Energy and Environmental Economics, Inc.

We’re headed to Detroit for the Forth Roadmap Conference this week, Oct 14-16. E3’s Chelsea Petrenko, PhD will join the “Powering the Big Shift” panel with a range of experts working in the space: Jessie Lund, Daivie Ghosh, Alexa Voytek, and Mo Dali. They'll discuss how New York fleets can accelerate electrification - what it takes both from a technical and social perspective, and how state and utility programs can smooth the path. Roadmap Forth is a premier electric transportation conference. If you'll be there, add this session to your calendar and come say hello. https://lnkd.in/g2cWM6v5

Our latest in Utility Dive: how OBBBA, recent tariffs, and changes in tax credits are reshaping project economics, just as load from data centers and electrification accelerates. We explain why similar projects are arriving at very different prices and outline practical ways to preserve flexibility in planning and procurement: https://lnkd.in/emm7Qptm

We're kicking off our Fall 2025 recruiting with a virtual Open House for all interested applicants, across all positions! Join us to learn about life at E3, gain insights into our hiring process, and hear about the impactful work we're doing to advance the clean energy transition.   The event will include a presentation from E3 senior leadership, followed by breakout rooms with E3 consultants where you'll have the opportunity to ask questions and engage in smaller group discussions.   The Open House will take place on Wednesday, October 29, Noon PT / 3pm ET. Register here: https://lnkd.in/gchPNnPB

SPP’s reliability needs are shifting as winter risk grows and new data centers drive load across the region. Our new white paper looks at how much demand response (DR) should “count” toward keeping the lights on, using the same ELCC approach SPP applies to wind, solar, and storage. We focus on event-based DR where customers agree ahead of time to reduce load when called and performance is measured, so planners can rely on it. What we find is that increment of DR matters most. At 2 GW of enrollment in 2025, a 4-hour DR program earns about 83% in summer and 55% in winter, while a 10-hour program earns about 100% and 82% because it can ride through long winter stretches. By 2030, as the resource mix changes and high-risk periods last longer, the 10-hour program holds its value while the 4-hour program declines. On average, the system needed about ten total DR hours per year in our simulations, so seasonal call caps usually aren’t binding at today’s scale. Read the blog and full paper here: https://lnkd.in/gH6FWpCR

2025 has been a very busy year for Energy and Environmental Economics, Inc., especially for our Asset Valuation and Market Advisory practice. We have been working with our clients on a number of fronts including evaluating and supporting investments into data centers, transmission, renewables, energy storage, and thermal generators. As part of that work I'm pleased to announce that E3 recently supported KKR as market advisor on its recent acquisition of 50% of TotalEnergies’ 1.4 GW Solar Portfolio in North America. E3 is grateful for the opportunity to leverage its market expertise, views, and suite of forecasting tools to support clients making high quality investments into the North American power sector. For more information on the transaction see: https://lnkd.in/gskcSvx5 and https://lnkd.in/gf3jT-tT   #EnergyMarkets #Renewables #Solar #Infrastructure #PrivateEquity #ProjectFinance #PowerSector #EnergyTransition #MarketAdvisory

An Energy and Environmental Economics, Inc. analysis of the state of resource adequacy in the Pacific Northwest projects a stark resource shortfall beginning in 2026 and reaching nearly 9 GW by 2030—or about the size of Oregon’s entire energy load. https://lnkd.in/gtwTKjTb

Maine’s electric grid is facing pressures: aging infrastructure, rising electricity, and the integration of renewable energy resources to meet the state’s Renewable Portfolio Standard (80% clean energy by 2030). New transmission lines would help address these challenges, but are capital-intensive and often face long lead times for planning, permitting, and construction. One way to get more out of the *existing* grid is through Grid-Enhancing Technologies (GETs), which can improve efficiency and performance and, in some cases, help defer the need for costlier upgrades.   E3 evaluated GETs for the Maine Public Utilities Commission and found potential long-term value. While they're not a substitute for all transmission investments, targeted deployments can alleviate congestion and facilitate Maine’s renewable energy targets at a fraction of the cost of rebuilding power lines. Read more: https://lnkd.in/g2Q6FZtJ

E3’s 2025 Core Case forecasts, fully incorporating OBBBA, map how policy shifts and structural load growth will shape energy, capacity, ancillary service, and REC prices through 2055 across every major North American market. In our new Utility Dive piece, we walk through case studies in ERCOT, PJM, WECC, MISO, and NYISO, spotlighting data center load growth, tightening reliability and capacity conditions, rising REC prices, and the launch of EDAM and Markets+. Read the story: https://lnkd.in/gZ9ZPg7a

Somehow Arne Olson and I had never crossed paths in person until meeting at NewsData's Western Energy Summit. And then, along with Jason Fordney, we recorded a podcast live on stage before a lunchtime audience! Even if you missed the conference, you can listen to Arne's insights on the latest episode of People in Power.

📢 E3’s new white paper, Unlocking the Value of Smart Panels, quantifies how SPAN® Edge ISP can deliver measurable customer and grid benefits when strategically deployed under a utility ownership model. Key findings from the representative feeder analyzed include: ✔️ $7.9K–$8.1K per-device customer benefits, driven by avoided panel upgrades and TOU savings ✔️ $3.2K–$10.6K utility benefits per device, primarily from deferred grid upgrades ✔️ $14K+ total net benefits (customer+utility) per device, with TRC ratios between 3.8 and 6.5 ✔️ $101K–$1.16M in avoided secondary distribution costs per feeder from deferred transformer upgrades and service extension allowances Smart panels can enable reliable load control at the household level, reducing grid strain and accelerating electrification. They represent one pathway for utilities to manage rising demand while keeping infrastructure costs down. Read the full paper (funded by SPAN, analysis and conclusions by E3) here: https://lnkd.in/gczTjhnN