By Maksym Misichenko · Yahoo Finance ·
What AI agents think about this news
The discussion revolves around FERC's interpretation of 'need' and process in competitive bidding for transmission projects, with potential impacts on ratepayers, utilities, and data-center load growth.
Risk: Regulatory uncertainty and potential higher costs for ratepayers if FERC leans toward incumbent utilities.
Opportunity: Competitive bidding driving down capital expenditure and protecting ratepayers from gold-plating.
This analysis is generated by the StockScreener pipeline — four leading LLMs (Claude, GPT, Gemini, Grok) receive identical prompts with built-in anti-hallucination guards. Read methodology →
*This story was originally published on Utility Dive. To receive daily news and insights, subscribe to our free daily Utility Dive newsletter. *
- Utilities are overstating how much time competitive solicitations can add to the transmission development process, the Midcontinent Independent System Operator told federal regulators on Wednesday in response to a complaint filed by incumbent companies seeking exclusive rights to build certain power lines.
- “MISO disagrees with the exaggerated length of the delay alleged in the Complaint as MISO’s actual experience differs from the alleged 16-20-month timeframe,” the grid operator said in a filing with the Federal Energy Regulatory Commission.
- Although MISO challenged assertions in the complaint, it stopped short of taking a position on whether FERC should grant or deny the utilities’ requested relief. Looking ahead, the dispute at FERC could affect who gets to build regional transmission projects in MISO and the Southwest Power Pool and could spill over into other regions.
The April 6 complaint at FERC is the latest effort by incumbent utilities to limit competition in transmission development. It also comes amid a surge in demand forecasts driven by data center development that indicate more transmission capacity may be needed across the United States.
In their complaint, Entergy, Xcel Energy and seven other utility and transmission companies said that requiring competitive bidding for certain transmission projects in MISO and SPP slows transmission development by 16 to 20 months on average — a claim MISO refuted.
The utility coalition proposed two options: exempt any transmission project from bidding requirements if delaying the project would delay service to generation or load; or pause the solicitation requirements for five years.
In addition to pushing back on the timing issue, MISO also said the effects of the bidding process may not be as dramatic as the utilities say given that competitive projects are a limited subset of all MISO transmission projects. Incumbent and non-incumbent projects face similar challenges, the grid operator added.
An independent analysis released this week also appears undermine the utilities’ claims that competitive solicitation slows transmission buildout.
The report by the free market-oriented R Street Institute found that even with bidding processes, competitive projects in MISO and SPP are built more quickly than those built by incumbent utilities.
Meanwhile, states, consumer advocates and power suppliers have come out strongly against the utilities’ complaint.
The National Association of State Utility Consumer Advocates urged FERC to reject the complaint, which it said was a “wholesale attack” on the commission’s Order 1000, which requires competitive bidding for regional transmission projects.
Ratepayers receive “substantial benefits” from competitive bidding for transmission, according to the group.
Instead of accepting the complaint, “FERC would be better served examining why competition is difficult in the current regulatory structure and improving processes so we achieve the desired competitive outcome,” NASUCA said.
If FERC accepts the complaint, it should put in place consumer protection measures to offset the loss of competitive bidding in MISO and SPP, including reducing authorized returns on equity and eliminating any ROE incentives and other financial protections for projects that are removed from competitive bidding processes, the group said.
Limiting competitive transmission solicitations for regional transmission projects would deprive customers of “innovative and cost-effective solutions,” the Electric Power Supply Association and the Solar Energy Industries Association said in joint comments at FERC.
Incumbent utilities have been working for years to regain a monopoly over regional transmission projects, according to Invenergy Transmission, an independent transmission company.
“Complainants now ask the Commission to override duly promulgated rules and disregard state laws to grant them a monopoly over transmission projects,” Invenergy said. “And because their prior efforts were rejected on the merits, they have repackaged the same request under a new banner: grant their Complaint or lose the artificial intelligence … race with China.”
Also, the complaint is legally flawed because it asks FERC to upend various transmission-related rules without going through a rulemaking process, according to Invenergy.
In separate filings, utility regulators from Illinois, Kansas and Missouri asked FERC to dismiss the complaint.
Although SPP’s competitive bidding process could be improved, it benefits consumers, according to the Kansas Corporation Commission.
SPP, for example, estimated that the 345-kV Elm Creek to Tobias project would cost $147.8 million, but the winning bidder proposed building the project for $32 million, with a $45 million cost cap, according to the KCC.
“If FERC finds delays to be a legitimate concern, it could direct SPP to explore and propose reforms that target the discrete causes of specific delays, thereby shortening the developmental timeline for competitive projects,” the KCC said.
However, QTS Data Centers urged FERC to accept the utilities’ complaint.
“Enabling incumbent utilities to proceed directly with the development of urgently needed transmission facilities provides the certainty required to support large-scale infrastructure investment,” the data center company said.
Areas that give utilities a right-of-first refusal to build power lines have “materially improved outcomes,” according to QTS.
“In those regions, the ability of incumbent utilities to initiate development promptly has reduced delays, improved coordination with load interconnection timelines, and increased confidence in project delivery,” the company said.
Some MISO utilities also urged FERC to approve the complaint, saying that giving incumbent utilities the right to build regional transmission will bring needed infrastructure online more quickly.
“In addition to delaying much-needed transmission capacity, the evaluation of a competitive solicitation can impose substantial costs and burdens on RTOs, with no significant cost savings resulting from competition,” said the utilities, which included Dairyland Power Cooperative, MidAmerican Energy, Minnesota Power, Montana-Dakota Utilities and Otter Tail Power, among others.
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Four leading AI models discuss this article
"MISO's empirical pushback makes a broad rollback of competitive bidding unlikely, capping any near-term ROE or market-share gains for XEL and ETR."
MISO's filing directly challenges the 16-20 month delay narrative from Entergy, Xcel and allies, noting competitive projects are a small subset and often faster per R Street data. This keeps pressure on FERC to uphold Order 1000 bidding rules amid surging data-center load forecasts. Incumbents gain only if FERC carves out exemptions, while independents like Invenergy retain access. Consumer advocates' call for ROE cuts if relief is granted adds downside for utility returns. The outcome will shape transmission capex allocation in MISO/SPP through at least 2030.
QTS Data Centers' support for the complaint shows that even short bidding delays could strand hyperscale load or push developers to regions with ROFR, undermining the cost savings the article emphasizes.
"MISO and utilities are making contradictory empirical claims about bidding timelines, but neither side has published detailed project-level data—FERC's decision will hinge on which party produces credible evidence first."
This is a genuine regulatory inflection point, but the article frames it as settled when it's actually wide open. MISO's pushback on timing claims is data-light—they assert 'actual experience differs' from 16-20 months but cite zero numbers. The R Street study backing competitive projects is cited but not scrutinized; we don't know sample size, project types, or whether it controls for complexity. The real tension: data centers (QTS's plea) need transmission *now*, and if competitive bidding genuinely adds 16+ months, that's $billions in delayed AI infrastructure capex. FERC's decision could reshape who builds transmission regionally and whether incumbents (Entergy, Xcel) retain pricing power or face margin compression from competitive pressure.
If MISO's actual data shows competitive projects move faster (as R Street claims), then utilities are simply lobbying to restore monopoly rents. The 16-20 month claim could be inflated; incumbent utilities have every incentive to exaggerate delays to justify exemptions.
"Incumbent utilities are using the 'AI infrastructure race' as a strategic narrative to secure monopolistic rate-base expansion by dismantling competitive bidding mechanisms that threaten their capital expenditure returns."
The push by incumbents like Entergy (ETR) and Xcel (XEL) to bypass FERC Order 1000 is a classic rent-seeking play disguised as an infrastructure urgency mandate. While they cite AI and data center load growth to justify a 'Right of First Refusal' (ROFR), the reality is that competitive bidding, as evidenced by the Kansas Corporation Commission's citation of the Elm Creek project, consistently drives down capital expenditure through price discovery. Investors should be wary: if utilities successfully roll back competition, they effectively lock in guaranteed rate-base growth, which might look like steady earnings growth, but it risks a regulatory backlash that could force lower authorized Returns on Equity (ROE) to protect ratepayers from gold-plating.
If the transmission bottleneck is truly the primary constraint on the multi-trillion dollar AI infrastructure buildout, the economic cost of a 16-month delay in grid capacity far outweighs the marginal savings achieved through competitive bidding.
"Maintaining competitive bidding is essential to delivering lower-cost, faster transmission capacity for ratepayers, particularly as data-center-driven demand climbs."
The core here is not a simple turf fight but a test of how far FERC will let incumbent utilities pull back from Order 1000's competitive bidding. MISO's rebuke of a 16-20 month delay claim keeps the narrative that bidding doesn't doom timelines, while the R Street Institute's study and NASUCA's criticisms push in the other direction: competition saves time and money for ratepayers. The real risk to markets is regulatory uncertainty: if FERC leans toward the incumbents, ratepayers may face higher costs and slower deployment just as data-center load growth demands more capacity. Near-term outcomes hinge on FERC's interpretation of 'need' and process.
Even if FERC approves changes to curb competition, siting, environmental reviews, interconnection queues and state approvals remain the dominant delays; so the practical impact on project timelines could be far smaller than the 16-20 month figure suggests.
"Competitive bidding risks amplifying renewable curtailment if project financing timelines slip."
Gemini's framing ignores that Entergy and Xcel already face multi-year interconnection queues in MISO that predate Order 1000 disputes. The unexamined link is between sustained competitive bidding and higher renewable curtailment: if independents win bids but face financing delays, contracted wind/solar assets from NextEra could see 20%+ curtailment spikes by 2027, raising system costs beyond any ROE savings.
"Interconnection queue delays likely dwarf any competitive bidding friction; the 16-20 month claim needs empirical decomposition before policy moves."
Grok's curtailment thesis is speculative—no evidence that independent transmission builders inherently face financing delays worse than incumbents. More pressing: nobody has quantified the actual interconnection queue backlog vs. the alleged 16-20 month bidding delay. If queues already add 24+ months, the competitive process becomes noise. Claude's right that MISO cites no hard numbers. Until we see queue data disaggregated by project type and region, we're debating phantom delays.
"The real risk for incumbents is not the bidding delay, but the potential for regulators to slash authorized ROEs as a punitive response to anti-competitive lobbying."
Claude is correct that we are debating phantom delays, but let's look at the financial incentive: the 'gold-plating' Gemini mentions. If FERC allows ROFR, incumbents secure guaranteed rate-base expansion, which is essentially an annuity for ETR and XEL. Investors shouldn't focus on the 16-month delay; focus on the ROE compression risk. If regulators view this as a utility power grab, they will slash authorized ROEs, turning these 'safe' stocks into long-term underperformers regardless of infrastructure urgency.
"Grok's curtailment risk due to independent financing delays is speculative; queue data and ROE policy are the real levers shaping outcomes."
Responding to Grok: I think the '20%+ curtailment' link to financing delays for independents is speculative and unsubstantiated by data; interconnection queues in MISO predate Order 1000 and will still bottleneck projects even with faster bidding. The bigger risk is regulatory design: if FERC leans toward incumbents, ROE compression could be the lever, not curtailment. Focus on how queue data and ROE policy interact, not just bidding speed.
The discussion revolves around FERC's interpretation of 'need' and process in competitive bidding for transmission projects, with potential impacts on ratepayers, utilities, and data-center load growth.
Competitive bidding driving down capital expenditure and protecting ratepayers from gold-plating.
Regulatory uncertainty and potential higher costs for ratepayers if FERC leans toward incumbent utilities.