Energy Grid AI

State of play.

• FERC has committed to finalizing large-load interconnection rules by June 30, 2026, following its April 16 "Order Regarding Intent to Act" covering loads exceeding 20 MW on the interstate transmission system — specific provisions remain undisclosed .
• FERC Order No. 919 is the most significant grid cybersecurity update in years, replacing "technical feasibility" exceptions with "per system capability" language across fifteen CIP requirements and introducing four new virtualization-related definitions, with mandatory compliance by April 1, 2028 .
• US utilities have announced $1.4 trillion in capital spending through 2030 — a 27% increase over prior projections — driven primarily by AI data center load growth, with cost allocation between residential and industrial customers still unsettled at the state commission level .
• Texas is emerging as the defining stress test for AI-driven grid infrastructure, with ERCOT interconnection queue congestion producing 5-to-10-year grid connection delays and forcing major developers — including Oracle's 1.4-gigawatt West Texas facility — to build independent on-site generation rather than wait for traditional infrastructure (→ Legal Series Examines AI Data Center Power Grid Challenges in Texas).
• For counsel advising data center developers, utilities, or large industrial users, the practical baseline is: FERC's interconnection rulemaking, CIP cybersecurity compliance, rate-case pressure, and state-level permitting and regulatory architecture are all simultaneously load-bearing for any client planning significant grid access or infrastructure investment through 2030.

Where things stand.

• FERC's large-load interconnection rulemaking is the near-term regulatory pivot point. The June 30, 2026 deadline follows DOE's October 2025 advance NPRM under Section 403 of the DOE Organization Act and more than 3,500 pages of stakeholder comments; PJM's already-implemented co-location and behind-the-meter reforms are the leading indicator of what FERC may standardize nationally .
• Order No. 919 resets the CIP compliance baseline for all NERC-registered Bulk Electric System entities. The shift from technical feasibility to per-system capability language permits virtualization without mandating it, but requires gap assessments now — the 24-month window to April 2028 is tight for complex infrastructure .
• New NERC definitional framework is operative. Four new definitions — Cyber System, Management Interface, Shared Cyber Infrastructure, Virtual Cyber Asset — and eighteen revised glossary entries take effect May 26, 2026; compliance and operational teams need to map existing implementations against the new taxonomy .
• Rate-case pressure is accelerating. Utilities requested $31 billion in rate increases in 2025 alone — double the prior year — and will cite AI infrastructure demands in future filings; PowerLines estimates residential customers could absorb approximately $700 billion of the $1.4 trillion total under current rate-setting trends .
• Co-location and behind-the-meter generation are active regulatory flashpoints. PJM submitted compliance filings in January and February 2026 on new transmission service options for co-located loads, with full activation delayed to 2027; FERC's June rulemaking will determine whether these models are standardized across all RTOs .
• Texas's regulatory and permitting architecture is now central to AI infrastructure project planning. Interconnection queue congestion, ERCOT demand forecast disputes — ERCOT's 250-gigawatt 2030 projection has been challenged by industry players as inflated by speculative applications — and the state's trajectory to surpass Virginia as the nation's largest data center hub make Texas-specific regulatory counsel a distinct practice need (→ Legal Series Examines AI Data Center Power Grid Challenges in Texas).
• Jurisdictional authority over large-load interconnection remains unresolved. FERC's rulemaking must address how federal interconnection rules interact with state commission authority over distribution-level resources and retail rate-setting .

Latest developments.

• Vinson & Elkins launched "Powering Progress," an audio series examining the collision of AI data center infrastructure with Texas's regulatory frameworks, highlighting ERCOT queue congestion, Oracle's on-site gas generation workaround, and Google's $40 billion Texas investment as the defining pressure points for project counsel (→ Legal Series Examines AI Data Center Power Grid Challenges in Texas).

Active questions and open splits.

• What will FERC's June interconnection rules actually require? The specific provisions — on jurisdictional authority, co-location requirements, and cost-sharing mechanisms — remain undisclosed; clients planning load additions above 20 MW cannot finalize project timelines or cost models until the rule issues .
• Who bears the $1.4 trillion infrastructure cost? State commissions will determine cost allocation between residential and industrial ratepayers through rate cases; the enforceability and scope of the voluntary Ratepayer Protection Pledge is untested, creating consumer protection and utility commission authority litigation exposure .
• Is on-site generation the new baseline for large AI data centers? Oracle's 1.4-gigawatt West Texas facility with on-site gas generation signals a structural workaround to interconnection queue delays — but the permitting, environmental compliance, and utility commission implications of widespread behind-the-fence generation at this scale are uncharted (→ Legal Series Examines AI Data Center Power Grid Challenges in Texas).
• How does "per system capability" language change CIP compliance obligations in practice? The shift from technical feasibility exceptions creates ambiguity about what a given entity's system capabilities require — and FERC's added reporting directives to NERC leave the full oversight mechanism to be detailed in subsequent guidance .
• Will FERC standardize PJM's co-location model nationally? PJM's transmission service options for co-located loads are the most developed template, but whether FERC adopts them wholesale, modifies them, or creates a different framework will determine the competitive landscape for data center grid access across all RTOs .
• How does federal interconnection rulemaking interact with state distribution authority? Large loads connecting at the distribution level may fall outside FERC's interstate transmission jurisdiction, creating a potential gap — or conflict — between federal interconnection rules and state commission authority .
• Is the 24-month CIP compliance window achievable for complex infrastructure? Entities managing virtualized bulk electric system assets face gap assessments, operational redesign, and reporting obligations under the new NERC definitions — early adoption at six or twelve months post-effective date may be necessary for some to avoid compliance risk .

What to watch.

• FERC's June 30, 2026 final rule on large-load interconnection — the specific provisions on cost allocation, co-location, and jurisdictional scope will immediately reshape project planning for any client with a pending or contemplated grid connection above 20 MW.
• State utility commission rate cases citing AI infrastructure demand — the first decisions allocating costs between residential and industrial customers will set precedent for the $700 billion residential exposure estimate.
• NERC guidance on the new CIP definitions and reporting directives under Order No. 919 — the full oversight mechanism for virtualization exceptions remains to be detailed.
• Whether Texas's ERCOT demand forecast disputes produce regulatory or legislative action that affects interconnection queue management and project timelines for the 400-plus data center facilities in planning or construction.
• Whether the Ratepayer Protection Pledge generates litigation — consumer protection claims or utility commission challenges to rate structures that shift AI infrastructure costs to residential customers are a plausible next step.
• PJM's 2027 activation of its co-located load transmission service options — the operational results will inform whether FERC's national framework tracks or diverges from PJM's model.