Lede: The week’s defining development was the $67 billion NextEra–Dominion merger announced May 18 — the largest utility consolidation in U.S. history — which crystallized the year’s dominant theme: AI data-center load growth is now the primary force reshaping DER strategy, capacity markets, and demand-side resource valuation. That theme ran through nearly every daily entry, from MISO’s projection of 35% peak-load growth by 2035 and PJM’s three-pathway capacity-market overhaul, to Eversource’s contrarian decision to “resist” data centers, to Pennsylvania’s first-of-its-kind large-load cost-causation tariff. Against this backdrop, the policy and market case for distributed resources strengthened on multiple fronts: the Pew Charitable Trusts published a national DER playbook quantifying VPPs at 40–60% the cost of conventional peak capacity, SEIA/Benchmark reported a record 9.7 GWh storage quarter, and New York, California, Texas (Austin), and New Jersey each advanced concrete residential-battery and storage-procurement frameworks. The deployment-speed advantage of demand-side resources — months versus the 5–10 year timelines for gas turbines and transmission — was the connecting logic across the week’s regulatory, market, and utility-program news.
All five weekday entries (Mon May 18 – Fri May 22) were present in the research log; no daily runs were missing.
🔋 Energy Storage
U.S. storage market sets a record quarter; 2030 forecast revised upward to 610+ GWh. The SEIA/Benchmark Mineral Intelligence Q1 2026 Energy Storage Market Outlook reported 9.7 GWh installed in Q1 2026, a 32% year-over-year jump and a new quarterly record (utility-scale 7.8 GWh; C&I 648 MWh; residential 515 MWh). Full-year 2026 deployments are projected at 35 GW/70 GWh (~$25.2B capital investment), nearly double the record 28 GW/57 GWh of 2025, with cumulative installations now forecast to exceed 610 GWh by 2030. Growth drivers cited: AI data-center demand for both utility-scale and behind-the-meter storage, electricity-price volatility creating merchant revenue, and gas/gas-turbine supply-chain disruptions extending conventional generation lead times to 5+ years. Notable structural signals: data centers could account for 83% of behind-the-meter C&I storage by 2030; 71% of Q1 2026 utility-scale installs occurred in Republican-led states (Texas overtook California by GW deployed); residential storage faces a potential Section 25D tax-credit headwind, partly offset by active state VPP programs (MA, CA, TX, AZ, CO). (Storage procurement also features heavily in New Jersey and Minnesota items — see Regulatory & Policy and Utility Programs sections.)
☀️ Distributed Solar & Community Solar
New Jersey expands community solar to a record 3 GW. As part of the BPU’s broader affordability strategy (referenced Thu), New Jersey expanded its Community Solar Energy Program to a record 3 GW allocation with a guaranteed 20% bill credit, reserving 50%+ of capacity and 25% of credits for low- and moderate-income households. (Standalone distributed-solar news was light this week; most solar activity appeared in solar-plus-storage and residential-battery contexts — see VPP & Demand Flexibility.)
⚡ Virtual Power Plants (VPP) & Demand Flexibility
The VPP market is “broadening faster than deepening.” Utility Dive’s 2026 DER outlook, drawing on Wood Mackenzie data, found North American VPP capacity grew only 13.7% to 37.5 GW even as active deployments, offtakers, and monetized programs each grew 33%+ — evidence of breadth without depth, attributed to pilot-phase limits and weak compensation. EnergyHub’s “Huels Test” rated even the most advanced VPPs at ~2 on a 0–4 maturity scale versus a gas-peaker benchmark, while DOE’s Jen Downing noted VPPs are already cost-effective for peak reductions up to 20%. State momentum is accelerating (NJ VPP mandate; Illinois VPP tariff filing deadline June 1; Massachusetts 3.5 GW load-management target; Minnesota’s $430M/200 MW Xcel program). Headwinds noted: PJM raised demand-side ELCC from 69% to 92% but narrowed eligibility, and Monitoring Analytics tied an estimated $16.6B in excess capacity costs to historically poor DR performance.
New York becomes the first state to condition battery incentives on grid service (BYOB). The NY PSC (April 16) mandated Bring-Your-Own-Battery enrollment in utility Dynamic Load Management programs for all NYSERDA-incentivized residential batteries across IOU territories — staggered rollout (National Grid/NYSEG/RG&E from March 1; Orange & Rockland from May 1; Con Edison later in 2026; Central Hudson TBD). Compensation runs ~$50/kW-year (~$180/yr for a typical 13.5 kWh system); an OEM onboarding grace period (Tesla, FranklinWH, Enphase, SolarEdge) runs through June 1, 2026. The design directly targets the “free rider” problem and builds the enrolled asset base for FERC Order 2222 aggregation ahead of ISO-NE’s Nov 1, 2026 deadline.
Austin Energy launches the first major municipal-utility VPP-aligned battery DR pilot in ERCOT. The Power Partner Battery pilot (March 24) targets 1,500 residential systems with a dual-incentive structure ($500 upfront + $300+/yr performance), supporting Tesla, FranklinWH, SolarEdge, and Enphase — the same OEM ecosystem New York is onboarding. Austin set explicit DR capacity targets of 78 MW by 2027 and 270 MW by 2035, testing VPP economics in ERCOT’s energy-only market (no capacity payments; value via energy arbitrage and ancillary services).
California advances an ownership-neutral path to make distributed batteries Resource Adequacy capacity. SB 913 (Sen. Becker, March 24; passed Senate Energy Committee April 7, now in Appropriations) would require the CPUC to update RA rules so aggregated DERs — home batteries, EVs, smart thermostats — qualify alongside conventional generation, with device-level performance measurement. In parallel, Ava Community Energy’s $11.25M SmartHome Battery program offers tiered rebates ($500/kWh income-qualified; $90/kWh others) plus $3/kWh/month participation. California is adding ~8,000 batteries/~100 MW per month, a base that could deliver meaningful RA within 12–18 months of enactment.
Front-of-meter, community-scale storage framed as the fastest path to capacity. Former DOE Loan Programs Office director Jigar Shah argued (op-ed, May 5) that 1–10 MW distribution-connected solar-plus-storage is the quickest, cheapest tool to meet ~128 GW of new five-year demand, given ~8-year average PJM transmission interconnection queues. Economic anchors cited: DOE estimate of $10B/yr national VPP savings; Massachusetts finding that ~1,800 MW of optimized distributed storage/solar yields $2.3B in ratepayer savings; and national modeling of up to $170B cumulative savings from shifting ~20% of peak. (The CERAWeek 2026 EPRI flexibility initiative referenced here appears in the EPRI Research Spotlight below.)
🔌 DERMS & Grid Integration Technology
DERMS crosses from niche grid-edge tooling to mainstream utility infrastructure spend. Two independent May 2026 market analyses converge on a global DERMS market of ~$1.7B in 2026 growing to $5.5B by 2033 (18.3% CAGR) — among the fastest-growing utility OT segments, outpacing SCADA/EMS refresh and ADMS deployment rates. Growth is driven by accelerating DER interconnection (217 GW of new capacity projected through 2028, per Pew — referenced Fri), smart-grid modernization funding, corporate sustainability mandates, and the need for real-time orchestration of heterogeneous EV/battery/inverter/flexible-load fleets. Platforms are expanding from monitoring into active VPP dispatch, microgrid islanding, and wholesale ancillary-services participation (EnergyHub cites 50+ utility DERMS deployments). Interoperability frameworks — IEEE 2030.5, OpenADR, and emerging CSIP-AUS — are flagged as critical adoption enablers. (NERC IBR reliability-standard timelines that bear directly on DERMS design appear under Regulatory & Policy.)
📋 Regulatory & Policy
Pew publishes a national DER policy playbook. The Pew Charitable Trusts’ report (April 28) is the most comprehensive nonpartisan framework to date for scaling DER/VPP deployment: VPPs at 40–60% the cost of conventional peak capacity; less than 20% of existing DER capacity enrolled in VPPs (2024); 217 GW of new DER projected 2024–2028 (more than 2x forecast data-center demand through 2035); and IOU grid spending of $1.1 trillion planned 2025–2029. Its six recommendations span three goals — integrating DERs into utility planning (including aligning utility financial incentives with DER deployment), reducing barriers (permitting/interconnection), and strengthening resilience — each mapped to market structure, action authority, and action type for cross-jurisdictional use.
Morgan Lewis maps five converging federal regulatory tracks through 2030. The analysis ties together Order 841 (100 kW storage wholesale threshold), Order 2222 DER aggregation (implementation: ISO-NE Nov 2026, PJM Feb 2028, MISO June 2029, SPP Q2 2030), data-center co-location rulemaking (DOE ANOPR Oct 2025; PJM directed to create new transmission-service alternatives), the DC Circuit’s post-Chevron affirmation of FERC’s QF “send out” policy (hybrid solar+storage >80 MW nameplate can qualify if grid output ≤80 MW), and NERC’s IBR reliability standards under Order 901 — remaining standards filed through late 2026, full implementation required by January 1, 2030.
FERC commits to a June 2026 decision on large-load interconnection. Chairman Laura Swett confirmed FERC will act by end of June on DOE’s Section 403 ANOPR for loads exceeding 20 MW (capturing virtually all data-center interconnections), building on precursor actions — the December 2025 PJM colocation order and January 2026 approval of SPP’s High Impact Large Load (HILL) initiative. The central design constraint is preserving clear federal-state jurisdictional boundaries, which will determine whether distribution-connected DER aggregations (state) and transmission-connected large loads (federal) are treated symmetrically on cost/benefit allocation.
PJM floats three pathways to overhaul its capacity market. PJM’s May 6 white paper, “Powering Reliability Through Market Design,” responds to “unsustainable stress” and a “credibility trap” after capacity prices surged over 1,000% across the last two Base Residual Auctions: Path A (stabilize via long-term bilateral capacity contracts; 2026–2029), Path B (differentiate reliability by customer class, letting large data centers self-procure; pilots 2027–2030), and Path C (shift price signals to energy/ancillary-services markets with a residual capacity backstop; 2028+). Chairman Swett separately questioned whether PJM is “too big to function,” adding a governance dimension.
Pennsylvania issues a first-of-its-kind large-load model tariff. The PA PUC’s final order (May 13) establishes a nonbinding “but-for” cost-causation standard requiring customers exceeding 50 MW individually / 100 MW in aggregate to fund triggered grid upgrades via Contributions in Aid of Construction, with a six-month study timeline and financial-security provisions. SEPA data shows 29 large-load tariffs approved in 2025 (versus 14 total in 2018–2024) and 75+ pending/active across 36 states — a national trend toward cost-causal regulation that sharpens the non-wires-alternative case. EDF praised the cost framework but flagged the absence of interruptible-service provisions.
New Jersey BPU details a three-pillar affordability counter-offensive. Facing the steepest residential price increase nationally (16.9%, ~$260/household), BPU President Guhl-Sadovy outlined: (1) bill assistance for 3.9M accounts; (2) accelerated storage/solar — Garden State Energy Storage Program Tranche 1 awarded 355 MW (projected $169M ratepayer savings) with Tranche 2 (645 MW) launched toward the 1 GW mandate, plus the 3 GW community-solar expansion; and (3) structural reform — a successful FERC challenge to PJM’s “de minimis” transmission cost-allocation rule (hundreds of millions in refunds) and a launched utility business-model modernization study (PBR, multi-year rate plans; consultant study due summer 2026). (California SB 913 and New York’s BYOB mandate are regulatory actions covered under VPP & Demand Flexibility above.)
🏭 Utility Programs & Deployments
NextEra to acquire Dominion in a $67B deal — the largest U.S. utility consolidation in history. The all-stock merger (announced May 18) combines the world’s largest renewable/storage generator with the utility serving northern Virginia’s data-center corridor: ~110 GW generation, a 130 GW large-load pipeline, and ~10M customers across FL, VA, NC, SC. The combined entity would span PJM (Virginia) and non-RTO (Florida) footprints — requiring DERMS orchestration across different market structures and harmonization of FPL’s utility-scale battery program with Dominion’s 450 MW VPP pilot. Regulatory approval (FERC, VA SCC, NC UC, FL PSC) is expected to take 12–18 months.
PSEG: nuclear outlook improves, but near-term capacity gap favors demand-side resources. On its Q1 call (May 5), PSEG confirmed New Jersey’s lifted nuclear moratorium and new task force, but stressed no project proceeds without federal support and hyperscaler offtakes. Its data-center pipeline (~11 GW) carries a 10–20% expected conversion rate (~1.1–2.2 GW actual). PSEG called PJM’s ~15 GW reliability backstop auction unlikely to be a “game-changer” because the 2031 online requirement excludes slow-to-build gas — directly validating the months-not-years deployment edge of storage and DR. The BPU’s concurrent utility business-model review could shift incentives away from capital toward customer outcomes.
Eversource takes a contrarian “resisting data centers” stance. On its Q1 call (May 7), CEO Joe Nolan said the company is “resisting data centers,” arguing computational loads are “of no value” to existing customers and would raise prices across CT, MA, NH (~4M customers) — the most explicit anti-data-center position from a major U.S. utility CEO, contrasting with PPL (28.3 GW pipeline), AEP, and Dominion. Eversource points to 700 MW Revolution Wind + 800 MW Vineyard Wind as its preferred supply path; for New England DERMS planners, the stance aligns with the approaching ISO-NE Order 2222 deadline (Nov 1, 2026).
MISO projects 35% peak-load growth by 2035. MISO’s updated long-range forecast sees peak demand rising from 121 GW (2025) to ~163 GW (2035) at ~2%/yr, with data centers (18% CAGR) reaching 20% of regional electricity by 2030 (25% by 2040), concentrated in Illinois, Indiana, and Michigan. With 8–14 GW of data centers expected to interconnect in 2026–2027 — far faster than the 5–10 year timelines for new generation/transmission — the forecast strengthens the demand-side bridge case (at ~$66/kW-yr Brattle capacity value, a 1 GW DR portfolio ≈ $66M/yr avoided capacity cost).
Minnesota PUC approves Xcel’s $430M utility-owned distributed-storage program — and reignites the ownership debate. Capacity*Connect Phase 2 (approved April 2) authorizes 50–200 MW of utility-owned distributed batteries at up to $430M over five years. SEIA, MnSEIA, and CCSA criticized it as the only U.S. distributed-storage model with a cost-benefit ratio below one, placing investment risk on ratepayers rather than competitive private capital; the PUC also declined to advance a behind-the-meter VPP program. The PUC required an evaluation plan within 180 days and DER-benefit estimates by November 2027 — a direct contrast with California’s ownership-neutral SB 913 approach.
🔬 EPRI Research Spotlight
EPRI-led CERAWeek 2026 flexibility-standardization initiative gains 30+ backers. Referenced in Jigar Shah’s May 5 op-ed (logged Tue), more than 30 major players — utilities, ISOs, hyperscalers, and technology providers — backed an EPRI-led effort to standardize how grid flexibility is defined and measured to accelerate “time to power,” reflecting consensus that current planning over-relies on worst-case assumptions and undervalues capacity already available in existing distribution infrastructure. This was the week’s primary EPRI signal and is directly relevant to utility flexibility-procurement and DERMS measurement-and-verification design.
🚩 Utility-Sector Relevance Flags
⚑ FERC June 2026 Large-Load Interconnection Decision
Topic: Regulatory / Interconnection
Relevance: A federal framework for connecting >20 MW loads will compress utility timelines to integrate large loads into distribution plans and define whether state-jurisdictional DER aggregations get symmetric cost/benefit treatment versus federally jurisdictional large loads. The jurisdictional line drawn here directly shapes downstream DERMS and DR program design across every RTO.
Action Signal: Engage — A decision is imminent; regulatory affairs teams should be positioned to respond and, where possible, comment on jurisdictional treatment of DER aggregations.
⚑ PJM Capacity-Market Overhaul (Three Pathways)
Topic: Regulatory / Market Design
Relevance: The single most consequential market-design proceeding for DSM/DR business cases in PJM’s 65M-customer footprint. Each pathway changes how VPPs and DR are compensated — Path A could stabilize multi-year DR revenue; Path B could make demand-side resources the primary capacity mechanism for non-data-center load; Path C shifts value from capacity to energy/ancillary services, favoring fast-response batteries over passive load reduction.
Action Signal: Engage — Participate in the stakeholder process now; portfolio strategy should be stress-tested against all three pathways.
⚑ NERC IBR Reliability Standards — Jan 1, 2030 Implementation
Topic: DERMS / Compliance
Relevance: Remaining standards file through late 2026 with full implementation by January 1, 2030. Any DERMS platform or inverter-based resource deployed today must be specified for forward-looking IBR ride-through and data-reporting obligations — a direct procurement requirement, not a future concern.
Action Signal: Implement — Bake IBR compliance capability into current DERMS/inverter RFPs and asset specifications.
⚑ Pennsylvania “But-For” Large-Load Tariff (National Template)
Topic: Regulatory / Cost Causation
Relevance: Cost-causal large-load tariffs (29 approved in 2025; 75+ across 36 states) make the marginal cost of serving new large loads transparent, directly strengthening the non-wires-alternative business case — a fraction of a multi-hundred-million-dollar upgrade redirected to DR/storage can provide equivalent relief faster.
Action Signal: Watch — Track adoption in your jurisdiction; use the cost-transparency framing to anchor NWA proposals. Engage if a tariff is under development in your state.
⚑ New York Mandatory BYOB Enrollment (Program-Design Model)
Topic: VPP / Program Design
Relevance: First U.S. framework conditioning residential-battery incentives on DR enrollment, converting every subsidized battery into a VPP asset at installation and solving the free-rider problem. A replicable template for utilities designing residential storage and DLM programs, with a built-in path to Order 2222 aggregation.
Action Signal: Implement — Strong candidate to adapt for residential battery/DLM program redesign; evaluate OEM interoperability requirements early.
⚑ NextEra–Dominion $67B Merger
Topic: Utility Strategy / DERMS
Relevance: Consolidates two of the most consequential utility DER strategies under one umbrella and creates a live test of cross-RTO DERMS orchestration (PJM + non-RTO). Sets precedent for how merged utilities harmonize VPP/DR programs and DERMS platforms across heterogeneous market structures.
Action Signal: Watch — Monitor regulatory proceedings and integration approach as a benchmark for multi-footprint DERMS interoperability.
⚑ New Jersey FERC Win on Transmission Cost Allocation + Business-Model Review
Topic: Regulatory / Ratemaking
Relevance: A successful FERC challenge to PJM’s “de minimis” transmission cost-allocation rule (with refunds) plus a launched PBR/multi-year-rate-plan study signals state regulators are actively restructuring utility incentives toward demand-side outcomes. Implications for ratemaking strategy and DER program economics across PJM states facing identical cost pressures.
Action Signal: Watch — Relevant precedent for cost-allocation disputes and performance-based-ratemaking design; engage if your jurisdiction opens a comparable proceeding.
⚑ EPRI CERAWeek Flexibility-Standardization Initiative
Topic: DERMS / Flexibility M&V
Relevance: An EPRI-led, 30+ player effort to standardize flexibility definitions and measurement bears directly on DERMS measurement-and-verification design and on how utilities quantify “time to power” from existing distribution capacity.
Action Signal: Engage — Worth tracking and, where feasible, participating in to align internal flexibility-procurement and M&V methods with an emerging industry standard.
⚑ Utility-Scale Storage Scaling vs. Demand-Side Resources
Topic: Storage / Capacity Markets
Relevance: A record storage quarter and a 610+ GWh-by-2030 forecast mean utility-scale BESS increasingly competes with DR for capacity-market value, while behind-the-meter storage simultaneously builds the VPP-enrollable asset base. Resource planners should model both the competitive and complementary dynamics in IRP/DSM business cases.
Action Signal: Watch — Factor accelerating BESS economics into capacity-value assumptions for demand-side portfolios.
📌 Sources Consulted
May 22 — Pew, Morgan Lewis, Utility Dive VPP outlook, DERMS market sizing
– The Pew Charitable Trusts — Distributed Energy Can Unleash the Resilient, Affordable Grid of the Future (April 28, 2026)
– Morgan Lewis — Federal Regulatory Outlook for Electric Storage, QFs, and Inverter-Based Resources (March 2026)
– Utility Dive — In 2026, Virtual Power Plants Must Scale or Risk Being Left Behind (January 27, 2026)
– OpenPR — DERMS Market to Reach US$5.5 Bn by 2033 (May 2026)
– OpenPR — DERMS Market Analysis: Global Industry Outlook and Forecast 2026–2033 (May 2026)
May 21 — SEIA/Benchmark storage, NJ BPU affordability, PSEG earnings
– Electrek — SEIA: AI Is Fueling a Massive US Energy Storage Boom (May 20, 2026)
– Utility Dive — 600+ GWh of US Energy Storage Expected by 2030: Benchmark/SEIA (March 3, 2026)
– SEIA — Energy Storage Market Outlook Q1 2026
– Utility Dive — In New Jersey, We’re Leading by Example, Tackling Energy Affordability Head-On (April 23, 2026)
– NJ BPU — BPU Takes Major Action to Advance Governor Sherrill’s Goals for Affordable, Clean Energy (March 5, 2026)
– Utility Dive — PSEG CEO: Nuclear Outlook for New Jersey Improves on Lifting of Moratorium (May 6, 2026)
– NJ BPU — BPU Takes a Step Forward to Modernize the Utility Business Model (May 5, 2026)
May 20 — NextEra–Dominion merger, PA model tariff, Austin Energy pilot
– Utility Dive — Combined NextEra-Dominion Would Have 130-GW Large-Load Pipeline (May 18, 2026)
– Fortune — NextEra’s $67 Billion Dominion Takeover Creates World’s Largest Utility (May 18, 2026)
– CNBC — NextEra Energy to Buy Dominion in Deal That Unites Two Key Players in Race to Power AI Data Centers (May 18, 2026)
– Utility Dive — Pennsylvania Releases ‘First-of-Its-Kind’ Large-Load Model Tariff (May 18, 2026)
– Pennsylvania PUC — Final Order Establishing First-of-Its-Kind Large-Load Model Tariff Framework (May 13, 2026)
– SEPA — Database of Emerging Large Load Tariffs (2026)
– Austin Energy — Austin Energy Launches Innovative Power Partner Battery Pilot Program (March 24, 2026)
May 19 — PJM capacity reform, Eversource, Jigar Shah, NY BYOB
– Utility Dive — PJM Floats Options for Capacity Market Overhaul (May 2026)
– PJM Inside Lines — PJM To Lead Market Reform Effort To Support Generation Investment and Reliability (May 6, 2026)
– The Daily Record — PJM Considering Market Overhaul (May 2026)
– Utility Dive — Eversource CEO: ‘We Are Resisting Data Centers’ (May 7, 2026)
– Hartford Business Journal — Eversource CEO ‘Resisting’ Data Centers in New England (May 2026)
– Utility Dive — 2026 Q1 Roundup: Utilities Divided on Data Centers as Affordability Looms Large (May 2026)
– Utility Dive — America’s Load Growth Moment Is a Chance to Scale Distributed Energy (Jigar Shah, May 5, 2026)
– EPRI — CERAWeek 2026 Flexibility Initiative (March 2026)
– NY Department of Public Service — Commission Improves Customer-Centered Electric Demand Response Programs (April 16, 2026)
– NYSERDA — Overview of Utility Residential Energy Storage Demand Load Management Program (January 2026)
– GreenSpark Solar — New York’s BYOB Program: What Battery Owners Need to Know (March 11, 2026)
May 18 — FERC interconnection, MISO forecast, California SB 913, Minnesota Xcel
– Utility Dive — FERC Tees Up June Decision on Data Center Interconnection Reform (April 2026)
– FERC — FERC to Act on Large Load Interconnection Docket by June 2026
– Holland & Knight — FERC to Act on Large-Load Interconnection Docket in June (April 2026)
– Utility Dive — MISO Expects Load to Jump 35% by 2035 on Data Center Growth (May 2026)
– RTO Insider — MISO Load Forecast: Data Centers Drive 163-GW Peak by 2035
– Data Center Dynamics — ERCOT and MISO Forecast Huge Increases in Peak Load (2026)
– Utility Dive — Distributed Batteries Get Legislative, Utility Lift in California (April 14, 2026)
– pv magazine USA — California Bill Would Unlock Distributed Energy Participation in Grid Resource Adequacy Market (March 26, 2026)
– Senator Josh Becker — Becker Introduces SB 913 (March 24, 2026)
– Utility Dive — Minnesota Got One Thing Right on Distributed Storage — But It Missed the Bigger Opportunity (April 21, 2026)
– pv magazine USA — Minnesota PUC Approves Utility Battery Program While Deferring VPP Decisions (April 8, 2026)
– SEIA/MnSEIA/CCSA — Joint Statement on Xcel Capacity*Connect Approval (April 4, 2026)