The Intersolar North America and Energy Storage North America 2023 conference program will highlight the readiness of solar and storage as available and immediate climate solutions. The program will also emphasize how grid electrification is a pillar of climate response strategies, in addition to the integral role solar and storage play in that transformation.
These 5 Session Spotlights are examples of the types of sessions that will be included in the 2023 conference program.
Presented by Adam Gerza, VP Business Development, Energy Toolbase
There are several powerful dynamics influencing California’s energy storage market today. With both headwinds and tailwinds, many evolving over time, it has become increasingly difficult to predict what the future of California’s energy storage system (ESS) market holds.
The Energy Toolbase team has compiled data from both internal and external sources to provide a state of the union on California’s energy storage market, unpacking the direct impacts of the most influential factors, including:
Overall, we are bullish and optimistic about the future growth of the energy storage market in California. Our ETB Developer platform data, which is a leading indicator, continues to show strong and consistent growth for ESS modeling activity across all metrics. The extension of the ITC via the IRA, the NEM-3 outcome creating a stronger price signal for ESS, retail electric rates continuing to inflate, and developers becoming more experienced. We fully expect ESS deployments and attachment rates to continue rising. That said, there are still looming headwinds that must be considered with the sunsetting of the SGIP incentive program, along with current ESS supply chain challenges.
Supply chain challenges and federal funding are reinforcing the value of reinvest in America’s clean energy workforce. This panel brings together perspectives from labor, industry, and leading labor economists to discuss the transition of the clean energy workforce, and key steps needed to realize this transition, including community engagement, training programs, and partnerships.
Moderated by Ed Burgess, Policy Director, Vehicle-Grid Integration Council (VGIC)
Other panelists TBA
As the grid becomes more electrified, electric vehicles will have a role to play in storing and releasing excess energy to the grid. We have already seen the use of time-of-use rates for EV charging to help shave demand peaks on the grid, but how else can we utilize EVs for the grid of the future?
This panel will discuss the existing policy and technological landscape around EVs as a storage resource before delving into how we can better utilize EVs as a way to handle additional demands on the grid, addressing:
Presented by Jesse Cruce, Energy & Policy Market Analyst, Strategic Energy Analysis Center at National Renewable Energy Laboratory (NREL)
This session covers NREL’s work evaluating residential PV adoption timelines and permitting/interconnection processes. The work utilizes project-level data covering 10-25% of U.S. installs each year 2017-2021, along with surveys of jurisdictions and installers. Questions of interest include:
Initial results from NREL’s collaborative development of the SolarAPP+ automated permitting platform will also be presented.
Presented by Jay Sandler, Distributed Energy Operations Manager, Duke Energy Corporation
Other panelists TBA
Battery energy storage is an evolving market and the fire safety aspect of this technology has become an emergent, hot topic in the utility industry. This session will hear from a variety of different utilities across the country, discussing their experiences and case studies with battery storage development and operation and the associated steps they are taking for fire safety. The session will cover best practices for storage container design, fire safety specifications, and fire safety trainings. Furthermore, speakers will evaluate the dangers of Li-ion batteries, lessons learned from industry fire safety events, utility safety systems that utilities have deployed at current battery sites, and utility first responder training programs.
Presented by Nehal Divekar, Manager, Emerging Technologies, Customized Energy Solutions
Other panelists TBA
A Virtual Power Plant (VPP) is a network of decentralized, medium-scale power generating units as well as flexible power consumers and storage systems. VPPs are managed via aggregation software, offering functions meant to mimic those of a traditional power plant control room. Depending on the particular market environment, VPPs can accomplish a whole range of tasks. In general, the objective is to network distributed energy resources such as wind farms, solar parks, and Combined Heat and Power (CHP) units, in order to monitor, forecast, optimize and trade their power. This way, fluctuations in the generation of renewables can be balanced by ramping up and down power generation and power consumption of controllable units. But the VPP not only helps stabilizing the power grids. It also creates the preconditions for integrating renewable energies into the markets. Individual small plants can in general not provide balancing services or offer their flexibility on the power exchanges. This is because their generation profile varies too strongly or they simply do not meet the minimum bid size of the markets. By aggregating the power of several units, a VPP can deliver the same service and redundancy and subsequently trade on the same markets as large central power plants or industrial consumers.
This session will cover the basics of what a virtual power plant is and how it can create value for both utilities and customers, with examples from real-world programs.
Moderated by Gary Dorris, CEO, Ascend Analytics
Other panelists TBA
Competitive power markets offer a unique opportunity to utilize storage as a physical hedge to serve financial firm obligations of a power hedge. On both a stand-alone basis or in conjunction with renewable generation, storage serves as a physical hedge that can secure the equivalent of a contracted revenue stream using over-the-counter hedges.
This presentation provides a case study for operating margins and risk of renewable plus storage projects hedged with market forward contracts and compares the outcome relative to a long-term Power Purchase Agreement (PPA). The analysis examines the optimal hedge ratio, reduction in risk, and the added premium of flexible storage serving as a physical hedge against spot market prices for both standalone storage and renewables plus storage. The comparison to PPAs will be based on utility procurements.