Offshore Electricity Infrastructure (Declared Area OEI-01-2022) Declaration 2022

The instrument rests on a small number of tightly drawn legal concepts and mechanisms.

Declared area: The instrument creates a declared area named “Declared Area OEI‑01‑2022” (s 4, s 5). That declared area is defined not by words on a map alone but by three sets of sequential geodesic coordinates in Schedules 1-3. Each part is defined as “the line commencing at point … and running along the geodesics sequentially connecting the points … and then along the geodesic to the point of commencement.” The instrument therefore creates closed polygonal lines which, interpreted with geodesics, define the maritime area to which the declaration applies. A simplified map is provided in Schedule 4 under s 5(2). The instrument’s definition note cross‑refers to the GDA94 geocentric data set, and to s 49 of the Regulations, for determinations of position.

Defence consultation area: The instrument defines a distinct spatial concept, the Defence consultation area, as “the area within an 80 nautical mile radius of the Royal Australian Airforce Base East Sale Airfield Surveillance Radar (Latitude 38° 11’ 18” South, Longitude 147° 10’ 57” East)” (s 4). That circle functions as a spatial trigger within the declared area for a heightened consultation requirement (see s 6 item 1).

Licence types and triggers: The instrument is selective in which licence types attract its requirements. The table in s 6 repeatedly targets feasibility licences. The instrument uses the Act’s definitions (s 4 note 1) for licence categories such as “feasibility licence,” “commercial licence,” “research and demonstration licence,” and for programmatic concepts like “management plan” and “licence area.” The operative language in s 6 is conditional: where the matters in column 1 are satisfied, the licence “must be subject to” the corresponding condition in column 2. That statutory framing makes the requirements mandatory where the factual predicates are met.

Consultation and management plan obligation: The instrument imposes a two‑stage duty on licence holders (s 6). The first is an obligation to consult specific entities “in preparing a management plan for the licence.” The second is to record and “address the outcomes of this consultation” within the management plan itself. As drafted, the “address” language is open to interpretation: it requires that the management plan engage with the consultation outcomes, but the instrument does not specify what form, level of detail or remedial action (such as mitigation measures) is sufficient.

Specified consultees: The instrument lists particular public agencies and private rights holders as consultees. Item 1 requires consultation with the Department of Defence (where the licence is a feasibility licence granted in respect of any part of the Defence consultation area). Item 2 requires consultation with the Bureau of Meteorology, the Director of National Parks (under the EPBC Act), the Australian Maritime Safety Authority, and any titleholders of existing petroleum or greenhouse gas titles under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 whose title area overlaps with the licence area. Item 3 addresses consultation with holders of fishing concessions under the Fisheries Management Act 1991 or permits under the Fisheries Act 1995 (Vic), and permits a nominated representative organisation to stand in for individual concession/permit holders where such a nomination exists.

Relation to the Act and Regulations: The instrument is made under s 17 of the Act (s 3) and expressly notes other statutory hooks. The definitions note in s 4 reminds readers that a number of expressions are defined in s 8 of the Act (including “feasibility licence,” “management plan,” and more). It also expressly tells readers that positional determinations use GDA94 and refers to s 49 of the Offshore Electricity Infrastructure Regulations 2022 for that technical rule.

Technical drafting features: Each declared area part is constructed from lists of points (latitude/longitude) and an instruction to run lines by geodesics sequentially connecting those points. Several coordinate pairs in the Schedules are effectively duplicates or near duplicates (for example, OEI‑P1‑66 and OEI‑P1‑67 are almost identical; OEI‑P1‑97 and OEI‑P1‑100 likewise). The instrument’s mapping approach requires careful geodetic application of the GDA94 datum and the Regulations to translate the table of points into a reliable polygon for licence and planning purposes.

Overall, the instrument operationalises spatial targeting of obligations: a declared maritime area is identified to which specific management‑plan consultation and content obligations attach to feasibility licence holders. The instrument does not itself create enforcement mechanisms or penalties; it relies on the Act and Regulations for broader licensing architecture (not reproduced here, but cross‑referenced in s 6 and s 4).

Primary affected parties

• Feasibility licence holders who are granted licences “in respect of the declared area or any part of the declared area.” Section 6 applies directly to such licence holders. Each of the mandatory conditions in the table in s 6 uses the trigger “the licence is a feasibility licence; the licence is granted in respect of the declared area or any part of the declared area”; where these predicates are satisfied, the licence “must be subject to” the condition. Put simply: if you hold or are applying for a feasibility licence covering any of the OEI‑01‑2022 area, this instrument imposes management‑plan consultation and content obligations on you.

• Feasibility licence holders with licence areas that fall within the Defence consultation area. Item 1 in s 6 adds a targeted obligation for feasibility licences granted in respect of any part of the Defence consultation area: consult Defence on potential impacts to operations and radar capability, and address those consultation outcomes in the management plan.

Secondary affected parties (consultees and adjacent titleholders)

• The Department of Defence. Where a feasibility licence overlaps the Defence consultation area, licence holders must consult Defence in preparing their management plan and then address the consultation outcomes in the plan (s 6 item 1). The instrument effectively makes Defence a necessary interlocutor for such feasibility projects.

• The Bureau of Meteorology, the Director of National Parks (EPBC Act office), and the Australian Maritime Safety Authority. Item 2 requires feasibility licence holders to consult these agencies and to address the consultation outcomes in their management plans when the licence covers any part of the declared area.

• Titleholders under the Offshore Petroleum and Greenhouse Gas Storage Act 2006. If an existing petroleum or greenhouse gas title overlaps with the licence area, the feasibility licence holder must consult those titleholders as part of preparing the management plan (s 6 item 2(b)(i)-(iv)). The instrument therefore identifies overlapping petroleum/greenhouse gas titleholders as stakeholders with a right to be consulted.

• Holders of fishing concessions under the Fisheries Management Act 1991, and permit holders under the Fisheries Act 1995 (Vic). Item 3 applies where rights under one or more such concessions or permits “can be exercised in relation to the licence area.” The licence holder must consult those holders (or a nominated representative organisation) and address consultation outcomes in the management plan, including “how impacts on these holders may be avoided, mitigated, or offset” (s 6 item 3(b)).

Indirectly affected parties

• Commercial licence holders and holders of research and demonstration licences. The instrument does not impose these particular consultation conditions on commercial licences or research and demonstration licences by its terms. However, the instrument’s note in s 6 states: “Licences will also be subject to other conditions: see sections 35, 45 and 54 of the Act.” Those other statutory sections (in the Act, not reproduced here) may impose different or additional duties on commercial and other licence types. Practitioners should therefore treat this instrument as adding specific obligations for feasibility licences while recognising broader regulatory overlays under the Act.

• Regulators and decision‑makers under the Act. The instrument changes the conditional content of licences that will be issued under the Act for the declared area. Regulators processing feasibility licence applications for OEI‑01‑2022 will need to ensure the licence includes the mandatory conditions set out in s 6 where the predicates apply.

Who pays and who decides

• Who pays: The immediate compliance cost sits with the feasibility licence holder. The licence holder must arrange and resource consultations, prepare management‑plan revisions to “address the outcomes,” and implement the mitigation/offsetting measures detailed in the management plan (the instrument explicitly requires management plans to address, e.g., how impacts on fishing concession/permit holders may be avoided, mitigated, or offset , s 6 item 3(b)). That will typically involve legal, environmental, stakeholder‑engagement and technical costs.

• Who decides: The Minister declared the area under the Act (s 3). The instrument leaves the detail of licence issuance, management‑plan approval and enforcement to the Act and Regulations; the instrument mandates conditions that must be attached to licences when the stated predicates are met, but operational decisions about sufficiency and enforcement are governed by the Act/Regulations (the instrument cross‑references those regimes in s 3 and the notes).

Temporal effect

• The instrument commenced the day after registration (s 2). It contains a note that the commencement table relates only to the instrument “as originally made,” indicating that any later amendments to the instrument would themselves be separately recorded.

In sum, feasibility licence applicants and holders operating in the OEI‑01‑2022 declared area bear the primary obligations and costs. Several public agencies and existing offshore titleholders are empowered by the instrument to be consulted and to have their concerns reflected in management plans. The instrument does not create new rights for those consultees beyond the duty to be consulted and to have outcomes addressed in a management plan; the precise regulatory consequences, timing and dispute resolution remain governed by the Act and Regulations.

The instrument imposes mandatory duties in relation to management plans for feasibility licences and defines who must be consulted. Rights and duties are expressed in a compact statutory table (s 6) and by the definition of the declared area (s 4-5).

Core duties on licence holders

• Duty to include prescribed consultation in preparation of a management plan. For any feasibility licence that is granted in respect of the declared area, the licence holder must, “in preparing a management plan for the licence, consult” the entities listed in the relevant item of the conditions table (s 6 items 1-3). The duty is processual: consultation must take place “in preparing” the plan, not merely after the plan is submitted.

• Duty to address consultation outcomes in the management plan. Each condition requires that the management plan “address the outcomes of this consultation.” Item 3 is explicit that this includes “how impacts on these holders may be avoided, mitigated, or offset.” The verb “address” is the operative standard the instrument sets for management plan content; the instrument does not specify a minimum content template beyond that consultation outcomes be addressed.

• Defence‑specific consultation duty. If the feasibility licence covers any part of the Defence consultation area, the licence holder must consult the Department of Defence specifically “to determine the potential impact of offshore infrastructure activities and other activities that are to be carried out under the licence on Defence operations and radar capability” (s 6 item 1(a)). The management plan must then “address the outcomes of this consultation” (item 1(b)).

• Consultation with designated agencies and titleholders. Item 2 compels consultation with a set group of agencies and overlapping titleholders: Bureau of Meteorology; Director of National Parks; Australian Maritime Safety Authority; and titleholders of existing petroleum or greenhouse gas titles under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 whose title area overlaps the licence area (s 6 item 2(a)(i)-(iv)). The management plan must address the outcomes.

• Consultation with fishing concession/permit holders (or representatives). Item 3 obliges a feasibility licence holder to consult concession or permit holders who can exercise rights in the licence area, and where a concession or permit holder has nominated a representative organisation for consultation purposes, to consult that organisation rather than each individual holder (s 6 item 3(a)(i)-(ii)). The management plan must address consultation outcomes, “including how impacts on these holders may be avoided, mitigated, or offset” (s 6 item 3(b)).

Rights and procedural implications for consultees

• Right to be consulted. The instrument imposes a statutory duty on licence holders to consult certain agencies, titleholders and fishing rights holders. That duty confers an expectation of engagement (a procedural right) that those entities will be included during management plan development; it does not create a veto or a separate statutory right to approve or refuse a licence within the instrument itself.

• Representative organisation mechanism. For fishing concessions/permits, the instrument allows a concession/permit holder to nominate a representative organisation to receive consultation. Where such a nomination exists, the licence holder is to consult that representative organisation (s 6 item 3(a)(i)). This drafting reduces the administrative burden on licence holders where representative arrangements have been agreed by concession/permit holders.

Interaction with other statutory duties

• The instrument explicitly notes that licences “will also be subject to other conditions: see sections 35, 45 and 54 of the Act” (s 6 note). Those provisions are not reproduced here, but the note signals that the duties imposed by this declaration are not the full catalogue of obligations that attach to licences under the Act; they are additional, targeted conditions layered onto the wider Act‑based licensing regime.

Technical and procedural obligations

• Precise spatial identification. Licence holders and applicants must use the GDA94 geocentric data set for positional determinations (s 4 note) and apply the geodesic construction of the Schedules when identifying licence areas vis‑à‑vis the declared area and Defence consultation area. That technical duty affects how a licence holder determines whether the s 6 consultation conditions apply and prepares maps and supporting material for the management plan.

What is not conferred or required by the instrument

• The instrument does not itself grant rights to veto, approval or compensation to consultees. The obligations are to consult and to address outcomes in the management plan; no automatic decision outcome based on consultee views is specified in the instrument.

• The instrument does not set timelines or procedural minimums for consultation, nor does it set a required form for addressing consultation outcomes (beyond the general “address the outcomes” wording). Those more detailed procedural standards, if any, will come from the Act, Regulations, or regulatory practice.

In summary, the instrument imposes mandatory process and content duties on feasibility licence holders operating in the declared area: consult specified actors when preparing management plans, and ensure management plans engage with and set out how consultation outcomes are handled, including mitigation/offsetting where fishing rights are affected. The scope of consultees is defined, and certain technical mapping rules control the spatial triggers for these duties.

The instrument itself does not create express penalties or a bespoke enforcement regime; it operates within the broader enforcement architecture of the Offshore Electricity Infrastructure Act 2021 and associated Regulations.

What the instrument says (and does not say)

• No penalties or enforcement mechanisms appear in the instrument text. Section 6 prescribes mandatory conditions that “must” be attached to licences where particular factual predicates are met, but the instrument does not specify enforcement steps, sanctioning powers, infringement notices, or penalty amounts.

• The instrument points to the Act for the wider licensing framework. The note in s 6 explicitly alerts readers that “Licences will also be subject to other conditions: see sections 35, 45 and 54 of the Act.” Those Act provisions, which are not reproduced in the instrument, are the logical place where enforcement mechanisms, contravention consequences, offences, or remedial powers are established. The instrument does not restate or modify those enforcement provisions.

Practical enforcement implications (based on the instrument’s mechanics)

• Compliance will be assessed via licence conditions. Because the instrument requires that the specified consultation and management‑plan obligations be conditions on relevant licences, compliance will largely be enforced through the licensing regime: licence application assessment, management‑plan approval processes, and any compliance/audit powers the Act furnishes regulators. The instrument’s use of mandatory phrasing (“must be subject to the corresponding condition”) places an obligation on the licensing authority to include these conditions in the licence instrument.

• Potential grounds for regulatory action. If a licence holder fails to carry out the required consultation in preparing the management plan, or fails to address consultation outcomes in the management plan, the authority likely has mechanisms under the Act to deem the management plan insufficient, require amendment, or take other action permitted by the Act (the instrument does not itself specify which of those mechanisms will be used). The instrument’s silence on timelines and standards means that sufficiency will be a matter of the regulator’s assessment under the Act and Regulations.

• Reliance on existing statutory powers. Because the instrument is made under s 17 of the Act (s 3), enforcement of the conditions is expected to flow from the Act’s licensing and compliance powers. The instrument does not create new civil causes of action in private rights holders’ favour. Consultees’ practical remedies for non‑compliance would depend on the Act’s administrative review and enforcement provisions, not on this declaration text.

Administrative and implementation risks relevant to enforcement

• Ambiguity of “address the outcomes.” The instrument requires management plans to “address the outcomes of this consultation,” but does not define the standard (for example, whether addressing means recording views, proposing mitigation, or adopting specific measures). That ambiguity could produce contested assessments about whether a management plan complies with the condition, leading to negotiation between licence holder and regulator and potential administrative appeals under the Act.

• No procedural timeline specified. The instrument requires consultation “in preparing a management plan” but places no temporal or procedural floor on how consultation must be conducted (notification periods, minimum response time, dispute resolution processes). Where consultees assert insufficient consultation, the regulator will need to interpret the instrument’s requirement in light of the Act’s review mechanisms.

• Interaction with other statutory frameworks. Item 2 requires consultation with existing petroleum/greenhouse gas titleholders whose areas overlap. Enforcement dynamics may involve coordination across regimes (the Offshore Petroleum and Greenhouse Gas Storage Act 2006), and the instrument’s silence on jurisdictional conflict resolution could shift enforcement complexity to inter‑agency processes.

Recordkeeping and evidence

• Because compliance depends on showing that consultation occurred and that the management plan addresses consultation outcomes, licence holders should expect to produce records, minutes, correspondence and management‑plan text evidencing consultation processes. Regulators assessing compliance will logically rely on such documentary proof.

Summary

The instrument establishes mandatory licence conditions rather than direct penalties. Enforcement will flow through the Act and Regulations: the licensing authority is required to attach the conditions to feasibility licences when the predicates are met, and the authority’s compliance, approval and enforcement powers under the Act will be the mechanism for ensuring those conditions are observed. The instrument’s lack of specificity on standards, timelines and sanctioning creates interpretive and implementation risk that will be resolved in practice against the Act’s compliance architecture.

The instrument is a declaratory and conditional instrument that explicitly cross‑refers to other statutory instruments and regimes. Its legal effect and operationalisation depend on the interaction between the declaration and the Act, the Regulations, and named external statutory regimes.

Primary statutory interaction

• Offshore Electricity Infrastructure Act 2021. The instrument is made under section 17 of that Act (s 3), and its defined expressions rely on section 8 of the Act (s 4 note 1). The instrument’s conditions are designed to be attached to licences issued under the Act. The instrument does not amend the Act; it exercises a delegated power under that Act to declare an area and impose licence conditions. The note in s 6 that “Licences will also be subject to other conditions: see sections 35, 45 and 54 of the Act” signals that the instrument’s conditions supplement, rather than displace, other Act‑derived licence obligations.

• Offshore Electricity Infrastructure Regulations 2022. The instrument’s definition note in s 4 instructs that “for the purposes of the Act, the position on the surface of the Earth of a point, a line or an area is to be determined by reference to the Geocentric Datum of Australia as defined in Gazette No. 35 of 6 September 1995 (GDA94 geocentric data set). See section 49 of the Offshore Electricity Infrastructure Regulations 2022.” That is a technical cross‑reference that prescribes the geodetic datum and mapping methodology for translating Schedules 1-3 into enforceable spatial boundaries.

Consultation and overlap with other sectoral regimes

• Offshore Petroleum and Greenhouse Gas Storage Act 2006. Item 2 requires feasibility licence holders to consult “titleholders of any existing petroleum or greenhouse gas titles issued under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 whose title area overlaps with the licence area.” This creates an embedded procedural interface between the offshore electricity licensing regime and existing petroleum/greenhouse gas title‑holders. The instrument does not change the rights or obligations under that petroleum statute; rather, it imposes a duty to consult overlapping titleholders and to address their input in the management plan.

• Fisheries Management Act 1991 and Fisheries Act 1995 (Vic). Item 3 targets holders of fishing concessions under the Fisheries Management Act 1991, and permits under the Fisheries Act 1995 (Vic). Here the instrument recognises existing fishing rights and imposes a duty to consult those holders where their rights “can be exercised in relation to the licence area.” It further requires management plans to address how impacts on those holders may be avoided, mitigated, or offset. The instrument does not alter the substantive content of either fisheries statute; it creates a process to consider fishery rights during feasibility licence management‑plan preparation.

• Australian Maritime Safety Authority Act 1990; Meteorology Act 1955; Environment Protection and Biodiversity Conservation Act 1999. Item 2 names AMSA, the Bureau of Meteorology and the Director of National Parks (the latter in the context of the EPBC Act) as consultees. These are procedural interlocks: statutory agencies with sectoral responsibilities are to be consulted when feasibility licences affect the declared area. The instrument does not create new statutory powers for those entities, but it ensures that their sectoral interests are formally considered in management plans.

Spatial and technical cross‑references

• Geospatial precision and datum. The instrument’s mapping language (Schedules 1-3) must be interpreted with the GDA94 geocentric datum and the Regulations’ s 49 for positional determination. That creates a technical point of interaction: marine spatial planners, applicants and regulators must reconcile coordinate lists, geodesic lines and the datum to determine precisely whether a licence area triggers the instrument’s conditions. Small mapping errors, use of different datums or projection errors could change whether a licence falls within the declared area or Defence consultation area.

Administrative interplay and decision sequencing

• Licence approval and management plan approval become points of interface. The instrument requires consultation “in preparing a management plan” and that the plan “address” consultation outcomes. In practice, this will require licence applicants to sequence engagement with other regulatory regimes (petroleum titleholders, fisheries stakeholders, AMSA, Bureau of Meteorology, Defence) before or during management plan submission. The instrument does not allocate timeframes or prioritise decision‑making across agencies; that means applicants will need to coordinate across regimes whose own statutory timetables and processes differ.

Limitations and boundaries of interaction

• No amendment of other statutes is effected. The instrument does not change the substantive rights or obligations in the named Acts. It adds procedural requirements for feasibility licence management plans under the Offshore Electricity Infrastructure Act 2021 framework.

• No creation of enforcement powers in other regimes. The instrument does not give consultees (for example, Defence or an overlapped petroleum titleholder) any express veto or an autonomous enforcement mechanism under the instrument itself. Any formal enforcement or decision‑making powers they exercise will derive from their own statutes or from standard administrative processes under the Act.

Practical implication

• The instrument operationalises inter‑agency consultation and stakeholder engagement at the feasibility stage for offshore electricity projects in the declared area. Practitioners must therefore treat licensing under the Act as a cross‑sectoral exercise involving petroleum titleholders, fisheries regulators, maritime safety and environmental authorities, meteorology, and Defence, with geospatial accuracy governed by the Regulations’ datum rule.

The instrument carries a simple amendment and commencement footprint in the text provided.

Original making and commencement

• The instrument is dated 17 December 2022 and states it is made by Chris Bowen, Minister for Climate Change and Energy. Section 2 contains a standard commencement table: “The whole of this instrument , The day after this instrument is registered.” The instrument also includes an editorial note in the commencement table that the table “relates only to the provisions of this instrument as originally made. It will not be amended to deal with any later amendments of this instrument.” That is a record‑keeping statement about the published commencement information rather than a substantive legal clause.

No amendments recorded in this text

• The text of the instrument as provided contains no amending provisions, no schedules or notes indicating prior or subsequent amendments, and no repeal or savings clauses. The Schedules and map are presented as originally made. There is no serial history included in the instrument itself.

How to interpret future amendment practice

• The instrument’s own note signals the conventional practice that the commencement table is not updated to reflect later amendments. In administratively maintained instruments, later amendments would typically appear as separate instruments amending the original declaration; this instrument contains no such amendments.

Practical consequence for users seeking amendment history

• This instrument, as presented, should be read as the original declaration made on 17 December 2022, commencing the day after registration. Any later changes, revocations or replacements would need to be located in the Federal Register of Legislation or other official compilations where instruments amending or repealing this declaration are published. The instrument itself provides no further history.

Administrative and archival points

• The instrument contains a discrete set of Schedules (1-4) and a defined list of conditions. Any future amendment to the declared area (for example, expansion, contraction, or re‑definition of coordinates) would, in typical legislative practice, be achieved by a further declaration instrument under the Act. Practitioners should therefore treat the Schedules here as the authoritative coordinates until such an amending instrument is located.

• The instrument’s references to other statutory provisions (for example, s 49 of the Regulations) should be read in light of the version of those subordinate instruments in force at the time a licence is issued or a management plan prepared, because Regulations and the Act may themselves be amended over time.

Summary

There is no amendment history recorded in the instrument text provided. It is an original instrument made on 17 December 2022 and commenced the day after registration. Any subsequent amendment or repeal must be found in later instruments; none are included here.

The instrument itself does not record any litigation history, judicial decisions, or administrative appeals. It contains no citations to cases and does not assert any adjudicative history. The text is a standalone delegated instrument that declares a maritime area and prescribes licence conditions.

What the absence of litigation information means for practitioners

• No reported cases cited in the instrument. Because the instrument does not list or reference judicial decisions, there is no litigation history embedded in the instrument to guide interpretation of its clauses. Practitioners seeking judicial treatment (for example, on the meaning of “address the outcomes of this consultation” or disputes over spatial overlap) will need to examine case law under the Offshore Electricity Infrastructure Act 2021 and associated regimes, should such cases arise, and not rely on precedent cited in the instrument.

• Administrative review and appeals. The instrument makes mandatory certain licence conditions. If an affected party (for example, a licence applicant, a consultee, or an existing titleholder) considers that a decision taken under the Act or under the instrument’s conditions is unlawful or procedurally deficient, remedies (such as merits review, judicial review, or specific statutory appeal mechanisms) would be sought under the Act’s review architecture and general administrative law principles. The instrument makes no statement about the availability of those remedies.

Potential litigation hotspots implied by the instrument

• Sufficiency of consultation and “addressing” outcomes. The instrument’s requirement that management plans “address the outcomes of this consultation” is potentially a locus for dispute. Where a consultee alleges inadequate consultation or insufficient response in a management plan, that claim would likely be framed as an administrative law issue about whether the regulator complied with statutory requirements in approving a plan, or whether the licence holder complied with the condition attached to the licence.

• Spatial determinations and datum application. Because the declared area is defined by coordinate lists and geodesics with a specified datum, disputes about whether a particular licence area overlaps the declared area could give rise to contested technical questions. Such disputes might lead to litigation or expert determinations where the precise application of GDA94, geodesics, or coordinate conversion is outcome‑determinative for the application of the s 6 conditions.

• Overlap with petroleum/greenhouse gas titles and fisheries rights. Item 2 requires consultation with overlapped petroleum/greenhouse gas titleholders; item 3 requires consultation with holders of fishery concessions and permits. Conflicts of interest or overlapping uses could give rise to administrative challenges or litigation if parties assert that consultations were inadequate or their statutory rights under other Acts were infringed by decisions taken pursuant to the management plan.

Practical note

• Because the instrument is procedural (declaring an area and prescribing consultation duties), any litigation stemming from it is most likely to be administrative in nature and driven by disputes over process, adequacy of consultation, spatial overlap, or the licensing authority’s exercise of statutory powers under the Act. The instrument does not itself generate criminal offences or private causes of action; any legal challenges would be directed at agency decisions to grant licences, approve management plans, or the sufficiency of consultation under the instrument and the Act.

Summary

No litigation history is recorded in the instrument. The likely legal friction points, if disputes were to arise, include interpretation of the management‑plan consultation/“address” requirement, spatial/datum determinations, and conflicts with existing petroleum or fisheries rights. Remedies and enforcement would be sought under the Act and general administrative law, not by reference to any cases cited in this instrument.

The text contains several drafting, operational and interpretive features that practitioners and stakeholders should flag as potential pitfalls.

1. Conditions apply only to feasibility licences by text

• The s 6 table repeatedly uses the predicate “the licence is a feasibility licence.” The instrument therefore does not, by its terms, attach the prescribed consultation and management‑plan duties to commercial licences or research and demonstration licences. A common operational mistake would be to assume the consultation duties apply to all licence types; they do not. The instrument’s note that “Licences will also be subject to other conditions: see sections 35, 45 and 54 of the Act” reinforces that other licence types will be regulated, but not necessarily by this instrument’s conditions.

2. “Address the outcomes” is vague

• The instrument requires management plans to “address the outcomes of this consultation.” The instrument does not define “address”: does it mean record the views, propose mitigation, incorporate compensatory measures, or meet a substantive standard endorsed by the consultee? That indeterminacy shifts the burden to the licensing authority and could generate disputes over sufficiency. Licence holders should not assume a minimalist record will be accepted; consultees may assert that more substantial remedial measures are required.

3. No timeframes or procedural minimums for consultation

• The instrument requires consultation “in preparing a management plan” but supplies no procedural timetable, response windows, minimum notice periods, or requirements for public notification. That gives practical power to consultees to argue procedural unfairness if they were not given adequate time or notice. Licence applicants should plan for generous timelines and documented outreach.

4. Spatial accuracy, datum and geodesics matter

• The Schedules define the declared area by lists of latitude/longitude points connected by geodesics. The s 4 note points to GDA94 and the Regulations’ s 49 for positional determination. Small errors in datum, projection or rounding could change whether a licence area triggers the instrument’s conditions. Practitioners must use GDA94 and adhere to the Regulations’ technical rules when mapping licence boundaries, and should include geodetic expertise in applications.

5. Duplicate or near‑duplicate coordinates in the Schedules

• The Schedules contain multiple coordinates that are identical or extremely close (for example, OEI‑P1‑66 and P1‑67; P1‑97 and P1‑100; OEI‑P3‑2 and P3‑3). These can create mapping ambiguity, and software or GIS workflows may treat such points differently (e.g. collapse a vertex, create zero‑area polygons, or trigger topology rules). GIS practitioners should carefully validate the polygon geometry and document the methodology used to translate the coordinate tables into polygon files for applications.

6. Defence consultation area is a radial concept anchored to a single radar location

• The instrument defines the Defence consultation area as an 80 nautical mile radius around particular radar coordinates (s 4). That circle creates a single binary trigger: licences within the circle require Defence consultation. The circle is substantial in area; applicants should map their areas early to identify whether they fall inside the radius. The instrument does not provide a process for reconciling Defence security or operational concerns versus development aims; expect inter‑agency negotiation.

7. Overlaps with petroleum/greenhouse gas titles and fisheries rights create practical complexity

• Item 2 requires consultation with titleholders of overlapping petroleum or greenhouse gas titles under the Offshore Petroleum and Greenhouse Gas Storage Act 2006; item 3 requires consultation with fishery concession/permit holders “that can be exercised in relation to the licence area.” Determining whether rights “can be exercised” or whether a title “overlaps” may be factually and legally complex. Licence holders bear the duty to identify overlapping titleholders and relevant fisheries rights and to engage with them. Failure to identify such overlaps accurately risks later contestation.

8. Representative organisation mechanism can be double‑edged

• Item 3 allows a concession or permit holder to nominate a representative organisation for consultation purposes. That can reduce administrative burden but can also lead to disputes over representativeness and whether a given organisation truly represents all affected holders. Licence holders should obtain documentary confirmation of any nomination and maintain evidence of outreach.

9. No express private enforcement rights for consultees

• The instrument creates a duty to consult and to address consultation outcomes, but it does not create private causes of action for consultees. A common misreading could be that consultees gain an independent statutory veto. In practice, consultees’ leverage depends on administrative processes and the regulator’s assessment under the Act. Consultees should instead assert their concerns through the prescribed consultation process and seek administrative remedies if their consultation rights are disregarded.

10. The instrument is technical and narrow in scope

• The instrument accomplishes a precise set of tasks (declare area; prescribe consultation conditions for feasibility licences). It does not address broader project approvals, environmental approvals under the EPBC Act, maritime safety approvals, or other sectoral consents. Practitioners should not conflate compliance with this instrument with compliance across all applicable regimes.

In short: the practical pitfalls are spatial precision, definitional ambiguity (notably “address the outcomes”), lack of procedural timetables, the limited scope to feasibility licences, potential for contested overlap with other titleholders, and the need for careful recordkeeping to demonstrate that consultation occurred and was meaningfully addressed.

A practical compliance checklist focused on feasibility licence applicants and holders operating in the OEI‑01‑2022 declared area.

1. Confirm spatial status early

• Use the GDA94 geocentric datum and apply the Offshore Electricity Infrastructure Regulations 2022 s 49 rules for positional determination, as required by the instrument’s definition note (s 4). Translate the Schedules’ latitude/longitude lists into a GIS polygon using geodesics and GDA94 so you can reliably determine whether your proposed licence area (or any part of it) lies within Declared Area OEI‑01‑2022 and whether it falls within the Defence consultation area (80 nm radius around the specified point).

• Obtain expert geospatial verification to avoid datum/projection errors. Save the GIS methodology and metadata so you can produce evidence of the spatial determination if challenged.

2. Identify licence type and trigger conditions

• Confirm that your licence is a feasibility licence as defined in the Act (s 4 note: several key expressions are defined in s 8 of the Act). The instrument’s consultation and management‑plan duties apply by text to feasibility licences only. If your licence is commercial or research/demonstration, these particular conditions in the instrument do not attach by their terms (but check other Act conditions noted in s 6).

• If your feasibility licence area overlaps the Defence consultation area, item 1 in s 6 is engaged; if it overlaps other parts of the declared area, items 2 and/or 3 may be engaged depending on the presence of overlapping petroleum/greenhouse gas titles or fishery rights.

3. Map and identify overlapping titles and rights

• For item 2: ascertain whether any existing petroleum or greenhouse gas titles under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 overlap your licence area. If overlaps exist, identify the exact titleholders and contact details.

• For item 3: identify whether any fishing concessions (Fisheries Management Act 1991) or permits (Fisheries Act 1995 (Vic)) can be exercised in relation to your licence area. Determine whether relevant concession/permit holders have nominated a representative organisation for consultation; if so, you may consult that organisation in lieu of individual holders (s 6 item 3(a)(i)).

4. Plan consultation and document evidence

• Prepare a consultation plan and timeline that builds consultation into the management‑plan preparation process. Because the instrument requires consultation “in preparing a management plan,” consultation must be proactive, and the management plan must incorporate or respond to consultation outcomes.

• Allow generous timeframes for consultees to respond. The instrument contains no prescribed minimum notice periods; to reduce risk, allow adequate time for agencies and titleholders to engage meaningfully.

• Keep contemporaneous records: copies of notices, meeting minutes, correspondence, submissions, responses, tendered technical materials, and logs of telephone or online meetings. These records will be evidence that consultation occurred and will form the basis for the management plan’s section “addressing the outcomes.”

5. Engage prescribed consultees and tailor consultation content

• Defence (if inside Defence consultation area): consult the Department of Defence and specifically discuss potential impacts on Defence operations and radar capability (s 6 item 1(a)). Document Defence’s technical concerns and any proposed steps to mitigate or avoid impacts. In your management plan, explicitly state how you addressed Defence’s outcomes (item 1(b)).

• Bureau of Meteorology, Director of National Parks, AMSA, and overlapping petroleum/greenhouse gas titleholders: consult these bodies as required by item 2. For each, tailor your consultation materials to the entity’s remit (e.g. meteorological infrastructure and data needs for BOM; maritime safety navigation and notice to mariners for AMSA; environmental information for the Director of National Parks).

• Fishing concession/permit holders or their nominated representative organisations: consult directly and ask about practicable measures to avoid, mitigate, or offset impacts. When fishing rights can be exercised in the licence area, item 3(b) requires the management plan to address “including how impacts on these holders may be avoided, mitigated, or offset.” Provide concrete proposals and costed mitigation/offset options where feasible.

6. Draft the management plan to clearly “address the outcomes”

• In the management plan, create a dedicated section for each consultee summarising: (a) the consultation undertaken; (b) key issues raised by the consultee; and (c) your proposed responses, including avoidance measures, mitigation strategies, offsets, monitoring regimes, or operational constraints. Use headings such as “Consultation , [Agency/Titleholder/Representative]” and append consultation records.

• For fisheries impacts, include specific measures for avoiding, mitigating or offsetting impacts (as required by s 6 item 3(b)) , for example temporal or spatial exclusion zones during key fishing periods, gear restrictions, compensation arrangements, or collaborative monitoring.

7. Anticipate regulator scrutiny and inter‑agency coordination

• Expect the licensing authority to evaluate consultation sufficiency as part of management‑plan approval. The instrument imposes the condition; the regulator will have discretion under the Act to determine whether the plan complies. Be prepared to revise the plan in response to regulator feedback.

• Where overlapping regimes are involved (petroleum titleholders, fisheries, Defence, environmental approvals), coordinate your consultation responses and ensure consistency with any obligations under those other regimes. Consider bilateral meetings or triage workshops with key stakeholders to resolve technical conflicts early.

8. Maintain compliance documentation and prepare for audits

• Store records of consultations, the management plan drafts and final approved plan, and any correspondence with regulators. Because the instrument’s compliance will be judged against documentary evidence of consultation and the management plan’s content, these records are critical in the event of compliance checks or disputes.

9. Legal review and risk assessment

• Obtain legal advice on the sufficiency of proposed consultation processes and the content of the management plan, particularly for contentious issues such as Defence radar impacts or overlapping petroleum titles.

• Consider a risk register that captures stakeholder positions, potential mitigation cost estimates, and timelines for addressing outstanding concerns.

10. Monitor for changes to the instrument, the Act and Regulations

• Keep a watching brief for any amending instruments, changes to the Act or Regulations, or development of administrative guidance on what constitutes sufficient consultation and how the regulator interprets “address the outcomes.” The instrument’s coordinate list and the Regulations’ datum rules should be consulted when ascertaining current spatial boundaries.

Summary checklist

• Use GDA94 and geodesics to map the declared area and Defence consultation area.
• Confirm your licence is a feasibility licence; otherwise, these specific conditions will not apply by their terms.
• Identify overlapping petroleum titles and fishery concession/permit holders; confirm representative nominations where applicable.
• Consult Defence (if inside the 80 nm radius), BOM, Director of National Parks, AMSA, overlapping titleholders, and fishing holders/representatives as required while preparing the management plan.
• Document consultation comprehensively and ensure the management plan explicitly “addresses” consultation outcomes, including measures to avoid, mitigate or offset fisheries impacts.
• Retain records and be prepared for regulator review and possible revisions.

Following these steps will align a licence holder’s management‑plan preparation with the instrument’s mandatory conditions and reduce the risk of administrative challenge for failure to consult or to address consultation outcomes.