PacifiCorp (Pacific Power / Rocky Mountain Power) Rate Selection Guide
PacifiCorp (Pacific Power in OR/WA/CA; Rocky Mountain Power in UT/WY/ID) is a Berkshire Hathaway Energy IOU serving ~2.1M electric customers across six western states. AMI is deployed (Oregon complete); customers get hourly/daily interval data via the online portal, but third-party access is limited — manual release forms, the Energy Profiler tool, ENERGY STAR benchmarking, and EDI 810 invoices. No Green Button or public API.
PacifiCorp (Pacific Power / Rocky Mountain Power) Rate Schedule Comparison
| Schedule | Type | Rate | Best For |
|---|---|---|---|
| Schedule 28 | Electric C&I 31-200 kW | Basic $24-$151/mo + demand $5.13/kW secondary (~$6.87 all-in) + ~2.209¢/kWh; min 15 kW (eff. Jan 1 2025) | Mid-size commercial/industrial under 200 kW |
| Schedule 30 | Electric C&I 201-999 kW | Basic ~$688/mo + demand $4.86/kW distribution (~$13.07 all-in) + ~0.790¢/kWh; min 100 kW (eff. Jan 1 2025) | Large commercial/industrial 201-999 kW |
| Schedule 48 | Electric industrial 1,000 kW+ | Basic $800-$4,480/mo + on-peak demand $6.28-$7.78/kW; facilities charge (eff. Jan 1 2025) | Large industrial / high-load campuses 1,000 kW+ |
| Schedules 728/730 | Direct access delivery | Delivery charges match Sch 28/30; supply via competitive ESS | C&I customers wanting competitive supply pricing |
Market Overview
PacifiCorp is a vertically integrated, regulated electric utility across six western states; most customers have no retail supplier choice. Data sharing relies on manual forms and EDI rather than market-driven Green Button/API access.
Need to pull your actual usage data to compare rates? See the PacifiCorp (Pacific Power / Rocky Mountain Power) Data Access Guide →
Current Rate Schedules
PacifiCorp serves Oregon as Pacific Power (it also operates as Rocky Mountain Power in Utah, Wyoming and Idaho). Oregon is used here as the representative state. Commercial and industrial customers take service under size-tiered nonresidential delivery schedules in P.U.C. OR No. 36: Schedule 28 (Large Nonresidential 31-200 kW), Schedule 30 (201-999 kW), and Schedule 48 (1,000 kW and over). Each combines a Distribution Charge (Basic Charge + Load Size/Facilities Charge + demand and energy charges) with a separate Transmission & Ancillary Services Charge and a System Usage Charge (supply). All rates shown are effective January 1, 2025 (Docket UE 433). Direct-access (competitive supply) equivalents exist as Schedules 728/730.
Effective: January 1, 2025 · Full Tariff Book →
| Schedule | Type | Applicability | Structure | Rate |
|---|---|---|---|---|
| Schedule 28 - General Service Large Nonresidential 31-200 kW | Commercial/Industrial (mid-size) | Large nonresidential consumers whose loads have not registered more than 200 kW more than six times in the preceding 12 months. Available at secondary or primary voltage. | Distribution Charge = tiered Basic Charge (by load size) + Load Size Charge (per kW, tiered) + Demand Charge (per kW, minimum 15 kW) + Distribution Energy Charge (per kWh) + Reactive Power Charge (per kvar), plus separate Transmission & Ancillary Services and System Usage charges. | Secondary: Demand Charge $5.13/kW (delivery), all-in demand $6.87/kW; Energy ~2.209¢/kWh total. Basic Charge $24-$151/mo by load size. (eff. Jan 1, 2025)+ Secondary $5.13/kW distribution ($6.87/kW all-in); Primary $6.58/kW distribution ($8.71/kW all-in); minimum billing demand 15 kW |
| Schedule 30 - General Service Large Nonresidential 201-999 kW | Commercial/Industrial (large) | Large nonresidential consumers with loads in the 201-999 kW range. Available at secondary or primary voltage; minimum billing demand 100 kW. | Distribution Charge = tiered Basic Charge (by load size) + Load Size Charge (per kW) + Demand Charge (per kW, minimum 100 kW) + Distribution Energy Charge (per kWh) + Reactive Power Charge, plus separate Transmission & Ancillary Services and System Usage charges. | Secondary: Demand Charge $4.86/kW distribution ($13.07/kW all-in incl. T&A); Energy ~0.790¢/kWh distribution; Basic Charge $688/mo base. (eff. Jan 1, 2025)+ Secondary $4.86/kW distribution ($13.07/kW all-in); Primary $4.72/kW distribution ($12.45/kW all-in); minimum billing demand 100 kW |
| Schedule 48 - Large General Service 1,000 kW and Over | Industrial / Large commercial | Loads that have registered 1,000 kW or more more than once in a preceding 18-month period; remains applicable until load falls below 1,000 kW for 36 consecutive months. Secondary, primary or transmission voltage. | Distribution Charge = Basic Charge (by facility capacity) + Facilities Charge + On-Peak Demand Charge (per kW) + energy charges, plus separate Transmission & Ancillary Services and System Usage charges. Time-differentiated demand. | On-Peak Demand Charge $6.28/kW secondary, $7.78/kW primary, $6.09/kW transmission; Basic Charge $800-$4,480/mo by voltage and facility capacity. (eff. Jan 1, 2025)+ On-Peak Demand $6.28/kW (secondary), $7.78/kW (primary), $6.09/kW (transmission) |
| Schedules 728 / 730 - Direct Access Delivery Service | Commercial/Industrial (competitive supply) | Schedule 28/30-equivalent customers electing direct access (competitive supply via an Electricity Service Supplier) rather than PacifiCorp cost-based supply. Delivery charges mirror the bundled schedules; supply is competitively procured. | Same distribution and transmission delivery charges as the corresponding bundled schedule; the System Usage / cost-based supply component is removed and replaced by the competitive supplier's energy charge. | Delivery charges match Schedule 28/30; supply priced by chosen Electricity Service Supplier+ Same delivery demand charges as Schedule 28/30 |
Rate Recommendations by Use Case
Demand-metered C&I facility
Use the portal or Energy Profiler to manage demand charges where no API exists.
PacifiCorp lacks Green Button/API, so the portal (view) and the paid Energy Profiler (daily interval + demand) are the main interval tools.
- Enroll in Energy Profiler ($260 + $32/mo) for demand tracking
- Confirm an interval meter is installed
- Review the state tariff for the optimal schedule
Multi-site / benchmarking
Automate whole-building benchmarking to ENERGY STAR Portfolio Manager.
PacifiCorp's benchmarking transfer is the closest thing to programmatic access — one-way monthly whole-building uploads.
- Document all building meter numbers
- Submit the Electrical Usage Data Request
- Owner authorization suffices for 5+ tenant meters
Energy consultant / aggregator
Use the manual release form or a data aggregator, since no Green Button/API exists.
The Usage/Billing History Release Form (one-time or one-year standing) provides 12-month data; Nectar can automate collection via its API (see docs.nectarclimate.com).
- Use a one-year standing authorization for recurring needs
- Email forms to BillingUsageRequests@pacificorp.com
- Evaluate Nectar for API access — docs.nectarclimate.com
Accounts payable / billing automation
Receive monthly invoices automatically via EDI 810.
EDI 810 (ANSI X12 v4010) delivers structured monthly invoices to first or third parties without manual entry.
- Call 1-866-870-3419 to enroll
- Choose FTP or VAN
- Handle 810/820/997 transactions
Historical Rate Trends
PacifiCorp (Pacific Power) filed its Oregon general rate case (UE 433) in February 2024. The current C&I delivery rates took effect January 1, 2025. Pacific Power has since pursued a further Oregon rate increase, reducing an originally proposed 17.9% request to 11.9% in reply testimony.
January 1, 2025
New Oregon C&I delivery rates effective under Docket UE 433 / P.U.C. OR No. 36 (Schedules 28, 30, 48). Demand and basic charges reset to current published levels.
Class-specific; overall Oregon increase implemented Jan 1, 2025July 26, 2024
Pacific Power filed reply testimony in its Oregon general rate case reducing its request from 17.9% ($322.3M) to 11.9% ($214.5M) overall; ~14.9% average proposed for residential. Pending OPUC approval.
~11.9% overall proposed (pending)Overall trend: Rising — multiple consecutive annual rate increases driven by transmission/wildfire-mitigation and capital investment.
Next expected change: A subsequent Oregon general rate case is pending OPUC review; Pacific Power's reply testimony proposed an overall ~11.9% increase (down from 17.9% requested, ~$214.5M), with new rates targeted for a January 1 effective date pending approval. Annual price-summary updates also adjust supply components.
Cost Optimization Strategies
PacifiCorp Oregon C&I bills are dominated by demand and basic charges that scale with size and voltage, with a separately-priced supply component. The biggest levers are correct schedule/voltage selection, peak-demand management, and (where eligible) electing direct access for competitive supply.
Manage peak demand
For: Schedules 28, 30, 48
Demand charges run $4.86-$8.71/kW (all-in) and Schedule 48 uses an on-peak demand charge. Peak shaving, staggering equipment startup, and shifting load off coincident peaks directly cut the demand component.
Right-size the rate schedule
For: Customers near 200 kW or 1,000 kW thresholds
Schedules step at 200 kW and 1,000 kW with different basic, load-size and demand charges. Confirm the account sits on the most economical schedule for its actual load profile and voltage (secondary vs primary).
Evaluate direct access (competitive supply)
For: Eligible nonresidential customers (subject to OPUC enrollment windows/caps)
Oregon nonresidential customers may take direct access (Schedules 728/730), procuring energy from a competitive Electricity Service Supplier while paying PacifiCorp only delivery charges — useful when market supply beats cost-based supply.
Improve power factor
For: Schedules 28, 30, 48
Reactive Power Charges (~$0.60-$0.65/kvar) apply. Correcting power factor with capacitors reduces reactive billing and can lower demand.
To implement these strategies, you need your 15-minute interval data. Learn how to download PacifiCorp (Pacific Power / Rocky Mountain Power) interval data →
Frequently Asked Questions
Does PacifiCorp support Green Button or an API?▾
No. As of 2026 PacifiCorp (Pacific Power / Rocky Mountain Power) has not implemented Green Button, Green Button Connect My Data, ESPI, or a public API. Third-party access relies on manual release forms, the Energy Profiler tool, ENERGY STAR benchmarking transfers, EDI 810 invoices, and possibly data aggregators.
How can a C&I customer get interval data?▾
Customers can view hourly/daily interval data in the online portal (business customers may see 15/30-minute increments), but there is no CSV/XML export. For detailed interval monitoring and demand tracking, enroll in the Energy Profiler ($260 setup + $32/month).
How does a third party get authorized data?▾
Use the Usage/Billing History Release Form (one-time or one-year standing authorization) for 12 months of monthly usage and/or billing data, emailed to BillingUsageRequests@pacificorp.com; processing takes 5-10 business days. EDI 810 invoices and ENERGY STAR benchmarking transfers are also available.
Can customers choose their electricity supplier?▾
Generally no. PacifiCorp is a vertically integrated, regulated utility across six states; most customers do not have retail supplier choice, and data sharing is form/EDI-based rather than market-driven.
How is whole-building data shared for benchmarking?▾
Complete the Electrical Usage Data Request listing all building meters; Pacific Power then auto-transfers whole-building monthly usage to your ENERGY STAR Portfolio Manager account (owner authorization suffices for buildings with 5+ tenant meters).
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