000

Schedule 7Transfer of title

(regulation 12.01)

Commonwealth of Australia

Transfer of title under Part 4.3 or 5.3 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006

I/We (1) (2)

being the registered holder/holders (1) of (3)

in consideration of (4)

hereby transfer all right, title and interest in that (3)

to (5)

IN WITNESS of this transfer the parties to the transfer have affixed their respective common seals or signatures below on this day of 20 .

(6) (7)

(1)Delete whichever is inapplicable.

(2)Insert the name of the transferor, or where there are two or more transferors, the name of each transferor.
(3)Insert the type (eg exploration permit, production licence), and number, of the property transferred that is a title within the meaning of section 467 or 519 of the Act.
(4)Insert the value of the consideration for the transfer or the value of the title transferred. Where the transfer of the title is pursuant to a dealing which has been approved and registered under the Act, insert a reference that is sufficient to identify that dealing.
(5)Insert the name and address of the transferee, or where there are two or more transferees, the name and address of each transferee.
(6)Affix the common seal or signature of the transferor or of each transferor, as the case may be.
(7)Affix the common seal or signature of the transferee or of each transferee, as the case may be.

Endnotes

Endnote 1About the endnotes

The endnotes provide information about this compilation and the compiled law.

The following endnotes are included in every compilation:

Endnote 1—About the endnotes

Endnote 2—Abbreviation key

Endnote 3—Legislation history

Endnote 4—Amendment history

Abbreviation key—Endnote 2

The abbreviation key sets out abbreviations that may be used in the endnotes.

Legislation history and amendment history—Endnotes 3 and 4

Amending laws are annotated in the legislation history and amendment history.

The legislation history in endnote 3 provides information about each law that has amended (or will amend) the compiled law. The information includes commencement details for amending laws and details of any application, saving or transitional provisions that are not included in this compilation.

The amendment history in endnote 4 provides information about amendments at the provision (generally section or equivalent) level. It also includes information about any provision of the compiled law that has been repealed in accordance with a provision of the law.

Editorial changes

The Legislation Act 2003 authorises First Parliamentary Counsel to make editorial and presentational changes to a compiled law in preparing a compilation of the law for registration. The changes must not change the effect of the law. Editorial changes take effect from the compilation registration date.

If the compilation includes editorial changes, the endnotes include a brief outline of the changes in general terms. Full details of any changes can be obtained from the Office of Parliamentary Counsel.

Misdescribed amendments

A misdescribed amendment is an amendment that does not accurately describe how an amendment is to be made. If, despite the misdescription, the amendment can be given effect as intended, then the misdescribed amendment can be incorporated through an editorial change made under section 15V of the Legislation Act 2003.

If a misdescribed amendment cannot be given effect as intended, the amendment is not incorporated and “(md not incorp)” is added to the amendment history.

Endnote 2Abbreviation key

ad = added or inserted	o = order(s)
am = amended	Ord = Ordinance
amdt = amendment	orig = original
c = clause(s)	par = paragraph(s)/subparagraph(s)
C[x] = Compilation No. x	/sub‑subparagraph(s)
Ch = Chapter(s)	pres = present
def = definition(s)	prev = previous
Dict = Dictionary	(prev…) = previously
disallowed = disallowed by Parliament	Pt = Part(s)
Div = Division(s)	r = regulation(s)/rule(s)
ed = editorial change	reloc = relocated
exp = expires/expired or ceases/ceased to have	renum = renumbered
effect	rep = repealed
F = Federal Register of Legislation	rs = repealed and substituted
gaz = gazette	s = section(s)/subsection(s)
LA = Legislation Act 2003	Sch = Schedule(s)
LIA = Legislative Instruments Act 2003	Sdiv = Subdivision(s)
(md) = misdescribed amendment can be given	SLI = Select Legislative Instrument
effect	SR = Statutory Rules
(md not incorp) = misdescribed amendment	Sub‑Ch = Sub‑Chapter(s)
cannot be given effect	SubPt = Subpart(s)
mod = modified/modification	underlining = whole or part not
No. = Number(s)	commenced or to be commenced

Endnote 3Legislation history

Number and year	Registration	Commencement	Application, saving and transitional provisions
2011 No. 54	28 Apr 2011 (F2011L00647)	29 Apr 2011 (r 1.02)
2011 No. 198	24 Oct 2011 (F2011L02112)	Sch 1: 1 Nov 2011 (r 2)	—
2011 No. 253	15 Dec 2011 (F2011L02689)	r 1–3 and Sch 1: 29 Apr 2011 (r 2(a)) Remainder: 1 Jan 2012 (r 2(b))	—
238, 2013	8 Nov 2013 (F2013L01914)	Sch 1: 9 Nov 2013 (s 2(1) item 2) Sch 2 (items 3, 4): 28 Nov 2013 (s 2(1) item 3)	—
154, 2015	4 Sept 2015 (F2015L01402)	Sch 1 (items 12–55): 1 Jan 2016 (s 2(1) item 1)	—
252, 2015	17 Dec 2015 (F2015L02065)	1 Jan 2016 (s 2(1) item 1)	—

Name	Registration	Commencement	Application, saving and transitional provisions
Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Amendment (Fees) Regulation 2016	9 May 2016 (F2016L00699)	1 July 2016 (s 2(1) item 1)	—
Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Amendment (Data Sharing) Regulations 2017	15 Dec 2017 (F2017L01623)	1 Jan 2018 (s 2(1) item 1)	—
Offshore Petroleum and Greenhouse Gas Storage Legislation Amendment (Greenhouse Gas Storage) Regulations 2020	3 Apr 2020 (F2020L00400)	Sch 2 (items 1–15): 28 Apr 2020 (s 2(1) items 7, 8)	—
Offshore Petroleum and Greenhouse Gas Storage Legislation Amendment (Cross‑boundary Greenhouse Gas Storage) Regulations 2020	18 Sept 2020 (F2020L01186)	Sch 1 (items 26–35) and Sch 2: 1 Oct 2020 (s 2(1) items 2, 3)	—
Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Amendment (Fees) Regulations 2021	15 Nov 2021 (F2021L01556)	1 Jan 2022 (s 2(1) item 1)	—
Offshore Petroleum and Greenhouse Gas Storage Legislation Amendment (Titles Administration) Regulations 2021	9 Dec 2021 (F2021L01747)	Sch 1 and Sch 2 (item 2): 2 Mar 2022 (s 2(1) items 2, 3)	—
Offshore Petroleum and Greenhouse Gas Storage Legislation (Repeal and Other Measures) Regulations 2022	19 Dec 2022 (F2022L01679)	Sch 2 (item 1): 20 Dec 2022 (s 2(1) item 3) Sch 2 (item 8): 2 Mar 2023 (s 2(1) item 5)	—
Offshore Petroleum and Greenhouse Gas Storage Legislation (Repeal and Consequential Amendments) Regulations 2023	10 July 2023 (F2023L00997)	Sch 2 (items 32–42): 10 Jan 2024 (s 2(1) item 1)	—
Offshore Petroleum and Greenhouse Gas Storage Legislation (Repeal and Consequential Amendments (No. 2)) Regulations 2023

24 Nov 2023 (F2023L01552)	Sch 2: 24 Feb 2024 (s 2(1) item 1)	—
Offshore Petroleum and Greenhouse Gas Storage (Resource Management and Administration) Amendment (Fees) Regulations 2024	8 Nov 2024 (F2024L01422)	1 Jan 2025 (s 2(1) item 1)	—
Offshore Petroleum and Greenhouse Gas Storage Legislation (Repeal and Consequential Amendments) Regulations 2024	9 Dec 2024 (F2024L01587)	Sch 2 (items 6–9): 12 June 2025 (s 2(1) item 2)	—

Endnote 4Amendment history

Provision affected	How affected
Part 1
r 1.02.........................................	rep LA s 48D
r 1.03.........................................	rep LA s 48C
r 1.04 ........................................	am No 154, 2015
r 1.04A ......................................	ad No 154, 2015
r. 1.05........................................	am. 2011 No. 253; No 154, 2015; F2017L01623
r 1.06.........................................	am No 253, 2011; F2020L00400; F2020L01186
Part 2
Division 1
r. 2.01........................................	am. 2011 No. 253
r. 2.02........................................	am. 2011 No. 253
r. 2.03........................................	am. 2011 No. 253
r. 2.04........................................	am. 2011 No. 253
Division 2
r 2.07.........................................	ad F2020L01186
Part 3
r. 3.02........................................	am. 2011 No. 253
r. 3.06........................................	am. 2011 No. 253
r. 3.07........................................	am. 2011 No. 253
r. 3.08........................................	am. 2011 No. 253
Part 4
Division 3
r. 4.04........................................	am. 2011 No. 253
r. 4.05........................................	am. 2011 No. 253
Division 4
r. 4.08........................................	am. 2011 No. 253
r. 4.10........................................	am. 2011 No. 253
r. 4.11........................................	am. 2011 No. 253
r. 4.12........................................	am. 2011 No. 253
r. 4.13........................................	am. 2011 No. 253
Division 5
r. 4.14........................................	am. 2011 No. 253
r. 4.15........................................	am. 2011 No. 253
Division 6
r. 4.16........................................	am. 2011 No. 253
Division 8
r. 4.19........................................	am. 2011 No. 253
Part 5
Part 5 heading.............................	rs No 154, 2015
Division 1
r 5.01.........................................	am No 154, 2015
r 5.02.........................................	am 2011 No 253; No 154, 2015; F2020L00400
ed C9
r 5.03.........................................	rs No 154, 2015
r 5.03A......................................	ad No 154, 2015
Division 2
r 5.04.........................................	am No 253, 2011; No 154, 2015; F2020L00400
r 5.05.........................................	am No 154, 2015; F2020L00400
Division 3
r 5.06.........................................	am No 154, 2015
r 5.07.........................................	rs No 154, 2015
r 5.07A......................................	ad No 154, 2015
r 5.08.........................................	rs No 154, 2015
r 5.09.........................................	am No 154, 2015
Division 4
Division 4..................................	rs No 154, 2015
r 5.10.........................................	rs No 154, 2015
am F2020L00400
r 5.11.........................................	rs No 154, 2015
r 5.12.........................................	am No 253, 2011
rs No 154, 2015
r 5.13.........................................	rs No 154, 2015
am No 252, 2015
r 5.14.........................................	rs No 154, 2015
r 5.15.........................................	rs No 154, 2015
r 5.16.........................................	rs No 154, 2015
Division 5
Division 5..................................	rs No 154, 2015
r 5.17.........................................	rs No 154, 2015
Division 6
r 5.18.........................................	am No 253; 2011; No 154, 2015; F2020L00400
r 5.19.........................................	am No 154, 2015
r 5.20A......................................	ad No 154, 2015
Division 7
Division 7..................................	rs No 154, 2015
r 5.22 ........................................	am No 253, 2011
rs No 154, 2015
r 5.23.........................................	rs No 154, 2015
r 5.24.........................................	rs No 154, 2015
r 5.25.........................................	rs No 154, 2015
Division 8
r 5.26.........................................	rs No 154, 2015
r 5.26A......................................	ad No 154, 2015
r 5.26B.......................................	ad No 154, 2015
Division 9
Division 9 heading......................	rs No 253, 2011
am F2020L00400
r 5.27.........................................	am No 253, 2011
rep F2020L00400
r. 5.28........................................	am. 2011 No. 253; No 154, 2015
r 5.29.........................................	rs No 253, 2011
am No 154, 2015; F2020L00400
Division 9A
Division 9A................................	ad F2021L01747
r 5.29A......................................	ad F2021L01747
Division 10
Division 10.................................	rs No 154, 2015
r. 5.30........................................	rs. 2011 No. 253; No 154, 2015
am No 252, 2015
r. 5.30A......................................	ad. 2011 No. 253
rep No 154, 2015
r. 5.31........................................	rs. 2011 No. 253; No 154, 2015
am No 252, 2015
r. 5.31A......................................	ad. 2011 No. 253
rep No 154, 2015
r 5.32.........................................	rs No 154, 2015
r 5.33.........................................	rs No 154, 2015
am No 252, 2015
r 5.34.........................................	rs No 154, 2015
r 5.35.........................................	rep No 154, 2015
ad No 252, 2015
r 5.36.........................................	ad No 252, 2015
Part 7
Division 2
r. 7.06........................................	am. 2011 No. 253
r. 7.07........................................	am. 2011 No. 253
r. 7.08........................................	am. 2011 No. 253
Division 3
Subdivision 3.1
r. 7.11........................................	am. 2011 No. 253
Subdivision 3.2
r. 7.12........................................	am. 2011 No. 253
r. 7.13........................................	am. 2011 No. 253
r. 7.14........................................	am. 2011 No. 253; No 238, 2013
Subdivision 3.3
r. 7.15........................................	am. 2011 No. 253; No 238, 2013
r. 7.16........................................	am. 2011 No. 253; No 238, 2013
r. 7.17........................................	am. 2011 No. 253; No 238, 2013
r. 7.18........................................	am. 2011 No. 253; No 238, 2013
Subdivision 3.4
r. 7.19........................................	am. 2011 No. 253
Subdivision 3.5
r. 7.20........................................	am. 2011 No. 253; No 238, 2013
Part 8
Division 2
r. 8.02........................................	am. 2011 No. 253
r. 8.03........................................	am. 2011 No. 253
r. 8.04........................................	am. 2011 No. 253
r. 8.05........................................	am. 2011 No. 253
r. 8.06........................................	am. 2011 No. 253
r. 8.07........................................	am. 2011 No. 253
r. 8.08........................................	am. 2011 No. 253
Division 3
r. 8.09........................................	am. 2011 No. 253
r. 8.10........................................	am. 2011 No. 253
r. 8.11........................................	am. 2011 No. 253; No 238, 2013
r. 8.12........................................	am. 2011 No. 253; No 238, 2013
r. 8.13........................................	am. 2011 No. 253; No 238, 2013
r 8.13A......................................	ad F2017L01623
Division 4
r. 8.14........................................	am. 2011 No. 253
r. 8.15........................................	am. 2011 No. 253
r. 8.16........................................	am. 2011 No. 253; No 238, 2013
Part 9
Division 2
r. 9.06........................................	am. 2011 No. 253
r. 9.07........................................	am. 2011 No. 253
r. 9.08........................................	am. 2011 No. 253
Division 3
Subdivision 3.1
r. 9.11........................................	am. 2011 No. 253
Subdivision 3.2
r. 9.12........................................	am. 2011 No. 253
r. 9.13........................................	am. 2011 No. 253
r. 9.14........................................	am. 2011 No. 253
Subdivision 3.3
r 9.15.........................................	am 2011 No 253; F2023L00997
r. 9.16........................................	am. 2011 No. 253
r. 9.17........................................	am. 2011 No. 253
r. 9.18........................................	am. 2011 No. 253
Subdivision 3.4
r. 9.19........................................	am. 2011 No. 253
r. 9.20........................................	am. 2011 No. 253
r. 9.21........................................	am. 2011 No. 253
r. 9.22........................................	am. 2011 No. 253
Subdivision 3.5
r. 9.23........................................	am. 2011 No. 253
Part 10
Division 2
r. 10.02......................................	rs. 2011 No. 253
r. 10.03......................................	rs. 2011 No. 253
r. 10.04......................................	rs. 2011 No. 253
r. 10.05......................................	rs. 2011 No. 253
r. 10.06......................................	rs. 2011 No. 253
r. 10.07......................................	rs. 2011 No. 253
r. 10.07A....................................	ad. 2011 No. 253
Division 3
r. 10.08......................................	am. 2011 No. 253
r. 10.09......................................	am. 2011 No. 253
r. 10.10......................................	am. 2011 No. 253
r. 10.11......................................	am. 2011 No. 253
r. 10.12......................................	am. 2011 No. 253; No 238, 2013
r. 10.13......................................	am. 2011 No. 253; No 238, 2013
Division 4
r. 10.14......................................	am. 2011 No. 253
r. 10.15......................................	am. 2011 No. 253
r. 10.16......................................	am. 2011 No. 253; No 238, 2013
Part 11
r 11.01.......................................	am No 238, 2013; F2016L00699; F2021L01556; F2021L01747
r 11.02.......................................	am 2011 No. 198
rep No 238, 2013
r 11.03.......................................	am 2011 No. 198
rep No 238, 2013
r 11.04.......................................	rs 2011 No. 198
rep No 238, 2013
r 11.05.......................................	rs 2011 No. 198
rep No 238, 2013
r 11.06.......................................	rs 2011 No. 198
rep No 238, 2013
Part 11A
Part 11A.....................................	ad No 238, 2013
r 11A.01.....................................	ad No 238, 2013
am F2020L00400
r 11A.02.....................................	ad No 238, 2013
r 11A.02A..................................	ad F2020L01186
r 11A.03.....................................	ad No 238, 2013
am F2022L01679
r 11A.04.....................................	ad No 238, 2013
r 11A.05.....................................	ad No 238, 2013
am F2020L00400
Part 11B
Part 11B.....................................	ad F2020L00400
r 11B.01.....................................	ad F2020L00400
am F2020L01186; F2022L01679; F2023L00997; F2023L01552; F2024L01587
Part 12
r. 12.02......................................	am. 2011 No. 253; No 238, 2013
r. 12.03......................................	am. 2011 No. 253
r. 12.04......................................	am. 2011 No. 253
r 12.05.......................................	am No 253, 2011; No 154, 2015; F2020L00400; F2023L00997
r. 12.06......................................	am. 2011 No. 253
r. 12.07......................................	am. 2011 No. 253
r. 12.08......................................	am. 2011 No. 253
Part 13
Part 13 heading...........................	rs F2016L00699
Part 13.......................................	ad No 238, 2013
Division 1
r 13.01.......................................	ad No 238, 2013
r 13.02.......................................	ad No 238, 2013
r 13.03.......................................	ad No 238, 2013
Division 2
Division 2..................................	ad F2016L00699
r 13.04.......................................	ad F2016L00699
Division 3
Division 3..................................	ad F2024L01422
r 13.05.......................................	ad F2024L01422
Schedule 6
Schedule 6 heading......................	rs F2016L00699
Schedule 6..................................	am No 198, 2011; No 238, 2013; F2016L00699; F2020L01186; F2021L01556; F2021L01747; F2024L01422
ed C17