The Electricity Industry Act 2004 sets the legal framework for generation, transmission, distribution and retailing of electricity in Western Australia. Key functions are licensing (who may generate, transport or sell electricity), regulation of access to network services, consumer protections for small customers, codes and market rules, dispute resolution, and financial arrangements to smooth prices across regions.
Recent amendments expand the Act from a licence‑centric regime to a fuller market and registration architecture: they introduce (a) a State electricity objective to guide decisions (s 3A); (b) a registration framework for providers of “alternative electricity services” (Part 3A, ss 59A–59Q and following); (c) an electricity system and market rules regime and a wholesale market for the South West interconnected system (Part 9, ss 122–124 and ss 123(1A)); (d) a Pilbara‑specific, lighter access regime (Part 8A, ss 119–120C) and a Pilbara independent system operator (ss 120W–120X); and (e) tariff equalisation and temporary access contribution mechanisms to transfer money between network participants and the Regional Power Corporation (Parts 9A and 9B, ss 129A–129Q and ss 129K–129Q).
Who it affects:
Electricity businesses: anyone who constructs, operates or sells electricity must hold a licence (generation, transmission, distribution, retail or integrated regional) (s 4, s 7) unless exempted. Holders of licences face audit/asset management/contract and code obligations (ss 13–14, Sch 1).
Zoe can write the in-depth analysis on top of the summary above: how it works, who it affects and what each part actually does.
Current sections
Direct links to the current provisions in Electricity Industry Act 2004.
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Authorised Version
The authorised version of this legislation is published by the jurisdiction's legislation service. Follow the link below to read or download it from the official source.
Sourced from the Western Australian Legislation website (legislation.wa.gov.au). Not the authorised version.
New service providers: firms offering alternative electricity services (DER aggregators, storage providers, embedded network operators, energy data platforms and similar) must register under Part 3A unless exempt (ss 59C, 59D).
Network service providers and network users: subject to access rules in the Code (Part 8, ss 104–107) or the Pilbara Access Code (Part 8A) for covered networks.
Small use customers (<=160 MWh pa): protected by standard form contract approvals, a code of conduct, ombudsman scheme membership and AES code protections (Parts 3, 6, 7, 3A Division 4).
Regulators and ministers: the Economic Regulation Authority (the Authority), the Minister, the Coordinator of Energy and the Treasurer acquire decision and direction powers (see s 3A, Part 3A, Parts 8/8A, Part 9, and ss 129D/129N respectively).
Why it matters (official purpose and practical implications):
Officially the amendments aim to promote “efficient investment in, and efficient operation and use of, electricity services for the long‑term interests of consumers” across quality, price and environment (State electricity objective, s 3A). The Act creates the instruments needed to deliver that objective: licensing/registration, Codes and rules, a wholesale market, access regulation and customer protections.
Practical trade‑offs and mechanics to watch (linked to sections):
Compliance costs and reporting: licensees and registration holders must provide performance audits and asset management reports, lodge contracts and be members of approved ombudsman schemes; fees and audits are recoverable (ss 13–14, 17, 59ZF, 59ZG). These raise ongoing costs for firms.
Regulatory discretion and timing: the Minister, Authority and Treasurer hold wide rulemaking and directional powers (e.g. to make Codes, approve access arrangements, determine tariff equalisation/temporary access contributions). Much substantive detail is left to subsidiary instruments and regulations (ss 39, 104–107, 122–124, 129D, 129N), so implementation depends on secondary instruments.
Market structure and access: the Code (Part 8) and Pilbara Access Code (Part 8A) regulate access terms, pricing principles and arbitration (ss 104B, 120C). These arrangements change how network owners sell access and thus affect competition and contract terms.
Redistribution mechanisms: tariff equalisation and temporary access contributions impose payments by Electricity Networks Corporation or its Pilbara NBU into State accounts to compensate the Regional Power Corporation (ss 129C–129G; 129M–129Q). These are concentrated transfers (benefit RPC) funded through access/user charges and potentially passed on to users (ss 129F, 129P).
Consumer protections and dispute resolution: standard form contract approvals, AES code of practice, code of conduct, and an approved electricity ombudsman scheme create administrative and enforcement pathways for small customers (ss 48–54, 59X–59Y, 79–82, 92–101C).
Who pays, who decides, and what behaviour changes (plainly):
Who pays: licensed businesses and registration holders pay application and annual fees, costs of audits and compliance; network users may be required to pass on tariff equalisation or temporary access contributions via network charges (ss 17, 59Q, 129F, 129P). Fines and civil penalties can apply for breaches (e.g. s 7 penalties; enforcement provisions under ss 32, 59ZI, 124J).
Who decides: the Authority administers licensing, approves codes and access arrangements and enforces many rules (ss 11, 37, 39, 104B, 124L). The Minister makes Codes, may issue AES code and the Pilbara Access Code, and the Treasurer sets contribution amounts for tariff schemes (ss 39, 59X, 120A, 129D, 129N).
Behaviour changes encouraged or required: firms must seek licences or registrations to operate, adopt approved standard contracts and codes, comply with access arrangements or Pilbara rules, produce periodic audits and asset management plans, and internalise potential financial transfers (tariff/temporary contributions). New entrants providing alternative services must register and comply with AES protections, increasing oversight of DER activity (Part 3A).
Costs, incentives, risks and trade‑offs to highlight:
Concentrated benefits and diffuse costs: tariff schemes concentrate benefits on the Regional Power Corporation while costs are recovered from network users (ss 129F–129G). Exclusive licence rules (ss 26–30) provide concentrated protection to winners of tenders but limit competition in specified areas.
Regulatory dependence and implementation risk: substantial policy detail is delegated to regulations, Codes and rules. Outcomes depend on regulatory design, publication and transitional arrangements (e.g. Parts 8/8A/9 and Part 11 transitional provisions, ss 136–143).
Compliance and administrative burden: recurring audits, reporting, code compliance and fees raise operating costs and favour better‑resourced participants (ss 13, 14, 59ZF–59ZG).
Contract freedom vs standards: standard form contract approvals and code requirements (ss 50–54, 59X) constrain contract terms for small customers while aiming to ensure consistent consumer protections.
Key sections to refer to quickly: s 3A (State electricity objective); ss 4 & 7 (licences and offences); Part 3A (ss 59A–59Q) (registration of alternative electricity services); Parts 8 & 8A (ss 104–107; 119–120C) (Code and Pilbara Access Code); Part 9 (ss 122–124) (electricity system and market rules/wholesale market); Parts 9A & 9B (ss 129A–129Q; 129K–129Q) (tariff equalisation and temporary access contributions); ss 79–101C (consumer codes, ombudsman, membership requirements).