PS2. Avoiding installation delays for public and fleet charging due to capacity constraints

PG&E is deploying systems that are able to dynamically limit power flow to public and fleet charging based on system constraints; however, not all existing charging equipment has the ability to respond to PG&E's signals by modulating load within these dynamic constraints or by utilizing alternate sources (e.g., storage) to meet load. 

Why is this important?

PG&E is actively supporting fleet electrification, but capacity constraints in the electrical system can result in delays while necessary upgrades are completed. To address this, PG&E is deploying systems that allow dynamic load management within the limits of the current infrastructure. These systems require charging equipment to respond to signals that adjust power usage as capacity fluctuates. As we scale public and fleet EV charging, we will need circuits that are capable of handling the load of large-scale charging infrastructure. We may also need to more dynamically manage these circuits which will require public and fleet charging customers who can operate within dynamic constraints. Both elements are critical to help California achieve its goal of transitioning 100% of medium- and heavy-duty vehicles to zero-emission vehicles (ZEVs) by 2045.

What is the current state and its primary limitations?

PG&E is in the process of deploying dynamic systems to manage capacity on constrained circuits, allowing for the connection of new EV charging infrastructure (both DCFC and L2) while larger-scale upgrades are being implemented. To fully benefit from this approach and connect to constrained circuits sooner, all charging equipment must be capable of flexibly adjusting power draw as system conditions change. Additionally, in situations where grid power is restricted or unavailable, alternative energy sources such as storage may be needed to meet demand during vehicle charging.

Primary limitations include:

• Lack of ability to ingest and respond to real-time signals to modulate load at scale to match capacity on a near real-time basis
• Limited integrated demand-offsetting solutions to reduce dependency on grid during times of constrained capacity 

What are the desired outcomes from R&D?

Novel technologies, including AI/ML, to:

• Enable customers to adjust consumption based on a real-time or near real-time signal from PG&E
• Enable customers to more seamlessly integrate DERs as a demand offsetting solution when grid capacity is limited, such that power needs can be met by a dynamic mix of energy resources as conditions on the grid change

PS3. Detecting and forecasting customer-led appliance electrification to support zonal electrification efforts

• Customer-led appliance replacement, which is often invisible to the utility, presents key challenges to both zonal electrification and capacity upgrades, especially without real-time tracking and forecasting tools. Water heaters, space conditioning equipment, cooking appliances, and dryers are often being replaced without utility coordination, causing localized electric load spikes that outpace capacity planning tools
• Gas throughput declines in pockets that are not targeted for decommissioning, which may signal shifting demand patterns and pose stranded asset risk
• End-of-life appliances (both gas and electric) represent a pivotal intervention point, but PG&E has limited visibility into when and where these transitions will occur
• Equity gaps widen when select customers electrify independently, while low- and moderate-income (LMI) households miss out on neighborhood-scale programs that lower costs through coordinated, zonal electrification
• Zonal electrification models cannot succeed without full visibility into surrounding load changes and appliance lifecycles that may occur adjacent to, or outside of, defined zones

The utility’s existing planning and customer engagement frameworks are not equipped to capture behind-the-meter, appliance-level changes in a timely or predictive manner.

Primary limitations include:

• No real-time tracking of uncoordinated appliance upgrades or replacements, especially for major loads like heat pump water heaters or space conditioning heat pumps
• Lack of predictive appliance lifecycle models to estimate when gas or electric devices may be reaching end-of-life and vulnerable to unplanned replacement
• Lack of dynamic modeling across zones means that electrification in adjacent neighborhoods may overload feeders or transformers without warning
• Lack of clear feedback loops between gas throughput decline due to electrification resulting in missed signals for grid and customer interventions

• ML models that identify neighborhoods heading toward mandatory electrification and forecast feeder-level load impacts by disaggregating demand load to identify types of appliances
• Dynamic load modeling platforms, including AI/ML, to detect emerging electrification trends in real time (e.g., AMI load signatures of new electric appliances, or unexpected gas use declines) to plan for cost-effective electrification
• Geospatial electrification detection to identify load shifts in areas not explicitly targeted for programs, particularly in surrounding or adjacent feeder zones
• Appliance lifecycle forecasting tools that predict end-of-life timelines across customer segments for both gas and electric devices, to proactively engage customers, particularly LMI households, at key decision points

PS4. Enhancing broad customer resiliency and grid benefits with utility-owned batteries

Since 2020, PG&E has offered back-up power battery programs to address the frequent outages affecting thousands of customers annually as a result of the Community Wildfire Safety Program, which includes planned Public Safety Power Shutoff (PSPS) events and unplanned Enhanced Powerline Safety Setting (EPSS) outages. PG&E aims to provide backup power resources for these customers while also gaining additional benefits from these resources, such as grid benefits and load management opportunities that would benefit all customers, not just those impacted by outages.

PG&E is providing single permanent battery installations at roughly 13 to 15 kWh, not paired with solar. These installations offer partial mitigation for three to six-hour EPSS outages.

Primary limitations include:

• This is costly on a per-customer basis and does not provide a whole-home solution
• This is not typically used beyond backup power resiliency and therefore does not offer grid benefits or load management opportunities for the broader customer base

• Exploring clean energy technical solutions to provide both resiliency and load management grid benefits for residential customers. This can include technologies beyond batteries, both behind the meter and front of the meter solutions
• Evaluating various products and technologies that can offer scalable backup power resources, supporting either whole home or partial home backup, and grid benefits beyond just resiliency
• Understanding the capabilities of different products in terms of load management services and their ability to receive signals for grid benefits
• Identifying innovative solutions for customer outreach, acquisition, site assessments, permitting, and installation processes
• Understanding of safety performance testing results and industry certifications as applicable, and indicative pricing if available, for the technologies presented