Pacific Gas & Electric Co. (PG&E) Rate Selection Guide
PG&E is California's largest investor-owned utility serving 5.7 million electric and 2.4 million gas customers across northern and central California. Comprehensive programmatic data access via Share My Data (ESPI 1.1), Green Button, EDI, and Energy Data Request Portal.
Pacific Gas & Electric Co. (PG&E) Rate Schedule Comparison
| Schedule | Type | Rate | Best For |
|---|---|---|---|
| E-TOU-C | Residential TOU | $0.35-$0.55/kWh | Standard homes, default rate |
| EV2-A | Residential EV | $0.20-$0.55/kWh | Homes with EV charging overnight |
| E-ELEC | Residential All-Electric | $0.33-$0.52/kWh | Fully electrified homes (no gas) |
| B-1 | Small Commercial | $0.28-$0.35/kWh | Offices and shops under 75 kW |
| B-10 | Medium Commercial | $0.25-$0.40/kWh + demand | Mid-size businesses 75-499 kW |
| B-19 | Medium-Large Commercial | $0.22-$0.48/kWh + demand | Campuses and large offices 500-999 kW |
| B-20 | Large C&I | $0.20-$0.45/kWh + demand | Industrial and large facilities 1000+ kW |
| AG-1 | Small Agricultural | $0.25-$0.38/kWh | Small farms under 35 kW |
| AG-4 | Medium Agricultural | $0.22-$0.42/kWh + demand | Mid-size ag operations 35-500 kW |
| BEV | Commercial EV | Reduced demand charges | Dedicated commercial EV charging meters |
Market Overview
California operates a partially deregulated electricity market. PG&E remains the default provider (bundled service) for generation, transmission, and distribution. However, customers in many jurisdictions can opt into Community Choice Aggregators (CCAs) that purchase power on their behalf — often with higher renewable content and competitive rates. Customers cannot choose a fully alternative retail electricity supplier for bundled service as in states like Texas or Ohio.
Need to pull your actual usage data to compare rates? See the Pacific Gas & Electric Co. (PG&E) Data Access Guide →
Community Choice Aggregation (CCA) Options
San Francisco's CCA offering Green (50% renewable) and SuperGreen (100% renewable) tiers at rates competitive with PG&E bundled service.
Serves San Mateo County with ECOplus (50% renewable, default) and ECO100 (100% renewable) options, typically 1-5% below PG&E generation rates.
Serves Marin, Napa, Contra Costa, and Solano counties. Light Green (60% renewable) default tier with Deep Green (100% renewable) and Local Sol options.
Serves Santa Clara County cities with GreenStart (50% renewable, default) and GreenPrime (100% renewable) programs.
Serves Alameda County with Bright Choice (default, matches PG&E renewable content at lower cost) and Brilliant 100 (100% renewable) tiers.
Current Rate Schedules
PG&E rates are among the highest in the nation, reflecting California's grid infrastructure investments, wildfire mitigation costs, and clean energy mandates. Most schedules are time-of-use (TOU) with significant peak/off-peak differentials designed to incentivize load shifting.
Effective: January 1, 2026 · Full Tariff Book →
| Schedule | Type | Applicability | Structure | Rate |
|---|---|---|---|---|
| EV2-A | ev | Residential customers with electric vehicles | Three-period TOU with super-off-peak (midnight-6 AM) designed for overnight EV charging. | — |
| B-1 | commercial | Small commercial customers with demand under 75 kW | Flat rate with seasonal variation. No demand charge. | — |
| B-10 | commercial | Medium commercial customers with demand 75-499 kW | TOU energy charges plus demand charge based on maximum kW during peak periods. | — |
| B-19 | commercial | Medium-large commercial customers with demand 500-999 kW | TOU energy charges with separate peak/part-peak/off-peak demand charges and voltage-level discounts. | — |
| B-20 | industrial | Large commercial and industrial customers with demand 1,000 kW or greater | TOU energy charges with tiered demand charges. Primary and transmission voltage discounts available. | — |
| E-19 | commercial | TOU version for medium-large customers (500-999 kW), mandatory TOU | Three-period TOU with seasonal peak/part-peak/off-peak energy and separate demand components. | — |
| E-20 | industrial | TOU version for large customers (1,000+ kW), mandatory TOU | Three-period TOU with voltage-level pricing. Transmission-level customers receive lowest rates. | — |
| AG-1 | agricultural | Small agricultural customers with demand under 35 kW | Flat or TOU options designed for irrigation pumping and crop processing. | — |
| AG-4 | agricultural | Large agricultural customers with demand 35-500 kW | TOU with demand charge. Multiple sub-options (A, B, C) for different usage patterns. | — |
| AG-5 | agricultural | Very large agricultural customers with demand over 500 kW | TOU with demand charge optimized for large-scale agricultural operations. | — |
Rate Recommendations by Use Case
Small Office / Retail (<75 kW)
Small commercial space — offices, small retail stores, restaurants under 75 kW demand.
B-1 has no demand charge, making costs predictable for small businesses. The flat rate structure means you do not need to worry about momentary demand spikes from equipment startups. For businesses open primarily during business hours, the simplicity of B-1 outweighs potential TOU savings.
- Monitor demand — if you consistently stay under 75 kW, B-1 avoids demand charges that B-10 would impose.
- LED lighting retrofits and smart thermostats can keep you under the 75 kW threshold.
- If your demand occasionally exceeds 75 kW, PG&E may move you to B-10 — install demand controllers to stay under.
Office / Campus + EV Chargers
Medium commercial facility with fleet EV charging or employee charging stations.
EV chargers create demand spikes that can dramatically increase demand charges on standard commercial rates. The BEV (Business EV) rate adder provides a separate meter and rate for EV charging with reduced demand charges, preventing charger spikes from inflating your building's demand bill.
- Separate EV charging on a dedicated BEV meter to isolate demand spikes from building load.
- Implement smart charging (OCPP-managed) to stagger charger starts and limit simultaneous demand.
- Consider battery-buffered chargers that charge from a battery at lower sustained power rather than hitting the grid at full L2/DC fast charge rates.
Large Building / Campus (>500 kW)
Large commercial, institutional, or industrial facility with demand exceeding 500 kW.
At this scale, demand charges often constitute 30-50% of the bill. B-19/B-20 or their TOU equivalents E-19/E-20 offer voltage-level discounts for primary or transmission service. Active demand management, on-site generation, and participation in demand response programs yield significant savings.
- Take service at the highest voltage level feasible (primary or transmission) for 5-15% lower rates.
- Implement automated demand response — PG&E Capacity Bidding Program pays $50-150/kW-year for committed load reduction.
- Sequence large motor starts and stagger HVAC compressors to shave peak demand by 10-20%.
Retail Store / Restaurant
Retail or food service business with variable demand depending on size and kitchen equipment.
Smaller locations (under 75 kW) benefit from B-1's simplicity and lack of demand charges. Larger restaurants with commercial kitchen equipment often exceed 75 kW and land on B-10. Kitchen demand management (sequencing fryers, ovens, HVAC) is critical on B-10 to control demand charges.
- Audit peak demand — if kitchen equipment pushes you over 75 kW, focus on staggering startup sequences.
- Install demand controllers that delay non-critical loads (ice machines, water heaters) during peak demand events.
- Refrigeration optimization (night curtains, EC motors, VFDs on walk-in compressors) can reduce both energy and demand.
Agricultural Operations
Farms, vineyards, and agricultural processors with irrigation pumping and crop processing loads.
Agricultural rates are specifically designed for seasonal, pump-heavy loads. AG-1 works for small operations under 35 kW. AG-4 and AG-5 offer TOU options that reward shifting irrigation to off-peak (nighttime pumping). The right AG sub-option depends on load factor and seasonal pattern.
- Schedule irrigation pumping for off-peak hours (before 8 AM or after 9 PM) to capture lowest TOU rates.
- Consider variable frequency drives (VFDs) on pumps to reduce demand charges and improve efficiency.
- Solar-powered pumping can offset daytime energy costs — AG rates pair well with behind-the-meter solar on agricultural land.
Historical Rate Trends
PG&E rates have increased significantly year-over-year since 2023, driven by wildfire liability costs, grid hardening investments, and the transition to clean energy infrastructure. Annual increases have averaged 6-8%, well above inflation.
January 1, 2023
General Rate Case Phase 2 increase. Average residential rates rose to $0.32/kWh. Wildfire mitigation surcharges expanded.
+8.2%July 1, 2023
Mid-year ERRA (Energy Resource Recovery Account) adjustment reflecting higher procurement costs from summer 2022 heat events.
+4.5%January 1, 2024
Annual rate adjustment including undergrounding program costs and Grid Safety and Resiliency Program charges. Average residential rate reached $0.36/kWh.
+7.1%January 1, 2025
Rate increase reflecting continued wildfire hardening, transmission upgrades, and clean energy procurement. Average residential rate exceeded $0.40/kWh.
+6.8%January 1, 2026
Latest General Rate Case increase. Average residential rate now $0.43/kWh. New fixed charge phase-in (income-graduated) partially offsets volumetric rate growth.
+5.9%Overall trend: Consistently increasing at 6-8% annually. PG&E's capital investment plan for grid modernization and wildfire prevention suggests continued upward pressure through at least 2028. The introduction of income-graduated fixed charges may slow volumetric rate growth slightly.
Next expected change: July 2026 (ERRA mid-year adjustment)
Cost Optimization Strategies
Given PG&E's high and rising rates, active cost optimization can yield 15-40% savings for commercial and industrial customers. The combination of TOU arbitrage, demand management, and distributed energy resources provides the highest return on investment in California.
TOU Load Shifting
For: All customer classes
Move flexible loads (HVAC pre-cooling, EV charging, thermal storage, batch processing) to off-peak and super-off-peak periods. Automated building controls can shift 20-30% of energy consumption to lower-cost periods without impacting operations.
Demand Management
For: Commercial and industrial (>75 kW)
Implement real-time demand monitoring and automated load shedding to reduce peak kW. Stagger motor starts, sequence HVAC compressors, and use demand controllers to limit coincident peak. Critical for B-10, B-19, and B-20 customers where demand charges represent 30-50% of bills.
Solar + Battery Storage
For: All customer classes with suitable roof/land
Behind-the-meter solar reduces energy purchases during high-cost daytime hours. Paired battery storage enables peak shaving (reducing demand charges) and TOU arbitrage (storing solar for evening peak discharge). Under NEM 3.0, batteries are essential to maximize solar ROI.
Demand Response Program Participation
For: Commercial and industrial (>100 kW curtailable)
Enroll in PG&E's Capacity Bidding Program (CBP), Base Interruptible Program (BIP), or third-party demand response aggregators. Earn $50-200/kW-year for committing to reduce load during grid emergencies (typically 40-80 hours/year).
Rate Schedule Optimization
For: All customer classes
Analyze 12+ months of interval data to identify the optimal rate schedule. Many customers remain on legacy or default rates that no longer match their load profile. Switching from B-19 Option A to Option R (or vice versa) based on load factor can save thousands monthly.
Power Factor Correction
For: Commercial and industrial with inductive loads
PG&E applies power factor penalties when PF drops below 0.85 (commercial/industrial). Installing capacitor banks or synchronous condensers to maintain PF above 0.95 eliminates penalties and reduces apparent power demand. Typical payback is 6-18 months.
To implement these strategies, you need your 15-minute interval data. Learn how to download Pacific Gas & Electric Co. (PG&E) interval data →
Deregulated Market Shopping
While California does not offer full retail choice, customers in PG&E territory can choose a Community Choice Aggregator (CCA) for their generation supply. CCAs purchase power on behalf of their communities, often providing higher renewable content at competitive or lower rates. PG&E continues to provide transmission, distribution, metering, and billing regardless of CCA enrollment.
How to Compare Pacific Gas & Electric Co. (PG&E) Suppliers
- 01Check if your city/county is served by a CCA — most of the Bay Area, Sacramento region, and Central Coast have CCA options.
- 02Compare the CCA's generation rate to PG&E's generation component (not the total bill). Your distribution charges remain identical.
- 03Review the CCA's renewable content — most default tiers exceed PG&E's 40% renewable mix. Premium tiers offer 100% renewable.
- 04Understand the Power Charge Indifference Adjustment (PCIA) — CCA customers pay this exit fee to PG&E for legacy procurement commitments.
- 05Enrollment is automatic if your jurisdiction joins a CCA. You must actively opt out to return to PG&E bundled service.
Contract Terms for Pacific Gas & Electric Co. (PG&E) Supply Agreements
- No contract or commitment — CCA enrollment is month-to-month with the right to opt out at any time.
- No enrollment fees or switching costs.
- Rate changes follow the same regulatory process as PG&E (CPUC-approved adjustments).
- CCAs set their own generation rates independently of PG&E, updated typically 1-2 times per year.
Common Pitfalls When Shopping Pacific Gas & Electric Co. (PG&E) Rates
- PCIA (exit fee) reduces net savings — compare the total bill, not just the generation rate.
- CCA rates can change independently of PG&E — a CCA that's cheaper today may not be next year.
- Some CCAs have limited track records — evaluate financial stability and procurement strategy.
- NEM solar customers should verify their CCA handles net billing credits correctly — most do, but the credit rate differs from PG&E's.
- Budget billing and some PG&E programs (CARE/FERA) are maintained regardless of CCA enrollment.
Frequently Asked Questions
How do I get 15-minute interval data from PG&E for my commercial building?▾
Sign in to myaccount.pge.com, navigate to Usage and rates, then click Green Button Download my data. Select the XML (ESPI) format for machine-readable 15-minute intervals, or CSV for spreadsheet analysis. For automated access across multiple meters, register as a Share My Data vendor to pull interval data via the ESPI 1.1 API with OAuth 2.0 authentication.
Can a third-party energy consultant access our PG&E billing data without our login credentials?▾
Yes. Through Share My Data (sharemydata.pge.com), your organization grants one-time OAuth authorization to a registered vendor. The vendor receives an API token — never your password. You maintain full control and can revoke access from your MyAccount settings at any time. Alternatively, submit Form 79-1095 for paper-based authorization.
How do I set up EDI with PG&E for automated invoice processing across multiple sites?▾
Contact your PG&E Account Manager to request EDI enrollment. Execute Form 79-861 (EDI Trading Partner Agreement), choose your connection method (VAN or direct SFTP/AS2), specify transaction sets needed (810 for invoices, 867 for meter data), complete 2-4 weeks of conformance testing, then cutover to production. EDI is recommended for organizations managing 10+ service agreements.
What is the fastest way to get historical usage data for a portfolio of PG&E commercial accounts?▾
The Share My Data API provides up to 4 years of historical interval data per authorized account. Register as a vendor at sharemydata.pge.com, then have each account holder authorize access via the OAuth flow. Data is available in XML (ESPI 1.1) format. For one-time bulk extraction, use the Download My Data portal with CSV export across multiple service agreements.
Does PG&E support real-time energy monitoring for demand management?▾
Yes. Stream My Data provides sub-minute electric usage data via SmartMeter devices for buildings with compatible hardware. For most C&I demand management, the 15-minute interval data available through Green Button or Share My Data (2-4 hour latency) is sufficient for load analysis, demand charge optimization, and TOU shifting strategies.
Automate Pacific Gas & Electric Co. (PG&E) Rate Analysis with Nectar
Nectar continuously monitors your Pacific Gas & Electric Co. (PG&E) rate options and alerts you when a better schedule is available. Save 10-30% on energy costs.
Nectar for Energy & Sustainability Teams
Managing utility costs for commercial or industrial buildings? Nectar offers a free rate analysis — we'll review your current rate schedules and identify where switching tariffs or shifting load can save 10-30%.
Get a Free Rate AnalysisNectar for Energy Brokers & Consultants
Advising clients on rate optimization? Nectar works with energy consultants who need reliable interval data and automated rate comparison tools.
Partner with Us