The Data Center Tariff forecast separates AEP Ohio delivery charges from competitively supplied electricity, capacity, and ancillary services. It covers new load at transmission voltage.
Service overview
| Item | Coverage |
|---|---|
| Service | Ohio · PJM · DCT new load, schedule codes 297/797. |
| Rate basis | October 2026 tariff book; DCT sheets 223-1 through 223-8. |
| Supply | Competitive retail supply priced from AEP-zone forecasts. Supplier margin is excluded. |
| Voltage | Transmission service at the selected connection voltage. A 34.5 kV connection requires service-class confirmation because the tariff also lists it under primary service. |
Charge breakdown
| Line item / what it pays for | Tariff Charge Type | How the Charge Is Assessed | Calculation basis |
|---|---|---|---|
| Retail electricity supply | Supply | Energy | Imported MWh multiplied by AEP-zone day-ahead price. |
| PJM capacity supply | Supply | Capacity (demand-based) | Monthly peak MW multiplied by capacity price multiplied by covered days multiplied by Forecast Pool Requirement. |
| Regulation and reserves | Stability | Energy | Imported MWh multiplied by allocated hourly ancillary-service rate. |
| BTCR demand recovery | Transmission | Fixed | 85% of grid-import capacity multiplied by demand rate multiplied by service-day allocation. |
| BTCR energy recovery | Transmission | Energy | Imported MWh multiplied by energy recovery rate. |
| Customer service | Distribution | Fixed | Monthly customer charge allocated by covered calendar days. |
| New-load customer service | Distribution | Fixed | Monthly supplemental customer charge allocated by covered calendar days. |
| Distribution investment | Rider | Fixed | Base customer charge multiplied by DIR percentage, allocated by covered calendar days, through May 2028. |
| Service reliability | Rider | Fixed | Base customer charge multiplied by ESR percentage, allocated by covered calendar days, through May 2028. |
| Economic development recovery | Rider | Fixed | Base customer charge multiplied by EDR percentage, allocated by covered calendar days. |
| Ohio electricity tax | Rider | Energy | Imported MWh multiplied by self-assessed tax rate. |
| Tax first-block adjustment | Rider | Fixed | Monthly share of the first-block premium and annual fee, allocated by covered calendar days. |
| Income-based payment assistance | Rider | Energy | Imported MWh multiplied by PIPP second-block rate. |
| PIPP first-block adjustment | Rider | Fixed | Monthly first-block premium allocated by covered calendar days. |
| Tax savings credit | Rider | Energy | Imported MWh multiplied by credit rate from April 10, 2026 through August 2027. |
| Smart-grid recovery | Rider | Fixed | Monthly gridSMART amount allocated by covered calendar days, through May 2028. |
| Storm-damage recovery | Rider | Fixed | Monthly amount allocated by covered calendar days, through October 2026. |
How charges are calculated
Supply
Energy is priced at the AEP-zone day-ahead price. Capacity supply pays for generation available to meet peak demand. The forecast uses monthly peak imports to estimate the customer’s share:
Capacity cost is calculated by multiplying monthly peak MW by the price in $/MW-day, the covered days, and the Forecast Pool Requirement.
The Forecast Pool Requirement is PJM’s multiplier for the generation capacity needed to serve each MW of peak demand. Ancillary-service rates allocate forecast regulation and reserve costs across PJM load each hour. No additional transmission-voltage loss factor is applied.
Transmission
The Basic Transmission Cost Rider (BTCR) has separate demand and energy charges. Demand is a fixed forecast assessment at 85% of maximum grid-import capacity, allocated to days in service. Actual peaks do not increase this assessment. The energy charge applies to imported MWh.
Customer charges, riders, and tax
The base and supplemental customer charges are fixed monthly amounts. DIR, ESR, and EDR apply percentages to the base customer charge. Electricity tax and PIPP each combine a per-MWh rate with a fixed first-block adjustment. This reproduces the assumed high-consumption case without counting the first block twice.
Forecast methodology
| Charge | How its rate changes |
|---|---|
| Energy and capacity | AEP-zone day-ahead and capacity forecasts. Forecast Pool Requirements use auction values, then PJM projections, and remain constant after the projection ends. |
| Ancillary services | Forecast regulation and reserve prices allocated using PJM load; reserve requirements remain at their measured average levels. |
| BTCR demand | Basic Transmission Cost Rider — demand charge. Filed rates through March 2027, then annual April updates based on AEP-zone network cost, class billing growth, and the timing of transmission recovery. |
| BTCR energy | Basic Transmission Cost Rider — energy charge. Held constant in real 2025 dollars. |
| Base and supplemental customer charges | Held constant in real 2025 dollars from the April 2026 rate sheet. |
| DIR and ESR |
Rates increase on their historical quarterly and annual trends, respectively, through May 2028, then end with Electric Security Plan V. |
| Economic development recovery | Economic Development Cost Recovery Rider. Retains its latest percentage. |
| Tax and PIPP | PIPP: Percentage of Income Payment Plan Rider. Tax and the PIPP second-block rate stay fixed nominally; the PIPP first-block premium follows its rate path in real 2025 dollars. |
| Tax savings credit | Ends September 1, 2027 under the assumed refund schedule. |
| gridSMART and storm damage | gridSMART Rider: smart-grid investment recovery. Storm Damage Recovery Rider: storm-related cost recovery. gridSMART ends June 1, 2028; storm recovery ends November 1, 2026. |
Assumptions and limitations
| Assumption | Effect on results |
|---|---|
| Demand minimums | The fixed 85% transmission assessment does not reproduce tiered minimums, the 11-month ratchet, ramp floors, or contract-capacity billing before energization. |
| Capacity supply | The monthly peak represents demand at the PJM system peak only when imports are constant. For varying imports, the two quantities must be measured separately. |
| Tax and PIPP thresholds | First-block adjustments assume more than 500,000 MWh in the May–April tax year and 833,000 kWh per month for PIPP. Lower consumption can overstate these charges. Self-assessment requires more than 45 million kWh per year at the meter or location. |
| Contract and supply costs | Supplier margin, administrative and make-whole charges, reactive demand, collateral, exit costs, and site-specific contributions are excluded. |
| Partial months | Monthly charges use covered days. A partial-month demand measurement can miss the full-month peak. |
Public tariffs and regulatory filings
| Source | Coverage |
|---|---|
| October 2026 tariff book | DCT pp. 113–120; BTCR p. 155; tax and riders pp. 156–168. |
Methodology version: October 2026. Results use real 2025 dollars.