{
  "asOf": "2026-10-07",
  "records": [
    {
      "id": "alabama-power",
      "states": [
        "Alabama"
      ],
      "name": "Alabama Power",
      "type": "Investor-owned utility",
      "status": "Published tariff",
      "document": "LPL",
      "size": "General industrial; billing floor 1,200 kVA. Negotiated terms possible above 30,000 kVA.",
      "service": "",
      "upfront": "",
      "minimum": "Greatest of actual, seasonal ratchet, 75% contract capacity or 1,200 kVA.",
      "term": "At least 5 years for new customers.",
      "security": "",
      "gaps": "January 2025 price components are not a current all-in quote.",
      "source": "https://www.alabamapower.com/content/dam/alabama-power/pdfs-docs/Rates/lpl.pdf"
    },
    {
      "id": "srp",
      "states": [
        "Arizona"
      ],
      "name": "Salt River Project (SRP)",
      "type": "Public power",
      "status": "Approved framework",
      "document": "E-67 / large customer integration",
      "size": "New accounts with at least 20 MW forecast load.",
      "service": "",
      "upfront": "Customer-specific upgrades paid upfront.",
      "minimum": "Greater of actual demand or 80% forecast.",
      "term": "",
      "security": "",
      "gaps": "Utility explanation of approved 2025 plan. Confirm account eligibility and executed agreement.",
      "source": "https://www.srpnet.com/about/data-center-facts"
    },
    {
      "id": "entergy-ar",
      "states": [
        "Arkansas"
      ],
      "name": "Entergy Arkansas",
      "type": "Investor-owned utility",
      "status": "Contract policy",
      "document": "Industrial tariffs and project agreements",
      "size": "Project-specific; general LPS and PST schedules exist.",
      "service": "",
      "upfront": "",
      "minimum": "",
      "term": "",
      "security": "",
      "gaps": "Cryptocurrency/mobile-load interruptible LPHLDS is not a generic hyperscale tariff. Proposed project deals are not statewide terms.",
      "source": "https://www.entergyarkansas.com/business/tariffs"
    },
    {
      "id": "georgia-power",
      "states": [
        "Georgia"
      ],
      "name": "Georgia Power",
      "type": "Investor-owned utility",
      "status": "Approved framework",
      "document": "PSC large-load contract rule",
      "size": "New customers above 100 MW.",
      "service": "",
      "upfront": "Generation, transmission and distribution cost recovery.",
      "minimum": "Minimum billing permitted; no universal percentage established.",
      "term": "Terms up to 15 years permitted, not a universal minimum.",
      "security": "",
      "gaps": "January 23, 2025 enabling rule. Obtain PSC-reviewed project contract.",
      "source": "https://psc.ga.gov/site/assets/files/8617/media_advisory_data_centers_rule_1-23-2025.pdf"
    },
    {
      "id": "comed",
      "states": [
        "Illinois"
      ],
      "name": "ComEd",
      "type": "Investor-owned utility",
      "status": "Verification gap",
      "document": "Large-demand retail proceeding / accepted Equinix TSA",
      "size": "June 2025 filing proposed at least 50 MW within 10 years; final retail threshold remains unverified.",
      "service": "",
      "upfront": "",
      "minimum": "",
      "term": "",
      "security": "FERC accepted the customer-specific Equinix TSA on March 10, 2026. Ramped transmission payments continue for delayed/cancelled projects, or a termination fee applies; not a universal retail price.",
      "gaps": "ICC docket lists March 19 final order, March 30 compliance filing and June appeal. Final retail sheets, deposits, TSA scope and current appeal outcome remain unverified. Do not use proposed terms as final requirements.",
      "source": "https://icc.illinois.gov/docket/P2025-0677/docket-sheet",
      "reviewedAt": "2026-10-09",
      "additionalSources": [
        {
          "label": "FERC: accepted Equinix TSA, ER26-989",
          "url": "https://www.ferc.gov/news-events/news/commissioner-changs-concurrence-order-accepting-transmission-security-agreement-re"
        }
      ]
    },
    {
      "id": "im",
      "states": [
        "Indiana"
      ],
      "name": "Indiana Michigan Power",
      "type": "Investor-owned utility",
      "status": "Approved framework",
      "document": "Large-load framework",
      "size": "70 MW individually or 150 MW aggregate.",
      "service": "",
      "upfront": "",
      "minimum": "Take-or-pay; exact demand percentage not verified.",
      "term": "At least 12 years; tariff index indicates ramp up to 5 years before initial term.",
      "security": "Financial guarantees; amount needs verification.",
      "gaps": "Utility confirms approved framework. Full tariff book could not be reopened.",
      "source": "https://www.indianamichiganpower.com/cp/lower-rates/"
    },
    {
      "id": "ku",
      "states": [
        "Kentucky"
      ],
      "name": "Kentucky Utilities",
      "type": "Investor-owned utility",
      "status": "Published tariff",
      "document": "EHLF",
      "size": "New customers above 50 MVA AND above 85% expected average monthly load factor.",
      "service": "",
      "upfront": "",
      "minimum": "Greatest of current peak, prior 11-month peak or 80% contract capacity.",
      "term": "At least 15 years.",
      "security": "Starts at 24 months of minimum bills, with credit/cash exceptions.",
      "gaps": "Effective February 16, 2026. MVA is not MW. Do not apply KU prices to LG&E.",
      "source": "https://psc.ky.gov/tariffs/electric/Kentucky%20Utilities%20Company/Tariff.pdf"
    },
    {
      "id": "entergy-la",
      "states": [
        "Louisiana"
      ],
      "name": "Entergy Louisiana",
      "type": "Investor-owned utility",
      "status": "Published tariff",
      "document": "LLHLFPS-L",
      "size": "At least 70 MW firm load; at least 80% average monthly load factor; at least 69 kV; one delivery point.",
      "service": "Firm",
      "upfront": "",
      "minimum": "Block-based demand charges and minimum bill; riders add costs.",
      "term": "",
      "security": "",
      "gaps": "Confirm service-area eligibility and ESA terms; no all-in quote established.",
      "source": "https://www.entergylouisiana.com/wp-content/uploads/ell_elec_llhlfps-l.pdf"
    },
    {
      "id": "entergy-ms",
      "states": [
        "Mississippi"
      ],
      "name": "Entergy Mississippi",
      "type": "Investor-owned utility",
      "status": "Contract policy",
      "document": "Data-center service agreements",
      "size": "Project-specific; universal threshold not established.",
      "service": "",
      "upfront": "Customer pays direct service costs under reviewed agreements.",
      "minimum": "",
      "term": "",
      "security": "",
      "gaps": "Company-wide explanation requires Mississippi project confirmation. Mississippi Power and TVA service are separate.",
      "source": "https://www.entergy.com/datacenters/facts"
    },
    {
      "id": "nv-energy",
      "states": [
        "Nevada"
      ],
      "name": "NV Energy",
      "type": "Investor-owned utility",
      "status": "Proposed",
      "document": "LLESA framework",
      "size": "Typically above 25 MW with new generation/transmission needs; proposed scope.",
      "service": "",
      "upfront": "Proposed upfront infrastructure recovery.",
      "minimum": "Proposed minimum payments; formula not established.",
      "term": "Proposed long-term commitment; years not verified.",
      "security": "Proposed guarantees and termination protection.",
      "gaps": "June 2026 proposal; each agreement requires PUCN approval. Do not treat as effective terms.",
      "source": "https://www.nvenergy.com/publish/content/dam/nvenergy/brochures_arch/help/brochures/Large-Load-Electric-Service-Agreement-LLESA-Fact-Sheet.pdf"
    },
    {
      "id": "duke-nc",
      "states": [
        "North Carolina"
      ],
      "name": "Duke Energy",
      "type": "Investor-owned utility",
      "status": "Proposed",
      "document": "High Load Factor settlement",
      "size": "Proposed: at least 50 MW and 80% load factor; ESAs after June 1, 2026.",
      "service": "",
      "upfront": "Proposed nonrefundable dedicated facilities costs.",
      "minimum": "",
      "term": "",
      "security": "Proposed deposits/security for shared upgrades.",
      "gaps": "October 7, 2026 announcement pending NCUC approval; exact filed settlement terms need confirmation.",
      "source": "https://news.duke-energy.com/releases/duke-energy-protects-customers-from-data-center-costs"
    },
    {
      "id": "aep-ohio",
      "states": [
        "Ohio"
      ],
      "name": "AEP Ohio (Ohio Power)",
      "type": "Investor-owned utility",
      "status": "Published tariff",
      "document": "DCT",
      "size": "Minimum-demand table starts at 25,001 kW; affiliate aggregation. Studies start at 25,000 kW.",
      "service": "",
      "upfront": "",
      "minimum": "Tiered contract-capacity formula plus prior-demand ratchet; not a flat 85% bill.",
      "term": "8 years plus ramp up to 4 years.",
      "security": "Conditional collateral: 50% of full-term minimum charges; exit provisions apply.",
      "gaps": "Effective July 23, 2025. Confirm aggregation and applicable demand tier.",
      "source": "https://www.aepohio.com/company/about/rates/data-center-tariff/"
    },
    {
      "id": "oge",
      "states": [
        "Oklahoma"
      ],
      "name": "OG&E",
      "type": "Investor-owned utility",
      "status": "Proposed",
      "document": "Large-load tariff",
      "size": "Threshold not established in reopened evidence.",
      "service": "",
      "upfront": "",
      "minimum": "",
      "term": "Indexed proposal: 15 years plus ramp up to 5 years; full terms need verification.",
      "security": "",
      "gaps": "September 30 status says proposed. Conflicting hearing dates remain unresolved; no approved minimum percentage.",
      "source": "https://www.oge.com/web/portal/hidden/article/rate-review"
    },
    {
      "id": "ppl",
      "states": [
        "Pennsylvania"
      ],
      "name": "PPL Electric",
      "type": "Investor-owned utility",
      "status": "Published tariff",
      "document": "LP-6, effective July 1, 2026",
      "size": "Service began on/after October 1, 2025; at least 69 kV; 50 MW at one facility or 75 MW aggregated within 10 miles. A 50-75 MW facility without network upgrade costs may qualify for LP-5 only with PUC approval.",
      "service": "Firm",
      "upfront": "Directly assigned transmission/distribution upgrades funded through construction contributions paid before work milestones.",
      "minimum": "Monthly distribution minimum $999.11; supply, transmission and riders additional. ESA uses greater of actual peak or 80% of ramp load until the Rate Base Security Obligation is satisfied. After satisfaction: 80% in first five years, 50% in second five years.",
      "term": "ESA at least 10 years, with a load ramp schedule. Initial ramp provisions reference five years but permit a schedule up to the ESA initial term.",
      "security": "Security covers attributable upgrades recovered through transmission rates. Exit fee is greater of remaining minimum-load guarantee or remaining Rate Base Security Obligation.",
      "gaps": "Voluntary interruptible option reduces minimum-load guarantees to 60%/30% for the first/second five years; confirm its interaction with security in the ESA. Supply, TSC, riders, actual upgrade costs and load-shedding arrangements require site review. September 2026 transmission rider proposal is separate from this final LP-6.",
      "source": "https://www.pplelectric.com/site/-/media/PPLElectric/At-Your-Service/Docs/Current-Electric-Tariff/2026/August/LP-6---Large-Load-Interconnections.pdf",
      "reviewedAt": "2026-10-09",
      "additionalSources": [
        {
          "label": "Current tariff index",
          "url": "https://www.pplelectric.com/site/More/About-Us/Electric-Rates-and-Rules/Current-Electric-Tariff/Table-of-Contents"
        },
        {
          "label": "Separate proposed transmission rider",
          "url": "https://investors.pplweb.com/2026-09-14-PPL-Electric-Proposes-New-Customer-Protection-Transmission-Rider,-Building-on-its-Existing-Customer-Protection-Framework"
        }
      ]
    },
    {
      "id": "santee",
      "states": [
        "South Carolina"
      ],
      "name": "Santee Cooper",
      "type": "Public power",
      "status": "Approved framework",
      "document": "L-25-LL",
      "size": "Index says data centers above 50 MW or mobile loads above 1 MW; exact boundary needs confirmation.",
      "service": "",
      "upfront": "",
      "minimum": "Special minimum demand and incremental demand charges.",
      "term": "",
      "security": "Collateral required; details need verification.",
      "gaps": "Approved April 2025; presentation lists April 24, 2029 expiration. Exact contract years not reconfirmed.",
      "source": "https://www.santeecooper.com/rates/"
    },
    {
      "id": "tva",
      "states": [
        "Tennessee"
      ],
      "name": "TVA wholesale network",
      "type": "Wholesale network",
      "status": "Approved framework",
      "document": "August 20, 2026 approved rate resolution",
      "size": "Qualifying data-center load above 5 MW enters Schedule DC; optional DCA covers above 1 through 5 MW. Identify local retail distributor.",
      "service": "",
      "upfront": "First FY2027 cohort, up to 2,000 MW: $1.521 million/MW, nonrefundable. For new requests, charge applies above first 5 MW. Existing/inflight rules and expansion waivers affect applicability; TVA sets payment terms.",
      "minimum": "Separate retail schedule and riders apply; the capacity commitment payment is additional.",
      "term": "",
      "security": "",
      "gaps": "Resolution verified, but final CCC rider exhibits and site agreement still needed. Cohort-specific interruption requirements and Firm Generation Date are set by TVA. Confirm eligibility, exemptions, cohort availability and payment schedule. MLGW is one retail implementation.",
      "source": "https://tva-azr-eastus-cdn-ep-tvawcm-prd.azureedge.net/cdn-tvawcma/docs/default-source/about-tva/board-of-directors/august-20--2026/resolutions/board-resolution---rate-change-and-related-actions---stamped-(1).pdf?sfvrsn=fefcb72d_1",
      "reviewedAt": "2026-10-09",
      "additionalSources": [
        {
          "label": "TVA approved resolutions index",
          "url": "https://www.tva.com/about-tva/our-leadership/board-of-directors/approved-resolutions"
        }
      ]
    },
    {
      "id": "oncor",
      "states": [
        "Texas"
      ],
      "name": "Oncor",
      "type": "Investor-owned utility",
      "status": "Published tariff",
      "document": "Transmission-voltage delivery",
      "size": "Delivery-voltage class; retail energy supply contracted separately.",
      "service": "",
      "upfront": "",
      "minimum": "4CP transmission billing and 80% prior-11-month actual-demand ratchet for distribution component.",
      "term": "",
      "security": "",
      "gaps": "Delivery tariff only. Retail supply, ERCOT requirements and site capacity are separate.",
      "source": "https://www.oncor.com/content/dam/oncorwww/documents/about-us/regulatory/tariff-and-rate-schedules/Tariff%20for%20Retail%20Delivery%20Service_.pdf.coredownload.pdf"
    },
    {
      "id": "rmp",
      "states": [
        "Utah"
      ],
      "name": "Rocky Mountain Power",
      "type": "Investor-owned utility",
      "status": "Verification gap",
      "document": "Large-load special contracts",
      "size": "Indexed statute: requests reaching 100 MW within 5 years; confirm applicable definition.",
      "service": "",
      "upfront": "",
      "minimum": "",
      "term": "",
      "security": "",
      "gaps": "Utility confirms special-contract path. Docket/statute direct retrieval failed; universal price and term not established.",
      "source": "https://www.rockymountainpower.net/about/newsroom/news-releases/utah-operation-gigawatt.html"
    },
    {
      "id": "dominion",
      "states": [
        "Virginia"
      ],
      "name": "Dominion Energy Virginia",
      "type": "Investor-owned utility",
      "status": "Approved future",
      "document": "GS-5",
      "size": "At least 25 MW and 75% load factor.",
      "service": "",
      "upfront": "",
      "minimum": "Qualifying new ESAs: 85% transmission/distribution and 60% generation minimums.",
      "term": "14 years including optional ramp up to 4 years for qualifying new ESAs.",
      "security": "Collateral conditions apply; existing contracts differ.",
      "gaps": "Approved for January 1, 2027. Not effective at the October 7, 2026 evidence date.",
      "source": "https://www.scc.virginia.gov/docketsearch/DOCS/89g601%21.PDF"
    },
    {
      "id": "we-energies",
      "states": [
        "Wisconsin"
      ],
      "name": "We Energies",
      "type": "Investor-owned utility",
      "status": "Approved framework",
      "document": "Very Large Customer / Bespoke Resources",
      "size": "100 MW threshold in PSC decision summary.",
      "service": "",
      "upfront": "Full-benefits resource model requires 100% of associated costs.",
      "minimum": "",
      "term": "At least 15 years.",
      "security": "",
      "gaps": "April 24, 2026 approval with modifications. Final prices and detailed collateral require filed rate sheets.",
      "source": "https://psc.wi.gov/Documents/PressReleases/04.24.2026PressRelease.PDF"
    },
    {
      "id": "novec",
      "states": [
        "Virginia"
      ],
      "name": "NOVEC HV-1",
      "type": "Retail co-op",
      "status": "Published tariff",
      "document": "HV-1",
      "size": "At least 5 MW new/separately metered additional load; annual load factor at least 70%; voltage conditions apply.",
      "service": "",
      "upfront": "Primary distribution investment and excess facilities can require contributions.",
      "minimum": "Greatest of monthly 30-minute peak, 5 MW or contract minimum.",
      "term": "Negotiated to recover investment; ESA normally effective 12 months before service.",
      "security": "",
      "gaps": "HV-1 effective April 1, 2023. Standard, market or qualifying third-party supply. See separate NOVEC HV-2 entry for dedicated-facilities contract service; exact ESA and capacity remain site-specific.",
      "source": "https://www.novec.com/About_NOVEC/upload/Large-Power-Dedicated-Distribution-Service-HV-1-3-22-23.pdf"
    },
    {
      "id": "rec",
      "states": [
        "Virginia"
      ],
      "name": "Rappahannock Electric Cooperative",
      "type": "Retail co-op",
      "status": "Published tariff",
      "document": "LP-DF",
      "size": "Above 25 MW; annual load factor at least 75%; dedicated facilities, at least 34.5 kV delivery from qualifying 115 kV source.",
      "service": "",
      "upfront": "Additional facilities may require upfront contribution plus recurring charges.",
      "minimum": "Agreement-specific distribution minimum; supply obligations are separate.",
      "term": "Negotiated; ESA normally effective 12 months before service.",
      "security": "Distribution and supply collateral set by agreement; attributable supply costs can survive exit.",
      "gaps": "Effective April 15, 2026. Excludes standby, supplemental, self-generation, net-metering and resale service.",
      "source": "https://www.myrec.coop/sites/default/files/documents/SCC%20Compliance%20Filing%20Acceptance_Sch%20LP-DF.pdf"
    },
    {
      "id": "ekpc",
      "states": [
        "Kentucky"
      ],
      "name": "East Kentucky Power Cooperative",
      "type": "Wholesale network",
      "status": "Approved framework",
      "document": "DCP / retail member agreements",
      "size": "At least 15 MW maximum capacity and operation at 60% or more of capacity.",
      "service": "",
      "upfront": "Capital upfront; study fee up to $250,000 plus excess study cost. Dedicated resource at 250 MW or more.",
      "minimum": "Operating costs prepaid on a rolling basis.",
      "term": "Three-party contract requires PSC approval; years not verified.",
      "security": "Prepaid operating account; other security needs contract review.",
      "gaps": "Utility explanation of approved tariff. Full filed DCP and retail delivery terms remain gaps.",
      "source": "https://www.ekpc.coop/data-centers"
    },
    {
      "id": "mlgw",
      "states": [
        "Tennessee"
      ],
      "name": "Memphis Light, Gas and Water",
      "type": "Municipal utility",
      "status": "Published tariff",
      "document": "TDC / TVA supply",
      "size": "Classes above 1 through 5 MW, above 5 through 15, above 15 through 25, and above 25 MW; qualifying use required.",
      "service": "Firm",
      "upfront": "",
      "minimum": "Tiered demand floors and minimum energy provisions; fuel/other adjustments and voltage charges apply.",
      "term": "At least 1 year for TDCA; at least 5 years for TDCB/C/D.",
      "security": "",
      "gaps": "Effective October 1, 2026. Separate TVA wholesale capacity-charge question unresolved; other distributors may differ.",
      "source": "https://www.mlgw.com/images/content/files/pdf_rates/businessrates26/TDCOct26.pdf"
    },
    {
      "id": "pec",
      "states": [
        "Texas"
      ],
      "name": "Pedernales Electric Cooperative",
      "type": "Retail co-op",
      "status": "Published tariff",
      "document": "Large Power / Transmission Level",
      "size": "Large power: 50 kW rolling average demand. Transmission service: at least 60 kV.",
      "service": "",
      "upfront": "",
      "minimum": "Transmission class: $1,000 monthly service charge, 4CP transmission and wholesale supply pass-through; not an all-in price.",
      "term": "",
      "security": "",
      "gaps": "October 1, 2026 tariff. Industrial Power section 500.5 is closed to new applicants. Exact project agreement and upgrades unverified.",
      "source": "https://mypec.com/wp-content/uploads/tariff/Tariff_and_Business_Rules.pdf"
    },
    {
      "id": "bluebonnet",
      "states": [
        "Texas"
      ],
      "name": "Bluebonnet Electric Cooperative",
      "type": "Retail co-op",
      "status": "Published tariff",
      "document": "Key Account schedules",
      "size": "Eligibility text says at least 1 MW; headings say above 1 MW. Distribution, substation and transmission versions.",
      "service": "",
      "upfront": "",
      "minimum": "Greatest of 30-minute peak, 1 MW or contract demand. Wholesale supply and applicable adjustments add costs.",
      "term": "",
      "security": "",
      "gaps": "Currently linked compilation retains 2017-2019 sheet dates. Confirm exact 1 MW boundary, supplier conditions and project contract.",
      "source": "https://www.bluebonnet.coop/sites/default/files/documents/tariffs-and-bylaws/Tariff-Section-II_01-07-2025.pdf"
    },
    {
      "id": "austin",
      "states": [
        "Texas"
      ],
      "name": "Austin Energy",
      "type": "Municipal utility",
      "status": "Published tariff",
      "document": "High Load Factor schedules",
      "size": "Primary: 3 to below 20 MW or at least 20 MW; annual average monthly load factor at least 85%. Transmission: at least 20 MW and 69 kV.",
      "service": "",
      "upfront": "",
      "minimum": "Primary 3-to-below-20 MW class: preceding 12-month highest billed kW times demand charge, plus power supply adjustment.",
      "term": "Multi-year sole-supplier contract; base rates fixed, not every bill component.",
      "security": "",
      "gaps": "Effective October 1, 2026. General industrial schedules; other class-specific minimums and exact term need review.",
      "source": "https://austinenergy.com/en/rates/approved-rates-schedules"
    },
    {
      "id": "greystone",
      "states": [
        "Georgia"
      ],
      "name": "GreyStone Power",
      "type": "Retail co-op",
      "status": "Contract policy",
      "document": "Data-center agreements",
      "size": "Project-specific; universal threshold not verified.",
      "service": "",
      "upfront": "Dedicated substations paid in full before construction; milestone deposits.",
      "minimum": "Market supply agreement can require fixed minimum payments even if facility is not online at start.",
      "term": "Negotiated; universal term not verified.",
      "security": "Performance assurance and termination payments for supply commitments.",
      "gaps": "January 2026 executive interview, not a published rate sheet. Delivery and supply agreements both matter.",
      "source": "https://www.greystonepower.com/setting-strategy-powering-data-centers-while-safeguarding-co-op-members"
    },
    {
      "id": "walton",
      "states": [
        "Georgia"
      ],
      "name": "Walton EMC",
      "type": "Retail co-op",
      "status": "Contract policy",
      "document": "Case-by-case data-center service",
      "size": "Project-specific; universal threshold not verified.",
      "service": "",
      "upfront": "Required transmission/substation upgrades and other service costs assigned to customer.",
      "minimum": "",
      "term": "",
      "security": "",
      "gaps": "Utility explanation confirms project selection case by case. Public price, term, security and minimum bill not established.",
      "source": "https://www.waltonemc.com/realite-newsletter/benefitting-from-the-boom/"
    },
    {
      "id": "hoosier",
      "states": [
        "Indiana",
        "Illinois"
      ],
      "name": "Hoosier Energy member network",
      "type": "Wholesale network",
      "status": "Contract policy",
      "document": "Consumer Directed Resource Policy",
      "size": "Loads above 50 MW; identify serving retail member.",
      "service": "",
      "upfront": "Customer pays studies, transmission and capacity costs, and prepays obligations.",
      "minimum": "Energy invoiced every 7 days with prepayments.",
      "term": "",
      "security": "Customer procures capacity; robust prepayments, exact security unverified.",
      "gaps": "May 2026 policy explanation. Outside traditional Hoosier tariffs; member delivery prices require separate review.",
      "source": "https://hoosierenergy.com/news-resources/data-centers-affordability-in-focus-at-annual-meeting/"
    },
    {
      "id": "oec",
      "states": [
        "Oklahoma"
      ],
      "name": "Oklahoma Electric Cooperative",
      "type": "Retail co-op",
      "status": "Contract policy",
      "document": "Interruptible data-center service / WFEC supply",
      "size": "Public rate page directs accounts at 1,000 kVA and above to a key-account specialist. This is a contact threshold, not a verified data-center eligibility rule.",
      "service": "Interruptible",
      "upfront": "",
      "minimum": "Must reduce operations during monthly system peak; substantial penalties if not reduced.",
      "term": "",
      "security": "",
      "gaps": "No public large-account contract verified. Curtailment duration, notice, penalty formula, backup requirements, term, security and price require the actual contract. Smaller commercial schedules are not a substitute.",
      "source": "https://okcoop.org/behind-the-servers-oec-news/",
      "reviewedAt": "2026-10-09",
      "additionalSources": [
        {
          "label": "OEC public rates and large-account contact path",
          "url": "https://okcoop.org/rates/"
        }
      ]
    },
    {
      "id": "trico",
      "states": [
        "Arizona"
      ],
      "name": "Trico Electric Cooperative",
      "type": "Retail co-op",
      "status": "Contract policy",
      "document": "Large data-center framework",
      "size": "Universal MW threshold not verified.",
      "service": "",
      "upfront": "100% upfront distribution/transmission costs and studies; generation costs directly assigned.",
      "minimum": "",
      "term": "",
      "security": "",
      "gaps": "January 2026 utility explanation, not a filed price schedule. Term, minimum bill and collateral remain unverified.",
      "source": "https://trico.coop/data-centers-a-strategic-opportunity-for-trico-members/"
    },
    {
      "id": "cps",
      "states": [
        "Texas"
      ],
      "name": "CPS Energy",
      "type": "Municipal utility",
      "status": "Interconnection process",
      "document": "Large-load studies",
      "size": "FAQ: aggregate at least 40 MW across common-development delivery points.",
      "service": "",
      "upfront": "Table: $75,000 study at 40 to below 75 MW; at least 75 MW: $75,000 screening and $150,000 LLIS per connection point. ERCOT fees extra.",
      "minimum": "",
      "term": "",
      "security": "",
      "gaps": "Study fees are not construction or energy prices. Prose/table differ at boundaries; confirm exactly 75 MW. Capacity/timing require studies.",
      "source": "https://www.cpsenergy.com/en/construction-and-renovation/large-load-customer-growth.html"
    },
    {
      "id": "denton",
      "states": [
        "Texas"
      ],
      "name": "Denton Municipal Electric",
      "type": "Municipal utility",
      "status": "Project example",
      "document": "Core Scientific amended agreement",
      "size": "Approximately 394 MW potential utility load in named project, not an eligibility threshold.",
      "service": "",
      "upfront": "",
      "minimum": "",
      "term": "Named agreement: 14 years plus two 7-year extensions.",
      "security": "",
      "gaps": "Retained SEC agreement evidence, not freshly fetched. Not an offer to other customers or a claim of available capacity.",
      "source": "https://www.sec.gov/Archives/edgar/data/1839341/000119312526165121/d149019dex992.htm"
    },
    {
      "id": "novec-hv2",
      "states": [
        "Virginia"
      ],
      "name": "NOVEC HV-2",
      "type": "Retail co-op",
      "status": "Published tariff",
      "document": "HV-2, effective April 1, 2023",
      "size": "Minimum contract billing demand 65 MW; alternatively at least 45 MW with delivery at least 34.5 kV through specified dedicated facilities sourced from 230 kV. Average annual load factor at least 85%. No backup/standby service.",
      "service": "",
      "upfront": "Excess facilities require a one-time construction contribution plus monthly charges on contributed investment: 0.442% high-voltage line, 0.644% substation, 0.893% primary distribution.",
      "minimum": "Distribution billing demand: greater of 30-minute monthly peak or contract minimum times ramp percentage. Distribution billing energy: greater of actual kWh or billing kW x month hours x 85%. Distribution minimum is contract amount plus excess-facilities charge.",
      "term": "Negotiated to recover investment, maintenance and operations. ESA normally effective at least 12 months before desired service.",
      "security": "",
      "gaps": "All supply purchased from NOVEC at a case-specific market rate. Published distribution charges: $1,420.23/month, $0.793/kW, $0.16/rKVA and $0.000337/kWh. These exclude supply and do not establish an all-in price. Confirm ESA ramp, collateral, service type and available capacity.",
      "source": "https://www.novec.com/About_NOVEC/upload/Large-Power-Dedicated-Facilities-Contract-Service-HV-2-3-22-23.pdf",
      "reviewedAt": "2026-10-09",
      "additionalSources": [
        {
          "label": "NOVEC current regulated-rate index",
          "url": "https://www.novec.com/About_NOVEC/Regulated-Rates.cfm"
        }
      ]
    }
  ]
}