The core question

On April 13, 2026, Idaho's Department of Water Resources declared a drought emergency covering every one of the state's forty-four counties after the second-warmest winter since 1896 and a record-low spring snowpack. Six weeks later, Pleasant Valley Solar 2 was scheduled to come online as the second half of a dedicated renewable ramp for Meta's new Kuna data center. This simultaneity frames a question Idaho's regulatory institutions have not yet answered on the public record: as hyperscale data centers arrive in the state, is the regulatory architecture in place calibrated to allocate their costs, their water demand, and their risk in the way five peer states have now concluded is necessary?

The Meta/Brisbie deal

Meta's Idaho entity is Brisbie, LLC, reached through a Delaware shell company (Foxtrot Acquisition Corp) registered to Meta's Menlo Park address. The Kuna facility is an $800 million, 960,000-square-foot hyperscale campus sized for 200 megawatts of power at full build-out — Meta's nineteenth data center. Idaho Power filed the "Brisbie Special Contract" with the Idaho Public Utilities Commission in December 2021; the commission approved it in May 2023 under Order No. 35777. The deal's public face is a five-page tariff schedule (Schedule 33) and a renewable-matching tariff (Schedule 62 — "Clean Energy Your Way — Construction") under which two solar arrays, Pleasant Valley Solar 1 (200 MW, operational March 2025) and Pleasant Valley Solar 2 (125 MW, targeted May 2026), provide generation sized to match Brisbie's annual consumption.

The deal's financial face is not public. The Energy Services Agreement, the Construction Agreement, and the "no-harm" revenue-requirement analysis that purports to show other Idaho Power customers are not disadvantaged were all filed under protective order and remain sealed. The public tariff confirms there are only two special-contract customers named in Idaho Power's schedule: Brisbie (Meta) and Lamb Weston, a frozen-potato processor. The renewable matching is annual, not hourly — at 2 a.m. on a cloudy January night, the facility draws from whatever is on the grid, which in 2024 was 44 percent hydroelectric, 31 percent natural gas, 15 percent wind, and about 9 percent solar and other renewables.

The rate case

On May 30, 2025, Idaho Power filed its first full general rate case in several years, requesting a $199.1 million annual revenue increase — a 13.09 percent jump that the Idaho Press called a significant break from prior requests "that have generally hovered around 7–8 percent." As filed, the rate case asked residential, small-commercial, and irrigation customers to absorb roughly 17 percent increases each, while large-power customers would absorb about 8 percent. In October 2025, Idaho Power filed a settlement stipulation that the IPUC approved on December 30, 2025: a 7.48 percent average increase effective January 1, 2026. The settlement muted every class's increase, but the residential-to-large-power ratio held. Residential customers' approved increase (roughly 9.74 percent) remained about twice that of the large-power class (4.72 percent).

The capital plan behind the rate case

Idaho Power's 2024–2028 capital plan totals approximately $4 billion, roughly double the prior five-year period. Its 2025 Integrated Resource Plan projects 8.3 percent annual retail-sales growth over the next five years, versus 1.4 percent in the 2021 IRP baseline, with peak-load growth of about 1,000 MW in five years and 1,700 MW over twenty. Idaho Power's resource planning leader, Jared Hansen, told the Idaho Capital Sun in August 2025 that data-center and industrial demand have produced a moment where the utility "just need[s] to expand like crazy." The holding company, IDACORP, reported 2025 earnings per share of $5.90 with 2026 guidance of $6.25–$6.45 — an 8 percent midpoint — on a regulated return on equity of 9.6 percent on an Idaho rate base of approximately $4.9 billion. Nationally, NERC's 2025 Long-Term Reliability Assessment identifies the WECC-Northwest and WECC-Basin regions, which include Idaho, at high resource-adequacy risk for 2026–2030, attributing +224 gigawatts of national peak demand growth to data centers and artificial intelligence.

The regulator

The Idaho Public Utilities Commission is a three-person body. Its president, appointed in February 2023, spent the preceding sixteen years (2004–2020) as Director of Government and Regulatory Affairs for Qwest/CenturyLink. A whistleblower lawsuit filed in October 2024 by IPUC's former executive director and former policy strategist alleges specific governance failures — commissioner retention of an unauthorized utility-information system access, serial individual commissioner meetings with Avista Utilities to evade open-meeting rules, and a February 2025 Meridian-restaurant meeting between the three sitting commissioners and a former commissioner representing Veolia, a water utility with a ~20 percent rate increase then pending. Veolia's case subsequently settled at about 12 percent. The Idaho Attorney General has moved to dismiss the suit; the allegations remain unresolved and should be treated as such. Independently documentable is the surrounding architecture: Idaho Code § 61-617A caps intervenor funding at $40,000 total for all parties combined in any single proceeding, and Idaho is among a small group of states without a dedicated utility consumer advocate office.

What peer states built between January and December 2025

Five states acted. Virginia's State Corporation Commission approved a new GS-5 rate class in November 2025 for customers of 25+ MW: 85 percent minimum transmission demand, 85 percent minimum distribution demand, 60 percent generation demand, 14-year contracts, collateral requirements, effective January 2027. Ohio's PUCO approved an AEP Ohio data-center tariff in July 2025: 25 MW, 85 percent minimum billing, 12-year contracts. Oregon's legislature passed the POWER Act (HB 3546) in June 2025: 20 MW, 10-year minimum contracts — applying to Portland General Electric, Pacific Power, and Idaho Power's Oregon customers. Georgia combined a January 2025 100-MW-plus tariff rule with a December 2025 structural innovation: Georgia Power agreed to financially backstop costs of new generation if data-center contracts don't materialize as expected, producing an estimated $8.50/month of downward pressure on residential bills for 2029–2031. Texas signed SB 6 in June 2025, imposing mandatory curtailment authority and $100,000 screening fees on 75+ MW loads. Arizona opened a formal inquiry in April 2025.

The jurisdictional asymmetry

Because Oregon's POWER Act applies to Idaho Power's Oregon customers, the same utility now operates under two different regulatory regimes: Idaho Power's Oregon ratepayers are protected by the 20 MW / 10-year minimum-payment structure, while Idaho Power's Idaho ratepayers — the overwhelming majority of its 650,000-customer base — are not. Same utility, two rulebooks.

The steelman and what it concedes

The strongest case for Idaho's current posture comes from Virginia's Joint Legislative Audit and Review Commission, whose December 2024 study concluded that Virginia's "current rates appropriately apportion costs to classes and customers responsible for incurring them, including large loads like data centers," and that there had been no historic cost-shifting. The data-center industry has cited JLARC to counter academic claims of cost-shifting. But JLARC itself wrote the next sentence: going forward, "the pace and scale of infrastructure development built as well as secondary impacts such as increasing tightness in energy and capacity markets is likely to lead to upward pressure on rates for all ratepayers in the near to medium term." Virginia still approved the GS-5 reforms in November 2025.

The water simultaneity

Canyon County, immediately adjacent to Kuna, received a five-year IDWR moratorium on new groundwater permits on March 20, 2026, three weeks before the statewide drought declaration. Meta declines to disclose facility-specific Kuna water use until the facility is operational; comparative Meta sites range from 9 million gallons annually (New Albany, Ohio) to more than 170 million gallons at its largest leased East Coast site. Idaho allocates water and power through different regulatory regimes, on different timelines, with different agencies; the Brisbie Special Contract was evaluated by the IPUC on an electricity no-harm basis, with no coupled water-impact requirement.

The federal frame

A July 2025 White House executive order streamlined federal permitting for data centers over 100 MW or $500 million. In March 2026, seven hyperscalers including Meta signed a voluntary White House Ratepayer Protection Pledge committing them to cover power-delivery infrastructure costs and to ensure expenses don't flow to households. Meta's Brisbie Special Contract predates the pledge by nearly three years.

The open question

None of the individual pieces described above is, on its own, evidence of corruption. What they amount to is a regulatory architecture built for an earlier category of problem — sealed special contracts, a thin intervention budget, a commission staffed from utility career tracks, no consumer advocate — meeting a category of customer whose arrival has prompted structural reform in five other states. Virginia's SCC, Ohio's PUCO, Oregon's legislature, Georgia's PSC, and Texas's legislature have each concluded, on their own public records, that the pre-existing allocation frameworks were not calibrated to the forward-looking pressure hyperscale demand places on their grids. Idaho has not yet concluded, on the record, one way or the other. That conclusion is the decision still in front of Idahoans, their commission, their legislature, and the farmers and households whose monthly bills are the arithmetic behind the question.