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14056244.083027111, "volume_mwh": -165166.41286222223 }, { "lead_party": "Smartestenergy Limited", "cost": 13889845.023575334, "volume_mwh": -197354.8342864364 }, { "lead_party": "Dunmaglass Wind Farm Limited", "cost": 13666146.430505842, "volume_mwh": -150938.51823851853 }, { "lead_party": "Beatrice Offshore Windfarm Ltd", "cost": 13248644.21591568, "volume_mwh": -127103.06748444444 }, { "lead_party": "Creag Riabhach Wind Farm Ltd", "cost": 12583850.27327623, "volume_mwh": -192330.0743704069 }, { "lead_party": "Griffin Wind Farm Ltd", "cost": 12467059.549287647, "volume_mwh": -131738.34469180554 }, { "lead_party": "Clyde Windfarm (Scotland) Ltd", "cost": 12114736.711265678, "volume_mwh": -126743.21868097222 }, { "lead_party": "Corriegarth Wind Energy LTD", "cost": 11419297.333433097, "volume_mwh": -139960.83698093297 }, { "lead_party": "AIK2A Sustainable Energy Ltd", "cost": 11158349.650767013, "volume_mwh": -169381.0235977965 }, { "lead_party": "South Kyle Wind Farm Limited", "cost": 10943820.647724241, "volume_mwh": -311583.34127354913 }, { "lead_party": "Greater Gabbard Offshore Winds", "cost": 9965494.60681167, "volume_mwh": -59703.591657083336 }, { "lead_party": "Erova Energy Limited", "cost": 9935471.327884704, "volume_mwh": -179699.57267378643 }, { "lead_party": "Limekiln Extension Ltd", "cost": 9109470.431436388, "volume_mwh": -245953.37601874396 } ], "curtailed_mwh": 27444801.096268937, "history_source_url": "https://www.ref.org.uk/constraints/index.php?tab=yr", "bottom_up_from": "2024-01-12", "bottom_up_to": "2026-09-30" }, { "id": "capacity_market", "label": "Capacity Market", "perspectives": [], "cadence": "monthly", "layer": "indirect", "attribution_pct": 1.0, "attribution_note": "Capacity Market levy counted in full: availability payments procure backup for intermittent generation", "attribution_confidence": "medium", "cumulative": 9024189621.33, "runrate_per_year": 1791769820.4799998, "data_to": "2026-07-01", "source": "LCCC data portal, capacity market payments", "source_url": "https://dp.lowcarboncontracts.uk/dataset/capacity-obligation-by-auction" }, { "id": "ro", "label": "Renewables Obligation", "perspectives": [ "renewables", "low_carbon" ], "cadence": "annual", "layer": "direct", "attribution_pct": 1.0, "attribution_note": "", "attribution_confidence": "", "cumulative": 74590000000.0, "runrate_per_year": 7700000000.0, "data_to": "2025-03-31", "source": "Ofgem Renewables Obligation Annual Reports. 2024 (SY23): Annual Report 2024-25 headline scheme value (PDF, RO_24-25_SY23_Annual_Report, Mar 2026). 2010-2023 (SY9-SY22): scheme value = total ROCs presented x notional worth of a ROC, Figure A4.1 of the SY22 Annual Report (2023-24, PDF, Mar 2025), cross-checked against headline values stated in the SY22/SY23 report text (SY1 GBP 0.25bn, SY18 GBP 6.31bn, SY19 GBP 5.73bn, SY22 GBP 6.75bn, SY23 GBP 7.70bn). 2002-2009 (SY1-SY8): ROCs presented x worth of a ROC from the compliance tables of Ofgem's second annual report (2003-04, Feb 2005), the RO Annual Report 2004-2005 (Feb 2006), the RO Annual Report 2008-09 (Feb 2010) and the RO Annual Report 2010-11 (Mar 2012).", "source_url": "https://www.ofgem.gov.uk/transparency-document/renewables-obligation-ro-annual-report-scheme-year-22-april-2023-march-2024", "verified": true, "by_station": [ { "station": "Drax Power Station", "technology": "Biomass", "cost": 6478643283.0 }, { "station": "London Array Offshore Windfarm", "technology": "Offshore Wind", "cost": 2921810149.0 }, { "station": "Greater Gabbard", "technology": "Offshore Wind", "cost": 2198286741.0 }, { "station": "Gwynt y Mor", "technology": "Offshore Wind", "cost": 1930213898.0 }, { "station": "West of Duddon Sands Offshore Wind Farm", "technology": "Offshore Wind", "cost": 1771953579.0 }, { "station": "Race Bank", "technology": "Offshore Wind", "cost": 1750094370.0 }, { "station": "Sheringham Shoal", "technology": "Offshore Wind", "cost": 1431951619.0 }, { "station": "Thanet Offshore Wind Farm", "technology": "Offshore Wind", "cost": 1303265231.0 }, { "station": "Lincs Wind Farm", "technology": "Offshore Wind", "cost": 1247317020.0 }, { "station": "Galloper Wind Farm", "technology": "Offshore Wind", "cost": 1133757519.0 }, { "station": "Rampion", "technology": "Offshore Wind", "cost": 1073161528.0 }, { "station": "Walney Offshore Wind Phase II", "technology": "Offshore Wind", "cost": 974459099.0 }, { "station": "Westermost Rough", "technology": "Offshore Wind", "cost": 951506226.0 }, { "station": "Walney Offshore Wind Phase I", "technology": "Offshore Wind", "cost": 896126414.0 }, { "station": "Humber Gateway Offshore Wind Farm", "technology": "Offshore Wind", "cost": 838364104.0 }, { "station": "Ormonde Wind Farm", "technology": "Offshore Wind", "cost": 629891547.0 }, { "station": "Whitelee Windfarm", "technology": "Onshore Wind", "cost": 472768538.0 }, { "station": "Robin Rigg Offshore Wind Farm (East)", "technology": "Offshore Wind", "cost": 366298883.0 }, { "station": "Inner Dowsing Offshore Wind Farm", "technology": "Offshore Wind", "cost": 365970909.0 }, { "station": "Lynn Offshore Wind Farm", "technology": "Offshore Wind", "cost": 360366128.0 }, { "station": "Gunfleet Sands I", "technology": "Offshore Wind", "cost": 348766631.0 }, { "station": "Burbo Offshore Windfarm - A (31/01/07)", "technology": "Offshore Wind", "cost": 319013493.0 }, { "station": "Robin Rigg Offshore Wind Farm (West)", "technology": "Offshore Wind", "cost": 308281938.0 }, { "station": "Rhyl Flats Wind farm", "technology": "Offshore Wind", "cost": 294062445.0 }, { "station": "Clyde Windfarm (North)", "technology": "Onshore Wind", "cost": 284952623.0 } ], "recipient_basis": "buyout" }, { "id": "fit", "label": "Feed-in Tariffs", "perspectives": [ "renewables", "low_carbon" ], "cadence": "annual", "layer": "direct", "attribution_pct": 1.0, "attribution_note": "", "attribution_confidence": "", "cumulative": 18233000000.0, "runrate_per_year": 1844000000.0, "data_to": "2025-03-31", "source": "Ofgem Feed-in Tariffs Annual Report Scheme Year 15 (April 2024 to March 2025), Figure 3.3 \"FIT scheme value, SY1-15\" (PDF, feed_in_tariff_annual_report_sy15, Dec 2025). The report states the series grew every year from SY1 to SY11 (GBP 1,764m), fell for the first time in SY12 (GBP 1,575m), peaked at GBP 1,858m in SY14, and was GBP 1,844m in SY15, which fixes the year order of the charted values.", "source_url": "https://www.ofgem.gov.uk/transparency-document/feed-tariffs-annual-report-scheme-year-15-april-2024-march-2025", "verified": true }, { "id": "ccl", "label": "Climate Change Levy (electricity share) + Carbon Price Support", "perspectives": [], "cadence": "annual", "layer": "indirect", "attribution_pct": 1.0, "attribution_note": "Electricity's share of CCL main-rate liabilities (HMRC's published commodity split of declarations) plus Carbon Price Support receipts, which fall wholly on electricity generation. Gas/solid-fuel main-rate CCL is excluded.", "attribution_confidence": "medium", "cumulative": 22848100000.0, "runrate_per_year": 1253000000.0, "data_to": "2024-12-31", "source": "HMRC Environmental Taxes Bulletin (formerly Climate Change Levy and Carbon Price Floor Bulletin), March 2026 edition, tables ODS (2026_March_env_tabs_test.ods), Table 1b \"CCL and CPF receipts and clearances data by calendar year\". Value = electricity main-rate declared liabilities (the only commodity split HMRC publishes) plus estimated CPF receipts (CPS applies solely to fossil fuels used for electricity generation, so it is wholly electricity-attributable). Sums rounded down to the nearest GBP 0.1m.", "source_url": "https://www.gov.uk/government/statistics/environmental-taxes-bulletin", "verified": true }, { "id": "ets", "label": "Emissions trading (power-sector share of UK auction revenue)", "perspectives": [], "cadence": "annual", "layer": "indirect", "attribution_pct": 1.0, "attribution_note": "Power-sector share of AUCTIONED allowance revenue only; free allocation excluded. Share taken as electricity generation's share of total verified covered emissions - a lower bound, since power receives no free allocation and so buys a larger share of auctioned allowances than its emissions share.", "attribution_confidence": "medium", "cumulative": 10516019346.0, "runrate_per_year": 882834732.0, "data_to": "2024-12-31", "source": "Auction revenue: 2012-2018 calendar-year sums of UK EUA auction results from the European Commission's UK Phase III Auction Platform Reports nos. 57 and 58 (ICE Futures Europe auctions on behalf of BEIS/DECC), converted from EUR at Bank of England annual average rates; 2019-2020 \"EU ETS auction income\" from the BEIS Annual Report and Accounts 2020-21 Trust Statement (FY2019-20 GBP 201.4m, FY2020-21 GBP 2,213.1m); 2021-2023 \"UK ETS auction income\" from the BEIS/DESNZ Annual Report and Accounts Trust Statements (FY2021-22 GBP 5,753,639k, FY2022-23 GBP 6,048,951k, FY2023-24 GBP 3,407,068k), attributed to the calendar year in which the financial year starts. 2024 uses the PUBLISHED CALENDAR-YEAR total instead - see calendar_year_revenue below. Power-sector share: from published UK ETS verified emissions (electricity generation / total covered); 2009-2020 a flat 0.5 estimate. See emissions_vintage below for the figures and their editions.", "source_url": "https://www.gov.uk/government/publications/desnz-annual-report-and-accounts-2023-to-2024/trust-statement", "verified": false }, { "id": "tnuos", "label": "Transmission Network Use of System (attributed uplift)", "perspectives": [], "cadence": "annual", "layer": "indirect", "attribution_pct": 0.4805543950088046, "attribution_note": "Raw totals stored; attribution happens in the money model. Only the increase above the CPIH-indexed 2002-05 baseline (GBP 0.9bn/yr) is attributed to renewables, floored at zero.", "attribution_confidence": "low", "cumulative": 24143725581.395355, "runrate_per_year": 2643151162.790698, "data_to": "2025-03-31", "source": "2013-2024: NESO TNUoS charging statements (total revenue), as compiled in David Turver's \"TNUoS and BSUoS summary\" workbook from NESO's Final TNUoS Tariffs publications. Calendar mapping is fiscal-year-ended-March minus one (the period starting April of the calendar year); validated because the 2022-24 calendar values reproduce our three independent NESO anchors exactly - \"Final TNUoS Tariffs for 2023/24\" (GBP 4,416.4m, our 2023) and \"Final TNUoS Tariffs for 2024/25\" (MAR Total Revenue GBP 4,188.5m, our 2024). 2002-2004: GBP 0.9bn/yr per the verified 2002-05 baseline (reference/baselines.yaml). Earliest intermediate years 2005-2012: REF April 2025 study Table 2 total-charge column (in parentheses), itself compiled from NESO/Ofgem charging statements - pending primary confirmation (not reached by the Turver/NESO series).", "source_url": "https://www.neso.energy/industry-information/charging/tnuos-charges", "verified": false, "raw_annual": [ { "year": 2002, "cost": 900000000.0 }, { "year": 2003, "cost": 900000000.0 }, { "year": 2004, "cost": 900000000.0 }, { "year": 2005, "cost": 900000000.0 }, { "year": 2006, "cost": 1000000000.0 }, { "year": 2007, "cost": 1000000000.0 }, { "year": 2008, "cost": 1400000000.0 }, { "year": 2009, "cost": 1600000000.0 }, { "year": 2010, "cost": 1600000000.0 }, { "year": 2011, "cost": 1600000000.0 }, { "year": 2012, "cost": 1600000000.0 }, { "year": 2013, "cost": 2196600000.0 }, { "year": 2014, "cost": 2524300000.0 }, { "year": 2015, "cost": 2636700000.0 }, { "year": 2016, "cost": 2708700000.0 }, { "year": 2017, "cost": 2631500000.0 }, { "year": 2018, "cost": 2670300000.0 }, { "year": 2019, "cost": 2837400000.0 }, { "year": 2020, "cost": 2843000000.0 }, { "year": 2021, "cost": 3594000000.0 }, { "year": 2022, "cost": 3594000000.0 }, { "year": 2023, "cost": 4416400000.0 }, { "year": 2024, "cost": 4188500000.0 } ] }, { "id": "bsuos", "label": "Balancing costs (BSUoS uplift)", "perspectives": [], "cadence": "daily", "layer": "indirect", "attribution_pct": 0.5930491024217076, "attribution_note": "Raw totals stored; attribution happens in the money model. Only the increase above the CPIH-indexed 2002-05 baseline (GBP 0.4bn/yr) is attributed, NET of wind constraint payments already counted in the direct layer, floored at zero.", "attribution_confidence": "low", "cumulative": 22848565648.3635, "runrate_per_year": 3406360913.2197866, "data_to": "2026-09-12", "raw_annual": [ { "year": 2002, "cost": 400000000.0 }, { "year": 2003, "cost": 400000000.0 }, { "year": 2004, "cost": 400000000.0 }, { "year": 2005, "cost": 642000000.0 }, { "year": 2006, "cost": 700000000.0 }, { "year": 2007, "cost": 700000000.0 }, { "year": 2008, "cost": 1000000000.0 }, { "year": 2009, "cost": 800000000.0 }, { "year": 2010, "cost": 700000000.0 }, { "year": 2011, "cost": 861500000.0 }, { "year": 2012, "cost": 861500000.0 }, { "year": 2013, "cost": 1002000000.0 }, { "year": 2014, "cost": 1000000000.0 }, { "year": 2015, "cost": 1100000000.0 }, { "year": 2016, "cost": 1200000000.0 }, { "year": 2017, "cost": 1238377287.45 }, { "year": 2018, "cost": 1305499730.77 }, { "year": 2019, "cost": 1487556555.39 }, { "year": 2020, "cost": 2004658460.17 }, { "year": 2021, "cost": 2970277561.79 }, { "year": 2022, "cost": 4577543822.51 }, { "year": 2023, "cost": 3258662770.01 }, { "year": 2024, "cost": 3038529128.0 }, { "year": 2025, "cost": 3715943392.71217 }, { "year": 2026, "cost": 3163225938.5444 } ], "source": "2005, 2011-2013: NAO \"Electricity Balancing Services\" (May 2014, HC 41, from Ofgem/National Grid data): total balancing costs recovered through BSUoS GBP 642m in 2005-06 rising to GBP 1,002m in 2013-14; 2011-12 plus 2012-13 expenditure totalled GBP 1,723m (split evenly here, the lower of NAO and REF figures). 2002-2004: GBP 0.4bn/yr per the verified 2002-05 baseline (reference/baselines.yaml). 2006-2010 and 2014-2016: REF April 2025 study Table 2 total-charge column, pending confirmation against National Grid Monthly Balancing Services Summary archives.", "source_url": "https://www.nao.org.uk/wp-content/uploads/2014/05/Electricity-Balancing-Services.pdf", "verified": false } ] }