Offshore Petroleum (Royalty) Act 2006

There are a small number of core concepts that structure the Act's mechanics and the practical interaction between government decision‑makers and the registered holders.

• Registered holder: The person or entity who holds the North West Shelf exploration permit, retention lease or production licence and who is made liable for royalty under s 5. The Act repeatedly frames obligations in terms of the registered holder rather than, for example, the operator or a purchaser.

• Royalty and royalty period: "Royalty" is the monetary amount payable under s 5. For North West Shelf instruments the Act defines "royalty period" as monthly: the period beginning on the day the permit, lease or licence comes into force and ending at the end of that month, and then each later month (s 4 definition). The monthly cadence is a central administrative rhythm for measurement, valuation and payment.

• Value at the wellhead: The base for calculating the royalty is the "value at the wellhead of the petroleum" (ss 6-8, 12). The Act separates the physical location or valve station constituting the wellhead (s 11) from the monetary "value at the wellhead" (s 12). Both the identity of the wellhead and the amount of value are first for parties to agree, and failing agreement the State Minister determines them within a period the Minister allows (ss 11-12).

• Measurement of quantity: The Act makes accurate measurement a statutory precondition for the royalty quantity. Quantity is taken as the amount measured by a device approved by the State Minister and installed at the wellhead or other approved location; if no approved device is installed or the State Minister/Joint Authority is not satisfied the measurement was proper, quantity is what the State Minister determines (s 13).

• Differentiated rate structure: The Act sets a default 10% rate for petroleum recovered under exploration permits (s 7(1)) and retention leases (s 8(1)), and, by item 1 of s 6(1), typically 10% for most production licences. The Act creates a distinct treatment for secondary petroleum production licences: the Joint Authority must determine the applicable rate under s 6(2), subject to the statutory floor and ceiling of 11% and 12.5% (s 6(3)). Primary licences in specific circumstances are linked to the secondary licence rate (s 6(3)-(4)). There are transitional rules tying certain production licence references to earlier legislation (Schedule 1 cl 5).

• Discretionary relief for uneconomic wells: The Act provides a mechanism by which, if the State Minister is satisfied recovery rate from a well has become sufficiently reduced such that recovery would be uneconomic at the statutory royalty rate, the Joint Authority may determine a lower royalty for that well from a specified date (s 9). The Joint Authority may later revoke or vary that determination (s 9(2)-(3)).

• Exemptions and exclusions: The Act exempts royalty in specific factual scenarios only where the State Minister is satisfied certain factual and compliance conditions are met. Examples include unavoidable loss prior to measurement (s 10(1)(a)), use in exploration or recovery operations (s 10(1)(b)), flaring or venting connected to recovery operations (s 10(1)(c)), and return of recovered petroleum to a natural reservoir (s 10(2)). Each of these exemptions requires the State Minister's satisfaction and that the use, flaring/venting or return did not contravene the Offshore Petroleum and Greenhouse Gas Storage Act 2006 or its regulations (s 10(1)(b)(ii), s 10(1)(c)(ii), s 10(2)(e)).

• Provisional values and adjustments: Where value has not been agreed or determined, the State Minister may set a provisional value (s 15). If a later agreement or determination produces a different value, the Act prescribes payment adjustments or refunds (s 16). The adjustment regime covers both situations where provisional values are replaced and where errors occur in calculation or valuation procedures (s 16(1)-(3)).

• Institutional roles: The Joint Authority (an entity established under the offshore petroleum regime) and the State Minister of Western Australia are the named decision makers. The Joint Authority sets or varies rates for secondary licences and issues directions to the State Minister about how the Minister must exercise powers under ss 11-13 (s 14). The State Minister has the determinative power on wellhead, value and quantity in the absence of agreement and may make provisional values (ss 11-13, 15). The State Minister may delegate powers to a Western Australian employee (s 16A).

• Transition and continuity with prior law: The Act expressly preserves the application of the 1967 Petroleum (Submerged Lands) (Royalty) Act for royalty periods that began before the Act's commencement and carries forward instruments made under that 1967 Act as effective under corresponding provisions of this Act (Schedule 1 cl 2-4). The Act also states it re-enacts the 1967 Act with certain modifications (Schedule 1 cl 6).

These main concepts structure the practical obligations and the points at which factual disputes, administrative decision making, and payments will be concentrated.

Primary economic actors affected by the Act are the registered holders of North West Shelf exploration permits, retention leases and production licences. The Act makes those registered holders the liable parties for royalties on petroleum recovered in any royalty period beginning on or after the commencement of s 5 (s 5). That liability attaches regardless of whether the holder is a corporate group member, operator or contractor; the statutory text speaks to the "registered holder".

The State Minister of Western Australia and the Joint Authority are the central public decision-makers under the Act. The State Minister assesses and determines the wellhead, provisional values, final values if parties do not agree, and quantities if measurement is absent or unsatisfactory (ss 11-13, 15). The Joint Authority must determine rates for secondary production licences within prescribed bounds and give directions to the State Minister on how to exercise powers under ss 11-13; the State Minister must comply with those directions (ss 6(2)-(4), 14). The State Minister may delegate powers to an employee of Western Australia (s 16A), which means public servants acting under delegation will execute many of these functions.

Third parties and markets are indirectly affected. Buyers or purchasers of petroleum downstream of the wellhead who enter contracts premised on a particular point of valuation may see that the statutory wellhead or the State Minister's valuation affects tax and royalty incidence at source. Because the Act defines royalty liability at the registered holder level with royalty calculated on value at the wellhead (s 5; s 12), purchasers further along the chain may face pass-through effects in price, contract adjustments or tracing issues if there is dispute over quantity or value.

Regulators and compliance officers under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 are affected because Chapter 1 of that Act applies to this Act in a corresponding way (s 3), and collection is governed by Part 6.7 of that Act (note to s 5). That means enforcement, reporting and possibly offence structures for non-payment are exercised through the offshore petroleum regulatory machinery rather than by separate mechanisms in this Act itself.

Operators and contractors who install measurement devices will be affected by the requirement that the measuring device be approved by the State Minister and installed at the wellhead or another approved place; if no such device is installed, or if the State Minister/Joint Authority are not satisfied with measurement, the State Minister determines quantity (s 13). The requirement that the use, flaring/venting or return of petroleum not contravene the Offshore Petroleum and Greenhouse Gas Storage Act 2006 or its regulations in order to qualify for exemptions (s 10) means compliance teams must ensure operations meet both safety/environmental rules and the conditions for royalty exemption.

Entities seeking secondary petroleum production licences are specifically affected by the rate-determination mechanism in s 6(2)-(4). Applicants must engage with the Joint Authority and be given an opportunity to confer with the State Minister about the rate; the State Minister may report to the Joint Authority and the Joint Authority must consider that report (s 6(4)). Applicants should expect the applicable rate will be within the 11-12.5% band (s 6(3)).

Finally, existing licensees and holders under older instruments are affected by Schedule 1 transitional provisions. Eligible instruments that were in force immediately before commencement and made under the repealed 1967 Act continue in effect as if made under the corresponding provision of this Act (Schedule 1 cl 3). References in leases and permits to "royalty at the prescribed rate" are read as references to the rate under this Act, and the transitional clauses ensure continuity of previously agreed references to prior legislation (s 6(6); ss 7(2), 8(2); Schedule 1 cl 4-5).

Duties and rights in the Act are primarily administrative and financial. The Act sets out who has the duty to pay (registered holder), who has the duty to measure and agree, what rates apply, and which public officials may decide open issues.

Primary duties of registered holders:

• Pay royalty on all petroleum recovered in each royalty period beginning at or after commencement of s 5 (s 5). The note to s 5 directs the reader to Part 6.7 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 for collection mechanisms.
• Ensure quantity measurement is conducted using a measuring device approved by the State Minister and installed at the wellhead or other approved location, where practicable (s 13(a)(i)-(ii)). If the approved device is not installed or the State Minister/Joint Authority is not satisfied with its accuracy, the registered holder is subject to whatever quantity the State Minister determines (s 13(b)).
• Arrange to agree on the wellhead and value at the wellhead with the State Minister (ss 11-12). If there is no agreement within such period as the State Minister allows, the State Minister may determine the wellhead (s 11(b)) and the value (s 12(b)).
• If a secondary petroleum production licence is sought (or granted in connection with a primary licence), engage with the Joint Authority and State Minister in the rate-determination process set out in s 6(2)-(4).

Rights and procedural protections for registered holders:

• The Act gives the registered holder an opportunity to confer with the State Minister about the rate when the Joint Authority is determining the rate for secondary licences, and requires the Joint Authority to give the State Minister an opportunity to report and to consider such a report (s 6(4)). This provides a structured consultative opportunity before the Joint Authority makes its rate determination.
• Where the State Minister determines a provisional value under s 15, the Act provides an adjustment mechanism if a later determination or agreement yields a different value: if the determined royalty is greater than the provisional royalty the difference is payable by the registered holder; if the determined royalty is less the difference is deducted from future payments or refunded (s 16(2)-(3)).
• Exemptions exist that the registered holder can rely upon if the State Minister is satisfied of the facts and compliance with the Offshore Petroleum and Greenhouse Gas Storage Act 2006 and its regulations (s 10). For example, unavoidable loss before quantity is ascertained is expressly exempt (s 10(1)(a)), and use of recovered petroleum in permitted exploration or recovery operations may be exempt if the State Minister is satisfied of both use and regulatory compliance (s 10(1)(b)(i)-(ii)).

Powers of the State Minister:

• Determine the wellhead where agreement is not reached within the period the State Minister allows (s 11(b)).
• Determine the value at the wellhead where parties do not agree within the time the State Minister allows (s 12(b)).
• Approve measuring devices and determine quantities where measurement is absent or unsatisfactory (s 13).
• Make provisional values where value has not been agreed or determined for a royalty period (s 15).
• Satisfy himself or herself about the facts for exemptions (s 10: repeated requirement that State Minister be "satisfied").

Powers of the Joint Authority:

• Determine, by written instrument, the percentage rate of royalty for petroleum recovered under a secondary petroleum production licence in cases covered by s 6(2); that determination must be between 11% and 12.5% (s 6(2)-(3)).
• Issue directions to the State Minister about the manner in which the State Minister exercises powers under ss 11-13; these directions must relate to a particular permit, lease or licence and the State Minister must comply (s 14(1)-(3)).
• Make determinations to reduce royalty for wells that have become potentially uneconomic due to reduced rates of recovery (s 9(2)) and revoke or vary those determinations (s 9(3)).

Form and reviewability:

• Some of the determinations and directions the Act contemplates are expressly not legislative instruments (s 6(5), s 14(4)). The Act does not itself create a right of internal appeal in the text provided; it makes certain instruments determinative and non‑legislative. The State Minister may delegate powers to an employee of Western Australia by written instrument (s 16A), which creates an administrative delegation pathway.

Obligations to comply with other statutes:

• Certain exemptions are conditional on the use, flaring/venting, or return actions not contravening the Offshore Petroleum and Greenhouse Gas Storage Act 2006 or regulations under that Act (s 10(1)(b)(ii), s 10(1)(c)(ii), s 10(2)(e)). The Act also applies Chapter 1 of that Act to this Act in a corresponding way (s 3), which imports definitions and potentially other procedural provisions.

Transitional rights:

• Instruments in force immediately before the commencement that were made under the repealed 1967 Act continue to have effect as if made under the corresponding provision of this Act (Schedule 1 cl 3). The Act therefore protects holders who had pre‑existing instruments from losing their operation by the repeal.

The Act combines concrete fiscal obligations for registered holders with administrative rights to be consulted and to have provisional valuation adjustments, while giving the State Minister and the Joint Authority significant powers to make determinations where parties do not reach agreement.

The Offshore Petroleum (Royalty) Act 2006 is tightly focused on liability and valuation; it does not itself set out a comprehensive offences and penalty schedule in the text provided. Instead, the Act points to the enforcement and collection machinery in the Offshore Petroleum and Greenhouse Gas Storage Act 2006. The most explicit cross‑reference is the note in s 5: "For collection of royalty, see Part 6.7 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006." That means the operational enforcement mechanisms, including notices, assessments, penalties, interest, recovery processes and any criminal or civil offence provisions that apply to non‑payment or non‑compliance will generally be found in Part 6.7 of that external Act rather than in this Act.

What the text here does provide about enforcement and remedies includes:

• Adjustment and refund procedure for differences arising from provisional values or errors in calculation (s 16). That prescribes who pays the shortfall and when refunds or deductions are required, which is an administrative remedial mechanism rather than a punitive one.
• The Joint Authority's and State Minister's powers to determine or re-determine wellhead, value and quantity where measurement or agreement is absent (ss 11-13) operate as enforcement levers because their determinations are binding in the absence of agreement. The practical enforcement effect is that the public decision-maker can fix the variables that determine liability.
• The Joint Authority may reduce royalty for potentially uneconomic wells or revoke/ vary those determinations (s 9(2)-(3)), which is a discretionary relief mechanism rather than a penalty.

Absent from the text:

• The Act as provided does not itself specify late payment penalties, interest rates, offence provisions (criminal or civil) for failing to pay royalty, or explicit administrative sanctions such as suspension of licences. Those matters are, according to the note in s 5, to be managed under the offshore petroleum Act's Part 6.7. Users needing the concrete penalty rates and enforcement steps must therefore consult the Offshore Petroleum and Greenhouse Gas Storage Act 2006 Part 6.7, which the Act imports for collection.

Practical enforcement implications derived from the Act's structure:

• Because the Act permits the State Minister to determine provisional values and to determine quantity where measurement is absent or inadequate (ss 13, 15), registered holders face immediate exposure to administrative decisions that fix their liability. That means effective dispute-resisting capability requires engaging early to agree values and install approved meters so that the Minister does not determine these variables unilaterally.
• Determinations and directions made by the Joint Authority and the State Minister are specified in the Act to be "written instruments" and certain categories are expressly not legislative instruments (s 6(5), s 14(4)). The absence of legislative instrument status may have implications for parliamentary disallowance regimes and administrative transparency; however, the Act does not itself specify review avenues, judicial review rights, or appeal mechanisms within its text.

In practice, enforcement therefore depends on the interplay between the royalty calculations here and the collection, notice, interest and penalty provisions in the offshore petroleum statute. For legal advice or compliance work on penalties, the Act directs the practitioner to the collection provisions in Part 6.7 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006.

The Act operates within a network of other Commonwealth and state legislation; it expressly imports definitions, relies on enforcement machinery elsewhere, and preserves continuity with prior legislation.

• Integration with the Offshore Petroleum and Greenhouse Gas Storage Act 2006: Section 3 states that Chapter 1 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 applies to this Act "in a corresponding way" to the way it applies to that Act. The Act notes this means definitions in s 7 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 apply to this Act. That importation of definitions and possibly other Chapter 1 provisions is central for interpreting terms such as "registered holder", and for the interplay of powers, administrative processes and possibly appeal or review mechanisms that are set out in that Act. The collection machinery is also separately referenced: s 5's note points readers to Part 6.7 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 for collection of royalty.

• References to the Petroleum Resource Rent Tax Assessment Act 1987: The Act uses the phrases "North West Shelf exploration permit", "North West Shelf production licence" and "North West Shelf retention lease", defined by cross‑reference to the Petroleum Resource Rent Tax Assessment Act 1987 (s 4 definitions). That means the set of instruments subject to this royalty regime aligns with the taxpayer-defined North West Shelf instruments in revenue law. Practically, holders and advisers need to reconcile their standing under both the royalty Act and the PRRT Assessment Act definitions.

• Compliance condition tied to Offshore Act regulations: Exemptions in s 10 are conditioned on uses, flaring/venting, or returns not contravening the Offshore Petroleum and Greenhouse Gas Storage Act 2006 or regulations under that Act (s 10(1)(b)(ii), s 10(1)(c)(ii), s 10(2)(e)). This makes compliance with the Offshore Act's regulatory regime (safety, environment, operational permits) a precondition for relief under the royalty Act.

• Continuity with the Petroleum (Submerged Lands) (Royalty) Act 1967: Schedule 1 contains transitional provisions preserving application of the 1967 Act for royalty periods that began before the new Act's commencement, and it carries forward instruments made under that Act into the new regime where they were in force immediately before commencement (Schedule 1 cl 2-3). Schedule 1 cl 4-5 and cl 6 address how the new provisions should be read to include references to the repealed Act, and it expressly states the Act re-enacts the 1967 Act with certain modifications (Schedule 1 cl 6). This design minimises disruption for holders with rights or obligations that originated under the 1967 Act.

• Acts Interpretation Act 1901: The Schedule 1 note references s 15AC of the Acts Interpretation Act 1901 about differences in drafting style not changing substance. This standard interpretive pointer is included to assist readers dealing with language shifts between the 1967 Act and the 2006 Act.

• Delegation and State law interface: The Act allows the State Minister to delegate powers to an employee of Western Australia (s 16A). That provision creates an administrative bridge to state public servants executing Commonwealth duties, and it will interact with state public service rules and delegations. The Joint Authority, which has directions and rate-determination powers (ss 6, 14), is an entity set up under the offshore regulatory framework; its function and membership will be defined under those other statutes.

• Non‑legislative instruments and parliamentary oversight: The Act expressly states that certain determinations and directions under the Act are not legislative instruments (s 6(5), s 14(4)). The practical effect is that those instruments fall outside the Parliamentary Instruments Act's disallowance procedure for legislative instruments. That difference in status has consequences for scrutiny, but any procedural or judicial review implications lie in administrative law doctrines outside the Act's text.

• Interaction with taxation and contractual regimes: While the Act stands as a fiscal instrument imposing royalty, it is silent on interaction with income tax, PRRT, or purchaser contracts. However, because the Act bases royalty on "value at the wellhead" (s 12), and because the PRRT legislation uses related definitional machinery, there is likely practical interplay between royalty calculations and other fiscal regimes. The Act does not itself dictate how royalties interact with contractual pricing down the chain; that will be a matter of commercial negotiation and, where relevant, other statutes.

Overall, the Act is designed to sit within the Commonwealth's offshore petroleum regulatory and collection framework, leaning on definitions, collection powers and regulatory compliance duties established in the Offshore Petroleum and Greenhouse Gas Storage Act 2006 and maintaining continuity with the repealed 1967 Act.

The body of text provided contains the original commencement and transitional provisions from when the Act was enacted in 2006 and re-enacted elements of the 1967 regime. The Act's commencement schedule shows a staged commencement:

• Sections 1 and 2 and anything not otherwise covered in the commencement table commenced on the day the Act received Royal Assent, 29 March 2006 (Commencement table, item 1).
• Sections 3 to 17 and Schedule 1 commenced "at the same time as Chapter 2 of the Offshore Petroleum Act 2006 commences", which is dated 1 July 2008 in the commencement table (Commencement table, item 2 and item 3 for Schedule 1).

Schedule 1 contains transitional provisions that preserve the operation of the Petroleum (Submerged Lands) (Royalty) Act 1967 for royalty periods that began before the commencement of the new Act (Schedule 1 cl 2). It also preserves the effect of instruments made under the repealed 1967 Act, treating them as if made under corresponding provisions of the new Act (Schedule 1 cl 3). The Schedule provides guidance on how to identify corresponding provisions (Schedule 1 cl 3(4)) and specific transitional readings for references to "royalty at the prescribed rate" and certain references in s 6(1) (Schedule 1 cl 4-5). Schedule 1 concludes by stating that the Act re-enacts the 1967 Act with certain modifications, citing the interpretive assist under s 15AC of the Acts Interpretation Act 1901 (Schedule 1 cl 6).

The text provided does not include any later amendments, insertions or repeals post‑original enactment. No amending Acts, dates of amendment, or updated text markings are present in the source supplied. Therefore, the Amendment history as recorded in the Act itself is limited to the original enactment and the staged commencement that tied parts of this Act to the commencement of Chapter 2 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006.

Readers requiring the subsequent statutory history, including any legislative amendments, should consult the consolidated statute on the Australian Government's legislation database or official parliamentary amendment records. The Act as provided in this source must be treated as the text as originally passed with the transitional modifications set out in Schedule 1.

The text of the Offshore Petroleum (Royalty) Act 2006 provided contains no case citations, no references to judicial interpretation, and no litigation history. The Act itself does not list court decisions or administrative appeal outcomes. The schedule and notes mention prior legislation and interpretive aids (for example, s 15AC of the Acts Interpretation Act 1901), but do not identify any judicial rulings that have construed the Act.

Because the Act creates multiple discretionary determinations by the State Minister and Joint Authority, and because it imports enforcement and collection procedures by reference to the Offshore Petroleum and Greenhouse Gas Storage Act 2006, litigation or administrative review may have occurred in practice on points such as:

• disputes about the correct wellhead location under s 11 where parties failed to agree and the State Minister determined the valve station;
• disagreements over valuation methodology and the State Minister's determination under s 12;
• contesting the State Minister's determination of provisional value under s 15 and resultant s 16 adjustments;
• measurement disputes arising under s 13 where the State Minister or Joint Authority is not satisfied with installed measuring devices;
• challenges to the Joint Authority's rate determinations for secondary licences under s 6(2)-(4);
• reviews of s 9 determinations reducing royalty for potentially uneconomic wells.

However, none of those hypothetical litigation types are recorded in the Act's text. The Act's own structure,especially the specification that certain instruments are not legislative instruments (s 6(5), s 14(4)),could shape the form of judicial review or other review rights in practice, but the Act does not elaborate review procedure or remedy.

For a practitioner or researcher seeking the litigation history that bears on the interpretation or application of this Act, the appropriate next step is to search judicial databases and administrative tribunal records for decisions mentioning the Offshore Petroleum (Royalty) Act 2006, Joint Authority determinations under s 6 or directions under s 14, and any enforcement actions that relied on Part 6.7 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006. The Act itself contains no litigation record in the materials supplied here.

The Act contains multiple technical points and discrete administrative traps where a registered holder or adviser could be surprised if they treat the statutory framework as straightforward.

1. Agreement versus determination is asymmetric and time‑limited

• For both the wellhead and the value at the wellhead, the statutory process places the initial onus on agreement between the registered holder and the State Minister (ss 11-12). However, if the parties fail to agree within "such period as the State Minister allows" the State Minister can determine the wellhead or value unilaterally (ss 11(b), 12(b)). The Act does not specify the length of the period; it is at the Minister's discretion. Registered holders who do not reach agreement risk a Ministerial determination that may be less favourable than commercial expectations.

2. Measurement device approval is a bottleneck

• Quantity becomes a State Minister-determined figure if there is no measuring device approved by the State Minister and installed at the wellhead, or if the State Minister or the Joint Authority is not satisfied with the adequacy of the measuring device or its measurement (s 13). This makes the timely approval and installation of State Minister‑approved meters critical to avoid adverse determinations. Operators relying on conventional industry meters should not assume those meters meet the statutory approval requirement.

3. Non‑legislative status of important instruments

• Certain determinations and directions are expressly not legislative instruments (s 6(5), s 14(4)). That has procedural implications: for instance, such instruments do not attract parliamentary disallowance procedures. Parties should treat written instruments under s 6(2) or directions under s 14(1) as administrative decisions with potential but not automatic statutory avenues for review.

4. Differing rate regimes across licence types; secondary licences attract higher band

• While the default royalty for exploration permits and retention leases is 10% (ss 7(1), 8(1)), secondary petroleum production licences are subject to a Joint Authority-determined rate which must be between 11% and 12.5% (s 6(2)-(3)). Primary licences tied to secondary licences become subject to the same percentage from the beginning of the next royalty period after the secondary licence takes effect (s 6(1) item 3). This creates a discontinuity where certain holders can move from 10% to at least 11% by virtue of secondary licence arrangements. Applicants for secondary licences should expect a nomination and negotiation process with the Joint Authority and the State Minister (s 6(4)).

5. Provisional values can lead to cash flow volatility

• The State Minister can set a provisional value in the absence of agreement (s 15). If the later agreed or determined value is different, s 16 requires adjustments: additional payments if the determined royalty is greater, and deductions or refunds if lower (s 16(2)-(3)). That provisional-determination and reconciliation regime can cause cash flow volatility, especially if provisional values are conservatively high.

6. Exemptions contingent on compliance with the Offshore Act

• The exemptions for use during operations, flaring/venting, or return to reservoir all require State Minister satisfaction and explicit compliance with the Offshore Petroleum and Greenhouse Gas Storage Act 2006 and its regulations (s 10). A registered holder cannot rely on an exemption if the underlying use or flaring contravened regulatory obligations elsewhere. Operational teams must ensure environmental and regulatory compliance to keep exemption options open.

7. Joint Authority directions to the State Minister are binding

• The Joint Authority must give directions to the State Minister about the manner in which the Minister exercises powers under ss 11-13 and the State Minister must comply (s 14(1)-(3)). Practically, the Joint Authority can shape how measurements, wellhead definitions and valuations are made, even though the State Minister retains the power to determine these matters in the absence of agreement. Understanding the Joint Authority's likely policies and direction practices is therefore essential to anticipate outcomes.

8. Transitional instruments preserved but require mapping

• Schedule 1 cl 3 preserves "eligible instruments" that were in force under the 1967 Act and treats them as if made under corresponding provisions of this Act. However, that requires a comparison of substance to determine "corresponding provision" (Schedule 1 cl 3(4)). Parties relying on historical instruments should ensure they can map the old instruments to the new framework explicitly.

9. No penalty schedule in this Act , look to Part 6.7

• The Act omits explicit penalty, interest, and recovery provisions, instead referring to Part 6.7 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 for collection (note to s 5). Failing to consult that Part can lead practitioners to miss interest accruals, payment notice requirements, or enforcement triggers that are binding in practice.

10. Delegation to state employees

• The State Minister may delegate powers to an employee of Western Australia (s 16A). That means statutory decisions may be made by state public servants under delegated authority. Understanding who holds delegated authority in practice is important when engaging with the decision-making process.

Each of these "gotchas" follows directly from the statutory language. Advisers should treat the Act as creating many decision points where public determinations, not market negotiations, can fix critical variables.

A practical compliance checklist, grounded in the Act's provisions, focuses on measurement, agreement processes, record-keeping, engagement with the Joint Authority and State Minister, and managing provisional-values risk.

1. Confirm instrument coverage and registration

• Verify that you are the "registered holder" of a North West Shelf exploration permit, retention lease or production licence as defined by cross‑reference to the Petroleum Resource Rent Tax Assessment Act 1987 (s 4 definitions) and ensure registration details are up to date since the registered holder is the party liable under s 5.

2. Measurement devices and approval

• Install a measuring device approved by the State Minister at the wellhead or another location approved by the State Minister (s 13(a)(i)-(ii)). Do not assume industry standard meters are acceptable; obtain explicit approval and keep documentation of approval and installation. Maintain calibration and inspection records in the event the State Minister or the Joint Authority challenges measurement accuracy (s 13(b)).

3. Agree on the wellhead location

• Seek to agree the valve station constituting the "wellhead" with the State Minister as soon as practicable (s 11(a)). Agreement removes uncertainty and reduces the risk of the State Minister later determining a less favourable point. Record any agreed written instrument specifying the wellhead and retain the State Minister's written acknowledgement.

4. Negotiate value at the wellhead

• Work with the State Minister to agree a method and an amount for "value at the wellhead" for each product stream (s 12(a)). Agreement avoids the State Minister's unilateral determination. If an agreement cannot be reached, be prepared for the Minister to set a value within the period the Minister allows (s 12(b)) and for provisional valuation under s 15 if the Minister does so for any royalty period.

5. Prepare for provisional valuations and adjustments

• If a provisional value is set under s 15, plan for potential post‑period adjustments under s 16. Maintain sufficient financial controls to pay additional sums if the determined royalty exceeds the provisional royalty (s 16(2)), and document and track any credits for refunds or deductions if the determined royalty is lower (s 16(3)).

6. Engage early with the Joint Authority on secondary licences

• If applying for a secondary petroleum production licence, expect a Joint Authority rate determination under s 6(2) and the statutory floor/ceiling of 11-12.5% (s 6(3)). Use the opportunity under s 6(4) to confer with the State Minister and prepare submissions that address the State Minister's and Joint Authority's likely considerations. Record meetings and any Ministerial report to the Joint Authority.

7. Ensure regulatory compliance to preserve exemptions

• If relying on exemption categories (s 10) , for example, use in operations, flaring/venting, return to reservoir , ensure every action is carried out in accordance with the Offshore Petroleum and Greenhouse Gas Storage Act 2006 and its regulations. Maintain contemporaneous records, incident reports and approvals demonstrating that the relevant activity did not contravene that Act or its regulations (s 10(1)(b)(ii), s 10(1)(c)(ii), s 10(2)(e)).

8. Monitor Joint Authority directions and State Minister instruments

• Track written instruments from the Joint Authority (rate determinations under s 6(2), reductions under s 9) and directions to the State Minister under s 14. Even where instruments are not legislative instruments (s 6(5), s 14(4)), they are binding and operational. Seek clarification on their practical effect and retain records of compliance with any directions.

9. Keep meticulous records for audits and collections

• Because collection is via Part 6.7 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 (note to s 5), ensure all production records, meter data, calibration certificates, custody transfer documents, and correspondence with the State Minister and the Joint Authority are retained in line with the offshore Act's recordkeeping and production reporting requirements.

10. Establish internal escalation and review pathways

• Given the Ministerial and Joint Authority decision points, set internal escalation for disagreements (e.g. disagreements about meter accuracy or valuation) so that legal, commercial and technical teams are engaged early. Consider preparing contemporaneous technical validation reports to support agreements or to challenge Ministerial determinations where appropriate through available administrative or judicial review channels external to this Act.

11. Identify delegated decision‑makers

• Confirm whether the State Minister has delegated powers under s 16A to particular employees of Western Australia; if so, address correspondence to the appropriate delegate and note delegation instruments for audit trail purposes.

12. Coordinate tax and contractual consequences

• Because the Act bases royalty on the value at the wellhead (s 12) and cross-refers to PRRT instrument definitions (s 4), coordinate compliance with tax, PRRT and contractual obligations. Ensure that purchase and sales contracts and internal transfer pricing reflect the potential for Ministerial valuation and provisional adjustment.

13. Prepare submissions for s 9 relief if required

• If a well's rate of recovery falls such that continued recovery would be uneconomic at the applicable royalty rate, prepare a factual and economic submission to the State Minister to seek a Joint Authority determination for reduced royalty under s 9(1)-(2). Expect that the State Minister must be "satisfied" the rate of recovery has become so reduced (s 9(1)), so build empirical reservoir and forecasting evidence.

14. Map legacy instruments and transitional rights

• If holding instruments under the old 1967 Act or instruments that commenced before the Act's commencement, map those "eligible instruments" to the corresponding provisions of this Act under Schedule 1 cl 3 so that rights and obligations are understood to continue.

Compliance under this Act is therefore a blend of technical metering and valuation work, administrative negotiation with the State Minister and the Joint Authority, and recordkeeping to support exemptions and adjustments. The central compliance strategy is to convert discretionary decision points into agreed written positions where possible and to maintain technical evidence to defend measurements and valuation positions.