PG&E Electrical Service Requirements and Standards

Pacific Gas and Electric Company (PG&E) serves approximately 5.5 million electric customer accounts across a 70,000-square-mile service territory in Northern and Central California, making its technical service standards among the most consequential utility specifications in the state. The requirements governing how electrical systems connect to PG&E infrastructure are defined in published documents known as Electric Rules, which establish voltage levels, metering configurations, service entrance specifications, and interconnection conditions. These standards interact directly with the California Electrical Code and state regulatory frameworks, and non-compliance at the utility interface can delay or permanently block project energization.

Definition and scope

PG&E's electrical service requirements are the technical and administrative conditions that a customer's electrical installation must satisfy before PG&E will extend, maintain, or modify a service connection. These requirements are codified in PG&E's Electric Rule No. 2 (Definitions), Electric Rule No. 15 (Service Extensions), and Electric Rule No. 16 (Service Connection and Meter Installation Requirements), all of which are filed with and approved by the California Public Utilities Commission (CPUC).

The scope of these standards covers:

• Service entrance equipment — the physical point at which PG&E's distribution system terminates and customer-owned wiring begins
• Metering requirements — meter base dimensions, socket configurations, and CT (current transformer) cabinet specifications
• Voltage and phase configurations — available service types by voltage class and customer load category
• Load addition and upgrade procedures — the formal process for increasing service capacity or modifying the point of delivery
• Interconnection requirements — conditions applicable to distributed generation, storage, and net energy metering (California Net Metering Electrical Impact)

PG&E's rules apply only within its certificated service territory. Adjacent investor-owned utilities — Southern California Edison and San Diego Gas & Electric — publish separate and independently structured service requirements; overlap with SCE or SDG&E territories is not covered here. Municipal utilities such as SMUD and LADWP operate under distinct regulatory frameworks and are outside the scope of this page.

How it works

Connecting to or upgrading a PG&E electrical service follows a structured sequence with discrete phases, each subject to approval before the next phase begins.

1. Load data submittal — The customer or licensed electrical contractor submits load calculations to PG&E demonstrating that the proposed service size is appropriate. PG&E uses these figures to determine whether existing distribution infrastructure can support the requested capacity.

2. Application for service — A formal service application is filed, specifying service voltage (commonly 120/240V single-phase for residential, or 120/208V and 277/480V three-phase for commercial and industrial loads), phase configuration, and metering class. PG&E Electric Rule No. 15 governs cost responsibility for service extensions; facilities charges may be assessed when new infrastructure must be built.

3. Design approval — For commercial, industrial, or complex residential projects, PG&E's construction department reviews single-line diagrams to confirm that service entrance equipment, metering enclosures, and clearance zones meet Rule 16 specifications.

4. Site preparation and inspection — The customer installs service entrance equipment to PG&E specifications, obtains a local building permit, and passes the Authority Having Jurisdiction (AHJ) inspection. The California Electrical Inspection Process (California Electrical Inspection Process) requires a signed-off job card before PG&E will schedule a meter set.

5. PG&E field verification — A PG&E field representative verifies that meter base configurations, grounding electrode systems, and clearance distances comply with Rule 16 before authorizing meter installation.

6. Energization — Following field verification, the meter is set and service is energized. For interconnected systems with solar or storage, interconnection agreement execution precedes this step.

Common scenarios

Residential service upgrade (100A to 200A or 400A)
Panel upgrades require a new or revised meter base that accepts the correct PG&E meter socket configuration. For single-family dwellings, Rule 16 requires meter bases mounted outdoors at specified heights (typically 4 to 6 feet to center of meter socket) with a clear working space of not less than 3 feet, consistent with California Electrical Panel Upgrade Requirements.

New commercial three-phase service
Commercial loads above 200A typically require a CT metering installation. PG&E specifies CT cabinet dimensions, wiring configurations, and sealing requirements. The metering compartment must be accessible to PG&E personnel at all times without entering customer space.

Solar PV and battery storage interconnection
Distributed generation systems must comply with PG&E's Wholesale Distribution Tariff or the Rule 21 interconnection tariff, depending on system size. Systems under 1 MW typically follow the Rule 21 simplified process. California Energy Storage Electrical Systems and California Solar Electrical Requirements address these configurations in greater technical detail.

EV charging infrastructure
High-capacity EV charging installations — particularly DC fast chargers drawing above 100 kW — often require a dedicated service point or load addition application. PG&E's Electric Vehicle programs publish load management specifications that interact with Rule 15 cost-of-extension obligations. See California EV Charging Electrical Requirements.

Temporary construction service
Temporary service connections must satisfy Rule 16 metering and grounding requirements even for short-duration installations. Grounding and bonding specifications are addressed in California Electrical Grounding and Bonding Requirements.

Decision boundaries

Several threshold conditions determine which PG&E process path applies and what level of engineering review is required.

Contractors and engineers navigating PG&E-specific requirements operate within the broader regulatory framework described at /regulatory-context-for-california-electrical-systems. The full spectrum of California utility interconnection rules, including coordination between local jurisdictions and investor-owned utilities, is covered under California Utility Interconnection Requirements.

Projects located in PG&E's High Fire Threat Districts (HFTDs) — a zone classification maintained by the CPUC under General Order 95 and General Order 128 — face additional overhead conductor and equipment hardening requirements. These wildfire-specific overlays are addressed separately in California Electrical Wildfire Safety Requirements.

The californiaelectricalauthority.com reference network covers all major California investor-owned utility territories and provides structured access to licensing, permitting, and code compliance information across the state's electrical sector.

References

• Pacific Gas and Electric Company Electric Tariff Rules (CPUC-filed)
• California Public Utilities Commission — Electric Utilities
• CPUC General Order 95 — Rules for Overhead Electric Line Construction
• CPUC General Order 128 — Rules for Underground Electric Line Construction
• PG&E Rule 21 Interconnection — Distributed Generation
• California Code of Regulations, Title 8 — Electrical Safety Orders (Cal/OSHA)
• NFPA 70: National Electrical Code (2023 Edition) — adopted by reference in California