{
"as_of": "2026-11-10",
"slug": "dcpi",
"note_zh": "大负荷费率条款台账。只登记「监管机构已批准/已生效的大负荷（数据中心）费率或特殊合约」，逐条给案件号与原文链接。价格公开度分四级：full=官方价单可逐条核验；partial=部分组件公开（如仅需量单价）；formula=按保密模型逐单定价；confidential=合约价保密。价格单元格（price_cells）只收 full 级。",
"note_en": "Register of large-load (data center) tariff terms. Only tariffs or special contracts approved/effective by a regulator are recorded, each with a case number and a source link. Price disclosure has four levels: full = official rate sheet verifiable line by line; partial = some components public (e.g. demand charges only); formula = priced per customer from a trade-secret model; confidential = contract price redacted. Price cells (price_cells) accept only the full level.",
"method": {
"load_factor": 0.8,
"hours_per_month": 730,
"summer_months": 4,
"winter_months": 8,
"formula_zh": "有效电价 $/MWh = 能量单价(¢/kWh)×10 + 需量单价($/kW·月) ÷ (负荷率 × 730h) × 1000；夏季 4 个月、冬季 8 个月按月加权得全年值",
"formula_en": "Effective $/MWh = energy ¢/kWh × 10 + demand $/kW-mo ÷ (load factor × 730h) × 1000; annual value weights 4 summer and 8 winter months",
"excludes_zh": "不含各项附加费（燃料调整、能效、可再生能源附加）、无功电费、客户费与税费——实际账单 all-in 更高",
"excludes_en": "Excludes riders (fuel adjustment, efficiency, RES), reactive charges, customer charges and taxes — actual all-in bills are higher",
"publication_threshold": 5,
"threshold_note_zh": "读数发布门槛：5 个 full 级价格单元格（2026-11-11 凑满 5 个首期发布；2026-11-12 增至 6 个，读数仍按全格中位数现算）。",
"threshold_note_en": "Reading threshold: 5 full-level price cells (met 2026-11-11; a sixth was added 2026-11-12 and the reading is recomputed as the median of all cells).",
"reading_rule_zh": "首期读数 = 全部 full 级价格单元格「全年有效价」的未加权中位数。不加权的原因：各单元格无自然权重（无成交量），且中位数对单格异常稳健。规则于凑满 5 格当日（2026-11-11）先行注册，读数由规则导出，不由结果反推。",
"reading_rule_en": "Issue-1 reading = the unweighted median of the annual effective prices of all full-level price cells. Unweighted because cells carry no natural weights (no volumes), and the median is robust to any single-cell anomaly. The rule was registered on the day the fifth cell was met (2026-11-11); the reading follows from the rule, never the reverse."
},
"terms": [
{
"state": "Missouri",
"utility": "Ameren Missouri (Union Electric)",
"tariff": "11(M) Large Primary / Large Load Customer Service",
"docket_zh": "MoPSC ET-2025-0184（费率本体：ER-2024-0319）",
"docket_en": "MoPSC ET-2025-0184 (rate itself: ER-2024-0319)",
"approved": "2025-11-24",
"effective_zh": "2025-06-01（费率）",
"effective_en": "2025-06-01 (rate)",
"threshold_zh": "≥75 MW（LLCS）；11(M) 计费需量 ≥5,000 kW",
"threshold_en": ">=75 MW (LLCS); 11(M) billing demand >=5,000 kW",
"min_demand_zh": "合约容量的 80%",
"min_demand_en": "80% of contract capacity",
"term_zh": "爬坡后 12 年，自动顺延 5 年",
"term_en": "12 years after ramp, auto-extend 5 years",
"price_disclosure": "full",
"verified": "primary",
"source_url": "https://www.ameren.com/-/media/rates/missouri/non-residential/electric-rates/rates/uecsheet61rate11mlps.ashx",
"source_label_zh": "Mo.P.S.C. Schedule No. 6 Sheet No. 61（官方价单原文）",
"source_label_en": "Mo.P.S.C. Schedule No. 6 Sheet No. 61 (official rate sheet)"
},
{
"state": "Virginia",
"utility": "Dominion Energy Virginia",
"tariff": "GS-5 Large General Service",
"docket_zh": "SCC PUR-2025-00058（价单受理：DCC 261030057，2026-10-14）",
"docket_en": "SCC PUR-2025-00058 (rate sheets accepted: DCC 261030057, 2026-10-14)",
"approved": "2025-11-25 (final order)",
"effective_zh": "2027-01-01",
"effective_en": "2027-01-01",
"threshold_zh": "≥25 MW 且负荷率 ≥75%",
"threshold_en": ">=25 MW and load factor >=75%",
"min_demand_zh": "输配 85% / 发电 60%（按合约容量）",
"min_demand_en": "85% T&D / 60% generation of contracted capacity",
"term_zh": "14 年（含爬坡）",
"term_en": "14 years incl. ramp",
"price_disclosure": "partial",
"verified": "secondary",
"source_url": "https://axis-intelligence.com/?p=38714",
"source_label_zh": "Axis Intelligence 转引 GS-5 价单（需量组件齐全，能量单价待核原文）",
"source_label_en": "Axis Intelligence quoting GS-5 sheets (demand components public; energy charge unverified)"
},
{
"state": "Ohio",
"utility": "AEP Ohio",
"tariff": "Schedule DCT (Data Center Tariff)",
"docket_zh": "PUCO 24-508-EL-ATA",
"docket_en": "PUCO 24-508-EL-ATA",
"approved": "2025-07-09",
"effective_zh": "2025-07-23",
"effective_en": "2025-07-23",
"threshold_zh": ">25 MW（新负荷，关联方合并计算）",
"threshold_en": ">25 MW new load (affiliates aggregated)",
"min_demand_zh": "合约容量的 85%",
"min_demand_en": "85% of contract capacity",
"term_zh": "12 年（含 4 年爬坡）",
"term_en": "12 years incl. 4-year ramp",
"price_disclosure": "none",
"verified": "primary",
"source_url": "https://aep.com/news/stories/view/10326",
"source_label_zh": "AEP 官方公告 + PUCO 裁定（DCT 只定条款，电价按适用标准费率另计）",
"source_label_en": "AEP announcement + PUCO order (DCT sets terms only; energy billed under otherwise-applicable rates)"
},
{
"state": "South Dakota",
"utility": "Otter Tail Power",
"tariff": "10.06 Super Large General Service",
"docket_zh": "SD PUC EL-18-021",
"docket_en": "SD PUC EL-18-021",
"approved": "2019-07-09",
"effective_zh": "2019-08-01",
"effective_en": "2019-08-01",
"threshold_zh": "单计量点 ≥25 MW、负荷率 ≥80%、年电量 ≥175,000 MWh",
"threshold_en": ">=25 MW at a single metering point, load factor >=80%, >=175,000 MWh/year",
"min_demand_zh": "按边际成本模型逐单核定",
"min_demand_en": "set per customer from a marginal-cost model",
"term_zh": "ESA ≥5 年",
"term_en": "ESA >=5 years",
"price_disclosure": "formula",
"verified": "primary",
"source_url": "https://puc.sd.gov/commission/tariffs/Electric/ottertail/section10/6.pdf",
"source_label_zh": "SD PUC 官方费率表原文（费率公式与成交价按商业秘密保密）",
"source_label_en": "SD PUC official rate sheet (rate formula and per-customer price are trade secret)"
},
{
"state": "Minnesota",
"utility": "Xcel Energy (NSPM)",
"tariff": "Very Large General Time of Day Service (Rate Code A97)",
"docket_zh": "MN PUC E002/M-25-289（令 2026-06-12）",
"docket_en": "MN PUC E002/M-25-289 (order 2026-06-12)",
"approved": "2026-06-12",
"effective_zh": "2026-08-01（价单生效）",
"effective_en": "2026-08-01 (rate sheet effective)",
"threshold_zh": "新增需量 ≥100 MW；20–100 MW 若被认定「系统密集」亦强制适用",
"threshold_en": "new demand >=100 MW; 20-100 MW also mandatory if deemed 'system intensive'",
"min_demand_zh": "爬坡容量 / 合约容量的 80%（需量计费下限）",
"min_demand_en": "80% of Load Ramp or Contract Capacity (billing-demand floor)",
"term_zh": "≥15 年（含最长 5 年爬坡）",
"term_en": ">=15 years (including up to 5-year load ramp)",
"price_disclosure": "full",
"verified": "primary",
"source_url": "https://efiling.web.commerce.state.mn.us/documents/%7BE0B9609F-0000-CB12-8AA7-B7163ABE3D94%7D/download",
"source_label_zh": "MN Electric Rate Book MPUC No. 2，第 5 节 Sheet 32.2–32.7（Rate Code A97；终版合规提交 20267-234085-01，2026-07-13）",
"source_label_en": "MN Electric Rate Book MPUC No. 2, Section 5, Sheets 32.2–32.7 (Rate Code A97; final compliance filing 20267-234085-01, 2026-07-13)"
},
{
"state": "Louisiana",
"utility": "Entergy Louisiana (special contract)",
"tariff": "Meta-specific ESA + high-load-factor schedule",
"docket_zh": "LPSC 2025-08 裁定",
"docket_en": "LPSC order, Aug 2025",
"approved": "2025-08",
"effective_zh": "—",
"effective_en": "—",
"threshold_zh": "超大型单客户",
"threshold_en": "very large single customer",
"min_demand_zh": "最低月账单覆盖新机组全年收入需求（无论实际用多少）",
"min_demand_en": "minimum monthly bill covers the full annual revenue requirement of planned generators regardless of usage",
"term_zh": "15 年（自动顺延 5 年）",
"term_en": "15 years (auto-extend 5 years)",
"price_disclosure": "confidential",
"verified": "primary",
"source_url": "https://www.congress.gov/119/meeting/house/119270/documents/HHRG-119-IF03-20260513-SD003.pdf",
"source_label_zh": "美国会能源商务委员会证词（LPSC 裁定要点，价格保密）",
"source_label_en": "US House Energy & Commerce testimony (LPSC order terms; price confidential)"
},
{
"state": "Indiana",
"utility": "Indiana Michigan Power (I&M, AEP)",
"tariff": "Industrial Power (Schedule 150, revised)",
"docket_zh": "IURC Cause No. 46097（终令 2025-02-19）",
"docket_en": "IURC Cause No. 46097 (final order 2025-02-19)",
"approved": "2025-02-19",
"effective_zh": "2025-02-19 起（Tariff I.P. 价单，IURC No. 20 现行版）",
"effective_en": "from 2025-02-19 (Tariff I.P. rate sheet, current IURC No. 20 book)",
"threshold_zh": "单点 ≥70 MW 或聚合 ≥150 MW（新扩负荷）",
"threshold_en": ">=70 MW at one site or >=150 MW aggregated (new/expanded)",
"min_demand_zh": "合约容量的 90%（原 60%）",
"min_demand_en": "90% of contracted capacity (up from 60%)",
"term_zh": "12 年 + 最长 5 年爬坡（合计最长 17 年）",
"term_en": "12 years plus up to 5-year ramp (17 total)",
"price_disclosure": "full",
"verified": "primary",
"source_url": "https://www.indianamichiganpower.com/lib/docs/ratesandtariffs/Indiana/IM_IN_TB_20_09-29-2026.pdf",
"source_label_zh": "I&M 官方 IURC No. 20 价目书原文（Sheet No. 21 起；存档副本 data/dcpi/src/）",
"source_label_en": "I&M official IURC No. 20 tariff book (from Sheet No. 21; archived copy in data/dcpi/src/)"
},
{
"state": "Michigan",
"utility": "Indiana Michigan Power (I&M, AEP)",
"tariff": "Tariff LP (large load, amended)",
"docket_zh": "MPSC Case No. U-21986（2026-08-27 批准）",
"docket_en": "MPSC Case No. U-21986 (approved 2026-08-27)",
"approved": "2026-08-27",
"effective_zh": "费率 2024-07-15 起（U-21461）；U-21986（2026-08-27）修订条款未改价",
"effective_en": "rates from 2024-07-15 (U-21461); U-21986 (2026-08-27) amended terms, not prices",
"threshold_zh": "≥50 MW",
"threshold_en": ">=50 MW",
"min_demand_zh": "最低需量 90% + 最低电量 65%",
"min_demand_en": "90% minimum demand + 65% minimum energy",
"term_zh": "15 年（含最长 5 年爬坡）；降容 >10% 需提前 4 年通知",
"term_en": "15 years (max 5-year ramp); 4 years' notice for >10% reduction",
"price_disclosure": "full",
"verified": "primary",
"source_url": "https://www.michigan.gov/mpsc/-/media/Project/Websites/mpsc/consumer/rate-books/electric/indiana-michigan/IM-18-current-A-B-C-D.pdf",
"source_label_zh": "MPSC 现行价目书 #18 原文（Tariff LP，Sheet D-35/36；存档副本 data/dcpi/src/）",
"source_label_en": "MPSC current rate book #18 (Tariff LP, Sheets D-35/36; archived copy in data/dcpi/src/)"
},
{
"state": "Illinois",
"utility": "Commonwealth Edison (ComEd)",
"tariff": "Extra Large Load Delivery Class (>10,000 kW)",
"docket_zh": "ICC Docket 24-0378（2025-01 价目）",
"docket_en": "ICC Docket 24-0378 (Jan 2025 rates)",
"approved": "2025-01-16",
"effective_zh": "2025-01 账期起",
"effective_en": "Jan 2025 billing period",
"threshold_zh": "最大需量 >10,000 kW",
"threshold_en": ">10,000 kW maximum demand",
"min_demand_zh": "输配按工作日 9–18 时同步需量计费（无 take-or-pay 下限）",
"min_demand_en": "distribution billed on 9am-6pm weekday coincident demand (no take-or-pay floor)",
"term_zh": "无强制长约（零售竞争州，能量按 PJM 小时价另购）",
"term_en": "no mandatory long-term contract (retail choice; energy bought at hourly PJM prices)",
"price_disclosure": "partial",
"verified": "primary",
"source_url": "https://www.comed.com/cdn/assets/v3/assets/blt3ebb3fed6084be2a/blt2a55fd60b0fa4cf2/679124a91d0aeed2124fed68/ADA_Summary_of_Typical_Nonresidential_Line_Item_Changes.pdf?branch=prod_alias",
"source_label_zh": "ComEd 官方价目汇总（输配单价公开：客户费 $2,293.55/月、DFC $12.28–13.10/kW；能量非价目项）",
"source_label_en": "ComEd official summary (delivery rates public: customer $2,293.55/mo, DFC $12.28-13.10/kW; energy is not a tariff item)"
},
{
"state": "Missouri",
"utility": "Evergy Metro, Inc. d/b/a Evergy Missouri Metro",
"tariff": "Schedule LLPS Large Load Power Service",
"docket_zh": "MoPSC EO-2025-0154（价目 JE-2026-0104，2026-02-25 批准）",
"docket_en": "MoPSC EO-2025-0154 (tariff JE-2026-0104, approved 2026-02-25)",
"approved": "2026-02-25",
"effective_zh": "2026-03-09",
"effective_en": "2026-03-09",
"threshold_zh": "≥75 MW（新增或扩容）",
"threshold_en": ">=75 MW (new or expanded load)",
"min_demand_zh": "合约容量的 80%",
"min_demand_en": "80% of contract capacity",
"term_zh": "爬坡至多 5 年 + 12 年（合计至多 17 年）；押金 = 2 年最低月账单；退出费 = 最低月账单 × 剩余月数（不少于 12 个月），不足 36 个月通知另加提前终止费",
"term_en": "Up to 5-year ramp + 12 years (17 max); collateral = 2 years of minimum monthly bills; exit fee = minimum monthly bill x remaining months (>=12), early-termination fee adds on <36 months' notice",
"price_disclosure": "full",
"verified": "primary",
"source_url": "https://www.efis.psc.mo.gov/Tariff/Display/103109",
"source_label_zh": "EFIS 价目档案 JE-2026-0104：P.S.C. MO. No. 7 Original Sheet No. 77（官方价单原文）",
"source_label_en": "EFIS tariff JE-2026-0104: P.S.C. MO. No. 7 Original Sheet No. 77 (official rate sheet)"
},
{
"state": "Missouri",
"utility": "Evergy Missouri West, Inc. d/b/a Evergy Missouri West",
"tariff": "Schedule LLPS Large Load Power Service",
"docket_zh": "MoPSC EO-2025-0154（价目 JE-2026-0105，2026-02-25 批准）",
"docket_en": "MoPSC EO-2025-0154 (tariff JE-2026-0105, approved 2026-02-25)",
"approved": "2026-02-25",
"effective_zh": "2026-03-09",
"effective_en": "2026-03-09",
"threshold_zh": "≥75 MW（新增或扩容）",
"threshold_en": ">=75 MW (new or expanded load)",
"min_demand_zh": "合约容量的 80%",
"min_demand_en": "80% of contract capacity",
"term_zh": "爬坡至多 5 年 + 12 年（合计至多 17 年）；押金 = 2 年最低月账单；退出费 = 最低月账单 × 剩余月数（不少于 12 个月），不足 36 个月通知另加提前终止费",
"term_en": "Up to 5-year ramp + 12 years (17 max); collateral = 2 years of minimum monthly bills; exit fee = minimum monthly bill x remaining months (>=12), early-termination fee adds on <36 months' notice",
"price_disclosure": "full",
"verified": "primary",
"source_url": "https://www.efis.psc.mo.gov/Tariff/Display/103110",
"source_label_zh": "EFIS 价目档案 JE-2026-0105：P.S.C. MO. No. 1 Original Sheet No. 187（官方价单原文）",
"source_label_en": "EFIS tariff JE-2026-0105: P.S.C. MO. No. 1 Original Sheet No. 187 (official rate sheet)"
}
],
"price_cells": [
{
"state": "Missouri",
"utility": "Ameren Missouri (Union Electric)",
"tariff": "11(M) Large Primary Service",
"effective_date": "2025-06-01",
"source_url": "https://www.ameren.com/-/media/rates/missouri/non-residential/electric-rates/rates/uecsheet61rate11mlps.ashx",
"docket": "ER-2024-0319",
"summer": {
"energy_cents_kwh": 4.06,
"demand_usd_kw_mo": 23.9
},
"winter": {
"energy_cents_kwh": 3.71,
"demand_usd_kw_mo": 10.63
},
"cross_check": {
"value_usd_mwh": 62,
"source_url": "https://s21.q4cdn.com/448935352/files/doc_events/2026/Jun/24/JPM-Conference-2026-vFINAL.pdf",
"note_zh": "Ameren 自述大负荷 all-in 约 $0.062/kWh（不含附加费，随负荷率变化）——与左表推算互证",
"note_en": "Ameren's own stated all-in ~$0.062/kWh for large load (excl. riders, load-factor dependent) — corroborates the computed value"
},
"effective": {
"summer": 81.5,
"winter": 55.3,
"annual": 64.0
}
},
{
"state": "Missouri",
"utility": "Evergy Metro, Inc.",
"tariff": "Schedule LLPS, Original Sheet No. 77",
"effective_date": "2026-03-09",
"source_url": "https://www.efis.psc.mo.gov/Document/Display/865318",
"docket": "EO-2025-0154 / JE-2026-0104",
"summer": {
"energy_cents_kwh": 2.988,
"demand_usd_kw_mo": 24.041
},
"winter": {
"energy_cents_kwh": 2.988,
"demand_usd_kw_mo": 22.041
},
"demand_components": {
"demand_charge_summer_usd_kw_mo": 21.038,
"demand_charge_winter_usd_kw_mo": 19.038,
"grid_charge_substation_usd_kw_mo": 3.003,
"grid_charge_transmission_usd_kw_mo": 2.2,
"note_zh": "需量 = 需量费（夏 21.038 / 冬 19.038）+ 电网费·变电站 3.003 $/kW·月；输电直连取 2.200（较变电站低 0.803 $/kW·月，按 80% 负荷率折合约 1.4 $/MWh）。电网费全年无季节差。客户费 $1,181.28/月与无功调整按口径排除",
"note_en": "Demand = demand charge (summer 21.038 / winter 19.038) + substation grid charge 3.003 $/kW-mo; transmission-connected customers use 2.200 (0.803 $/kW-mo lower, about 1.4 $/MWh at an 80% load factor). The grid charge carries no seasonality. Customer charge $1,181.28/mo and reactive adjustment excluded per method"
},
"effective": {
"summer": 71.0,
"winter": 67.6,
"annual": 68.7
}
},
{
"state": "Missouri",
"utility": "Evergy Missouri West, Inc.",
"tariff": "Schedule LLPS, Original Sheet No. 187",
"effective_date": "2026-03-09",
"source_url": "https://www.efis.psc.mo.gov/Document/Display/865322",
"docket": "EO-2025-0154 / JE-2026-0105",
"summer": {
"energy_cents_kwh": 2.881,
"demand_usd_kw_mo": 21.885
},
"winter": {
"energy_cents_kwh": 2.881,
"demand_usd_kw_mo": 19.885
},
"demand_components": {
"demand_charge_summer_usd_kw_mo": 17.074,
"demand_charge_winter_usd_kw_mo": 15.074,
"grid_charge_substation_usd_kw_mo": 4.811,
"grid_charge_transmission_usd_kw_mo": 4.75,
"note_zh": "需量 = 需量费（夏 17.074 / 冬 15.074）+ 电网费·变电站 4.811 $/kW·月；输电直连取 4.750（较变电站低 0.061 $/kW·月，按 80% 负荷率折合约 0.1 $/MWh）。电网费全年无季节差。客户费 $675/月与无功调整按口径排除",
"note_en": "Demand = demand charge (summer 17.074 / winter 15.074) + substation grid charge 4.811 $/kW-mo; transmission-connected customers use 4.750 (0.061 $/kW-mo lower, about 0.1 $/MWh at an 80% load factor). The grid charge carries no seasonality. Customer charge $675/mo and reactive adjustment excluded per method"
},
"effective": {
"summer": 66.3,
"winter": 62.9,
"annual": 64.0
}
},
{
"state": "Indiana",
"utility": "Indiana Michigan Power (I&M, AEP)",
"tariff": "Tariff I.P. (Industrial Power), IURC No. 20, First Revised Sheet No. 21",
"effective_date": "2025-02-19",
"source_url": "https://www.indianamichiganpower.com/lib/docs/ratesandtariffs/Indiana/IM_IN_TB_20_09-29-2026.pdf",
"docket": "IURC Cause No. 46097",
"summer": {
"energy_cents_kwh": 3.9342,
"demand_usd_kw_mo": 10.194
},
"winter": {
"energy_cents_kwh": 3.9342,
"demand_usd_kw_mo": 10.194
},
"price_components": {
"voltage": "transmission (tariff code 324)",
"demand_charge_usd_kw_mo": 10.194,
"minimum_demand_charge_usd_kw_mo": 14.7,
"energy_first_410kwh_per_kw_cents": 5.058,
"energy_over_410kwh_per_kw_cents": 1.286,
"service_charge_usd_mo": 275.0,
"note_zh": "≥70MW 大负荷按 46097 修订后的 I.P. 取传输级。能量两段（每 kW 需量前 410 kWh 5.058¢、超出 1.286¢）在 80% 负荷率（584 kWh/kW·月）下混合为 3.934¢。最低需量费 $14.700/kW·月仅构成最低账单下限；80% 负荷率下常规路径（$33.17/kW·月）高于下限，故取常规需量费。费率无季节差异，夏冬同值。客户费与无功调整、各项 riders 按口径排除",
"note_en": "Loads >=70MW take transmission-level I.P. as amended in 46097. Two-tier energy (first 410 kWh per kW of demand at 5.058c, over at 1.286c) blends to 3.934c at 80% load factor (584 kWh/kW-mo). The $14.700/kW-mo minimum demand charge only sets the minimum-bill floor; at 80% LF the regular path ($33.17/kW-mo) exceeds it, so the regular demand charge applies. No seasonality: summer = winter. Customer charge, reactive adjustment and riders excluded per method"
},
"effective": {
"summer": 56.8,
"winter": 56.8,
"annual": 56.8
}
},
{
"state": "Michigan",
"utility": "Indiana Michigan Power (I&M, AEP)",
"tariff": "Tariff LP (Large Power), M.P.S.C. No. 18, Original Sheet No. D-35/D-36",
"effective_date": "2024-07-15",
"source_url": "https://www.michigan.gov/mpsc/-/media/Project/Websites/mpsc/consumer/rate-books/electric/indiana-michigan/IM-18-current-A-B-C-D.pdf",
"docket": "MPSC Case No. U-21461 (rates) / U-21986 (2026 data-center terms)",
"summer": {
"energy_cents_kwh": 3.6316,
"demand_usd_kw_mo": 23.59
},
"winter": {
"energy_cents_kwh": 3.6316,
"demand_usd_kw_mo": 23.59
},
"price_components": {
"voltage": "transmission (tariff codes 310/863)",
"demand_charge_usd_kw_mo": 23.59,
"demand_components_usd_kw_mo": "power supply 5.97 + capacity 17.22 + non-capacity/delivery 0.40",
"energy_onpeak_first_210kwh_per_kw_cents": 4.753,
"energy_onpeak_over_cents": 3.002,
"energy_offpeak_cents": 3.002,
"service_charge_usd_mo": 880.0,
"note_zh": "≥50MW 数据中心按 U-21986 修订后的 LP 取传输级标准服务。TOU 能量（工作日 7-21 点为 on-peak：前 210 kWh/kW 4.753¢、超出 3.002¢；off-peak 3.002¢）在 80% 负荷率（on-peak 243.3 + off-peak 340.7 kWh/kW·月）下混合为 3.632¢。U-21986 修订条款（15 年、最低需量 90%、最低电量 65%）未改价格——现行价目书 LP 页仍为 U-21461 费率，MPSC 已令下一轮总费率案另设数据中心专档。无季节差异。客户费、无功与 riders 按口径排除",
"note_en": "Data centres >=50MW take transmission-level standard service under LP as amended by U-21986. TOU energy (on-peak = weekdays 7am-9pm: first 210 kWh/kW at 4.753c, over at 3.002c; off-peak 3.002c) blends to 3.632c at 80% load factor (243.3 on-peak + 340.7 off-peak kWh/kW-mo). U-21986 amended terms (15-year term, 90% minimum demand, 65% minimum energy) but not prices - the current book's LP sheets still carry U-21461 rates; the MPSC has ordered a standalone data-centre class in the next rate case. No seasonality. Customer charge, reactive and riders excluded per method"
},
"effective": {
"summer": 76.7,
"winter": 76.7,
"annual": 76.7
}
},
{
"state": "Minnesota",
"utility": "Xcel Energy (NSPM)",
"tariff": "Very Large General Time of Day Service, Rate Code A97 (Sheet 5-32.2)",
"effective_date": "2026-08-01",
"source_url": "https://efiling.web.commerce.state.mn.us/documents/%7BE0B9609F-0000-CB12-8AA7-B7163ABE3D94%7D/download",
"docket": "E002/M-25-289 (order 2026-06-12)",
"summer": {
"energy_cents_kwh": 1.5728,
"demand_usd_kw_mo": 25.9
},
"winter": {
"energy_cents_kwh": 1.5728,
"demand_usd_kw_mo": 21.31
},
"price_components": {
"voltage": "transmission (voltage discount $3.35/kW-mo + $0.00329/kWh applied to the secondary-voltage table)",
"demand_onpeak_secondary_usd_kw_mo": "24.66 (Oct-May) / 29.25 (Jun-Sep)",
"demand_onpeak_transmission_usd_kw_mo": "21.31 (Oct-May) / 25.90 (Jun-Sep)",
"demand_offpeak_excess_usd_kw_mo": 3.35,
"energy_onpeak_transmission_cents": 2.422,
"energy_offpeak_transmission_cents": 1.119,
"energy_blended_cents": 1.5728,
"on_peak_hours_share": 0.3483,
"customer_charge_usd_mo": 9000.0,
"interim_surcharge": "7.14% Interim Rate Surcharge applies to rider-specified components; excluded here per method",
"note_zh": "需量取输电级 On Peak 档（二次侧 24.66/29.25 减输电电压折扣 3.35）＝夏 25.90 / 冬 21.31 $/kW·月；恒负载下 Off Peak 需量不超过 On Peak，3.35 的超额需量费不生效。电量两段（峰段 9:00–21:00 周一至周五、扣 7 个节假日 ＝ 全年 3,048h、占 34.83%；峰 2.751¢ / 非峰 1.448¢，减输电折扣 0.329¢）在 80% 负荷率下混合为 1.5728¢。若按二次侧电压（不打折扣）全年为 63.8 $/MWh、输变电（折扣 2.35/0.334¢）为 56.5。客户费 $9,000/月、7.14% 临时附加费、燃料与资源附加费按口径排除——实际账单更高。个案 ESA（如 Google Pine Island，案号 26-170）金额仍被涂黑，故本格是「价单骨架」而非该客户实付价",
"note_en": "Demand takes the transmission-level On Peak tier (secondary 24.66/29.25 less the $3.35/kW-mo voltage discount) = 25.90 summer / 21.31 winter $/kW-mo; under flat load the off-peak demand never exceeds on-peak, so the $3.35 excess-demand charge does not bite. Two-tier energy (on-peak = 9am-9pm Mon-Fri less 7 holidays = 3,048 h/yr, 34.83% of hours; 2.751c on-peak / 1.448c off-peak, less the 0.329c transmission discount) blends to 1.5728c at 80% load factor. On the undiscounted secondary-voltage table the annual value would be 63.8 $/MWh, and 56.5 at transmission-transformed (2.35/0.334c). Customer charge $9,000/mo, the 7.14% interim surcharge and the fuel/resource riders are excluded per method - actual bills are higher. Individual ESAs (e.g. Google Pine Island, docket 26-170) remain redacted, so this cell is the rate-sheet skeleton, not what that customer pays"
},
"note_zh": "MN PUC 2026-05-15 批准、06-12 出令、价单 08-01 生效。价格层公开度：full——费率表逐条可核（需量、电量、电压折扣、客户费全在 32.2–32.3 页）。这恰是「条款与费率骨架公开、个案合约金额涂黑」的明尼苏达样本：同州 Google Pine Island 的 ESA 金额仍以商业秘密处理",
"note_en": "Approved 2026-05-15, order issued 06-12, rate sheet effective 08-01. Price disclosure: full - every component is verifiable on sheets 32.2-32.3 (demand, energy, voltage discounts, customer charge). Minnesota is therefore the case where the terms and rate skeleton are public while the customer-specific ESA dollars stay redacted (Google Pine Island, docket 26-170)",
"effective": {
"summer": 60.1,
"winter": 52.2,
"annual": 54.8
}
}
],
"published": true,
"reading_blocked_by": null,
"cross_ref": {
"source": "E3 (Energy and Environmental Economics) x Halcyon Large Load Tariff Tracker",
"as_of": "2026-05",
"source_url": "https://www.ethree.com/halcyon-whitepaper/",
"title_zh": "第三方对照：同一 25 MW 模型数据中心在五个费率下的年化成本（非本站口径）",
"title_en": "Third-party reference: the same modelled 25 MW data center under five tariffs (not this site's basis)",
"note_zh": "E3 2026-05 白皮书（自筹研究，用 Halcyon 费率数据）对一座假想的 25 MW、输电直挂数据中心做了五种费率的年化账单建模，含客户费、需量费、能量费与附加费。这是第三方模型值，不是本站价格单元格——负荷形状、电压与站点假设都是 E3 的，不能与本站从官方价单逐条复算的口径混同。放在这里只为一件事：给读者一个跨州量级参照。",
"note_en": "E3's May 2026 white paper (self-funded, using Halcyon tariff data) modelled the annual bill of a hypothetical 25 MW, transmission-connected data center under five tariffs, including customer, demand, energy charges and riders. These are third-party modelled values, not this site's price cells — the load shape, voltage and site assumptions are E3's and must not be mixed with our line-by-line recomputation from official rate sheets. It is shown only to give readers a cross-state order of magnitude.",
"rows": [
{
"tariff_zh": "Oncor 输电服务（得州）",
"tariff_en": "Oncor transmission service (TX)",
"cents_kwh": 5.44
},
{
"tariff_zh": "Dominion GS-4（弗吉尼亚）",
"tariff_en": "Dominion GS-4 (VA)",
"cents_kwh": 6.54
},
{
"tariff_zh": "Dominion GS-5（弗吉尼亚）",
"tariff_en": "Dominion GS-5 (VA)",
"cents_kwh": 7.96
},
{
"tariff_zh": "ComEd Extra Large Load（伊利诺伊）",
"tariff_en": "ComEd Extra Large Load (IL)",
"cents_kwh": 8.86
},
{
"tariff_zh": "Georgia Power PLL-18（佐治亚）",
"tariff_en": "Georgia Power PLL-18 (GA)",
"cents_kwh": 9.43
}
]
},
"reading_published": "2026-11-11"
}