The regulation’s conceptual architecture rests on a small set of statutory constructs and decision points. Those constructs are: the distribution network code, the role of QCA in proposing and consulting on code changes, the distributor’s operational powers and duties regarding disconnection and reconnection, and the imposition and collection of fees tied to distribution authorities.

Distribution network code and proposals (Part 3)

• A “proponent” is any person who may ask QCA to amend a distribution network code (s 25). The proponent must make the proposal in the form QCA reasonably requires and may be required to justify how the proposal meets the QCA code objective (s 25(2)-(3)). QCA must decide within two months whether to submit the proposal for consultation (s 26(2)), and if it chooses to submit, it can do so in any form and with or without change (s 26(3)).
• The consultation architecture comprises two subdivisions. Subdivision 2 (interim consultation) prescribes an interim consultation notice, an issues document, and an interim consultation period during which written submissions may be made (ss 32-34). Subdivision 3 (final consultation) prescribes publication of a draft report and draft proposed code, a final consultation notice, a final consultation period for submissions, and a requirement that QCA consider submissions and publish a final report and final code (ss 35-39). The regulation permits the final consultation steps to apply even where subdivision 2 did not (s 36(1)).
• Exceptions: the detailed consultation steps in subdivision 2 do not apply if QCA decides the issues are minor or if QCA reasonably considers it unnecessary or inappropriate to carry out those steps (s 31).

Disconnection and reconnection (Part 4)

• Part 4 applies to a distributor’s gas infrastructure that is not a distribution system under the NERL (Qld) (s 40). Rights to disconnect are subject to any relevant distribution network code limitations or conditions (s 41).
• The regulator authorises specific grounds for disconnection (s 43) including emergency, compliance with dangerous situation directions under the Petroleum and Gas (Production and Safety) Act, urgent safety work, scheduled work where reasonable notice is given, contractual grounds, insufficiency of supply directions, failure to provide safe access required under s 130 of the Act, unlawful taking of gas, and retailer requests. Two local government distributors (Maranoa and Western Downs) are explicitly noted where their exemptions allow disconnection (s 43(j)-(k)).
• Timelines: a distributor must comply with a retailer disconnection request within five business days unless it reasonably believes compliance would be unsafe or impractical (s 46). Reconnection after disconnection must be effected within five business days upon a retailer’s notice, provided installations and meters comply with requirements under the Petroleum and Gas (Production and Safety) Act and any other Act; reconnection obligations are subject to limits under s 109 of the Act (s 47).

Fees and fiscal variables (Part 5)

• The annual distribution fee is prescribed under s 40(b) of the Act and set out in s 51. For authorities operating less than 100 km of pipelines immediately before the financial year starts, the fee is fixed at 812.60 fee units (s 51(2)). For larger operators, the fee is calculated using a specified formula with variables DF (dollar amount), P (length in km of pipelines under the authority immediately before the financial year started) and TP (total length in km of all pipelines operated under any distribution authority immediately before the financial year started) (s 51(3)). Fees are payable on the date fixed by regulator notice (s 51(6)-(8)). Subsection (5) requires rateable reduction where an authority takes effect after the financial year starts.

Cross‑cutting and miscellaneous ideas

• The regulation ties consultation for pricing investigation reports to the distribution network code consultation model (s 55), making that model the default procedural route for key pricing processes under the Act.
• Exemptions are narrowly defined: s 55A exempts holders of the two specifically enumerated distribution authorities from registration under the National Gas (Queensland) Law, s 91LB(2), and preserves the ability of those councils to participate in the retail gas market in registrable capacities (s 55A(2)).
• Many sections are marked as omitted or amended in later statutory instruments; the instrument contains amendment-history annotations (for example, many sections are "om 2014 SL No. 338 s 42" or "amd 2014 SL No. 338 s 44"). The 2003 regulation is explicitly repealed (s 56).

These concepts create a regulatory space where procedural due process (consultation steps), operational discretion (reasonable belief thresholds for disconnection), and fiscal obligations (annual fees) interact. The rules are framed to balance a centralised code-making and consultation function (QCA) against distributor operational needs and retailer/distributor interactions for connection services. The regulation repeatedly ties operational duties to compliance with the Petroleum and Gas (Production and Safety) Act and the Act itself, embedding cross‑statutory dependencies that distributors and retailers must manage.

Primary regulated actors

• Distribution authority holders: every holder of a distribution authority is liable for the annual distribution fee under s 51. The fee mechanics (fixed minimum fee for authorities operating less than 100 km, formula for larger networks and pro rata adjustments where authorities commence mid‑year) mean all authority holders are financially affected and must track pipeline lengths as at "immediately before the financial year starts" (s 51(2)-(5)).
• Distributors: Part 4 applies to distributors in relation to gas infrastructure that is not a NERL (Qld) distribution system (s 40). Distributors are the party given explicit rights to disconnect premises on enumerated grounds (s 42-43), and they carry the obligations to comply with retailer disconnection requests within five business days (s 46) and to reconnect within five business days when conditions are met (s 47). Distributors are also subject to limitations in any applicable distribution network code (s 41).

Secondary regulated actors and stakeholders

• Retailers: retailers can trigger disconnection and reconnection by giving notices to the distributor (s 43(i), s 47). Section 48 recognises the retailer as a potential claimant for compensation if a distributor contravenes s 46 or s 47; specifically, for section 46 the retailer who made the disconnection request, and for section 47 the retailer that requested reconnection, may claim damages for cost, damage or loss caused by the contravention (s 48(1)(b)-(c), s 48(2)-(3)). Retailers therefore gain an enforcement tool and are parties to operational timelines.
• Customers (end users): customers whose premises are disconnected or require reconnection are directly affected. They are explicit claimants under s 48(1)(a) where they suffer loss from a distributor’s failure to disconnect or reconnect in accordance with the statutory timelines. Customers are also subject to distributor action for lack of safe access under s 130 of the Act (s 43(g)).
• Proponents and interested persons: any person may propose amendments to a distribution network code (s 25). The consultation provisions require QCA to publish notices and give them to anyone it reasonably believes will be interested (ss 32(1)(c), 36(3)). Interested persons, including industry participants, consumer groups and local government entities, are therefore brought into the procedural loop.
• QCA: QCA is the central decision‑maker for the code process. It receives proposals (s 25), decides whether to submit them for consultation within two months (s 26), prepares consultation notices and reports (ss 32, 35, 36) and may make amendments on its own initiative (s 28). QCA also fixes the fee payment day by notice (s 51(6)).
• Maranoa Regional Council and Western Downs Regional Council: the regulation contains specific references to these councils both in the disconnection grounds (s 43(j)-(k)) and in the exemption from registration for market participation (s 55A). Those councils, as holders of particular distribution authorities, are subject to special treatment under the regulation: they can disconnect where their exemption from requiring a retailer authorisation under NERL (Qld) allows it (s 43(j)-(k)), and holders of those distribution authorities are exempted from registration under the National Gas (Queensland) Law, s 91LB(2) (s 55A(1)-(3)).

Indirectly affected entities

• The regulator’s staff and contractors: administrative obligations to prepare notices, publish material on a website, and consider submissions (ss 32-39) create workload and process responsibilities.
• Parties affected by cross‑referenced regimes: the regulation repeatedly cross‑references the Petroleum and Gas (Production and Safety) Act and the NERL (Qld). Operators and service providers who supply or maintain meters, installations and safety compliance systems are indirectly affected because reconnection (s 47) is conditional on compliance with those Acts.

Who pays and who may receive compensation

• Fee payers are the holders of distribution authorities (s 51). Compensation recipients under s 48 include customers seeking reconnection and the retailer who made or requested the relevant disconnection/reconnection notice.

Who decides

• QCA decides which proposals are submitted for consultation and may set form and content requirements on proponents (ss 25-26). QCA also controls the consultation timetable and publication of draft and final reports/codes (ss 32-39), and fixes the day by notice on which fees are payable (s 51(6)). Distributors decide on disconnection in the exercise of the statutory grounds but subject to the “reasonable belief” standard (s 42(2)) and subject to any relevant distribution network code limitations (s 41). Courts decide compensation claims where a distributor is alleged to have contravened s 46 or s 47 (s 48(3)).

In short, this regulation affects distribution authority holders financially, places operational duties on distributors, gives retailers procedural leverage over disconnection/reconnection, channels participation through QCA consultation steps, and creates limited exemptions for specified local councils.

This section lists the principal duties imposed and rights conferred by the regulation, with the operative cross‑references.

QCA’s duties and powers

• To accept proposals to amend a distribution network code from any person, as long as the proposal is made in the manner QCA reasonably requires (s 25(1)-(2)). QCA may require the proponent to justify how the proposal meets the QCA code objective (s 25(3)).
• To decide within two months whether to submit a proposal for consultation under Part 3 Division 2, provided the procedural requirements in s 25 have been complied with (s 26(1)-(2)). If it submits the proposal, QCA may do so in any form and may change it (s 26(3)).
• To prepare and publish an interim consultation notice and give it to anyone reasonably believed to be interested, and to identify where an issues document may be inspected and provide an interim consultation period for submissions (s 32). QCA must consider submissions made within that period (s 34).
• To publish a draft report and draft proposed code on its website after considering interim submissions (s 35).
• To prepare and publish a final consultation notice, give it to those reasonably believed to be interested, state where drafts may be inspected, and provide a final consultation period (s 36). QCA must consider final submissions (s 38) and then publish a final report and final version of the proposed code (s 39).
• QCA may amend a distribution network code on its own initiative; the consultation division does not prevent that (s 28).
• QCA has discretion to consider issues minor and skip certain consultation steps where it reasonably considers it unnecessary or inappropriate (s 31).

Distributor duties and rights (Part 4)

• Right to disconnect premises: a distributor may disconnect the premises of a customer on grounds enumerated in s 43. The disconnection may be to the extent and for the period the distributor reasonably believes is appropriate (s 42(1)-(2)).
• Grounds for disconnection include: emergency or health/safety reason; a dangerous situation direction under the Petroleum and Gas (Production and Safety) Act; urgent work to prevent emergency/health/safety incidents; scheduled work to the distributor’s distribution system where it is reasonably required, done at a reasonable time, and the person is given reasonable notice; grounds under a connection contract; customer connection services denied under insufficiency of supply directions; failure to provide safe access as required under s 130 of the Act; unlawful taking of covered gas (contravention of s 289 of the Act or s 809 of the Petroleum and Gas (Production and Safety) Act); retailer disconnection requests; and special grounds for Maranoa and Western Downs councils where their exemptions permit (s 43).
• Obligation to comply with retailer disconnection requests within five business days, unless the distributor reasonably believes it would be unsafe or impractical to comply (s 46).
• Obligation to reconnect within five business days after receiving a reconnection notice from a retailer, provided meters and installations comply with statutory safety requirements (s 47(2)). Reconnection obligations are subject to limits on the distributor’s obligation to provide customer connection services under s 109 of the Act (s 47(3)) and, where no connection contract applies, reconnection must be on fair and reasonable terms (s 47(4)).

Compensation and legal remedy

• If a distributor contravenes s 46 or s 47 and a claimant (customer seeking reconnection, the retailer who asked for disconnection under s 46, or the retailer who requested reconnection under s 47) suffers loss, compensation for that loss is payable by the distributor; the compensation may be claimed and ordered in a court of competent jurisdiction (s 48(1)-(3)).

Fee obligations

• Annual distribution fee payable by each holder of a distribution authority in each financial year that the authority is in force, with the standard for small pipelines (<100 km) set at 812.60 fee units (s 51(1)-(2)).
• For authorities with 100 km or more of pipelines immediately before the financial year starts, the annual distribution fee is determined by a prescribed formula using variables DF (dollars), P (length in km of pipelines under the authority immediately before the financial year), and TP (total length in km of all pipelines under any distribution authority immediately before the financial year) (s 51(3)). The fee is rateably reduced for authorities that take effect after the start of the year (s 51(5)).
• The fee is payable on the day fixed by the regulator by notice to the holder (s 51(6)-(8)).

Procedural and publication duties

• Publication on the regulator’s website of consultation notices, draft reports, draft codes and final reports and codes at the appropriate stages (ss 32(1)(b), 35(1), 36(2), 39).
• Delivery of consultation notices to “anyone [QCA] reasonably believes will be interested” (ss 32(1)(c), 36(3)).

Rights to propose and to be heard

• Any person may ask QCA to amend a distribution network code (s 25(1)).
• Anyone may make written submissions during the interim consultation period (s 33) and the final consultation period (s 37).

Exceptions and qualifications

• Subdivision 2 does not apply if QCA decides the issues are minor or if QCA reasonably considers it unnecessary or inappropriate to carry out the steps (s 31). However, prescribed consultation for a pricing investigation report is the consultation under Part 3 Division 2 and subdivision 2 applies despite s 31 (s 55).

Cross‑statutory dependencies

• Reconnection requires compliance with the Petroleum and Gas (Production and Safety) Act and any other Act (s 47(2)).
• Disconnection rights are subject to relevant distribution network code limitations or restrictions (s 41).
• The exemption from registration in s 55A interacts with the National Gas (Queensland) Law, s 91LB(2) and s 91LA.

These duties and rights structure operational timelines, create administrative publication duties, impose financial obligations on authority holders and provide private remedies for specified failures by distributors.

The regulation itself contains limited express penalty provisions; enforcement mechanisms are a mix of administrative duties, private rights of action and cross‑references to other statutory regimes.

Express enforcement mechanisms in this regulation

• Private civil remedy for breaches of disconnection/reconnection timelines: Section 48 creates a cause of action for compensation where a distributor contravenes s 46 or s 47 and certain persons suffer loss. The provision specifies who may be claimants (the person wanting reconnection, the retailer who made the disconnection request for s 46, and the retailer who requested reconnection for s 47) and directs that compensation may be claimed and ordered in a court of competent jurisdiction (s 48(1)-(3)). This operates as a private enforcement mechanism rather than an administrative penalty.

Administrative/operational enforcement (procedural duties)

• QCA has procedural duties to publish consultation materials and consider submissions (ss 32-39). The regulation does not itself specify statutory fines or administrative penalties directly for non‑performance of those QCA duties. Instead, compliance is framed as statutory obligations on QCA; failure to follow the prescribed steps could be subject to judicial review or other remedies available under general administrative law, though the text does not describe those remedies.

Financial enforcement

• Section 51 requires payment of the annual distribution fee on the day fixed by the regulator by notice to the holder. The regulation does not in these excerpts specify late payment penalties, interest or enforcement mechanisms for non‑payment; those mechanisms may be detailed in the Act or in other instruments, but are not in the supplied text. The regulation does, however, require the regulator to fix the payment day by notice (s 51(6)-(8)), which gives the regulator an administrative control point for collection.

Interaction with other enforcement regimes

• Several operative duties are explicitly qualified by obligations under other statutes. Reconnection is conditional on compliance with the Petroleum and Gas (Production and Safety) Act and "any other Act" (s 47(2)). Disconnection may be ordered under a dangerous situation direction under the Petroleum and Gas (Production and Safety) Act (s 43(b)). Distributors’ rights and duties are also subject to any relevant distribution network code limitations (s 41) and limits on obligations to provide customer connection services under s 109 of the Act (s 47(3)). Those cross‑referenced Acts and provisions may carry their own enforcement regimes, criminal offences, contraventions and administrative penalties; enforcement of those would proceed under those statutes rather than this regulation.

Discretion and judicial oversight

• Many obligations in the regulation are qualified by “reasonable belief” or “reasonable” standards (for example, disconnection extent and period under s 42(2), QCA requiring proposals be made in the way it reasonably requires s 25(2), and QCA reasonably considering it unnecessary to carry out consultation steps s 31). Those standards import observer subjectivity into enforcement considerations. Where disputes arise over whether a distributor reasonably believed compliance would be unsafe or impractical (s 46), or whether QCA acted reasonably in declining consultation steps, the enforcement route would likely be judicial review or civil proceedings based on the particular cause of action (for distributors, private compensation actions under s 48, and potentially other remedies in the Act or external judicial review).

No criminal penalties in the excerpt

• The regulation text provided does not specify criminal penalties. The only express monetary remedy contained in the regulation itself is the compensatory remedy in s 48. Other penalties for contraventions of related safety or gas laws are referenced (for example, unlawful taking of gas under s 289 of the Act or s 809 of the Petroleum and Gas (Production and Safety) Act), but those penalty regimes are in their respective Acts and not set out here.

Practical enforcement implications

• The immediate practical enforcement tool for market participants affected by distributor failure to meet disconnection/reconnection timing is a court action for compensation (s 48). For administrative non‑compliance by QCA with consultation steps, remedies are not specified and would depend on administrative law principles or provisions in the Act. For fee collection, the regulator has the power to fix the payable day by notice (s 51(6)), but enforcement consequences for non‑payment are not specified in the supplied text and would require consultation of the Act or other instruments.

In summary, enforcement within the regulation is focused on private compensatory remedies for specified operational failures and administrative publication and duty obligations, with broader enforcement of safety and unlawful taking reserved to other statutes referenced in the instrument.

This regulation is tightly interwoven with the Act it implements and with other gas and safety statutes. The text repeatedly cross‑references the Act, the Petroleum and Gas (Production and Safety) Act, NERL (Qld), and the National Gas (Queensland) Law. These references allocate tasks across regimes and create conditional obligations.

Interaction with the Act

• The regulation prescribes amounts under section 40(b) of the Act for the annual distribution fee (s 51). The consultation requirements in Part 3 are prescribed for the purposes of sections 270G(2) and 270OA(1) of the Act (s 29). Section 55 prescribes the consultation for a pricing investigation report under section 227F of the Act by reference to Part 3 Division 2 consultation. Section 40 states Part 4 imposes conditions on a distributor under section 51(1) of the Act. Section 57 is a transitional provision for section 326 of the Act concerning the definition of “small customer”. In each case, the regulation gives operational effect to powers and duties in the Act by prescribing procedural and financial details. To understand enforcement, fee recovery mechanics, and some substantive duties, one must read the Act together with this regulation.

Interaction with the Petroleum and Gas (Production and Safety) Act

• The regulation conditions the exercise of disconnection and reconnection powers on directions and standards from the Petroleum and Gas (Production and Safety) Act. Section 43(b) permits disconnection where it has been directed under a dangerous situation direction under that Act. Section 47(2) makes reconnection conditional on the relevant installation and meters complying with all requirements under the Petroleum and Gas (Production and Safety) Act and any other Act. Section 43(h) references unlawful taking of a covered gas in contravention of s 289 of the Act or s 809 of the Petroleum and Gas (Production and Safety) Act as a ground for disconnection. These cross‑references bind operational network decisions to safety and production standards in that separate statute.

Interaction with NERL (Qld)

• Part 4 applies where the distributor’s gas infrastructure is not a distribution system under the National Energy Retail Law (Queensland) (NERL (Qld)) (s 40). This carve‑out means the regulation’s operational disconnection/reconnection regime is intended to apply to those distribution systems outside the NERL (Qld) framework. Section 41 also makes any right to disconnect subject to relevant limitations in a distribution network code, which may itself be shaped by NERL‑derived rules where applicable. The regulation therefore sits alongside NERL (Qld) and effectively fills regulatory gaps for non‑NERL distribution systems.

Interaction with the National Gas (Queensland) Law

• Section 55A grants an exemption from registration under the National Gas (Queensland) Law (s 91LB(2)) to holders of an "exempted authority", defined as the distribution authority held by Maranoa Regional Council or Western Downs Regional Council immediately before commencement. Section 55A(2) clarifies the exemption applies even if the holder participates in the Queensland retail gas market in a registrable capacity under s 91LA. This is a specific derogation that alters the usual registration interaction between local council distribution authority holders and the National Gas (Queensland) Law.

Cross‑statutory operational conditioning

• Several operative provisions are conditional on compliance with other Acts or existing contracts: reconnection subject to s 109 of the Act (s 47(3)); disconnection on grounds under a relevant connection contract (s 43(e)); and denial or limitation of customer connection services under insufficiency of supply directions (s 43(f)). These conditions mean that the distribution regulation must be read and applied together with the Act, distribution network codes, connection contracts and safety legislation.

Consultation linkages

• Section 29 prescribes the Part 3 consultation steps as the consultation required under ss 270G(2) and 270OA(1) of the Act for QCA to make or amend a distribution network code, and states substantial compliance is sufficient (s 29(2)). Section 55 prescribes Part 3 Division 2 consultation for pricing investigation reports under s 227F of the Act, applying the distribution network code consultation model to pricing processes. This creates a harmonised consultation approach across code‑making and pricing reporting.

Repeal and transitional interaction

• The regulation repeals the Gas Supply Regulation 2003 (s 56) and provides a transitional rule for the definition of “small customer” in s 326 of the Act, treating the day of gazettal of this regulation as the FRC day for that purpose (s 57). Transitional provisions therefore ensure continuity and an orderly handover from the previous instrument to this regulation.

Practical implications of the interactions

• Because reconnection is conditional on compliance with safety statutes and the regulation disclaims operation where the NERL (Qld) applies, distributors must coordinate across multiple regulatory regimes before reconnecting customers. The consultation rules require QCA to follow divisible and staged steps that are also used for pricing investigations, creating procedural consistency but also procedural dependencies that callers must follow. The exemption in s 55A creates a targeted departure from the registration regime for specific council authority holders.

In short, this regulation operates as a subordinate instrument that fills procedural, operational and fee details around the Act, while deferring to safety, production and national gas laws for substantive safety and registration requirements. Effective compliance requires actors to navigate the interconnected framework of the Act, distribution network codes, safety regulation and national gas law.

The text contains multiple amendment annotations and shows a history of changes recorded in the instrument's annotations. The following points summarise the amendment and omission signals present in the provided text; where the regulation shows an amendment or omission reference, that is reported as the source does.

Broad amendment pattern

• Numerous sections carry annotations "om 2014 SL No. 338 s 42" indicating that substantial portions of the regulation were omitted by State Law 2014 No. 338, section 42. For example, ss 4-24 and multiple later sections are marked omitted by that 2014 instrument. The source therefore reflects a substantial 2014 consolidation or revision that removed or re‑worked earlier provisions.
• Several sections were amended by various other State Law instruments across multiple years. Section 51, the annual distribution fee, records a series of amendments spanning 2008-2022: "amd 2008 SL No. 192 s 12; 2009 SL No. 73 s 19; 2010 SL No. 116 s 17; 2011 SL No. 93 s 6; 2012 SL No. 94 s 6; 2013 SL No. 85 s 6; 2014 SL No. 138 s 6; 2015 SL No. 59 s 7; 2016 SL No. 93 s 7; 2017 SL No. 74 s 7; 2018 SL No. 63 s 19; 2019 SL No. 80 s 19; 2020 SL No. 107 s 20; 2021 SL No. 83 s 13; 2022 SL No. 78 s 14." These annotations indicate repeated legislative attention to the annual fee provision, likely updating numeric values, formula or indexing mechanisms across the years (the detail of each amendment is not contained in the excerpt).
• Part 3 amendments or consolidations are noted in 2014: ss 25-39 show amendments annotated "amd 2014 SL No. 338 s 44". These indicate 2014 changes to the consultation and code proposal framework.
• Section 43 (grounds for disconnection) carries annotations "amd 2014 SL No. 338 s 47; 2024 SL No. 31 s 4", showing it was amended in 2014 and again in 2024. Section 47 similarly notes "amd 2014 SL No. 338 s 49; 2024 SL No. 31 s 5", and s 48 is noted as "amd 2024 SL No. 31 s 6". These recent amendments (2024) indicate the disconnection/reconnection sections were updated in that year.

Inserted and retroactive provisions

• Section 55A (Exemption from registration for market participation under National Gas (Queensland) Law) is annotated "ins 2009 SL No. 163 s 5 (retro) amd 2014 SL No. 338 s 53". The "(retro)" annotation indicates a retrospective insertion in 2009, later amended in 2014. The section itself defines "excluded distribution authority" as those distribution authorities held by Maranoa Regional Council and Western Downs Regional Council immediately before commencement, and grants an exemption from registration to the holder of an exempted authority (s 55A(1)-(3)).

Repeal actions

• Section 56 expressly repeals the Gas Supply Regulation 2003 SL No. 122. The instrument therefore replaced the 2003 regulation.

Transitional provisions

• Section 57 provides a transitional provision for the definition of “small customer” under section 326 of the Act, directing that part 2 division 1 (other than s 4) applies as if a reference to the FRC day were a reference to the day this regulation was notified in the gazette.

Sections omitted or moved

• Multiple sections are marked as omitted (om) by 2014 SL No. 338 s 42 or s 48/51/52. For example, s 4-24 have omission markers. Sections 44, 45, 49, 50, 52, 54 are annotated as omitted. The omission annotations mean earlier regulatory content was excised by the 2014 State Law instrument, reshaping the regulation’s structure.

Implications

• The amendment history annotations show repeated legislative adjustments to fee provisions, code consultation procedures and disconnection/reconnection mechanics. Recent amendments in 2024 targeted operational reconnection/disconnection provisions and compensation (ss 43, 47, 48). The insertion and amendment of an exemption for specified councils (s 55A) in 2009 (retroactive) and its later amendment signals targeted policy treatment for particular local government entities.

Limitations of the excerpt

• The precise content of many historical amendments is not present in this excerpt; only annotation markers are provided. For precise amendment texts (for example, what changed in each year for s 51), one must consult the amending statutory instruments referenced in the annotations (the listed SL No. and section). The annotations do, however, provide a reliable pointer to the legislative trajectory and which provisions have been subject to recurrent change.

In short, the regulation has been materially revised over time, with a significant consolidation or omission event in 2014 and further amendments as recently as 2024 affecting operational duties. Financial provisions have been adjusted repeatedly over a multi‑year timespan.

The regulation text provided does not include any judicial decisions, case names or reported litigation concerning its provisions. There are no cases cited in the instrument itself. Section 48 contemplates that compensation for contraventions of ss 46 or 47 "may be claimed and ordered in a proceeding brought in a court of competent jurisdiction" (s 48(3)), but the document does not list precedents or judicial interpretations.

What the source shows and does not show

• The regulation creates a private right of action for compensation (s 48), which is a channel by which litigation could arise, but the regulation does not record any litigation outcomes or judicial guidance on how courts should apply terms such as "reasonably believes", "reasonable notice", or whether particular conduct satisfies the reconnection requirements tied to safety compliance under the Petroleum and Gas (Production and Safety) Act.
• The absence of recorded cases in the provided text means there is no statutory commentary or annexed case list to indicate how courts have interpreted the regulation’s standards (for example, what constitutes "unsafe or impractical" compliance with a disconnection request under s 46).
• To identify litigation history, one must search judicial databases and reported decisions for proceedings brought under the Act and this regulation (not provided here). The regulation itself simply contemplates judicial enforcement for private claims.

Practical note for practitioners

• In the absence of judicial guidance in the instrument, parties relying on or challenging distributor conduct under ss 42-48 should prepare to articulate statutory standards (reasonable belief, reasonable notice, safety compliance) and cross‑refer to the Act and to the Petroleum and Gas (Production and Safety) Act, which may supply more detailed standards and enforcement mechanisms. The regulation’s private compensation remedy (s 48) is the likely litigation vehicle for disputes over timing and reconnection outcomes arising from distributor conduct.

Because the source contains no litigation references, readers must conduct an independent case‑law search if they need precedent or judicial interpretation relevant to the regulation’s operative provisions.

The regulation is concise but contains several provisions with operationally significant ambiguities and cross‑statutory dependencies that create practical risks. The following "gotchas" arise directly from the text.

Reasonable belief and reasonable notice are subjective standards

• The regulation uses "reasonably believes" to qualify both the extent/period of disconnection (s 42(2)) and the exception to complying with a disconnection request if it would be unsafe or impractical (s 46). "Reasonably believes" is fact‑dependent and invites dispute. The regulation does not define the evidentiary threshold or provide a safe‑harbour checklist. Distributors should document the factual basis for any "reasonable belief" about safety or impracticality; retailers and customers should expect to test that belief in any compensation proceeding under s 48.

Five business day timelines may be operationally tight

• Distributors must comply with a disconnection request within five business days (s 46) and must reconnect within five business days after a reconnection notice, subject to compliance with safety and other Acts (s 47). For larger systems or where installers or meter providers are needed, meeting the five business day deadline may be operationally challenging. The regulation allows a safety/impracticality exception for disconnection requests (s 46) but for reconnection there is no explicit exception besides statutory compliance with safety requirements. Distributors should have procedures and resourcing in place to meet the five business day obligation or to promptly demonstrate why compliance is not possible.

Reconnection conditional on other Acts and s 109 of the Act

• Section 47 requires that "the relevant installation and meters for a covered gas comply with all requirements under the Petroleum and Gas (Production and Safety) Act and any other Act" before reconnection, and states reconnection obligations are "subject to the limits on the distributor’s obligation to provide customer connection services, under section 109 of the Act" (s 47(2)-(3)). The content of the safety requirements and s 109 limits are not in this regulation. Parties must check those external provisions to determine whether reconnection should occur, and disputes can arise where safety compliance is contested or where s 109 limits a distributor’s obligation.

Fee calculation gap in the excerpt

• Section 51(3) refers to a formula to calculate the annual distribution fee when pipeline length is 100 km or more and defines DF, P and TP. The excerpt provided does not include the explicit arithmetic formula; therefore, readers cannot directly compute the amount from this text alone. Practitioners must retrieve the full regulation text (or the amending instruments that set out the formula) to compute the payable fee. This omission is a practical gotcha for financial planning.

Payment day set by regulator notice

• The annual fee is payable on the day fixed by the regulator by notice to the holder (s 51(6)-(8)). The day may be any day, including a day in the financial year, but cannot be before the giving of the notice. Authorities should monitor regulator notices carefully; late notice could create short timeframes for payment. The instrument does not set a default or require advance timing; the regulator’s notice is decisive.

QCA discretion to skip consultation steps

• Section 31 allows QCA to decide subdivision 2 does not apply where the issues are minor or QCA reasonably considers the subdivision unnecessary or inappropriate. This discretion concentrates procedural control in QCA and may limit stakeholder input if QCA exercises that discretion. However, s 55 preserves subdivision 2 for pricing investigation reports despite s 31. Proponents should therefore manage expectations about the level of consultation QCA will engage in.

Interaction with distribution network codes may limit rights

• Section 41 states any right under Part 4 to disconnect is subject to relevant limitations or restrictions in the distribution network code. Depending on the code’s content (which this regulation does not reproduce), distributors’ rights to disconnect may be curtailed or conditioned. Parties need to examine the relevant distribution network code(s) to understand the full legal terrain.

Targeted exemptions create asymmetric regulatory burdens

• Section 55A grants an exemption from registration under the National Gas (Queensland) Law to holders of specified distribution authorities (Maranoa and Western Downs). This targeted exemption produces unequal regulatory obligations for different distributors and may complicate market entry or competitive dynamics in affected regions.

Omissions and amendment annotations require current text checks

• Numerous sections are marked as omitted (om 2014 SL No. 338 s 42) or amended across many years. Practitioners must work from the current consolidated text in the official gazette or legislation database. Relying on this excerpt without checking the consolidated instrument risks missing substantive changes.

Compensation remedy limited to specific contraventions

• The private remedy in s 48 applies only to contraventions of s 46 (failure to comply with a disconnection request within five business days) or s 47 (failure to reconnect within five business days where reconnection conditions are met). The remedy does not expressly extend to other distributor misconduct (for example, wrongful initial disconnection not triggered by a retailer request, or disconnection outside the enumerated grounds), so parties should assess alternative remedies under the Act, common law or other statutes for those situations.

Requirements to give “reasonable notice” for some disconnections

• Section 43(d) allows disconnection to carry out “work to the distributor’s distribution system” where the work is reasonably required, done at a reasonable time and the person is given reasonable notice of the disconnection. The regulation does not specify the length or mode of such notice, potentially creating disputes about adequacy. Distributors should adopt a clear notice policy aligned with accepted industry practice and document notice delivery.

No express penalties or enforcement mechanisms for QCA or fee non‑payment in this excerpt

• The regulation sets duties but does not, in the provided text, specify administrative penalties for failure by QCA to follow prescribed consultation steps, nor does it specify recovery mechanics (interest, enforcement) for late fee payment. Those mechanisms may exist elsewhere (in the Act or in other instruments), but are not present here and must be sought to determine full enforcement exposure.

In short, the primary practical risks are operational: subjective standards ("reasonable"), tight 5‑business day timelines, dependency on external safety/compliance laws for reconnection, fee calculation opacity in the excerpt, and QCA’s discretion over consultation. Each of these requires concrete procedures, documentation and cross‑checking with the Act and other referenced statutes.

This section translates the regulation’s duties into concrete compliance steps and risk mitigation measures for the main affected parties: QCA, distributors, distribution authority holders, retailers and customers. Where the regulation cross‑references other statutes (the Act, the Petroleum and Gas (Production and Safety) Act, NERL (Qld) and National Gas (Queensland) Law), compliance requires parallel checks of those instruments.

For QCA (consultation and code‑making compliance)

• Receive and process proposals: establish a documented intake process for any person’s proposal under s 25, including a standard form or template that meets QCA’s reasonable requirements. If QCA requires proponent justification of how the proposal meets the QCA code objective, provide a template checklist to be completed by proponents (s 25(2)-(3)).
• Two‑month decision clock: implement a workflow to reach a decision within two months from compliance with any requirements under s 25 about whether to submit a proposal for consultation (s 26(2)). Record the decision and reasons promptly, and if declining to submit, give the proponent a notice with reasons as soon as practicable (s 27).
• Publish consultation materials: for interim consultation (where subdivision 2 applies), prepare and publish an interim consultation notice on the website and distribute it to anyone QCA reasonably believes will be interested (s 32(1)). Include where the issues document can be inspected and set an interim consultation period that is reasonable in light of complexity (s 32(2)-(4)).
• Consider submissions and publish draft materials: consider all written submissions promptly after the interim consultation period (s 34), then publish a draft report and draft proposed code on the website (s 35). Maintain public records of submissions and decisions.
• Final consultation and finalisation: prepare and publish a final consultation notice, provide a final consultation period, consider submissions (s 36-38), and publish a final report and final version of the code (s 39). Where subdivision 2 did not apply, ensure a draft report and draft code are published before the final consultation notice (s 36(2)-(3)).
• Exercise discretion and record reasons: if QCA decides the issues are minor or that subdivision 2 is unnecessary (s 31), record the basis for that decision with evidentiary justification. For pricing investigation reports, note that subdivision 2 applies despite s 31 (s 55(3)), and follow subdivision 2 steps accordingly.

For distributors (disconnection/reconnection compliance)

• Document grounds and decision process: maintain a written policy that maps each enumerated ground for disconnection in s 43 to operational procedures and evidentiary requirements. For each disconnection, create and preserve a file that documents the specific ground relied upon, the facts supporting it, and why the disconnection extent and period were those the distributor reasonably believed appropriate (s 42(2), s 43).
• Safe access and contract checks: ensure processes are in place to check and record whether a customer has provided safe access as required under s 130 of the Act (s 43(g)), and whether relevant connection contract terms justify disconnection (s 43(e)).
• Respond to retailer disconnection requests within 5 business days: implement an intake and scheduling system for retailer disconnection requests with a five business day service level, together with an escalation process where safety or impracticality concerns arise. If non‑compliance is necessary for safety or impracticality, document the reasons and why compliance was unsafe or impractical (s 46).
• Reconnection process and safety checks: upon receiving a reconnection notice from a retailer, verify that installations and meters comply with the Petroleum and Gas (Production and Safety) Act and any other Act before reconnecting (s 47(2)). If reconnection is delayed for safety compliance, record what remedial steps are required, expected timeframes and communications to the retailer and customer. Reconnect within five business days once compliance is confirmed (s 47(2)).
• Contractual and fair/reasonable terms: where no connection contract applies to reconnected services, ensure reconnection is offered on fair and reasonable terms (s 47(4)). Have standard form reconnection terms and record how those terms satisfy the fair and reasonable test.
• Compensation exposure: be aware that contravention of s 46 or s 47 may result in a court‑ordered compensation claim (s 48). Keep comprehensive records of requests, notices, safety checks and communications to defend against potential claims.
• Distribution network code constraints: review and implement any relevant limits in the applicable distribution network code that may affect disconnection rights (s 41).

For distribution authority holders (fee compliance)

• Track pipeline lengths: calculate and record the total length of pipelines operated or maintained under the authority "immediately before a financial year starts" to determine whether the authority falls below the 100 km threshold for the fixed fee (s 51(2)-(3)). Keep historical snapshots as at each financial year start.
• Compute fees and pro rata adjustments: for authorities with 100 km or more, apply the formula in s 51(3) to compute the annual distribution fee. If the authority takes effect after the financial year starts, apply the rateable reduction in s 51(5). Note that the full arithmetic detail must be taken from the consolidated regulation text if not present in this excerpt.
• Monitor regulator notices for payable day: watch for the regulator’s notice fixing the day the fee is payable (s 51(6)-(8)). Arrange cashflow planning and payment on the day specified. Confirm with the regulator if the notice provides a short payment window.
• Check schedule 1 for other fees: s 53 states that other fees are in schedule 1; locate schedule 1 in the consolidated regulation to identify any additional fees and deadlines.

For retailers

• Use disconnection/reconnection request rights properly: issue disconnection requests to distributors where appropriate; be prepared to provide evidence supporting the request. Where a distributor does not comply with a disconnection or reconnection request as required, remember the regulation specifically recognises retailers as potential claimants for compensation (s 48).
• Coordinate safety evidence for reconnection: when requesting reconnection, provide any available evidence that installations and meters comply with the Petroleum and Gas (Production and Safety) Act and any other Act, to expedite reconnection within the five business day period (s 47(2)).

For customers (end users)

• Provide safe access and compliance: ensure safe access to premises per s 130 of the Act to avoid disconnection under s 43(g). Where disconnected, be aware of the five business day reconnection mechanics and the need for installations/meters to comply with safety requirements before reconnection (s 47).
• Compensation claims: if a distributor fails to reconnect within the five business day period in circumstances covered by s 47, or fails to act on a disconnection request under s 46, customers may be claimants under s 48.

Cross‑cutting compliance controls

• Record retention and evidence: because many of the regulation’s standards depend on fact‑based "reasonable" judgments and cross‑statutory compliance, maintain contemporaneous records of all decisions, notices, safety checks, communications with retailers/customers and file notes justifying decisions to disconnect or delay compliance.
• Integration with other statutes: establish procedures to verify compliance with the Petroleum and Gas (Production and Safety) Act and the Act, and check NERL (Qld) status to determine whether Part 4 applies (s 40). Where the holder is one of the exempted councils, confirm applicability of the exemption in s 55A.
• Policies and training: adopt written policies addressing the five business day timelines, notice templates for disconnection/reconnection communications, safety compliance checklists, and staff training to ensure consistent application of "reasonable" standards.
• Legal and operational liaison: maintain contact points with the regulator for fee notices, with QCA for code amendment processes, and with safety regulators for compliance confirmation before reconnection.
• Update processes after amendment: monitor legislative updates and the cited State Law instruments (e.g. 2014 SL No. 338, 2024 SL No. 31, and the other amending instruments listed in s 51) to ensure procedures and fee calculations reflect current law.

Implementing these steps will not eliminate all legal risk, but will materially reduce exposure by providing documentary evidence to justify reasonable decisions, meeting statutory timelines, and ensuring fee and regulatory notices are promptly actioned.