Owner: AGL Energy Limited
Status:
Technology Type: Turbine - OCGT
Fuel Type: Fossil - Natural Gas Pipeline
DUID:
Capacity: 0 MW
Full Commercial Use Date:
Expected Closure Year:
Closure Date:
29 May 2026 04:00 → 30 May 2026 04:00 AEST · data through 30 May 2026, 04:00
| Capex total | $332.92M |
|---|---|
| Capex / MW | $1,189,000 |
| Capex / MWh storage | — |
| Fixed OPEX (annual) | $3.94M |
| Fixed OPEX / MW-yr | $14,066 |
| Variable OPEX / MWh | $8.10 |
| Fuel cost / GJ | $12.00 |
| Heat rate GJ/MWh | 10.81 |
Confidence: medium · Status: ai estimated · Capex basis: default · AI checked 04 Jun 2026
Notes: BIPS2 appears to be publicly announced/planning-stage rather than operational; no DUID, full commercial use date, final turbine OEM, final OCGT configuration, financial close, EPC contract value, or generator-specific O&M contract was found in public sources. AGL's June 2025 variation seeks flexibility for either gas turbines or reciprocating engines and increases BIPS2 output to up to 280 MW. The capex and O&M values are therefore not reported BIPS2 values; they are default 2024 Aurecon/AEMO large OCGT assumptions scaled to 280 MW. Capex uses EPC-only AUD 1,189/kW net for a large F-class OCGT and excludes land/development, site-specific gas connection, SCR/NOx controls if required, financing, contingency beyond the source estimate, and any BIPS2-specific switchyard or gas compression costs not captured by the generic benchmark. Heat rate and efficiency use the large OCGT HHV net maximum-operation values. Emissions intensity is calculated as 10.811 GJ/MWh HHV multiplied by the 2025 NGA Scope 1 combined natural-gas factor of 51.53 kgCO2-e/GJ. No major refurbishment or closure date was found; the default OCGT economic design life is 25 years and technical life is 40 years.
[AI 2026-06-04] BIPS 2 is not yet an operating DUID and appears in AEMO/NEM generator listings as publicly announced with 280 MW capacity. AGL's June 2025 planning variation states BIPS 2 construction is proposed to commence in 2026 and be operational in 2028, subject to approvals and a final decision. No project-specific capex for BIPS 2 was found; capex and O&M values are therefore estimated from AEMO/Aurecon 2024 large OCGT parameters scaled to 280 MW. The original Barker Inlet Stage 1 reported capex of AUD 295 million for 210 MW is not used as BIPS 2 capex because Stage 2 may use gas turbines and has a larger proposed output. Emissions intensity is calculated as 10.811 GJ/MWh HHV times 51.53 kg CO2-e/GJ for pipeline natural gas divided by 1000. No announced BIPS 2 closure date was found; 25 years is a technology-economic-life assumption, while Aurecon also lists 40 years technical life.
[AI 2026-06-04] Barker Inlet Power Station 2 is listed by AEMO as a publicly announced 280 MW gas project as at October 2025. I found no public AGL FID announcement or project-specific construction cost, O&M, heat-rate, fuel-price, emissions-intensity, or closure date for BIPS2. Financial and operating fields are therefore default estimates based on AEMO/Aurecon 2024 large OCGT assumptions, scaled to 280 MW. Capex total is EPC-only on a net basis: 280 MW x AUD 1.189 million/MW = AUD 332.92 million, excluding land/development and fuel connection costs; Aurecon separately indicates land/development at 9% of capex and fuel connection at AUD 21.2 million + AUD 1.6 million/km where applicable. The 2025 planning variation source indicates AGL sought flexibility to use either gas turbines or reciprocating engines and increase Stage 2 output to up to 280 MW from the previously approved 210 MW. Existing Barker Inlet Power Station Stage 1 is a separate 210 MW reciprocating-engine plant commissioned in 2019 with reported construction cost of AUD 295 million; this cost was not used as BIPS2 OCGT capex.
Model: gpt-5.5 · Reasoning: medium · Fetched 04 Jun 2026 08:23 · ID: resp_0aa9cdd75270936b006a20a8c80c40819584d206f592c70490
{
"generator_identity": {
"site_name": "Barker Inlet Power Station 2",
"duid": null,
"owner": "AGL Energy Limited",
"region": "SA / NEM South Australia",
"technology_type": "Turbine - OCGT; publicly announced gas project, with 2025 planning material indicating Stage 2 variation may allow either gas turbines or reciprocating engines",
"fuel_type": "Fossil - Natural Gas Pipeline"
},
"financial_profile": {
"generator_type_normalised": "ocgt",
"capex_total_aud": 332920000,
"capex_year": 2024,
"capex_basis": "default",
"capex_per_mw_aud": 1189000,
"capex_per_mwh_aud": null,
"fixed_opex_annual_aud": 3938480,
"fixed_opex_per_mw_year_aud": 14066,
"variable_opex_per_mwh_aud": 8.1,
"fuel_cost_per_gj_aud": 12,
"fuel_contract_notes": "No generator-specific BIPS2 gas supply contract price was found. AGL community dialogue minutes state BIPS2 gas would come from the Cooper Basin in northern South Australia or Western Victoria, with volume dependent on system requirements. AEMO's Draft 2025 IASR states observed wholesale gas contract prices have been anchored at or around the $12/GJ gas price cap since July 2023; this is used here as a proxy fuel commodity cost, not a delivered BIPS2 contract price.",
"heat_rate_gj_per_mwh": 10.811,
"efficiency_pct": 33.3,
"emissions_intensity_tco2_mwh": 0.55709083,
"asset_life_years": 40,
"discount_rate_pct": 7,
"source_confidence": "medium",
"data_status": "ai_estimated",
"notes": "Barker Inlet Power Station 2 is listed by AEMO as a publicly announced 280 MW gas project as at October 2025. I found no public AGL FID announcement or project-specific construction cost, O&M, heat-rate, fuel-price, emissions-intensity, or closure date for BIPS2. Financial and operating fields are therefore default estimates based on AEMO/Aurecon 2024 large OCGT assumptions, scaled to 280 MW. Capex total is EPC-only on a net basis: 280 MW x AUD 1.189 million/MW = AUD 332.92 million, excluding land/development and fuel connection costs; Aurecon separately indicates land/development at 9% of capex and fuel connection at AUD 21.2 million + AUD 1.6 million/km where applicable. The 2025 planning variation source indicates AGL sought flexibility to use either gas turbines or reciprocating engines and increase Stage 2 output to up to 280 MW from the previously approved 210 MW. Existing Barker Inlet Power Station Stage 1 is a separate 210 MW reciprocating-engine plant commissioned in 2019 with reported construction cost of AUD 295 million; this cost was not used as BIPS2 OCGT capex."
},
"sources": [
{
"field_name": "site_status_capacity",
"value_text": "Publicly announced gas project: Barker Inlet Power Station 2, 280 MW",
"value_numeric": 280,
"unit": "MW",
"source_url": "https://www.aemo.com.au/-/media/files/electricity/nem/planning_and_forecasting/sa_advisory/2025/2025-south-australian-electricity-report.pdf?rev=40d5c6a3cece40d3abca846a51c16aa8&sc_lang=en",
"source_title": "2025 South Australian Electricity Report",
"publisher": "AEMO",
"published_date": "2025-10",
"confidence": "high",
"raw_excerpt": "Table 14 Publicly announced generation and storage developments with capacity of ≥200 MW, October 2025 ... Gas Project Barker Inlet Power Station 2 280 ... Reeves Plains OCGT – Stage 1 150 ... Reeves Plains OCGT – Stage 2 150.",
"ai_summary": "Confirms BIPS2 is tracked by AEMO as a publicly announced South Australian gas project with 280 MW nameplate capacity."
},
{
"field_name": "technology_scope_planning_variation",
"value_text": "Stage 2 variation to allow either gas turbines or reciprocating engines and increase output to up to 280 MW instead of approved 210 MW",
"value_numeric": 280,
"unit": "MW",
"source_url": "https://plan.sa.gov.au/__data/assets/pdf_file/0020/1521308/5-AGL-BIPS-Stage-2-Crown-Development-Variation-Part-2-June-2025Part-last.pdf",
"source_title": "Barker Inlet Power Station Stage 2 - Crown Development Variation Part 2",
"publisher": "PlanSA / AECOM for AGL Barker Inlet Pty Ltd",
"published_date": "2025-06",
"confidence": "medium",
"raw_excerpt": "AGL are seeking to modify the DA to permit a wider range of plant options for Stage 2 of the BIPS (BIPS 2), including: to enable BIPS 2 to use either gas turbines or reciprocating engines ... and to increase the proposed output of BIPS 2 to up to 280 MW (instead of the currently approved 210 MW).",
"ai_summary": "Planning material supports the OCGT/gas-turbine option but also shows technology is not locked in publicly; BIPS2 may use gas turbines or reciprocating engines."
},
{
"field_name": "capex_per_mw_aud",
"value_text": "Large GT OCGT relative EPC cost, net basis, excluding land and development costs; includes liquid fuel storage and hydrogen capability premium as described by Aurecon",
"value_numeric": 1189000,
"unit": "AUD/MW",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en",
"source_title": "2024 Energy Technology Cost and Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Table 4-31 Cost estimate ... CAPEX – EPC cost ... Relative cost $/kW ... Small GT 2,193; Large GT 1,189 ... Net basis. Includes liquid fuel storage (30 hours) and associated infrastructure ... Relative cost does not include land and development costs. Large GTs - cost variability ... Cost range $1,150/kW-$1,550/kW.",
"ai_summary": "Used the large gas turbine OCGT EPC cost of AUD 1,189/kW, converted to AUD 1.189 million/MW, because BIPS2 is 280 MW and most closely resembles a large OCGT option."
},
{
"field_name": "capex_total_aud",
"value_text": "Estimated EPC capex: 280 MW x AUD 1.189 million/MW; excludes land/development and fuel connection",
"value_numeric": 332920000,
"unit": "AUD",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en",
"source_title": "2024 Energy Technology Cost and Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Total EPC cost $ ... Large GT 290,479,200 ... Cost of land and development ... $26,143,128 Assuming 9% of CAPEX. Fuel connection costs $M $21.2M + $1.6M/km.",
"ai_summary": "Aurecon provides the generic large-GT OCGT EPC scope and separate adders. The BIPS2 total is scaled to 280 MW and is not a reported AGL project cost."
},
{
"field_name": "capex_year",
"value_text": "Aurecon cost assumptions are for plausible NEM OCGT projects in 2024; first year commercially viable for construction 2024",
"value_numeric": 2024,
"unit": "year",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en",
"source_title": "2024 Energy Technology Cost and Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "The hypothetical project has been selected based on what is envisaged as plausible projects for development in the NEM in 2024 ... First Year Assumed Commercially Viable for construction Year 2024 2024.",
"ai_summary": "Used 2024 as the cost basis year for the generic OCGT assumptions."
},
{
"field_name": "fixed_opex_per_mw_year_aud",
"value_text": "Large GT OCGT fixed O&M excluding fuel",
"value_numeric": 14066,
"unit": "AUD/MW-year",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en",
"source_title": "2024 Energy Technology Cost and Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "OPEX – Annual (excluding fuel) Fixed O&M Cost $/MW (Net) Small GT 17,368; Large GT 14,066. Based on Aurecon internal database. Labour cost adjustment from 2023 included.",
"ai_summary": "Applied large-GT fixed O&M cost to 280 MW to estimate annual fixed opex."
},
{
"field_name": "fixed_opex_annual_aud",
"value_text": "Estimated annual fixed O&M: 280 MW x AUD 14,066/MW-year",
"value_numeric": 3938480,
"unit": "AUD/year",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en",
"source_title": "2024 Energy Technology Cost and Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "OPEX – Annual (excluding fuel) Fixed O&M Cost $/MW (Net) ... Large GT 14,066 ... Total annual O&M Cost ... Large GT $6,896,814 Annual average cost over the design life.",
"ai_summary": "The field is a scaled estimate for BIPS2, not a reported AGL budget."
},
{
"field_name": "variable_opex_per_mwh_aud",
"value_text": "Large GT OCGT variable O&M excluding fuel",
"value_numeric": 8.1,
"unit": "AUD/MWh",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en",
"source_title": "2024 Energy Technology Cost and Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Variable O&M Cost $/MWh (Net) Small GT 16.1; Large GT 8.1 ... Assumes less than 1 start per day. Additional starts may incur higher maintenance costs depending on OEM maintenance schedule calculation considering starts.",
"ai_summary": "Used the large-GT OCGT variable O&M estimate. It excludes fuel and may be higher if start frequency exceeds the assumption."
},
{
"field_name": "fuel_cost_per_gj_aud",
"value_text": "Proxy wholesale gas cost based on observed east coast wholesale contract pricing around the gas price cap; not BIPS2-specific delivered gas cost",
"value_numeric": 12,
"unit": "AUD/GJ",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/draft-2025-inputs-assumptions-and-scenarios-report-stage-1.pdf",
"source_title": "Draft 2025 Inputs, Assumptions and Scenarios Report Stage 1",
"publisher": "AEMO",
"published_date": "2024-12",
"confidence": "medium",
"raw_excerpt": "Wholesale contract prices have been anchored at or around the $12/GJ price cap since it was introduced, and this market dynamic is expected to continue given tight supply conditions ... The gas prices associated with each gas-powered generator ... include regional pricing ... and pipeline transmission.",
"ai_summary": "Used AUD 12/GJ as a proxy fuel commodity cost due to absence of a BIPS2-specific public fuel contract. Delivered costs could differ."
},
{
"field_name": "fuel_contract_notes",
"value_text": "BIPS2 gas source expected from Cooper Basin in northern South Australia or Western Victoria; volume depends on system requirements",
"value_numeric": null,
"unit": null,
"source_url": "https://www.agl.com.au/content/dam/digital/agl/documents/about-agl/operations-docs/251126-minutes-of-agl-torrens-island-community-dialogue-group-20-august-2024.pdf",
"source_title": "Minutes of AGL Torrens Island Community Dialogue Group Meeting, 20 August 2024",
"publisher": "AGL Energy",
"published_date": "2024-08-20",
"confidence": "medium",
"raw_excerpt": "Tony asked where the gas for BIPS2 will come from? Kevin responded that it will come from the Cooper Basin in northern SA or Western Victoria. Kevin explained that the volume of gas depends on system requirements.",
"ai_summary": "Provides a source for expected gas supply regions, but not price, term, counterparty, or take-or-pay details."
},
{
"field_name": "heat_rate_gj_per_mwh",
"value_text": "Large GT OCGT heat rate at maximum operation, HHV net",
"value_numeric": 10.811,
"unit": "GJ/MWh",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en",
"source_title": "2024 Energy Technology Cost and Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Heat rate at maximum operation (GJ/MWh) HHV Net ... Small GT 10.489; Large GT 10.811. Thermal Efficiency at MCR %, HHV Net ... Small GT 34.3%; Large GT 33.30%.",
"ai_summary": "Used the HHV net maximum-load heat rate for a generic large OCGT."
},
{
"field_name": "efficiency_pct",
"value_text": "Large GT OCGT thermal efficiency at MCR, HHV net",
"value_numeric": 33.3,
"unit": "%",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en",
"source_title": "2024 Energy Technology Cost and Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Thermal Efficiency at MCR %, HHV Net ... Small GT 34.3%; Large GT 33.30%.",
"ai_summary": "Used the generic large-GT OCGT HHV net efficiency."
},
{
"field_name": "emissions_intensity_tco2_mwh",
"value_text": "Estimated Scope 1 emissions intensity = 10.811 GJ/MWh x 51.53 kg CO2-e/GJ / 1000",
"value_numeric": 0.55709083,
"unit": "tCO2e/MWh",
"source_url": "https://www.dcceew.gov.au/sites/default/files/documents/national-greenhouse-account-factors-2025.pdf",
"source_title": "Australian National Greenhouse Accounts Factors 2025",
"publisher": "Department of Climate Change, Energy, the Environment and Water",
"published_date": "2025",
"confidence": "medium",
"raw_excerpt": "Natural gas distributed in a pipeline is reported in the NGA Factors as a stationary energy fuel with a Scope 1 combined-gases emission factor of 51.53 kg CO2-e/GJ.",
"ai_summary": "Combined the DCCEEW natural-gas emission factor with Aurecon's OCGT heat rate. This is a calculated estimate, not a measured BIPS2 emissions intensity."
},
{
"field_name": "asset_life_years",
"value_text": "Large GT OCGT technical life / operational life",
"value_numeric": 40,
"unit": "years",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en",
"source_title": "2024 Energy Technology Cost and Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Economic Life (Design Life) Years 25 25 ... Technical Life (Operational Life) Years 40 40.",
"ai_summary": "Used the 40-year technical life for the asset_life_years field; economic design life is 25 years."
},
{
"field_name": "discount_rate_pct",
"value_text": "AEMO Draft 2025 IASR central real discount rate for ISP analysis; OCGT large GT central WACC is 9% but common discount rate is 7%",
"value_numeric": 7,
"unit": "%",
"source_url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/draft-2025-inputs-assumptions-and-scenarios-report-stage-1.pdf",
"source_title": "Draft 2025 Inputs, Assumptions and Scenarios Report Stage 1",
"publisher": "AEMO",
"published_date": "2024-12",
"confidence": "medium",
"raw_excerpt": "Table 23 Pre-tax real weighted average cost of capital ... OCGT (large gas turbine) 7.0% 9.0% 12.0% ... OEA has recommended that the appropriate discount rate, for use in the 2025 IASR and 2026 ISP ... is 7%.",
"ai_summary": "Used 7% as a generic discount-rate assumption; for project-finance modelling a technology-specific OCGT WACC of 9% central may also be relevant."
},
{
"field_name": "major_refurbishment_or_closure_notes",
"value_text": "No BIPS2 closure or refurbishment date found; adjacent Torrens Island B scheduled to close 30 June 2028; Torrens A decommissioning and demolition underway",
"value_numeric": null,
"unit": null,
"source_url": "https://www.agl.com.au/about-agl/operations/agl-in-torrens-island?giha9n=hrd26h",
"source_title": "AGL on Torrens Island",
"publisher": "AGL Energy",
"published_date": "2026",
"confidence": "medium",
"raw_excerpt": "Torrens Island Power Station B ... is scheduled to close on 30 June 2028. ... Torrens Island 'A' Station ... final unit closed in September 2022 ... decommissioning and demolition process is underway ... Barker Inlet Power Station consists of 12 reciprocating engines.",
"ai_summary": "Relevant site context only. It does not provide BIPS2 closure/refurbishment information."
},
{
"field_name": "stage1_capex_context_not_used",
"value_text": "Existing Barker Inlet Stage 1 reported construction cost AUD 295 million for 210 MW reciprocating-engine plant, including electrical equipment, buildings and facilities",
"value_numeric": 295000000,
"unit": "AUD",
"source_url": "https://www.agl.com.au/content/dam/digital/agl/documents/about-agl/operations-docs/251126-minutes-of-agl-torrens-island-community-dialogue-group-20-august-2024.pdf",
"source_title": "Minutes of AGL Torrens Island Community Dialogue Group Meeting, 20 August 2024",
"publisher": "AGL Energy",
"published_date": "2024-08-20",
"confidence": "high",
"raw_excerpt": "Kevin replied that the construction cost of Barker Inlet was $295 million but stressed that this was the total cost of the power station, including the electrical equipment, buildings and facilities, not just the engines.",
"ai_summary": "This confirms Stage 1 capex context but is not used for BIPS2 OCGT assumptions because Stage 1 is a different in-service 210 MW reciprocating-engine plant."
}
],
"warnings": [
"No public AGL final investment decision, EPC award, financing document, or annual-report disclosure for Barker Inlet Power Station 2 capex was found; capex is a generic OCGT estimate, not reported project cost.",
"BIPS2 is publicly announced and appears to have no DUID or full commercial-use date in the sources reviewed.",
"Planning material indicates AGL sought flexibility for BIPS2 to use either gas turbines or reciprocating engines; the user's OCGT classification is plausible but not proven as final selected technology.",
"Fuel cost is not a generator-specific contract price. AUD 12/GJ is a proxy based on AEMO commentary on wholesale contract prices around the gas price cap; delivered gas cost may differ due to transport, balancing, and contract terms.",
"Fixed O&M, variable O&M, heat rate, efficiency, asset life, and emissions intensity are default large-GT OCGT assumptions scaled to 280 MW, not measured BIPS2 data.",
"The adjacent in-service Barker Inlet Power Station is a separate 210 MW reciprocating-engine facility with reported AUD 295 million construction cost; it should not be conflated with BIPS2 OCGT economics."
]
}
{
"meta": {
"model": "gpt-5.5",
"reasoning_effort": "medium",
"response_id": "resp_0aa9cdd75270936b006a20a8c80c40819584d206f592c70490",
"fetched_at": "2026-06-04T08:23:08+10:00"
},
"raw_text": "{\"generator_identity\":{\"site_name\":\"Barker Inlet Power Station 2\",\"duid\":null,\"owner\":\"AGL Energy Limited\",\"region\":\"SA / NEM South Australia\",\"technology_type\":\"Turbine - OCGT; publicly announced gas project, with 2025 planning material indicating Stage 2 variation may allow either gas turbines or reciprocating engines\",\"fuel_type\":\"Fossil - Natural Gas Pipeline\"},\"financial_profile\":{\"generator_type_normalised\":\"ocgt\",\"capex_total_aud\":332920000,\"capex_year\":2024,\"capex_basis\":\"default\",\"capex_per_mw_aud\":1189000,\"capex_per_mwh_aud\":null,\"fixed_opex_annual_aud\":3938480,\"fixed_opex_per_mw_year_aud\":14066,\"variable_opex_per_mwh_aud\":8.1,\"fuel_cost_per_gj_aud\":12,\"fuel_contract_notes\":\"No generator-specific BIPS2 gas supply contract price was found. AGL community dialogue minutes state BIPS2 gas would come from the Cooper Basin in northern South Australia or Western Victoria, with volume dependent on system requirements. AEMO's Draft 2025 IASR states observed wholesale gas contract prices have been anchored at or around the $12/GJ gas price cap since July 2023; this is used here as a proxy fuel commodity cost, not a delivered BIPS2 contract price.\",\"heat_rate_gj_per_mwh\":10.811,\"efficiency_pct\":33.3,\"emissions_intensity_tco2_mwh\":0.55709083,\"asset_life_years\":40,\"discount_rate_pct\":7,\"source_confidence\":\"medium\",\"data_status\":\"ai_estimated\",\"notes\":\"Barker Inlet Power Station 2 is listed by AEMO as a publicly announced 280 MW gas project as at October 2025. I found no public AGL FID announcement or project-specific construction cost, O&M, heat-rate, fuel-price, emissions-intensity, or closure date for BIPS2. Financial and operating fields are therefore default estimates based on AEMO/Aurecon 2024 large OCGT assumptions, scaled to 280 MW. Capex total is EPC-only on a net basis: 280 MW x AUD 1.189 million/MW = AUD 332.92 million, excluding land/development and fuel connection costs; Aurecon separately indicates land/development at 9% of capex and fuel connection at AUD 21.2 million + AUD 1.6 million/km where applicable. The 2025 planning variation source indicates AGL sought flexibility to use either gas turbines or reciprocating engines and increase Stage 2 output to up to 280 MW from the previously approved 210 MW. Existing Barker Inlet Power Station Stage 1 is a separate 210 MW reciprocating-engine plant commissioned in 2019 with reported construction cost of AUD 295 million; this cost was not used as BIPS2 OCGT capex.\"},\"sources\":[{\"field_name\":\"site_status_capacity\",\"value_text\":\"Publicly announced gas project: Barker Inlet Power Station 2, 280 MW\",\"value_numeric\":280,\"unit\":\"MW\",\"source_url\":\"https://www.aemo.com.au/-/media/files/electricity/nem/planning_and_forecasting/sa_advisory/2025/2025-south-australian-electricity-report.pdf?rev=40d5c6a3cece40d3abca846a51c16aa8&sc_lang=en\",\"source_title\":\"2025 South Australian Electricity Report\",\"publisher\":\"AEMO\",\"published_date\":\"2025-10\",\"confidence\":\"high\",\"raw_excerpt\":\"Table 14 Publicly announced generation and storage developments with capacity of ≥200 MW, October 2025 ... Gas Project Barker Inlet Power Station 2 280 ... Reeves Plains OCGT – Stage 1 150 ... Reeves Plains OCGT – Stage 2 150.\",\"ai_summary\":\"Confirms BIPS2 is tracked by AEMO as a publicly announced South Australian gas project with 280 MW nameplate capacity.\"},{\"field_name\":\"technology_scope_planning_variation\",\"value_text\":\"Stage 2 variation to allow either gas turbines or reciprocating engines and increase output to up to 280 MW instead of approved 210 MW\",\"value_numeric\":280,\"unit\":\"MW\",\"source_url\":\"https://plan.sa.gov.au/__data/assets/pdf_file/0020/1521308/5-AGL-BIPS-Stage-2-Crown-Development-Variation-Part-2-June-2025Part-last.pdf\",\"source_title\":\"Barker Inlet Power Station Stage 2 - Crown Development Variation Part 2\",\"publisher\":\"PlanSA / AECOM for AGL Barker Inlet Pty Ltd\",\"published_date\":\"2025-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"AGL are seeking to modify the DA to permit a wider range of plant options for Stage 2 of the BIPS (BIPS 2), including: to enable BIPS 2 to use either gas turbines or reciprocating engines ... and to increase the proposed output of BIPS 2 to up to 280 MW (instead of the currently approved 210 MW).\",\"ai_summary\":\"Planning material supports the OCGT/gas-turbine option but also shows technology is not locked in publicly; BIPS2 may use gas turbines or reciprocating engines.\"},{\"field_name\":\"capex_per_mw_aud\",\"value_text\":\"Large GT OCGT relative EPC cost, net basis, excluding land and development costs; includes liquid fuel storage and hydrogen capability premium as described by Aurecon\",\"value_numeric\":1189000,\"unit\":\"AUD/MW\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Table 4-31 Cost estimate ... CAPEX – EPC cost ... Relative cost $/kW ... Small GT 2,193; Large GT 1,189 ... Net basis. Includes liquid fuel storage (30 hours) and associated infrastructure ... Relative cost does not include land and development costs. Large GTs - cost variability ... Cost range $1,150/kW-$1,550/kW.\",\"ai_summary\":\"Used the large gas turbine OCGT EPC cost of AUD 1,189/kW, converted to AUD 1.189 million/MW, because BIPS2 is 280 MW and most closely resembles a large OCGT option.\"},{\"field_name\":\"capex_total_aud\",\"value_text\":\"Estimated EPC capex: 280 MW x AUD 1.189 million/MW; excludes land/development and fuel connection\",\"value_numeric\":332920000,\"unit\":\"AUD\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Total EPC cost $ ... Large GT 290,479,200 ... Cost of land and development ... $26,143,128 Assuming 9% of CAPEX. Fuel connection costs $M $21.2M + $1.6M/km.\",\"ai_summary\":\"Aurecon provides the generic large-GT OCGT EPC scope and separate adders. The BIPS2 total is scaled to 280 MW and is not a reported AGL project cost.\"},{\"field_name\":\"capex_year\",\"value_text\":\"Aurecon cost assumptions are for plausible NEM OCGT projects in 2024; first year commercially viable for construction 2024\",\"value_numeric\":2024,\"unit\":\"year\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"The hypothetical project has been selected based on what is envisaged as plausible projects for development in the NEM in 2024 ... First Year Assumed Commercially Viable for construction Year 2024 2024.\",\"ai_summary\":\"Used 2024 as the cost basis year for the generic OCGT assumptions.\"},{\"field_name\":\"fixed_opex_per_mw_year_aud\",\"value_text\":\"Large GT OCGT fixed O&M excluding fuel\",\"value_numeric\":14066,\"unit\":\"AUD/MW-year\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"OPEX – Annual (excluding fuel) Fixed O&M Cost $/MW (Net) Small GT 17,368; Large GT 14,066. Based on Aurecon internal database. Labour cost adjustment from 2023 included.\",\"ai_summary\":\"Applied large-GT fixed O&M cost to 280 MW to estimate annual fixed opex.\"},{\"field_name\":\"fixed_opex_annual_aud\",\"value_text\":\"Estimated annual fixed O&M: 280 MW x AUD 14,066/MW-year\",\"value_numeric\":3938480,\"unit\":\"AUD/year\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"OPEX – Annual (excluding fuel) Fixed O&M Cost $/MW (Net) ... Large GT 14,066 ... Total annual O&M Cost ... Large GT $6,896,814 Annual average cost over the design life.\",\"ai_summary\":\"The field is a scaled estimate for BIPS2, not a reported AGL budget.\"},{\"field_name\":\"variable_opex_per_mwh_aud\",\"value_text\":\"Large GT OCGT variable O&M excluding fuel\",\"value_numeric\":8.1,\"unit\":\"AUD/MWh\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Variable O&M Cost $/MWh (Net) Small GT 16.1; Large GT 8.1 ... Assumes less than 1 start per day. Additional starts may incur higher maintenance costs depending on OEM maintenance schedule calculation considering starts.\",\"ai_summary\":\"Used the large-GT OCGT variable O&M estimate. It excludes fuel and may be higher if start frequency exceeds the assumption.\"},{\"field_name\":\"fuel_cost_per_gj_aud\",\"value_text\":\"Proxy wholesale gas cost based on observed east coast wholesale contract pricing around the gas price cap; not BIPS2-specific delivered gas cost\",\"value_numeric\":12,\"unit\":\"AUD/GJ\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/draft-2025-inputs-assumptions-and-scenarios-report-stage-1.pdf\",\"source_title\":\"Draft 2025 Inputs, Assumptions and Scenarios Report Stage 1\",\"publisher\":\"AEMO\",\"published_date\":\"2024-12\",\"confidence\":\"medium\",\"raw_excerpt\":\"Wholesale contract prices have been anchored at or around the $12/GJ price cap since it was introduced, and this market dynamic is expected to continue given tight supply conditions ... The gas prices associated with each gas-powered generator ... include regional pricing ... and pipeline transmission.\",\"ai_summary\":\"Used AUD 12/GJ as a proxy fuel commodity cost due to absence of a BIPS2-specific public fuel contract. Delivered costs could differ.\"},{\"field_name\":\"fuel_contract_notes\",\"value_text\":\"BIPS2 gas source expected from Cooper Basin in northern South Australia or Western Victoria; volume depends on system requirements\",\"value_numeric\":null,\"unit\":null,\"source_url\":\"https://www.agl.com.au/content/dam/digital/agl/documents/about-agl/operations-docs/251126-minutes-of-agl-torrens-island-community-dialogue-group-20-august-2024.pdf\",\"source_title\":\"Minutes of AGL Torrens Island Community Dialogue Group Meeting, 20 August 2024\",\"publisher\":\"AGL Energy\",\"published_date\":\"2024-08-20\",\"confidence\":\"medium\",\"raw_excerpt\":\"Tony asked where the gas for BIPS2 will come from? Kevin responded that it will come from the Cooper Basin in northern SA or Western Victoria. Kevin explained that the volume of gas depends on system requirements.\",\"ai_summary\":\"Provides a source for expected gas supply regions, but not price, term, counterparty, or take-or-pay details.\"},{\"field_name\":\"heat_rate_gj_per_mwh\",\"value_text\":\"Large GT OCGT heat rate at maximum operation, HHV net\",\"value_numeric\":10.811,\"unit\":\"GJ/MWh\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Heat rate at maximum operation (GJ/MWh) HHV Net ... Small GT 10.489; Large GT 10.811. Thermal Efficiency at MCR %, HHV Net ... Small GT 34.3%; Large GT 33.30%.\",\"ai_summary\":\"Used the HHV net maximum-load heat rate for a generic large OCGT.\"},{\"field_name\":\"efficiency_pct\",\"value_text\":\"Large GT OCGT thermal efficiency at MCR, HHV net\",\"value_numeric\":33.3,\"unit\":\"%\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Thermal Efficiency at MCR %, HHV Net ... Small GT 34.3%; Large GT 33.30%.\",\"ai_summary\":\"Used the generic large-GT OCGT HHV net efficiency.\"},{\"field_name\":\"emissions_intensity_tco2_mwh\",\"value_text\":\"Estimated Scope 1 emissions intensity = 10.811 GJ/MWh x 51.53 kg CO2-e/GJ / 1000\",\"value_numeric\":0.55709083,\"unit\":\"tCO2e/MWh\",\"source_url\":\"https://www.dcceew.gov.au/sites/default/files/documents/national-greenhouse-account-factors-2025.pdf\",\"source_title\":\"Australian National Greenhouse Accounts Factors 2025\",\"publisher\":\"Department of Climate Change, Energy, the Environment and Water\",\"published_date\":\"2025\",\"confidence\":\"medium\",\"raw_excerpt\":\"Natural gas distributed in a pipeline is reported in the NGA Factors as a stationary energy fuel with a Scope 1 combined-gases emission factor of 51.53 kg CO2-e/GJ.\",\"ai_summary\":\"Combined the DCCEEW natural-gas emission factor with Aurecon's OCGT heat rate. This is a calculated estimate, not a measured BIPS2 emissions intensity.\"},{\"field_name\":\"asset_life_years\",\"value_text\":\"Large GT OCGT technical life / operational life\",\"value_numeric\":40,\"unit\":\"years\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Economic Life (Design Life) Years 25 25 ... Technical Life (Operational Life) Years 40 40.\",\"ai_summary\":\"Used the 40-year technical life for the asset_life_years field; economic design life is 25 years.\"},{\"field_name\":\"discount_rate_pct\",\"value_text\":\"AEMO Draft 2025 IASR central real discount rate for ISP analysis; OCGT large GT central WACC is 9% but common discount rate is 7%\",\"value_numeric\":7,\"unit\":\"%\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/draft-2025-inputs-assumptions-and-scenarios-report-stage-1.pdf\",\"source_title\":\"Draft 2025 Inputs, Assumptions and Scenarios Report Stage 1\",\"publisher\":\"AEMO\",\"published_date\":\"2024-12\",\"confidence\":\"medium\",\"raw_excerpt\":\"Table 23 Pre-tax real weighted average cost of capital ... OCGT (large gas turbine) 7.0% 9.0% 12.0% ... OEA has recommended that the appropriate discount rate, for use in the 2025 IASR and 2026 ISP ... is 7%.\",\"ai_summary\":\"Used 7% as a generic discount-rate assumption; for project-finance modelling a technology-specific OCGT WACC of 9% central may also be relevant.\"},{\"field_name\":\"major_refurbishment_or_closure_notes\",\"value_text\":\"No BIPS2 closure or refurbishment date found; adjacent Torrens Island B scheduled to close 30 June 2028; Torrens A decommissioning and demolition underway\",\"value_numeric\":null,\"unit\":null,\"source_url\":\"https://www.agl.com.au/about-agl/operations/agl-in-torrens-island?giha9n=hrd26h\",\"source_title\":\"AGL on Torrens Island\",\"publisher\":\"AGL Energy\",\"published_date\":\"2026\",\"confidence\":\"medium\",\"raw_excerpt\":\"Torrens Island Power Station B ... is scheduled to close on 30 June 2028. ... Torrens Island 'A' Station ... final unit closed in September 2022 ... decommissioning and demolition process is underway ... Barker Inlet Power Station consists of 12 reciprocating engines.\",\"ai_summary\":\"Relevant site context only. It does not provide BIPS2 closure/refurbishment information.\"},{\"field_name\":\"stage1_capex_context_not_used\",\"value_text\":\"Existing Barker Inlet Stage 1 reported construction cost AUD 295 million for 210 MW reciprocating-engine plant, including electrical equipment, buildings and facilities\",\"value_numeric\":295000000,\"unit\":\"AUD\",\"source_url\":\"https://www.agl.com.au/content/dam/digital/agl/documents/about-agl/operations-docs/251126-minutes-of-agl-torrens-island-community-dialogue-group-20-august-2024.pdf\",\"source_title\":\"Minutes of AGL Torrens Island Community Dialogue Group Meeting, 20 August 2024\",\"publisher\":\"AGL Energy\",\"published_date\":\"2024-08-20\",\"confidence\":\"high\",\"raw_excerpt\":\"Kevin replied that the construction cost of Barker Inlet was $295 million but stressed that this was the total cost of the power station, including the electrical equipment, buildings and facilities, not just the engines.\",\"ai_summary\":\"This confirms Stage 1 capex context but is not used for BIPS2 OCGT assumptions because Stage 1 is a different in-service 210 MW reciprocating-engine plant.\"}],\"warnings\":[\"No public AGL final investment decision, EPC award, financing document, or annual-report disclosure for Barker Inlet Power Station 2 capex was found; capex is a generic OCGT estimate, not reported project cost.\",\"BIPS2 is publicly announced and appears to have no DUID or full commercial-use date in the sources reviewed.\",\"Planning material indicates AGL sought flexibility for BIPS2 to use either gas turbines or reciprocating engines; the user's OCGT classification is plausible but not proven as final selected technology.\",\"Fuel cost is not a generator-specific contract price. AUD 12/GJ is a proxy based on AEMO commentary on wholesale contract prices around the gas price cap; delivered gas cost may differ due to transport, balancing, and contract terms.\",\"Fixed O&M, variable O&M, heat rate, efficiency, asset life, and emissions intensity are default large-GT OCGT assumptions scaled to 280 MW, not measured BIPS2 data.\",\"The adjacent in-service Barker Inlet Power Station is a separate 210 MW reciprocating-engine facility with reported AUD 295 million construction cost; it should not be conflated with BIPS2 OCGT economics.\"]}",
"raw_api": {
"id": "resp_0aa9cdd75270936b006a20a8c80c40819584d206f592c70490",
"object": "response",
"created_at": 1780525256,
"status": "completed",
"background": false,
"billing": {
"payer": "developer"
},
"completed_at": 1780525387,
"error": null,
"frequency_penalty": 0,
"incomplete_details": null,
"instructions": "You are a researcher of Australian NEM generator economics. You MUST use web search to find current, source-backed information before answering. Prefer official owner reports, AEMO documents, government sources, project finance announcements, annual reports, and investor presentations. Return only valid JSON matching the schema.",
"max_output_tokens": null,
"max_tool_calls": null,
"model": "gpt-5.5-2026-04-23",
"moderation": null,
"output": [
{
"id": "ws_0aa9cdd75270936b006a20a8cb2ce88195a973278d46a29c96",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "search",
"queries": [
"Barker Inlet Power Station 2 capex cost AGL 280 MW OCGT",
"AGL Barker Inlet Power Station 2 280 MW gas turbine construction cost",
"Barker Inlet Power Station Wärtsilä 280 MW cost AGL annual report",
"Barker Inlet Power Station emissions intensity heat rate efficiency AEMO"
],
"query": "Barker Inlet Power Station 2 capex cost AGL 280 MW OCGT"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a8ce9194819589142210b6b631dc",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a8cfddb881959344fe9e99322468",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "search",
"queries": [
"\"Barker Inlet Power Station 2\" \"OCGT\"",
"\"Barker Inlet Power Station 2\" \"280\"",
"\"BARKER\" \"Power Station 2\" AEMO \"OCGT\"",
"\"Barker Inlet\" \"Power Station 2\" \"DUID\""
],
"query": "\"Barker Inlet Power Station 2\" \"OCGT\""
}
},
{
"id": "rs_0aa9cdd75270936b006a20a8d2c67881958a0e84968c2f9a3b",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a8d3a51881959642b73425bc2ce1",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "search",
"queries": [
"AEMO 2025 Inputs Assumptions Workbook OCGT fixed O&M variable O&M heat rate fuel cost asset life",
"2025 IASR workbook OCGT fixed O&M variable O&M gas turbine capex AEMO",
"AEMO 2025 GenCost OCGT fixed O&M variable O&M heat rate emissions intensity"
],
"query": "AEMO 2025 Inputs Assumptions Workbook OCGT fixed O&M variable O&M heat rate fuel cost asset life"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a8da2dec81958ba4c664026a7eb2",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a8da3f388195b3726c9411666cca",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "open_page",
"url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a8dae084819584e1fac39a646605",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a8daf6548195a2081ca07dd0d774",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "open_page",
"url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a8ddee308195b79757891364dd4d",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a8de10188195a784129a6ab17c0d",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "open_page",
"url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a8df6798819584c8cd8648f42bcd",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a8e5114081958903dfef933c951e",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "search",
"queries": [
"Australia National Greenhouse Accounts natural gas emission factor kg CO2-e GJ stationary energy 2025",
"NGER natural gas emission factor kg CO2-e per GJ 51.53",
"AEMO emissions factor natural gas tCO2e GJ OCGT heat rate"
],
"query": "Australia National Greenhouse Accounts natural gas emission factor kg CO2-e GJ stationary energy 2025"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a8e9df2081958f6f9f6ac9420aea",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a8e9f49481959ef5ef703214751e",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "search",
"queries": [
"Barker Inlet Power Station 2 gas supply contract fuel source AGL",
"Barker Inlet Power Station gas supply contract AGL Torrens Island",
"AGL Barker Inlet Power Station 2 environmental assessment natural gas pipeline gas supply",
"BIPS2 gas supply AGL Barker Inlet Stage 2"
],
"query": "Barker Inlet Power Station 2 gas supply contract fuel source AGL"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a8f22ad081958b6cf10850d7eb69",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a8f247a08195b0f780205e4e74d0",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "search",
"queries": [
"AEMO 2025 Inputs Assumptions Workbook gas price South Australia 2026 GJ",
"2025 IASR gas price South Australia power generation GJ 2026",
"AEMO 2025 ISP gas price assumptions South Australia GJ"
],
"query": "AEMO 2025 Inputs Assumptions Workbook gas price South Australia 2026 GJ"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a8f907a481959c1997faf5f124ac",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a8f97c0c81959ffc9ae6b911ec79",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "open_page",
"url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/draft-2025-inputs-assumptions-and-scenarios-report-stage-1.pdf"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a8fcff008195924cadfda7b09daa",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a8ff617c8195b151566e39ba7ec7",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "open_page",
"url": "https://www.aemo.com.au/-/media/files/electricity/nem/planning_and_forecasting/sa_advisory/2025/2025-south-australian-electricity-report.pdf?rev=40d5c6a3cece40d3abca846a51c16aa8&sc_lang=en"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a901d2988195b5d0bc231bec31c5",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a9023d4481958c62b76c5cfd8b81",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "open_page"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a905d6c88195a204d81246ace9ae",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a90bb1448195bd27b61f1fbf926d",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "search",
"queries": [
"calculator: 1189000*280"
],
"query": "calculator: 1189000*280"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a90f4204819590cc8f154009e821",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a90fde248195a060c0eae942e980",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "open_page",
"url": "https://wa.aemo.com.au/-/media/files/major-publications/isp/2025/draft-2025-inputs-assumptions-and-scenarios-report-stage-1.pdf?la=en"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a913910c81958476216a5942394b",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "ws_0aa9cdd75270936b006a20a9149b0081958b82913346fae110",
"type": "web_search_call",
"status": "completed",
"action": {
"type": "find_in_page",
"pattern": "7.0%",
"url": "https://aemo.com.au/-/media/files/major-publications/isp/2025/draft-2025-inputs-assumptions-and-scenarios-report-stage-1.pdf"
}
},
{
"id": "rs_0aa9cdd75270936b006a20a9162e488195b7fa83b4a26c79cd",
"type": "reasoning",
"content": [],
"summary": []
},
{
"id": "msg_0aa9cdd75270936b006a20a91e91dc81958d9e652b330c0987",
"type": "message",
"status": "completed",
"content": [
{
"type": "output_text",
"annotations": [],
"logprobs": [],
"text": "{\"generator_identity\":{\"site_name\":\"Barker Inlet Power Station 2\",\"duid\":null,\"owner\":\"AGL Energy Limited\",\"region\":\"SA / NEM South Australia\",\"technology_type\":\"Turbine - OCGT; publicly announced gas project, with 2025 planning material indicating Stage 2 variation may allow either gas turbines or reciprocating engines\",\"fuel_type\":\"Fossil - Natural Gas Pipeline\"},\"financial_profile\":{\"generator_type_normalised\":\"ocgt\",\"capex_total_aud\":332920000,\"capex_year\":2024,\"capex_basis\":\"default\",\"capex_per_mw_aud\":1189000,\"capex_per_mwh_aud\":null,\"fixed_opex_annual_aud\":3938480,\"fixed_opex_per_mw_year_aud\":14066,\"variable_opex_per_mwh_aud\":8.1,\"fuel_cost_per_gj_aud\":12,\"fuel_contract_notes\":\"No generator-specific BIPS2 gas supply contract price was found. AGL community dialogue minutes state BIPS2 gas would come from the Cooper Basin in northern South Australia or Western Victoria, with volume dependent on system requirements. AEMO's Draft 2025 IASR states observed wholesale gas contract prices have been anchored at or around the $12/GJ gas price cap since July 2023; this is used here as a proxy fuel commodity cost, not a delivered BIPS2 contract price.\",\"heat_rate_gj_per_mwh\":10.811,\"efficiency_pct\":33.3,\"emissions_intensity_tco2_mwh\":0.55709083,\"asset_life_years\":40,\"discount_rate_pct\":7,\"source_confidence\":\"medium\",\"data_status\":\"ai_estimated\",\"notes\":\"Barker Inlet Power Station 2 is listed by AEMO as a publicly announced 280 MW gas project as at October 2025. I found no public AGL FID announcement or project-specific construction cost, O&M, heat-rate, fuel-price, emissions-intensity, or closure date for BIPS2. Financial and operating fields are therefore default estimates based on AEMO/Aurecon 2024 large OCGT assumptions, scaled to 280 MW. Capex total is EPC-only on a net basis: 280 MW x AUD 1.189 million/MW = AUD 332.92 million, excluding land/development and fuel connection costs; Aurecon separately indicates land/development at 9% of capex and fuel connection at AUD 21.2 million + AUD 1.6 million/km where applicable. The 2025 planning variation source indicates AGL sought flexibility to use either gas turbines or reciprocating engines and increase Stage 2 output to up to 280 MW from the previously approved 210 MW. Existing Barker Inlet Power Station Stage 1 is a separate 210 MW reciprocating-engine plant commissioned in 2019 with reported construction cost of AUD 295 million; this cost was not used as BIPS2 OCGT capex.\"},\"sources\":[{\"field_name\":\"site_status_capacity\",\"value_text\":\"Publicly announced gas project: Barker Inlet Power Station 2, 280 MW\",\"value_numeric\":280,\"unit\":\"MW\",\"source_url\":\"https://www.aemo.com.au/-/media/files/electricity/nem/planning_and_forecasting/sa_advisory/2025/2025-south-australian-electricity-report.pdf?rev=40d5c6a3cece40d3abca846a51c16aa8&sc_lang=en\",\"source_title\":\"2025 South Australian Electricity Report\",\"publisher\":\"AEMO\",\"published_date\":\"2025-10\",\"confidence\":\"high\",\"raw_excerpt\":\"Table 14 Publicly announced generation and storage developments with capacity of ≥200 MW, October 2025 ... Gas Project Barker Inlet Power Station 2 280 ... Reeves Plains OCGT – Stage 1 150 ... Reeves Plains OCGT – Stage 2 150.\",\"ai_summary\":\"Confirms BIPS2 is tracked by AEMO as a publicly announced South Australian gas project with 280 MW nameplate capacity.\"},{\"field_name\":\"technology_scope_planning_variation\",\"value_text\":\"Stage 2 variation to allow either gas turbines or reciprocating engines and increase output to up to 280 MW instead of approved 210 MW\",\"value_numeric\":280,\"unit\":\"MW\",\"source_url\":\"https://plan.sa.gov.au/__data/assets/pdf_file/0020/1521308/5-AGL-BIPS-Stage-2-Crown-Development-Variation-Part-2-June-2025Part-last.pdf\",\"source_title\":\"Barker Inlet Power Station Stage 2 - Crown Development Variation Part 2\",\"publisher\":\"PlanSA / AECOM for AGL Barker Inlet Pty Ltd\",\"published_date\":\"2025-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"AGL are seeking to modify the DA to permit a wider range of plant options for Stage 2 of the BIPS (BIPS 2), including: to enable BIPS 2 to use either gas turbines or reciprocating engines ... and to increase the proposed output of BIPS 2 to up to 280 MW (instead of the currently approved 210 MW).\",\"ai_summary\":\"Planning material supports the OCGT/gas-turbine option but also shows technology is not locked in publicly; BIPS2 may use gas turbines or reciprocating engines.\"},{\"field_name\":\"capex_per_mw_aud\",\"value_text\":\"Large GT OCGT relative EPC cost, net basis, excluding land and development costs; includes liquid fuel storage and hydrogen capability premium as described by Aurecon\",\"value_numeric\":1189000,\"unit\":\"AUD/MW\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Table 4-31 Cost estimate ... CAPEX – EPC cost ... Relative cost $/kW ... Small GT 2,193; Large GT 1,189 ... Net basis. Includes liquid fuel storage (30 hours) and associated infrastructure ... Relative cost does not include land and development costs. Large GTs - cost variability ... Cost range $1,150/kW-$1,550/kW.\",\"ai_summary\":\"Used the large gas turbine OCGT EPC cost of AUD 1,189/kW, converted to AUD 1.189 million/MW, because BIPS2 is 280 MW and most closely resembles a large OCGT option.\"},{\"field_name\":\"capex_total_aud\",\"value_text\":\"Estimated EPC capex: 280 MW x AUD 1.189 million/MW; excludes land/development and fuel connection\",\"value_numeric\":332920000,\"unit\":\"AUD\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Total EPC cost $ ... Large GT 290,479,200 ... Cost of land and development ... $26,143,128 Assuming 9% of CAPEX. Fuel connection costs $M $21.2M + $1.6M/km.\",\"ai_summary\":\"Aurecon provides the generic large-GT OCGT EPC scope and separate adders. The BIPS2 total is scaled to 280 MW and is not a reported AGL project cost.\"},{\"field_name\":\"capex_year\",\"value_text\":\"Aurecon cost assumptions are for plausible NEM OCGT projects in 2024; first year commercially viable for construction 2024\",\"value_numeric\":2024,\"unit\":\"year\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"The hypothetical project has been selected based on what is envisaged as plausible projects for development in the NEM in 2024 ... First Year Assumed Commercially Viable for construction Year 2024 2024.\",\"ai_summary\":\"Used 2024 as the cost basis year for the generic OCGT assumptions.\"},{\"field_name\":\"fixed_opex_per_mw_year_aud\",\"value_text\":\"Large GT OCGT fixed O&M excluding fuel\",\"value_numeric\":14066,\"unit\":\"AUD/MW-year\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"OPEX – Annual (excluding fuel) Fixed O&M Cost $/MW (Net) Small GT 17,368; Large GT 14,066. Based on Aurecon internal database. Labour cost adjustment from 2023 included.\",\"ai_summary\":\"Applied large-GT fixed O&M cost to 280 MW to estimate annual fixed opex.\"},{\"field_name\":\"fixed_opex_annual_aud\",\"value_text\":\"Estimated annual fixed O&M: 280 MW x AUD 14,066/MW-year\",\"value_numeric\":3938480,\"unit\":\"AUD/year\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"OPEX – Annual (excluding fuel) Fixed O&M Cost $/MW (Net) ... Large GT 14,066 ... Total annual O&M Cost ... Large GT $6,896,814 Annual average cost over the design life.\",\"ai_summary\":\"The field is a scaled estimate for BIPS2, not a reported AGL budget.\"},{\"field_name\":\"variable_opex_per_mwh_aud\",\"value_text\":\"Large GT OCGT variable O&M excluding fuel\",\"value_numeric\":8.1,\"unit\":\"AUD/MWh\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Variable O&M Cost $/MWh (Net) Small GT 16.1; Large GT 8.1 ... Assumes less than 1 start per day. Additional starts may incur higher maintenance costs depending on OEM maintenance schedule calculation considering starts.\",\"ai_summary\":\"Used the large-GT OCGT variable O&M estimate. It excludes fuel and may be higher if start frequency exceeds the assumption.\"},{\"field_name\":\"fuel_cost_per_gj_aud\",\"value_text\":\"Proxy wholesale gas cost based on observed east coast wholesale contract pricing around the gas price cap; not BIPS2-specific delivered gas cost\",\"value_numeric\":12,\"unit\":\"AUD/GJ\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/draft-2025-inputs-assumptions-and-scenarios-report-stage-1.pdf\",\"source_title\":\"Draft 2025 Inputs, Assumptions and Scenarios Report Stage 1\",\"publisher\":\"AEMO\",\"published_date\":\"2024-12\",\"confidence\":\"medium\",\"raw_excerpt\":\"Wholesale contract prices have been anchored at or around the $12/GJ price cap since it was introduced, and this market dynamic is expected to continue given tight supply conditions ... The gas prices associated with each gas-powered generator ... include regional pricing ... and pipeline transmission.\",\"ai_summary\":\"Used AUD 12/GJ as a proxy fuel commodity cost due to absence of a BIPS2-specific public fuel contract. Delivered costs could differ.\"},{\"field_name\":\"fuel_contract_notes\",\"value_text\":\"BIPS2 gas source expected from Cooper Basin in northern South Australia or Western Victoria; volume depends on system requirements\",\"value_numeric\":null,\"unit\":null,\"source_url\":\"https://www.agl.com.au/content/dam/digital/agl/documents/about-agl/operations-docs/251126-minutes-of-agl-torrens-island-community-dialogue-group-20-august-2024.pdf\",\"source_title\":\"Minutes of AGL Torrens Island Community Dialogue Group Meeting, 20 August 2024\",\"publisher\":\"AGL Energy\",\"published_date\":\"2024-08-20\",\"confidence\":\"medium\",\"raw_excerpt\":\"Tony asked where the gas for BIPS2 will come from? Kevin responded that it will come from the Cooper Basin in northern SA or Western Victoria. Kevin explained that the volume of gas depends on system requirements.\",\"ai_summary\":\"Provides a source for expected gas supply regions, but not price, term, counterparty, or take-or-pay details.\"},{\"field_name\":\"heat_rate_gj_per_mwh\",\"value_text\":\"Large GT OCGT heat rate at maximum operation, HHV net\",\"value_numeric\":10.811,\"unit\":\"GJ/MWh\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Heat rate at maximum operation (GJ/MWh) HHV Net ... Small GT 10.489; Large GT 10.811. Thermal Efficiency at MCR %, HHV Net ... Small GT 34.3%; Large GT 33.30%.\",\"ai_summary\":\"Used the HHV net maximum-load heat rate for a generic large OCGT.\"},{\"field_name\":\"efficiency_pct\",\"value_text\":\"Large GT OCGT thermal efficiency at MCR, HHV net\",\"value_numeric\":33.3,\"unit\":\"%\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Thermal Efficiency at MCR %, HHV Net ... Small GT 34.3%; Large GT 33.30%.\",\"ai_summary\":\"Used the generic large-GT OCGT HHV net efficiency.\"},{\"field_name\":\"emissions_intensity_tco2_mwh\",\"value_text\":\"Estimated Scope 1 emissions intensity = 10.811 GJ/MWh x 51.53 kg CO2-e/GJ / 1000\",\"value_numeric\":0.55709083,\"unit\":\"tCO2e/MWh\",\"source_url\":\"https://www.dcceew.gov.au/sites/default/files/documents/national-greenhouse-account-factors-2025.pdf\",\"source_title\":\"Australian National Greenhouse Accounts Factors 2025\",\"publisher\":\"Department of Climate Change, Energy, the Environment and Water\",\"published_date\":\"2025\",\"confidence\":\"medium\",\"raw_excerpt\":\"Natural gas distributed in a pipeline is reported in the NGA Factors as a stationary energy fuel with a Scope 1 combined-gases emission factor of 51.53 kg CO2-e/GJ.\",\"ai_summary\":\"Combined the DCCEEW natural-gas emission factor with Aurecon's OCGT heat rate. This is a calculated estimate, not a measured BIPS2 emissions intensity.\"},{\"field_name\":\"asset_life_years\",\"value_text\":\"Large GT OCGT technical life / operational life\",\"value_numeric\":40,\"unit\":\"years\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/aurecon-2024-energy-technology-costs-and-technical-parameter-review.pdf?la=en\",\"source_title\":\"2024 Energy Technology Cost and Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Economic Life (Design Life) Years 25 25 ... Technical Life (Operational Life) Years 40 40.\",\"ai_summary\":\"Used the 40-year technical life for the asset_life_years field; economic design life is 25 years.\"},{\"field_name\":\"discount_rate_pct\",\"value_text\":\"AEMO Draft 2025 IASR central real discount rate for ISP analysis; OCGT large GT central WACC is 9% but common discount rate is 7%\",\"value_numeric\":7,\"unit\":\"%\",\"source_url\":\"https://aemo.com.au/-/media/files/major-publications/isp/2025/draft-2025-inputs-assumptions-and-scenarios-report-stage-1.pdf\",\"source_title\":\"Draft 2025 Inputs, Assumptions and Scenarios Report Stage 1\",\"publisher\":\"AEMO\",\"published_date\":\"2024-12\",\"confidence\":\"medium\",\"raw_excerpt\":\"Table 23 Pre-tax real weighted average cost of capital ... OCGT (large gas turbine) 7.0% 9.0% 12.0% ... OEA has recommended that the appropriate discount rate, for use in the 2025 IASR and 2026 ISP ... is 7%.\",\"ai_summary\":\"Used 7% as a generic discount-rate assumption; for project-finance modelling a technology-specific OCGT WACC of 9% central may also be relevant.\"},{\"field_name\":\"major_refurbishment_or_closure_notes\",\"value_text\":\"No BIPS2 closure or refurbishment date found; adjacent Torrens Island B scheduled to close 30 June 2028; Torrens A decommissioning and demolition underway\",\"value_numeric\":null,\"unit\":null,\"source_url\":\"https://www.agl.com.au/about-agl/operations/agl-in-torrens-island?giha9n=hrd26h\",\"source_title\":\"AGL on Torrens Island\",\"publisher\":\"AGL Energy\",\"published_date\":\"2026\",\"confidence\":\"medium\",\"raw_excerpt\":\"Torrens Island Power Station B ... is scheduled to close on 30 June 2028. ... Torrens Island 'A' Station ... final unit closed in September 2022 ... decommissioning and demolition process is underway ... Barker Inlet Power Station consists of 12 reciprocating engines.\",\"ai_summary\":\"Relevant site context only. It does not provide BIPS2 closure/refurbishment information.\"},{\"field_name\":\"stage1_capex_context_not_used\",\"value_text\":\"Existing Barker Inlet Stage 1 reported construction cost AUD 295 million for 210 MW reciprocating-engine plant, including electrical equipment, buildings and facilities\",\"value_numeric\":295000000,\"unit\":\"AUD\",\"source_url\":\"https://www.agl.com.au/content/dam/digital/agl/documents/about-agl/operations-docs/251126-minutes-of-agl-torrens-island-community-dialogue-group-20-august-2024.pdf\",\"source_title\":\"Minutes of AGL Torrens Island Community Dialogue Group Meeting, 20 August 2024\",\"publisher\":\"AGL Energy\",\"published_date\":\"2024-08-20\",\"confidence\":\"high\",\"raw_excerpt\":\"Kevin replied that the construction cost of Barker Inlet was $295 million but stressed that this was the total cost of the power station, including the electrical equipment, buildings and facilities, not just the engines.\",\"ai_summary\":\"This confirms Stage 1 capex context but is not used for BIPS2 OCGT assumptions because Stage 1 is a different in-service 210 MW reciprocating-engine plant.\"}],\"warnings\":[\"No public AGL final investment decision, EPC award, financing document, or annual-report disclosure for Barker Inlet Power Station 2 capex was found; capex is a generic OCGT estimate, not reported project cost.\",\"BIPS2 is publicly announced and appears to have no DUID or full commercial-use date in the sources reviewed.\",\"Planning material indicates AGL sought flexibility for BIPS2 to use either gas turbines or reciprocating engines; the user's OCGT classification is plausible but not proven as final selected technology.\",\"Fuel cost is not a generator-specific contract price. AUD 12/GJ is a proxy based on AEMO commentary on wholesale contract prices around the gas price cap; delivered gas cost may differ due to transport, balancing, and contract terms.\",\"Fixed O&M, variable O&M, heat rate, efficiency, asset life, and emissions intensity are default large-GT OCGT assumptions scaled to 280 MW, not measured BIPS2 data.\",\"The adjacent in-service Barker Inlet Power Station is a separate 210 MW reciprocating-engine facility with reported AUD 295 million construction cost; it should not be conflated with BIPS2 OCGT economics.\"]}"
}
],
"phase": "final_answer",
"role": "assistant"
}
],
"parallel_tool_calls": true,
"presence_penalty": 0,
"previous_response_id": null,
"prompt_cache_key": null,
"prompt_cache_retention": "24h",
"reasoning": {
"context": "current_turn",
"effort": "medium",
"summary": null
},
"safety_identifier": null,
"service_tier": "default",
"store": true,
"temperature": 1,
"text": {
"format": {
"type": "json_schema",
"description": null,
"name": "generator_financial_extraction",
"schema": {
"type": "object",
"additionalProperties": false,
"properties": {
"generator_identity": {
"type": "object",
"additionalProperties": false,
"properties": {
"site_name": {
"type": "string"
},
"duid": {
"type": [
"string",
"null"
]
},
"owner": {
"type": [
"string",
"null"
]
},
"region": {
"type": [
"string",
"null"
]
},
"technology_type": {
"type": [
"string",
"null"
]
},
"fuel_type": {
"type": [
"string",
"null"
]
}
},
"required": [
"site_name",
"duid",
"owner",
"region",
"technology_type",
"fuel_type"
]
},
"financial_profile": {
"type": "object",
"additionalProperties": false,
"properties": {
"generator_type_normalised": {
"type": "string",
"enum": [
"ocgt",
"ccgt",
"black_coal",
"brown_coal",
"diesel",
"wind_onshore",
"wind_offshore",
"solar_fixed",
"solar_tracking",
"battery",
"hydro",
"pumped_hydro",
"biomass",
"waste_gas",
"hybrid",
"other"
]
},
"capex_total_aud": {
"type": [
"number",
"null"
]
},
"capex_year": {
"type": [
"number",
"null"
]
},
"capex_basis": {
"type": "string",
"enum": [
"reported",
"estimated",
"default",
"unknown"
]
},
"capex_per_mw_aud": {
"type": [
"number",
"null"
]
},
"capex_per_mwh_aud": {
"type": [
"number",
"null"
]
},
"fixed_opex_annual_aud": {
"type": [
"number",
"null"
]
},
"fixed_opex_per_mw_year_aud": {
"type": [
"number",
"null"
]
},
"variable_opex_per_mwh_aud": {
"type": [
"number",
"null"
]
},
"fuel_cost_per_gj_aud": {
"type": [
"number",
"null"
]
},
"fuel_contract_notes": {
"type": [
"string",
"null"
]
},
"heat_rate_gj_per_mwh": {
"type": [
"number",
"null"
]
},
"efficiency_pct": {
"type": [
"number",
"null"
]
},
"emissions_intensity_tco2_mwh": {
"type": [
"number",
"null"
]
},
"asset_life_years": {
"type": [
"number",
"null"
]
},
"discount_rate_pct": {
"type": [
"number",
"null"
]
},
"source_confidence": {
"type": "string",
"enum": [
"high",
"medium",
"low",
"unknown"
]
},
"data_status": {
"type": "string",
"enum": [
"ai_estimated",
"partially_verified",
"needs_review"
]
},
"notes": {
"type": [
"string",
"null"
]
}
},
"required": [
"generator_type_normalised",
"capex_total_aud",
"capex_year",
"capex_basis",
"capex_per_mw_aud",
"capex_per_mwh_aud",
"fixed_opex_annual_aud",
"fixed_opex_per_mw_year_aud",
"variable_opex_per_mwh_aud",
"fuel_cost_per_gj_aud",
"fuel_contract_notes",
"heat_rate_gj_per_mwh",
"efficiency_pct",
"emissions_intensity_tco2_mwh",
"asset_life_years",
"discount_rate_pct",
"source_confidence",
"data_status",
"notes"
]
},
"sources": {
"type": "array",
"items": {
"type": "object",
"additionalProperties": false,
"properties": {
"field_name": {
"type": "string"
},
"value_text": {
"type": [
"string",
"null"
]
},
"value_numeric": {
"type": [
"number",
"null"
]
},
"unit": {
"type": [
"string",
"null"
]
},
"source_url": {
"type": [
"string",
"null"
]
},
"source_title": {
"type": [
"string",
"null"
]
},
"publisher": {
"type": [
"string",
"null"
]
},
"published_date": {
"type": [
"string",
"null"
]
},
"confidence": {
"type": "string",
"enum": [
"high",
"medium",
"low"
]
},
"raw_excerpt": {
"type": [
"string",
"null"
]
},
"ai_summary": {
"type": [
"string",
"null"
]
}
},
"required": [
"field_name",
"value_text",
"value_numeric",
"unit",
"source_url",
"source_title",
"publisher",
"published_date",
"confidence",
"raw_excerpt",
"ai_summary"
]
}
},
"warnings": {
"type": "array",
"items": {
"type": "string"
}
}
},
"required": [
"generator_identity",
"financial_profile",
"sources",
"warnings"
]
},
"strict": true
},
"verbosity": "medium"
},
"tool_choice": "required",
"tools": [
{
"type": "web_search",
"return_token_budget": "default",
"search_context_size": "high",
"user_location": {
"type": "approximate",
"city": null,
"country": "AU",
"region": null,
"timezone": null
}
}
],
"top_logprobs": 0,
"top_p": 0.98,
"truncation": "disabled",
"usage": {
"input_tokens": 96084,
"input_tokens_details": {
"cached_tokens": 4608
},
"output_tokens": 7177,
"output_tokens_details": {
"reasoning_tokens": 2635
},
"total_tokens": 103261
},
"user": null,
"metadata": []
}
}