{
 "customer_charge_month": 343.54,
 "dist_demand_kw_month": 0.0,
 "trans_demand_kw_month": 2.31,
 "gen_demand_kw_month": 9.28,
 "riders_trans_kw_month": 4.673,
 "riders_gen_kw_month": 5.091,
 "energy_kwh": 0.004017,
 "fuel_rider_kwh": 0.037648,
 "other_riders_kwh": 0.011096,
 "cap_share_of_gen": 1.0,
 "fuel_mult_high": 1.5,
 "components": [
  [
   "cust",
   "Basic customer charge (Schedule GS-4, transmission voltage)",
   343.54,
   "$/month",
   "01-01-2026",
   "Schedule GS-4, Large General Service, filed 12-09-25, effective for usage on and after 01-01-26 (dominionenergy.com, large-business/schedule-gs4.pdf)"
  ],
  [
   "dist",
   "Distribution demand charge (zero at 69 kV and above)",
   0.0,
   "$/kW-month",
   "01-01-2026",
   "Schedule GS-4: $2.717/kW for the first 5,000 kW and $2.076/kW thereafter at primary voltage; not charged at delivery voltages of 69 kV and above. The reference design connects at 230 kV."
  ],
  [
   "trans",
   "Transmission demand charge, base",
   2.31,
   "$/kW-month",
   "01-01-2026",
   "Schedule GS-4, transmission voltage, on on-peak electricity-supply demand"
  ],
  [
   "gen",
   "Generation demand charge, on-peak",
   9.28,
   "$/kW-month",
   "01-01-2026",
   "Schedule GS-4 II.B.1, transmission voltage, on on-peak electricity-supply demand (Section VI). From January 1, 2027, Section VIII applies to customers of 25 MW or more that do not qualify for GS-5: generation demand is the highest of the measured on-peak demand, 75% of the prior summer's peak, or 60% of contracted demand, and when the 60% floor controls the charge excludes PJM capacity expense."
  ],
  [
   "offpeak",
   "Generation demand charge, off-peak (on off-peak demand above 90% of on-peak demand, Section VII)",
   0.558,
   "$/kW-month",
   "01-01-2026",
   "Schedule GS-4 II.B.2 and VII. For a flat 240 MW load the billable off-peak demand is 10% of on-peak demand, 24,000 kW."
  ],
  [
   "riders_trans",
   "Rider T1 (transmission)",
   4.673,
   "$/kW-month",
   "09-01-2026",
   "Rider T1 sheet, effective 09-01-26 (dominionenergy.com, shared/rider-t1.pdf); $4.729/kW at primary voltage. Billed on on-peak electricity-supply demand like the base transmission charge; grouped with transmission demand for the GS-5 85% minimum."
  ],
  [
   "riders_gen",
   "Rider E (environmental)",
   0.145,
   "$/kW-month",
   "11-01-2025",
   "Rider E sheet (shared/rider-e.pdf). Riders E, GEN, SNA, CERC, SMR, CE and OSW are billed on on-peak electricity-supply demand; grouped with generation demand for the GS-5 60% minimum in the credit scenario."
  ],
  [
   "riders_gen",
   "Rider GEN (generation facilities)",
   0.967,
   "$/kW-month",
   "04-01-2026",
   "Rider GEN sheet (shared/rider-gen.pdf)"
  ],
  [
   "riders_gen",
   "Rider SNA (Surry and North Anna life extension)",
   0.886,
   "$/kW-month",
   "09-01-2026",
   "Rider SNA sheet (shared/rider-sna.pdf)"
  ],
  [
   "riders_gen",
   "Rider CERC (Chesterfield Energy Reliability Center)",
   0.158,
   "$/kW-month",
   "03-01-2026",
   "Rider CE sheet (shared/rider-ce.pdf). Non-bypassable; the Exhibit of Applicable Riders notes exceptions for qualifying accelerated renewable energy buyers and certain grandfathered competitive-supply customers. The modeled customer is a bundled-service customer with no exemption."
  ],
  [
   "riders_gen",
   "Rider SMR (small modular reactor development)",
   0.04,
   "$/kW-month",
   "09-01-2026",
   "Rider SMR sheet (shared/rider-smr.pdf), through 08-31-27"
  ],
  [
   "riders_gen",
   "Rider CE (clean energy, non-bypassable)",
   0.499,
   "$/kW-month",
   "05-01-2026",
   "Rider CE sheet (shared/rider-ce.pdf). Non-bypassable; the Exhibit of Applicable Riders notes exceptions for qualifying accelerated renewable energy buyers and certain grandfathered competitive-supply customers. The modeled customer is a bundled-service customer with no exemption."
  ],
  [
   "riders_gen",
   "Rider OSW (Coastal Virginia Offshore Wind, non-bypassable)",
   2.396,
   "$/kW-month",
   "09-01-2026",
   "Rider OSW sheet (shared/rider-osw.pdf)"
  ],
  [
   "riders_gen",
   "Rider DIST (distribution projects; zero at transmission voltage)",
   0.0,
   "$/kW-month",
   "06-01-2026",
   "Rider DIST sheet (shared/rider-dist.pdf); $0.311/kW on distribution demand at primary voltage"
  ],
  [
   "energy",
   "Generation energy charge, blended on-peak and off-peak",
   0.00386,
   "$/kWh",
   "01-01-2026",
   "Schedule GS-4: 0.4648 cents/kWh on-peak, 0.3299 cents/kWh off-peak. On-peak hours are weekdays 10 a.m. to 10 p.m. June through September and 7 a.m. to 10 p.m. October through May, about 3,650 of 8,760 hours (41.7%); a flat load pays the hour-weighted blend."
  ],
  [
   "energy",
   "Distribution energy charge",
   0.000157,
   "$/kWh",
   "01-01-2026",
   "Schedule GS-4, transmission voltage"
  ],
  [
   "fuel",
   "Rider A (fuel factor), interim",
   0.037648,
   "$/kWh",
   "07-01-2026",
   "Rider A sheet filed 05-29-26, effective 07-01-26 (shared/rider-a.pdf), Case PUR-2026-00058. PJM capacity cost is recovered in base rates, not through Rider A (SCC final order, Case PUR-2025-00058, November 25, 2025)."
  ],
  [
   "riders_kwh",
   "Rider CCR (coal combustion residuals, non-bypassable)",
   0.001765,
   "$/kWh",
   "01-01-2026",
   "Rider CCR sheet (shared/rider-ccr.pdf)"
  ],
  [
   "riders_kwh",
   "Rider RPS (renewable portfolio standard, non-bypassable)",
   0.00552,
   "$/kWh",
   "09-01-2026",
   "Rider RPS sheet (shared/rider-rps.pdf). Non-bypassable; same exceptions as Rider CE for accelerated renewable energy buyers. The modeled customer is a bundled-service customer with no exemption."
  ],
  [
   "riders_kwh",
   "Rider C1A (peak shaving)",
   0.000212,
   "$/kWh",
   "09-01-2026",
   "Rider C1A sheet (shared/rider-c1a.pdf)"
  ],
  [
   "riders_kwh",
   "Rider C4A (energy efficiency)",
   0.000698,
   "$/kWh",
   "09-01-2026",
   "Rider C4A sheet (shared/rider-c4a.pdf)"
  ],
  [
   "riders_kwh",
   "Rider RGGI and Rider PIPP",
   0.0,
   "$/kWh",
   "04-01-2025",
   "Both at 0.0000 cents/kWh on the current sheets"
  ],
  [
   "riders_kwh",
   "Deferred fuel cost charge (2023 securitization bonds), all kWh",
   0.002901,
   "$/kWh",
   "08-01-2026",
   "Deferred Fuel Cost Charge sheet, filed 06-15-26, effective 08-01-26 (shared/deferred-fuel-cost-charge-tariff.pdf): non-bypassable, 0.2901 cents/kWh on all kWh under Schedule GS-4 among others. Read on October 24, 2026."
  ]
 ],
 "notes": {
  "general1": "Basis: Dominion Energy Virginia Schedule GS-4 (Large General Service) at transmission delivery voltage, with the riders listed in the Exhibit of Applicable Riders filed 09-16-26 and effective 09-01-26. Schedule GS-5, the rate class created by the SCC's final order in Case PUR-2025-00058 (November 25, 2025) for customers of 25 MW or more at a 75% load factor, applies to agreements signed on or after January 1, 2027; its unit rates had not been published at the status date (compliance tariffs are due 45 days before the effective date), so GS-4 transmission-voltage rates are the proxy and the GS-5 minimum-billing provisions (85% of contracted transmission and distribution demand, 60% of contracted generation demand, PJM capacity excluded from the 60% floor) are applied. Tariff sheets were read on dominionenergy.com on October 23, 2026 (Tier 1 for the rates; the mapping of the sheets to a GS-5 bill is the author's).",
  "general2": "Not modeled: the Virginia consumption tax and local utility taxes, the reactive (rkVA) demand charge, excess-facilities charges, Rider D (tax gross-up on contributions in aid of construction), GS-5 collateral ($1.5 million per MW, reducible by 70%), and the direct-connect transmission contribution ordered in Case PUR-2026-00056 (July 31, 2026), whose implementing line-extension policy is pending and for which no amounts have been set. Billing-period proration: Schedule GS-4 Section IX multiplies the customer charge and the on-peak, off-peak and transmission demand charges by the days in the billing period divided by 30, so over 365 days those charges total 365/30 months rather than 12; the model applies that factor to the Schedule GS-4 charges and bills the riders at 12 months (the Rider T1 sheet states no proration clause; the other rider sheets were not checked for one). The high-gas case raises the Rider A fuel factor by 50%, an assumption rather than a derivation from Dominion's fuel mix (gas-fired generation and gas-indexed purchased power account for roughly half to two-thirds of the factor; the factor rose from 2.07 to 3.76 cents/kWh between July 2024 and July 2026); base energy and demand rates do not move with gas prices between rate cases. The uncapped-capacity case escalates the whole generation demand charge ($111/kW-yr, close to the 2027/28 PJM capped price of $122/kW-yr) by the ratio of PJM's uncapped Dominion-zone simulation ($542.83/MW-day) to the capped clearing price ($333.44/MW-day); because only part of that charge is purchased-capacity expense, this is an upper-bound stress case, not an estimate of the bill an uncapped auction would produce. The capacity-credit scenario lowers generation billing demand to the 60% floor (144 MW) and prices the floor at the full generation demand charge; Schedule GS-4 VIII.B.2 excludes PJM capacity expense when the floor controls, which cannot be implemented without the unpublished capacity component, so the scenario bill is an upper bound of a floor bill."
 },
 "offpeak_gen_demand_kw_month": 0.558,
 "offpeak_threshold": 0.9,
 "billing_days": 365
}