Owner: AETV Pty Ltd
Status:
Technology Type: Turbine - OCGT
Fuel Type: Fossil - Natural Gas Pipeline
DUID: BBTHREE3
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
Dispatch target (cleared) vs availability — 5‑minute intervals. TAS1 regional price (RRP) on right axis.
Estimated $ per interval using regional RRP and MLF effective on each day.
UNIT_SOLUTION (5‑minute intervals). Intervention intervals excluded.dispatch_price RRP matched by settlement time and NEM region (from generator registry).| Effective from | MLF |
|---|---|
| 2024-07-01 | 0.9977 |
| 2025-07-01 | 0.9986 |
| Capex total | $87.72M |
|---|---|
| Capex / MW | $2,193,000 |
| Capex / MWh storage | — |
| Fixed OPEX (annual) | $694.7k |
| Fixed OPEX / MW-yr | $17,368 |
| Variable OPEX / MWh | $16.10 |
| Fuel cost / GJ | $12.00 |
| Heat rate GJ/MWh | 10.49 |
Confidence: medium · Status: ai estimated · Capex basis: estimated · AI checked 04 Jun 2026
Notes: No specific financial data found for Bell Bay Three at this time.
[AI 2026-06-04] Bell Bay Three BBTHREE3 is one of the three 40 MW Pratt & Whitney FT8 Twin Pac OCGT units at Tamar Valley Power Station/Bell Bay. Hydro Tasmania reports the station has 178 MW of OCGT comprising a 58 MW Rolls Royce Trent 60WLE and 3 x 40 MW Pratt & Whitney FT8 Twin Pac, with the Tamar Valley Power Station commissioned in 2009. Tasmanian Treasury RTI material states the three 40 MW FT8 gas turbines formed part of the old Bell Bay Power Station and were refurbished as part of the TVPS project. No generator-specific capex/refurbishment cost for BBTHREE3 was found; capex is therefore a 2024 default using Aurecon/AEMO small aero-derivative OCGT EPC cost of AUD 2,193/kW multiplied by 40 MW, excluding site-specific land/development and fuel connection costs. Fixed and variable O&M are also defaults from the same Aurecon/AEMO small GT assumptions, excluding fuel. Heat rate is generator-specific from AEMO heat-rate data for Bell Bay Three: static heat rate 12.04 GJ/MWh HHV as-generated. Efficiency is calculated as 3.6/12.04 = 29.9% HHV. Emissions intensity is estimated from AEMO heat rate times DCCEEW 2025 stationary natural gas pipeline combustion factor 51.53 kg CO2-e/GJ, giving 0.6204 tCO2-e/MWh scope 1. Asset life uses Aurecon/AEMO new-entrant OCGT economic design life of 25 years; this is a default assumption and not an indication of remaining life for the refurbished BBTHREE3 unit. Public closure information is inconsistent/limited: the AEMO generation information page publishes updated expected closure-year files, while third-party mirrors have shown stale expected closure dates; no confirmed closure of BBTHREE3 was found in the searched official sources.
[AI 2026-06-04] Bell Bay Three / BBTHREE3 is one of the Pratt & Whitney FT8 OCGT units now reported within Tamar Valley Power Station. Exact unit-specific original construction cost, fixed O&M, VOM, heat rate and fuel price were not found publicly. Capex is an estimate: Alinta agreed in 2007 to buy the Bell Bay peaking plant site from Hydro Tasmania for AUD 75m, including gas pipeline capacity agreements; this has been allocated one-third to BBTHREE3 because Bell Bay Three comprised three 40 MW FT8 units. This is an acquisition/scope proxy, not a clean EPC construction cost. Default OCGT O&M, heat-rate, efficiency, life and emissions assumptions are taken from AEMO/GHD 2018 OCGT-without-CCS parameters, which are for a large frame OCGT new entrant rather than the smaller aero-derivative FT8, so confidence is medium-to-low for unit economics. Emissions intensity of 0.624 tCO2e/MWh is combustion-only, calculated as 11.75 GJ/MWh * 53.15 kgCO2e/GJ / 1000; including AEMO/GHD fugitive emissions of 3.9-13.5 kgCO2e/GJ would imply roughly 0.670-0.783 tCO2e/MWh. Hydro Tasmania's 2023-24 Annual Environmental Review reports FT8 unit 103B permanently in long-term in-situ storage and FT8 unit 103A not operational through the reporting period, indicating BBTHREE3 availability/derating issues requiring review.
[AI 2026-06-04] Bell Bay Three comprises the three Pratt & Whitney FT8 Twin Pac OCGT units at Tamar Valley Power Station; BBTHREE3 is one 40 MW DUID within the 3 x 40 MW FT8 group. Exact historical construction/acquisition cost for BBTHREE3 was not found. The capex value is a 2024 replacement-cost estimate using Aurecon/AEMO small aero-derivative OCGT EPC cost of AUD 2,193/kW multiplied by 40 MW; it is not the original 2000s nominal project cost. Hydro Tasmania states the Tamar Valley station was commissioned in 2009 and includes 178 MW of OCGT from a 58 MW Rolls Royce Trent and 3 x 40 MW Pratt & Whitney FT8 Twin Pac. AETV’s 2023-24 AER states TVPS has been operated by AETV since full operation as a gas-fired base-load station on 19 September 2009; Unit 103B was taken offline in 2017/18 and remains in long-term in situ storage, while Unit 103A was not available for generation during 2023/24 due to ongoing operational issues. Because the public sources report many values at station/technology level rather than DUID level, O&M, heat rate, efficiency, asset life and replacement capex are technology-default estimates for a small OCGT and should be reviewed against OEM/owner data if available. Emissions intensity is estimated from the HHV heat rate and a standard natural-gas combustion factor; no DUID-specific CO2 intensity was found in public AETV material.
Model: gpt-5.5 · Reasoning: medium · Fetched 04 Jun 2026 09:07 · ID: resp_0ec7ba3199be73a3006a20b32a0c0081909e78dcd6e792043c
{
"generator_identity": {
"site_name": "Bell Bay Three",
"duid": "BBTHREE3",
"owner": "AETV Pty Ltd",
"region": "TAS1 / Tasmania, NEM",
"technology_type": "Turbine - OCGT",
"fuel_type": "Fossil - Natural Gas Pipeline"
},
"financial_profile": {
"generator_type_normalised": "ocgt",
"capex_total_aud": 87720000,
"capex_year": 2024,
"capex_basis": "estimated",
"capex_per_mw_aud": 2193000,
"capex_per_mwh_aud": null,
"fixed_opex_annual_aud": 694720,
"fixed_opex_per_mw_year_aud": 17368,
"variable_opex_per_mwh_aud": 16.1,
"fuel_cost_per_gj_aud": null,
"fuel_contract_notes": "Generator-specific gas commodity price was not found. Hydro Tasmania announced a multi-year Tasmanian Gas Pipeline transportation contract commencing 1 January 2022 for all five Tamar Valley units, including the CCGT, with commercial terms confidential. AETV’s 2023-24 AER reports all TVPS generation equipment operated on natural gas, with no distillate consumed. ACIL Allen/AEMO 2024 fuel-price work includes GPG gas price projections for Tasmania and Bell Bay Three but published PDF extraction exposes the chart rather than a numeric Bell Bay Three gas price series.",
"heat_rate_gj_per_mwh": 10.489,
"efficiency_pct": 34.3,
"emissions_intensity_tco2_mwh": 0.54,
"asset_life_years": 40,
"discount_rate_pct": null,
"source_confidence": "medium",
"data_status": "partially_verified",
"notes": "Bell Bay Three comprises the three Pratt & Whitney FT8 Twin Pac OCGT units at Tamar Valley Power Station; BBTHREE3 is one 40 MW DUID within the 3 x 40 MW FT8 group. Exact historical construction/acquisition cost for BBTHREE3 was not found. The capex value is a 2024 replacement-cost estimate using Aurecon/AEMO small aero-derivative OCGT EPC cost of AUD 2,193/kW multiplied by 40 MW; it is not the original 2000s nominal project cost. Hydro Tasmania states the Tamar Valley station was commissioned in 2009 and includes 178 MW of OCGT from a 58 MW Rolls Royce Trent and 3 x 40 MW Pratt & Whitney FT8 Twin Pac. AETV’s 2023-24 AER states TVPS has been operated by AETV since full operation as a gas-fired base-load station on 19 September 2009; Unit 103B was taken offline in 2017/18 and remains in long-term in situ storage, while Unit 103A was not available for generation during 2023/24 due to ongoing operational issues. Because the public sources report many values at station/technology level rather than DUID level, O&M, heat rate, efficiency, asset life and replacement capex are technology-default estimates for a small OCGT and should be reviewed against OEM/owner data if available. Emissions intensity is estimated from the HHV heat rate and a standard natural-gas combustion factor; no DUID-specific CO2 intensity was found in public AETV material."
},
"sources": [
{
"field_name": "technology_and_capacity",
"value_text": "Tamar Valley Power Station includes 178 MW of OCGT from one 58 MW Rolls Royce Trent 60WLE and 3 x 40 MW Pratt & Whitney FT8 Twin Pac units.",
"value_numeric": 40,
"unit": "MW",
"source_url": "https://www.hydro.com.au/our-energy-system/our-power-stations/tamar-valley-power-station",
"source_title": "Tamar Valley Power Station",
"publisher": "Hydro Tasmania",
"published_date": null,
"confidence": "high",
"raw_excerpt": "The 386 MW station has 208 MW of combined-cycle gas generation (CCGT) from a Mitsubishi M701DA turbine and 178 MW of open-cycle gas generation (OCGT) from a 58 MW Rolls Royce Trent 60WLE and 3 x 40 MW Pratt & Whitney FT8 Twin Pac.",
"ai_summary": "Official owner page confirms the FT8 OCGT configuration and 40 MW unit size used for Bell Bay Three DUID-level assumptions."
},
{
"field_name": "owner_and_operation",
"value_text": "TVPS is operated by AETV Pty Ltd, a wholly owned subsidiary of Hydro Tasmania; full operation as a gas-fired station began on 19 September 2009.",
"value_numeric": 2009,
"unit": "year",
"source_url": "https://www.hydro.com.au/sites/default/files/2025-12/tvps-aer-2023-24-final-signed-v2_compiled.pdf",
"source_title": "Annual Environmental Review Report: Tamar Valley Power Station, 1 July 2023 to 30 June 2024",
"publisher": "AETV Pty Ltd / Hydro Tasmania",
"published_date": "2024-12-08",
"confidence": "high",
"raw_excerpt": "The TVPS has been operated by AETV Pty Ltd (AETV) since it came into full operation as a gas fired base load station on 19 September 2009. AETV is a wholly owned subsidiary of Hydro Tasmania.",
"ai_summary": "AETV’s environmental review confirms operator/ownership context and station operating start date."
},
{
"field_name": "capex_per_mw_aud",
"value_text": "Estimated replacement EPC cost for small aero-derivative OCGT: AUD 2,193/kW net basis, excluding land/development and some fuel connection items; applied to 40 MW BBTHREE3.",
"value_numeric": 2193000,
"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 Costs and Technical 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 ... Net basis. Includes liquid fuel storage (30 hours) and associated infrastructure ... Relative cost does not include land and development costs.",
"ai_summary": "No BBTHREE3 construction cost was found, so the small GT OCGT EPC benchmark was used as a 2024 replacement-cost estimate."
},
{
"field_name": "capex_total_aud",
"value_text": "Estimated as AUD 2,193/kW x 40,000 kW = AUD 87.72 million for BBTHREE3 replacement EPC scope.",
"value_numeric": 87720000,
"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 Costs and Technical Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Small GT ... Relative cost $ / kW 2,193 ... Total EPC cost $ 430,943,200 ... Cost of land and development ... Assuming 9% of CAPEX ... Fuel connection costs ... required / not included depending on scope.",
"ai_summary": "Capex total is calculated for the 40 MW DUID from the AEMO/Aurecon small GT EPC benchmark. It is a replacement estimate, not a reported project cost."
},
{
"field_name": "fixed_opex_per_mw_year_aud",
"value_text": "Small GT fixed O&M cost excluding fuel: AUD 17,368/MW-year.",
"value_numeric": 17368,
"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 Costs and Technical 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) 17,368 ... Based on Aurecon internal database. Labour cost adjustment from 2023 included.",
"ai_summary": "Used as default fixed O&M for BBTHREE3 because DUID-specific fixed O&M was not publicly found."
},
{
"field_name": "fixed_opex_annual_aud",
"value_text": "Estimated as AUD 17,368/MW-year x 40 MW = AUD 694,720/year.",
"value_numeric": 694720,
"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 Costs and Technical 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) 17,368 ... Total annual O&M Cost $ 8,943,477 ... Annual average cost over the design life.",
"ai_summary": "Annual fixed O&M is a DUID-level calculation from the Aurecon/AEMO small GT fixed O&M benchmark and 40 MW capacity."
},
{
"field_name": "variable_opex_per_mwh_aud",
"value_text": "Small GT variable O&M excluding fuel: AUD 16.1/MWh; assumes less than one start per day and excludes potential additional starts-related maintenance.",
"value_numeric": 16.1,
"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 Costs and Technical Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Variable O&M Cost $ / MWh (Net) 16.1 ... Based on Aurecon internal database ... 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 as default variable O&M for BBTHREE3 because no public DUID-specific VOM was identified."
},
{
"field_name": "fuel_contract_notes",
"value_text": "Hydro Tasmania and TGP agreed gas transportation terms commencing 1 January 2022 for Tamar Valley Power Station; details are commercial in confidence.",
"value_numeric": null,
"unit": null,
"source_url": "https://www.hydro.com.au/news/media-releases/2021/12/23/hydro-tasmania-and-tgp-reach-agreement-on-gas-transportation",
"source_title": "Hydro Tasmania and TGP reach agreement on gas transportation",
"publisher": "Hydro Tasmania",
"published_date": "2021-12-23",
"confidence": "high",
"raw_excerpt": "The new agreement locks in gas transportation for the Tamar Valley Power Station for an extended term ... all 5 units at Tamar Valley Power Station (including the combined cycle gas turbine), have access to gas transportation ... Details of the contract are commercial in confidence.",
"ai_summary": "Confirms a multi-year gas transportation arrangement but not gas commodity price."
},
{
"field_name": "fuel_usage_and_fuel_type",
"value_text": "TVPS total 2023/24 gas consumption was 2,196,698 GJ and all power generating equipment operated on natural gas; no distillate consumed.",
"value_numeric": 2196698,
"unit": "GJ",
"source_url": "https://www.hydro.com.au/sites/default/files/2025-12/tvps-aer-2023-24-final-signed-v2_compiled.pdf",
"source_title": "Annual Environmental Review Report: Tamar Valley Power Station, 1 July 2023 to 30 June 2024",
"publisher": "AETV Pty Ltd / Hydro Tasmania",
"published_date": "2024-12-08",
"confidence": "high",
"raw_excerpt": "The total gas consumption of power generating equipment at the TVPS including when FT8s were operated as synchronous condensers during the reporting period was 2,196,698 GJ ... All power generating equipment at the TVPS was operated on natural gas. No distillate fuel (diesel) was consumed.",
"ai_summary": "Confirms natural gas operation and station-level fuel use; not sufficient to allocate exact BBTHREE3 fuel cost."
},
{
"field_name": "heat_rate_gj_per_mwh",
"value_text": "Default small GT HHV net heat rate at maximum operation: 10.489 GJ/MWh.",
"value_numeric": 10.489,
"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 Costs and Technical Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Heat rate at maximum operation (GJ/MWh) HHV Net 10.489 ... Thermal Efficiency at MCR %, HHV Net 34.3%.",
"ai_summary": "Used as default OCGT heat-rate assumption for BBTHREE3 because no FT8 unit-specific heat rate was found in public owner/AEMO sources."
},
{
"field_name": "efficiency_pct",
"value_text": "Default small GT HHV net thermal efficiency at MCR: 34.3%.",
"value_numeric": 34.3,
"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 Costs and Technical Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Thermal Efficiency at MCR %, HHV Net 34.3%.",
"ai_summary": "Used as default efficiency for the BBTHREE3 OCGT; actual FT8 performance may differ."
},
{
"field_name": "emissions_intensity_tco2_mwh",
"value_text": "Estimated as 10.489 GJ/MWh HHV heat rate multiplied by an assumed Australian natural gas combustion factor of about 0.0515 tCO2/GJ, giving about 0.54 tCO2/MWh.",
"value_numeric": 0.54,
"unit": "tCO2/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 Costs and Technical Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "low",
"raw_excerpt": "Heat rate at maximum operation (GJ/MWh) HHV Net 10.489 ... Thermal Efficiency at MCR %, HHV Net 34.3%.",
"ai_summary": "Emissions intensity is derived from the sourced heat rate and a standard natural gas emission factor; DUID-specific measured CO2 intensity was not found."
},
{
"field_name": "asset_life_years",
"value_text": "Aurecon/AEMO OCGT technical life is 40 years; economic/design life is 25 years and can be capacity-factor dependent.",
"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 Costs and Technical Parameters Review",
"publisher": "Aurecon for AEMO",
"published_date": "2024-12-06",
"confidence": "medium",
"raw_excerpt": "Economic Life (Design Life) Years 25 ... Can be capacity factor dependent. Technical Life (Operational Life) Years 40.",
"ai_summary": "Used 40-year technical life as the asset-life assumption; note the FT8 units were pre-existing units incorporated into Tamar Valley."
},
{
"field_name": "major_refurbishment_or_closure_notes",
"value_text": "Unit 103B was taken offline in 2017/18 and remains in long-term in situ storage; Unit 103A was not available for generation in 2023/24 due to operational issues; FT8 units 101 and 102 were used sparingly after NOx non-compliance tests.",
"value_numeric": null,
"unit": null,
"source_url": "https://www.hydro.com.au/sites/default/files/2025-12/tvps-aer-2023-24-final-signed-v2_compiled.pdf",
"source_title": "Annual Environmental Review Report: Tamar Valley Power Station, 1 July 2023 to 30 June 2024",
"publisher": "AETV Pty Ltd / Hydro Tasmania",
"published_date": "2024-12-08",
"confidence": "high",
"raw_excerpt": "Unit 103B This unit was taken offline during the 2017/18 reporting period and has remained permanently in a state of long term in situ storage ... Unit 103A OCGT was not available for generation during the reporting period due to ongoing operational issues.",
"ai_summary": "Provides material availability/refurbishment/closure-relevant notes for the unit group most likely associated with BBTHREE3."
},
{
"field_name": "closure_history_context",
"value_text": "AEMO’s 2015 ESOO listed Bell Bay Three Power Station, 120 MW gas, as 'to be withdrawn'; later AEMC review notes this withdrawal announcement was rescinded.",
"value_numeric": 120,
"unit": "MW",
"source_url": "https://aemo.com.au/-/media/files/electricity/nem/planning_and_forecasting/nem_esoo/2015/2015-electricity-statement-of-opportunities-version-20.pdf",
"source_title": "2015 Electricity Statement of Opportunities",
"publisher": "AEMO",
"published_date": "2015-08",
"confidence": "medium",
"raw_excerpt": "To be withdrawn ... Bell Bay Three Power Station ... TAS ... 120.0 ... Gas.",
"ai_summary": "Historical withdrawal notice existed, but it is not treated as current closure because subsequent sources indicate continuing Tamar Valley/FT8 operation and AEMC notes the announcement was rescinded."
}
],
"warnings": [
"Exact BBTHREE3 construction/acquisition capex was not found in public sources; capex is a 2024 replacement EPC estimate, not reported historical nominal cost.",
"DUID-to-physical-unit mapping is not explicitly confirmed in the retrieved official sources; BBTHREE3 is treated as one of the three Bell Bay Three 40 MW Pratt & Whitney FT8 Twin Pac units.",
"Fuel commodity price is not populated because Hydro/TGP contract details are commercial-in-confidence and no generator-specific AUD/GJ gas price was found in accessible sources.",
"O&M, heat rate, efficiency, emissions intensity and asset life are technology-default estimates based on AEMO/Aurecon small OCGT benchmarks, not measured BBTHREE3 values.",
"Emissions intensity is calculated from heat rate and an assumed standard natural-gas emission factor; no public DUID-specific CO2 intensity was found.",
"AETV’s 2023-24 AER reports operational issues for Unit 103A and long-term in-situ storage for Unit 103B; if BBTHREE3 maps to Unit 103, current available capacity may be materially below nominal 40 MW and should be validated against registration/availability data."
]
}
{
"meta": {
"model": "gpt-5.5",
"reasoning_effort": "medium",
"response_id": "resp_0ec7ba3199be73a3006a20b32a0c0081909e78dcd6e792043c",
"fetched_at": "2026-06-04T09:07:16+10:00"
},
"raw_text": "{\"generator_identity\":{\"site_name\":\"Bell Bay Three\",\"duid\":\"BBTHREE3\",\"owner\":\"AETV Pty Ltd\",\"region\":\"TAS1 / Tasmania, NEM\",\"technology_type\":\"Turbine - OCGT\",\"fuel_type\":\"Fossil - Natural Gas Pipeline\"},\"financial_profile\":{\"generator_type_normalised\":\"ocgt\",\"capex_total_aud\":87720000,\"capex_year\":2024,\"capex_basis\":\"estimated\",\"capex_per_mw_aud\":2193000,\"capex_per_mwh_aud\":null,\"fixed_opex_annual_aud\":694720,\"fixed_opex_per_mw_year_aud\":17368,\"variable_opex_per_mwh_aud\":16.1,\"fuel_cost_per_gj_aud\":null,\"fuel_contract_notes\":\"Generator-specific gas commodity price was not found. Hydro Tasmania announced a multi-year Tasmanian Gas Pipeline transportation contract commencing 1 January 2022 for all five Tamar Valley units, including the CCGT, with commercial terms confidential. AETV’s 2023-24 AER reports all TVPS generation equipment operated on natural gas, with no distillate consumed. ACIL Allen/AEMO 2024 fuel-price work includes GPG gas price projections for Tasmania and Bell Bay Three but published PDF extraction exposes the chart rather than a numeric Bell Bay Three gas price series.\",\"heat_rate_gj_per_mwh\":10.489,\"efficiency_pct\":34.3,\"emissions_intensity_tco2_mwh\":0.54,\"asset_life_years\":40,\"discount_rate_pct\":null,\"source_confidence\":\"medium\",\"data_status\":\"partially_verified\",\"notes\":\"Bell Bay Three comprises the three Pratt & Whitney FT8 Twin Pac OCGT units at Tamar Valley Power Station; BBTHREE3 is one 40 MW DUID within the 3 x 40 MW FT8 group. Exact historical construction/acquisition cost for BBTHREE3 was not found. The capex value is a 2024 replacement-cost estimate using Aurecon/AEMO small aero-derivative OCGT EPC cost of AUD 2,193/kW multiplied by 40 MW; it is not the original 2000s nominal project cost. Hydro Tasmania states the Tamar Valley station was commissioned in 2009 and includes 178 MW of OCGT from a 58 MW Rolls Royce Trent and 3 x 40 MW Pratt & Whitney FT8 Twin Pac. AETV’s 2023-24 AER states TVPS has been operated by AETV since full operation as a gas-fired base-load station on 19 September 2009; Unit 103B was taken offline in 2017/18 and remains in long-term in situ storage, while Unit 103A was not available for generation during 2023/24 due to ongoing operational issues. Because the public sources report many values at station/technology level rather than DUID level, O&M, heat rate, efficiency, asset life and replacement capex are technology-default estimates for a small OCGT and should be reviewed against OEM/owner data if available. Emissions intensity is estimated from the HHV heat rate and a standard natural-gas combustion factor; no DUID-specific CO2 intensity was found in public AETV material.\"},\"sources\":[{\"field_name\":\"technology_and_capacity\",\"value_text\":\"Tamar Valley Power Station includes 178 MW of OCGT from one 58 MW Rolls Royce Trent 60WLE and 3 x 40 MW Pratt & Whitney FT8 Twin Pac units.\",\"value_numeric\":40,\"unit\":\"MW\",\"source_url\":\"https://www.hydro.com.au/our-energy-system/our-power-stations/tamar-valley-power-station\",\"source_title\":\"Tamar Valley Power Station\",\"publisher\":\"Hydro Tasmania\",\"published_date\":null,\"confidence\":\"high\",\"raw_excerpt\":\"The 386 MW station has 208 MW of combined-cycle gas generation (CCGT) from a Mitsubishi M701DA turbine and 178 MW of open-cycle gas generation (OCGT) from a 58 MW Rolls Royce Trent 60WLE and 3 x 40 MW Pratt & Whitney FT8 Twin Pac.\",\"ai_summary\":\"Official owner page confirms the FT8 OCGT configuration and 40 MW unit size used for Bell Bay Three DUID-level assumptions.\"},{\"field_name\":\"owner_and_operation\",\"value_text\":\"TVPS is operated by AETV Pty Ltd, a wholly owned subsidiary of Hydro Tasmania; full operation as a gas-fired station began on 19 September 2009.\",\"value_numeric\":2009,\"unit\":\"year\",\"source_url\":\"https://www.hydro.com.au/sites/default/files/2025-12/tvps-aer-2023-24-final-signed-v2_compiled.pdf\",\"source_title\":\"Annual Environmental Review Report: Tamar Valley Power Station, 1 July 2023 to 30 June 2024\",\"publisher\":\"AETV Pty Ltd / Hydro Tasmania\",\"published_date\":\"2024-12-08\",\"confidence\":\"high\",\"raw_excerpt\":\"The TVPS has been operated by AETV Pty Ltd (AETV) since it came into full operation as a gas fired base load station on 19 September 2009. AETV is a wholly owned subsidiary of Hydro Tasmania.\",\"ai_summary\":\"AETV’s environmental review confirms operator/ownership context and station operating start date.\"},{\"field_name\":\"capex_per_mw_aud\",\"value_text\":\"Estimated replacement EPC cost for small aero-derivative OCGT: AUD 2,193/kW net basis, excluding land/development and some fuel connection items; applied to 40 MW BBTHREE3.\",\"value_numeric\":2193000,\"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 Costs and Technical 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 ... Net basis. Includes liquid fuel storage (30 hours) and associated infrastructure ... Relative cost does not include land and development costs.\",\"ai_summary\":\"No BBTHREE3 construction cost was found, so the small GT OCGT EPC benchmark was used as a 2024 replacement-cost estimate.\"},{\"field_name\":\"capex_total_aud\",\"value_text\":\"Estimated as AUD 2,193/kW x 40,000 kW = AUD 87.72 million for BBTHREE3 replacement EPC scope.\",\"value_numeric\":87720000,\"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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Small GT ... Relative cost $ / kW 2,193 ... Total EPC cost $ 430,943,200 ... Cost of land and development ... Assuming 9% of CAPEX ... Fuel connection costs ... required / not included depending on scope.\",\"ai_summary\":\"Capex total is calculated for the 40 MW DUID from the AEMO/Aurecon small GT EPC benchmark. It is a replacement estimate, not a reported project cost.\"},{\"field_name\":\"fixed_opex_per_mw_year_aud\",\"value_text\":\"Small GT fixed O&M cost excluding fuel: AUD 17,368/MW-year.\",\"value_numeric\":17368,\"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 Costs and Technical 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) 17,368 ... Based on Aurecon internal database. Labour cost adjustment from 2023 included.\",\"ai_summary\":\"Used as default fixed O&M for BBTHREE3 because DUID-specific fixed O&M was not publicly found.\"},{\"field_name\":\"fixed_opex_annual_aud\",\"value_text\":\"Estimated as AUD 17,368/MW-year x 40 MW = AUD 694,720/year.\",\"value_numeric\":694720,\"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 Costs and Technical 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) 17,368 ... Total annual O&M Cost $ 8,943,477 ... Annual average cost over the design life.\",\"ai_summary\":\"Annual fixed O&M is a DUID-level calculation from the Aurecon/AEMO small GT fixed O&M benchmark and 40 MW capacity.\"},{\"field_name\":\"variable_opex_per_mwh_aud\",\"value_text\":\"Small GT variable O&M excluding fuel: AUD 16.1/MWh; assumes less than one start per day and excludes potential additional starts-related maintenance.\",\"value_numeric\":16.1,\"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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Variable O&M Cost $ / MWh (Net) 16.1 ... Based on Aurecon internal database ... 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 as default variable O&M for BBTHREE3 because no public DUID-specific VOM was identified.\"},{\"field_name\":\"fuel_contract_notes\",\"value_text\":\"Hydro Tasmania and TGP agreed gas transportation terms commencing 1 January 2022 for Tamar Valley Power Station; details are commercial in confidence.\",\"value_numeric\":null,\"unit\":null,\"source_url\":\"https://www.hydro.com.au/news/media-releases/2021/12/23/hydro-tasmania-and-tgp-reach-agreement-on-gas-transportation\",\"source_title\":\"Hydro Tasmania and TGP reach agreement on gas transportation\",\"publisher\":\"Hydro Tasmania\",\"published_date\":\"2021-12-23\",\"confidence\":\"high\",\"raw_excerpt\":\"The new agreement locks in gas transportation for the Tamar Valley Power Station for an extended term ... all 5 units at Tamar Valley Power Station (including the combined cycle gas turbine), have access to gas transportation ... Details of the contract are commercial in confidence.\",\"ai_summary\":\"Confirms a multi-year gas transportation arrangement but not gas commodity price.\"},{\"field_name\":\"fuel_usage_and_fuel_type\",\"value_text\":\"TVPS total 2023/24 gas consumption was 2,196,698 GJ and all power generating equipment operated on natural gas; no distillate consumed.\",\"value_numeric\":2196698,\"unit\":\"GJ\",\"source_url\":\"https://www.hydro.com.au/sites/default/files/2025-12/tvps-aer-2023-24-final-signed-v2_compiled.pdf\",\"source_title\":\"Annual Environmental Review Report: Tamar Valley Power Station, 1 July 2023 to 30 June 2024\",\"publisher\":\"AETV Pty Ltd / Hydro Tasmania\",\"published_date\":\"2024-12-08\",\"confidence\":\"high\",\"raw_excerpt\":\"The total gas consumption of power generating equipment at the TVPS including when FT8s were operated as synchronous condensers during the reporting period was 2,196,698 GJ ... All power generating equipment at the TVPS was operated on natural gas. No distillate fuel (diesel) was consumed.\",\"ai_summary\":\"Confirms natural gas operation and station-level fuel use; not sufficient to allocate exact BBTHREE3 fuel cost.\"},{\"field_name\":\"heat_rate_gj_per_mwh\",\"value_text\":\"Default small GT HHV net heat rate at maximum operation: 10.489 GJ/MWh.\",\"value_numeric\":10.489,\"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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Heat rate at maximum operation (GJ/MWh) HHV Net 10.489 ... Thermal Efficiency at MCR %, HHV Net 34.3%.\",\"ai_summary\":\"Used as default OCGT heat-rate assumption for BBTHREE3 because no FT8 unit-specific heat rate was found in public owner/AEMO sources.\"},{\"field_name\":\"efficiency_pct\",\"value_text\":\"Default small GT HHV net thermal efficiency at MCR: 34.3%.\",\"value_numeric\":34.3,\"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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Thermal Efficiency at MCR %, HHV Net 34.3%.\",\"ai_summary\":\"Used as default efficiency for the BBTHREE3 OCGT; actual FT8 performance may differ.\"},{\"field_name\":\"emissions_intensity_tco2_mwh\",\"value_text\":\"Estimated as 10.489 GJ/MWh HHV heat rate multiplied by an assumed Australian natural gas combustion factor of about 0.0515 tCO2/GJ, giving about 0.54 tCO2/MWh.\",\"value_numeric\":0.54,\"unit\":\"tCO2/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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"low\",\"raw_excerpt\":\"Heat rate at maximum operation (GJ/MWh) HHV Net 10.489 ... Thermal Efficiency at MCR %, HHV Net 34.3%.\",\"ai_summary\":\"Emissions intensity is derived from the sourced heat rate and a standard natural gas emission factor; DUID-specific measured CO2 intensity was not found.\"},{\"field_name\":\"asset_life_years\",\"value_text\":\"Aurecon/AEMO OCGT technical life is 40 years; economic/design life is 25 years and can be capacity-factor dependent.\",\"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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Economic Life (Design Life) Years 25 ... Can be capacity factor dependent. Technical Life (Operational Life) Years 40.\",\"ai_summary\":\"Used 40-year technical life as the asset-life assumption; note the FT8 units were pre-existing units incorporated into Tamar Valley.\"},{\"field_name\":\"major_refurbishment_or_closure_notes\",\"value_text\":\"Unit 103B was taken offline in 2017/18 and remains in long-term in situ storage; Unit 103A was not available for generation in 2023/24 due to operational issues; FT8 units 101 and 102 were used sparingly after NOx non-compliance tests.\",\"value_numeric\":null,\"unit\":null,\"source_url\":\"https://www.hydro.com.au/sites/default/files/2025-12/tvps-aer-2023-24-final-signed-v2_compiled.pdf\",\"source_title\":\"Annual Environmental Review Report: Tamar Valley Power Station, 1 July 2023 to 30 June 2024\",\"publisher\":\"AETV Pty Ltd / Hydro Tasmania\",\"published_date\":\"2024-12-08\",\"confidence\":\"high\",\"raw_excerpt\":\"Unit 103B This unit was taken offline during the 2017/18 reporting period and has remained permanently in a state of long term in situ storage ... Unit 103A OCGT was not available for generation during the reporting period due to ongoing operational issues.\",\"ai_summary\":\"Provides material availability/refurbishment/closure-relevant notes for the unit group most likely associated with BBTHREE3.\"},{\"field_name\":\"closure_history_context\",\"value_text\":\"AEMO’s 2015 ESOO listed Bell Bay Three Power Station, 120 MW gas, as 'to be withdrawn'; later AEMC review notes this withdrawal announcement was rescinded.\",\"value_numeric\":120,\"unit\":\"MW\",\"source_url\":\"https://aemo.com.au/-/media/files/electricity/nem/planning_and_forecasting/nem_esoo/2015/2015-electricity-statement-of-opportunities-version-20.pdf\",\"source_title\":\"2015 Electricity Statement of Opportunities\",\"publisher\":\"AEMO\",\"published_date\":\"2015-08\",\"confidence\":\"medium\",\"raw_excerpt\":\"To be withdrawn ... Bell Bay Three Power Station ... TAS ... 120.0 ... Gas.\",\"ai_summary\":\"Historical withdrawal notice existed, but it is not treated as current closure because subsequent sources indicate continuing Tamar Valley/FT8 operation and AEMC notes the announcement was rescinded.\"}],\"warnings\":[\"Exact BBTHREE3 construction/acquisition capex was not found in public sources; capex is a 2024 replacement EPC estimate, not reported historical nominal cost.\",\"DUID-to-physical-unit mapping is not explicitly confirmed in the retrieved official sources; BBTHREE3 is treated as one of the three Bell Bay Three 40 MW Pratt & Whitney FT8 Twin Pac units.\",\"Fuel commodity price is not populated because Hydro/TGP contract details are commercial-in-confidence and no generator-specific AUD/GJ gas price was found in accessible sources.\",\"O&M, heat rate, efficiency, emissions intensity and asset life are technology-default estimates based on AEMO/Aurecon small OCGT benchmarks, not measured BBTHREE3 values.\",\"Emissions intensity is calculated from heat rate and an assumed standard natural-gas emission factor; no public DUID-specific CO2 intensity was found.\",\"AETV’s 2023-24 AER reports operational issues for Unit 103A and long-term in-situ storage for Unit 103B; if BBTHREE3 maps to Unit 103, current available capacity may be materially below nominal 40 MW and should be validated against registration/availability data.\"]}",
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"text": "{\"generator_identity\":{\"site_name\":\"Bell Bay Three\",\"duid\":\"BBTHREE3\",\"owner\":\"AETV Pty Ltd\",\"region\":\"TAS1 / Tasmania, NEM\",\"technology_type\":\"Turbine - OCGT\",\"fuel_type\":\"Fossil - Natural Gas Pipeline\"},\"financial_profile\":{\"generator_type_normalised\":\"ocgt\",\"capex_total_aud\":87720000,\"capex_year\":2024,\"capex_basis\":\"estimated\",\"capex_per_mw_aud\":2193000,\"capex_per_mwh_aud\":null,\"fixed_opex_annual_aud\":694720,\"fixed_opex_per_mw_year_aud\":17368,\"variable_opex_per_mwh_aud\":16.1,\"fuel_cost_per_gj_aud\":null,\"fuel_contract_notes\":\"Generator-specific gas commodity price was not found. Hydro Tasmania announced a multi-year Tasmanian Gas Pipeline transportation contract commencing 1 January 2022 for all five Tamar Valley units, including the CCGT, with commercial terms confidential. AETV’s 2023-24 AER reports all TVPS generation equipment operated on natural gas, with no distillate consumed. ACIL Allen/AEMO 2024 fuel-price work includes GPG gas price projections for Tasmania and Bell Bay Three but published PDF extraction exposes the chart rather than a numeric Bell Bay Three gas price series.\",\"heat_rate_gj_per_mwh\":10.489,\"efficiency_pct\":34.3,\"emissions_intensity_tco2_mwh\":0.54,\"asset_life_years\":40,\"discount_rate_pct\":null,\"source_confidence\":\"medium\",\"data_status\":\"partially_verified\",\"notes\":\"Bell Bay Three comprises the three Pratt & Whitney FT8 Twin Pac OCGT units at Tamar Valley Power Station; BBTHREE3 is one 40 MW DUID within the 3 x 40 MW FT8 group. Exact historical construction/acquisition cost for BBTHREE3 was not found. The capex value is a 2024 replacement-cost estimate using Aurecon/AEMO small aero-derivative OCGT EPC cost of AUD 2,193/kW multiplied by 40 MW; it is not the original 2000s nominal project cost. Hydro Tasmania states the Tamar Valley station was commissioned in 2009 and includes 178 MW of OCGT from a 58 MW Rolls Royce Trent and 3 x 40 MW Pratt & Whitney FT8 Twin Pac. AETV’s 2023-24 AER states TVPS has been operated by AETV since full operation as a gas-fired base-load station on 19 September 2009; Unit 103B was taken offline in 2017/18 and remains in long-term in situ storage, while Unit 103A was not available for generation during 2023/24 due to ongoing operational issues. Because the public sources report many values at station/technology level rather than DUID level, O&M, heat rate, efficiency, asset life and replacement capex are technology-default estimates for a small OCGT and should be reviewed against OEM/owner data if available. Emissions intensity is estimated from the HHV heat rate and a standard natural-gas combustion factor; no DUID-specific CO2 intensity was found in public AETV material.\"},\"sources\":[{\"field_name\":\"technology_and_capacity\",\"value_text\":\"Tamar Valley Power Station includes 178 MW of OCGT from one 58 MW Rolls Royce Trent 60WLE and 3 x 40 MW Pratt & Whitney FT8 Twin Pac units.\",\"value_numeric\":40,\"unit\":\"MW\",\"source_url\":\"https://www.hydro.com.au/our-energy-system/our-power-stations/tamar-valley-power-station\",\"source_title\":\"Tamar Valley Power Station\",\"publisher\":\"Hydro Tasmania\",\"published_date\":null,\"confidence\":\"high\",\"raw_excerpt\":\"The 386 MW station has 208 MW of combined-cycle gas generation (CCGT) from a Mitsubishi M701DA turbine and 178 MW of open-cycle gas generation (OCGT) from a 58 MW Rolls Royce Trent 60WLE and 3 x 40 MW Pratt & Whitney FT8 Twin Pac.\",\"ai_summary\":\"Official owner page confirms the FT8 OCGT configuration and 40 MW unit size used for Bell Bay Three DUID-level assumptions.\"},{\"field_name\":\"owner_and_operation\",\"value_text\":\"TVPS is operated by AETV Pty Ltd, a wholly owned subsidiary of Hydro Tasmania; full operation as a gas-fired station began on 19 September 2009.\",\"value_numeric\":2009,\"unit\":\"year\",\"source_url\":\"https://www.hydro.com.au/sites/default/files/2025-12/tvps-aer-2023-24-final-signed-v2_compiled.pdf\",\"source_title\":\"Annual Environmental Review Report: Tamar Valley Power Station, 1 July 2023 to 30 June 2024\",\"publisher\":\"AETV Pty Ltd / Hydro Tasmania\",\"published_date\":\"2024-12-08\",\"confidence\":\"high\",\"raw_excerpt\":\"The TVPS has been operated by AETV Pty Ltd (AETV) since it came into full operation as a gas fired base load station on 19 September 2009. AETV is a wholly owned subsidiary of Hydro Tasmania.\",\"ai_summary\":\"AETV’s environmental review confirms operator/ownership context and station operating start date.\"},{\"field_name\":\"capex_per_mw_aud\",\"value_text\":\"Estimated replacement EPC cost for small aero-derivative OCGT: AUD 2,193/kW net basis, excluding land/development and some fuel connection items; applied to 40 MW BBTHREE3.\",\"value_numeric\":2193000,\"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 Costs and Technical 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 ... Net basis. Includes liquid fuel storage (30 hours) and associated infrastructure ... Relative cost does not include land and development costs.\",\"ai_summary\":\"No BBTHREE3 construction cost was found, so the small GT OCGT EPC benchmark was used as a 2024 replacement-cost estimate.\"},{\"field_name\":\"capex_total_aud\",\"value_text\":\"Estimated as AUD 2,193/kW x 40,000 kW = AUD 87.72 million for BBTHREE3 replacement EPC scope.\",\"value_numeric\":87720000,\"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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Small GT ... Relative cost $ / kW 2,193 ... Total EPC cost $ 430,943,200 ... Cost of land and development ... Assuming 9% of CAPEX ... Fuel connection costs ... required / not included depending on scope.\",\"ai_summary\":\"Capex total is calculated for the 40 MW DUID from the AEMO/Aurecon small GT EPC benchmark. It is a replacement estimate, not a reported project cost.\"},{\"field_name\":\"fixed_opex_per_mw_year_aud\",\"value_text\":\"Small GT fixed O&M cost excluding fuel: AUD 17,368/MW-year.\",\"value_numeric\":17368,\"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 Costs and Technical 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) 17,368 ... Based on Aurecon internal database. Labour cost adjustment from 2023 included.\",\"ai_summary\":\"Used as default fixed O&M for BBTHREE3 because DUID-specific fixed O&M was not publicly found.\"},{\"field_name\":\"fixed_opex_annual_aud\",\"value_text\":\"Estimated as AUD 17,368/MW-year x 40 MW = AUD 694,720/year.\",\"value_numeric\":694720,\"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 Costs and Technical 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) 17,368 ... Total annual O&M Cost $ 8,943,477 ... Annual average cost over the design life.\",\"ai_summary\":\"Annual fixed O&M is a DUID-level calculation from the Aurecon/AEMO small GT fixed O&M benchmark and 40 MW capacity.\"},{\"field_name\":\"variable_opex_per_mwh_aud\",\"value_text\":\"Small GT variable O&M excluding fuel: AUD 16.1/MWh; assumes less than one start per day and excludes potential additional starts-related maintenance.\",\"value_numeric\":16.1,\"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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Variable O&M Cost $ / MWh (Net) 16.1 ... Based on Aurecon internal database ... 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 as default variable O&M for BBTHREE3 because no public DUID-specific VOM was identified.\"},{\"field_name\":\"fuel_contract_notes\",\"value_text\":\"Hydro Tasmania and TGP agreed gas transportation terms commencing 1 January 2022 for Tamar Valley Power Station; details are commercial in confidence.\",\"value_numeric\":null,\"unit\":null,\"source_url\":\"https://www.hydro.com.au/news/media-releases/2021/12/23/hydro-tasmania-and-tgp-reach-agreement-on-gas-transportation\",\"source_title\":\"Hydro Tasmania and TGP reach agreement on gas transportation\",\"publisher\":\"Hydro Tasmania\",\"published_date\":\"2021-12-23\",\"confidence\":\"high\",\"raw_excerpt\":\"The new agreement locks in gas transportation for the Tamar Valley Power Station for an extended term ... all 5 units at Tamar Valley Power Station (including the combined cycle gas turbine), have access to gas transportation ... Details of the contract are commercial in confidence.\",\"ai_summary\":\"Confirms a multi-year gas transportation arrangement but not gas commodity price.\"},{\"field_name\":\"fuel_usage_and_fuel_type\",\"value_text\":\"TVPS total 2023/24 gas consumption was 2,196,698 GJ and all power generating equipment operated on natural gas; no distillate consumed.\",\"value_numeric\":2196698,\"unit\":\"GJ\",\"source_url\":\"https://www.hydro.com.au/sites/default/files/2025-12/tvps-aer-2023-24-final-signed-v2_compiled.pdf\",\"source_title\":\"Annual Environmental Review Report: Tamar Valley Power Station, 1 July 2023 to 30 June 2024\",\"publisher\":\"AETV Pty Ltd / Hydro Tasmania\",\"published_date\":\"2024-12-08\",\"confidence\":\"high\",\"raw_excerpt\":\"The total gas consumption of power generating equipment at the TVPS including when FT8s were operated as synchronous condensers during the reporting period was 2,196,698 GJ ... All power generating equipment at the TVPS was operated on natural gas. No distillate fuel (diesel) was consumed.\",\"ai_summary\":\"Confirms natural gas operation and station-level fuel use; not sufficient to allocate exact BBTHREE3 fuel cost.\"},{\"field_name\":\"heat_rate_gj_per_mwh\",\"value_text\":\"Default small GT HHV net heat rate at maximum operation: 10.489 GJ/MWh.\",\"value_numeric\":10.489,\"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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Heat rate at maximum operation (GJ/MWh) HHV Net 10.489 ... Thermal Efficiency at MCR %, HHV Net 34.3%.\",\"ai_summary\":\"Used as default OCGT heat-rate assumption for BBTHREE3 because no FT8 unit-specific heat rate was found in public owner/AEMO sources.\"},{\"field_name\":\"efficiency_pct\",\"value_text\":\"Default small GT HHV net thermal efficiency at MCR: 34.3%.\",\"value_numeric\":34.3,\"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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Thermal Efficiency at MCR %, HHV Net 34.3%.\",\"ai_summary\":\"Used as default efficiency for the BBTHREE3 OCGT; actual FT8 performance may differ.\"},{\"field_name\":\"emissions_intensity_tco2_mwh\",\"value_text\":\"Estimated as 10.489 GJ/MWh HHV heat rate multiplied by an assumed Australian natural gas combustion factor of about 0.0515 tCO2/GJ, giving about 0.54 tCO2/MWh.\",\"value_numeric\":0.54,\"unit\":\"tCO2/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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"low\",\"raw_excerpt\":\"Heat rate at maximum operation (GJ/MWh) HHV Net 10.489 ... Thermal Efficiency at MCR %, HHV Net 34.3%.\",\"ai_summary\":\"Emissions intensity is derived from the sourced heat rate and a standard natural gas emission factor; DUID-specific measured CO2 intensity was not found.\"},{\"field_name\":\"asset_life_years\",\"value_text\":\"Aurecon/AEMO OCGT technical life is 40 years; economic/design life is 25 years and can be capacity-factor dependent.\",\"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 Costs and Technical Parameters Review\",\"publisher\":\"Aurecon for AEMO\",\"published_date\":\"2024-12-06\",\"confidence\":\"medium\",\"raw_excerpt\":\"Economic Life (Design Life) Years 25 ... Can be capacity factor dependent. Technical Life (Operational Life) Years 40.\",\"ai_summary\":\"Used 40-year technical life as the asset-life assumption; note the FT8 units were pre-existing units incorporated into Tamar Valley.\"},{\"field_name\":\"major_refurbishment_or_closure_notes\",\"value_text\":\"Unit 103B was taken offline in 2017/18 and remains in long-term in situ storage; Unit 103A was not available for generation in 2023/24 due to operational issues; FT8 units 101 and 102 were used sparingly after NOx non-compliance tests.\",\"value_numeric\":null,\"unit\":null,\"source_url\":\"https://www.hydro.com.au/sites/default/files/2025-12/tvps-aer-2023-24-final-signed-v2_compiled.pdf\",\"source_title\":\"Annual Environmental Review Report: Tamar Valley Power Station, 1 July 2023 to 30 June 2024\",\"publisher\":\"AETV Pty Ltd / Hydro Tasmania\",\"published_date\":\"2024-12-08\",\"confidence\":\"high\",\"raw_excerpt\":\"Unit 103B This unit was taken offline during the 2017/18 reporting period and has remained permanently in a state of long term in situ storage ... Unit 103A OCGT was not available for generation during the reporting period due to ongoing operational issues.\",\"ai_summary\":\"Provides material availability/refurbishment/closure-relevant notes for the unit group most likely associated with BBTHREE3.\"},{\"field_name\":\"closure_history_context\",\"value_text\":\"AEMO’s 2015 ESOO listed Bell Bay Three Power Station, 120 MW gas, as 'to be withdrawn'; later AEMC review notes this withdrawal announcement was rescinded.\",\"value_numeric\":120,\"unit\":\"MW\",\"source_url\":\"https://aemo.com.au/-/media/files/electricity/nem/planning_and_forecasting/nem_esoo/2015/2015-electricity-statement-of-opportunities-version-20.pdf\",\"source_title\":\"2015 Electricity Statement of Opportunities\",\"publisher\":\"AEMO\",\"published_date\":\"2015-08\",\"confidence\":\"medium\",\"raw_excerpt\":\"To be withdrawn ... Bell Bay Three Power Station ... TAS ... 120.0 ... Gas.\",\"ai_summary\":\"Historical withdrawal notice existed, but it is not treated as current closure because subsequent sources indicate continuing Tamar Valley/FT8 operation and AEMC notes the announcement was rescinded.\"}],\"warnings\":[\"Exact BBTHREE3 construction/acquisition capex was not found in public sources; capex is a 2024 replacement EPC estimate, not reported historical nominal cost.\",\"DUID-to-physical-unit mapping is not explicitly confirmed in the retrieved official sources; BBTHREE3 is treated as one of the three Bell Bay Three 40 MW Pratt & Whitney FT8 Twin Pac units.\",\"Fuel commodity price is not populated because Hydro/TGP contract details are commercial-in-confidence and no generator-specific AUD/GJ gas price was found in accessible sources.\",\"O&M, heat rate, efficiency, emissions intensity and asset life are technology-default estimates based on AEMO/Aurecon small OCGT benchmarks, not measured BBTHREE3 values.\",\"Emissions intensity is calculated from heat rate and an assumed standard natural-gas emission factor; no public DUID-specific CO2 intensity was found.\",\"AETV’s 2023-24 AER reports operational issues for Unit 103A and long-term in-situ storage for Unit 103B; if BBTHREE3 maps to Unit 103, current available capacity may be materially below nominal 40 MW and should be validated against registration/availability data.\"]}"
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