The complaint placed the matter before the commission’s consumer-affairs unit after electrical-supply problems affected both municipal facilities and people living nearby. The city’s notice identifies the completed review as the latest publicly reported action in the matter. It does not say that the commission found a utility at fault, and completion of the review is not itself an announcement of penalties or other corrective measures.

The notice does not disclose the review’s findings, name the utility involved or describe any remedy. It also does not announce a further procedural step, such as a new proceeding or an order. For now, residents and city officials have confirmation that the state review is complete, but no public conclusion about what caused the 2025 incidents or what action, if any, will follow. Any next step would have to be announced by the commission or the city.

The village held a public forum July 14, 2026, at the Bolingbrook Community Center to oppose the pending rate case. Bolingbrook also directed residents to submit comments through ICC docket P2026-0127, the regulatory case where the request is being considered.

What residents are challenging

Illinois American Water is seeking a $142.4 million increase through the Illinois Commerce Commission. The request is a proposal, not a final increase approved by state regulators.

Public comments filed in the ICC docket include submissions from residential customers who identify Bolingbrook as their community. Those comments place local customers directly in the rate case rather than leaving the issue as a statewide utility dispute with no local participation.

The village’s public position is opposition to the proposed increase. Its forum gave Bolingbrook customers a place to learn about the request and organize their response, while the ICC docket provides the formal channel for comments in the regulatory proceeding.

Why the case matters locally

A final decision could affect water costs for Bolingbrook households and businesses served by Illinois American Water. The proposed statewide increase of $142.4 million should not be read as the amount any individual Bolingbrook customer would pay. Customer impacts would depend on the outcome of the case and how any approved changes are applied.

For now, Bolingbrook water bills have not been established by this proceeding as having increased. The Illinois Commerce Commission has not approved the request in the records documenting the case, and the final amount remains unresolved.

That distinction is important for residents trying to understand the issue. The July forum and customer comments represent opposition and participation in a pending case; they do not represent a final ruling on the utility’s rates.

What happens next

The rate case continues before the Illinois Commerce Commission under docket P2026-0127. Bolingbrook residents who want to weigh in can use the docket’s public-comments process. The village has identified that docket as the place for residents to submit their views.

The public records documenting the case do not establish a final approved increase or a specific new bill amount for Bolingbrook customers. Until the commission issues a decision, the $142.4 million figure remains Illinois American Water’s proposed rate-increase request.

Bolingbrook’s involvement gives local customers a direct role in a decision that could affect the cost of water service. The village’s July 14 forum, along with comments from Bolingbrook residential customers, shows that the pending case has become a local issue as well as a state regulatory proceeding.

The Washington Utilities and Transportation Commission issued a July 28, 2026, media advisory announcing a public comment process and hybrid workshop on emerging large electric loads. The proceeding is docketed as UE-260162.

Comments are due Aug. 5. The workshop is scheduled for the week of Aug. 10, although the advisory does not identify a specific day in the materials announcing the process.

What regulators are examining

The commission identified several issues for public discussion: power rates, cost sharing, interconnection conditions, energy flexibility and protections for existing customers.

Those questions are important because a large new customer can require planning and investment in the electric system before service begins. The terms governing that connection can determine which costs are assigned to the new customer, which may be shared through utility systems, and how the utility manages the added demand.

The process includes large-load customers such as data centers, but the commission’s announcement describes the issue more broadly as emerging large electric loads. The proceeding concerns their effects on Washington investor-owned electric utilities and the customers those utilities already serve.

The UTC said current utilities do not serve many large-load customers. It said the planning process is intended to help keep electricity service safe, equitable, available, reliable and fairly priced while accommodating new economic activity.

A policy is still ahead

The public process is meant to guide a future policy for connecting large energy users to the grid. The commission has not adopted a final policy or rate structure for those customers, and the workshop’s recommendations and any later commission order remain pending.

That means the proceeding is not a decision to approve a particular data center, set a new electricity rate or assign a specific cost to residential or small-business customers. It is an opportunity to establish the rules that could govern future large-load connections.

The eventual effect on customer bills is not yet known. The outcome could depend on the policy adopted, the size and location of proposed projects, the infrastructure required and the cost-sharing terms approved for connections. The commission’s announced topics include those policy choices, but do not establish a final rate impact.

Broader planning for future electricity needs

The UTC proceeding comes as Washington also examines the resources needed to maintain reliable electricity while transportation, buildings and industry shift away from fossil fuels.

The Washington Department of Commerce is soliciting proposals for an analysis of generation, transmission, storage, efficiency and grid-support resources. The analysis is intended to address future electricity needs while the state meets its clean-energy laws. Commerce set an Aug. 13, 2026, deadline for proposals.

The Commerce effort is separate from the UTC’s large-load proceeding, but both address planning questions that affect the state’s electric system: how much capacity and supporting infrastructure will be needed, and how the system can remain reliable as demand changes.

For Washington utility customers, the UTC process will be the nearer-term venue for commenting on the rules surrounding large new electricity users. Comments submitted by Aug. 5 are expected to inform the hybrid workshop during the week of Aug. 10 and the future policy process under docket UE-260162.

The ruling leaves the commission-approved charge in place and ends the state-court challenge unless a party seeks further review. The dispute began in 2021 and has centered on whether Ohio utilities could pass the charge on to customers under the state’s utility regulations.

For Ohio electricity customers, the decision preserves a charge connected to a policy that became entangled in the House Bill 6 corruption scandal. It also gives the commission’s approval legal force after challengers sought to overturn it.

The dispute over customer costs

Opponents of the charge argued that the commission’s decision could allow utilities to overcharge customers by roughly $115 million. That figure is an estimate offered by the challengers, not a finding by the Ohio Supreme Court that customers were overcharged by that amount.

The disputed amount represents the central financial concern raised in the challenge. The case therefore involved more than whether regulators had approved a fee. It also raised questions about how much Ohio electricity customers could be required to pay through a charge associated with the coal-plant bailout.

The court’s decision does not establish that every cost associated with House Bill 6 is valid. It upholds the utility commission’s decision at issue in this case and leaves that commission-approved charge in place.

What the ruling changes

The ruling closes the state-court phase of the challenge unless further review is pursued. That means the commission’s decision is no longer being blocked or overturned by this state-court case.

The decision also clarifies the outcome of this particular regulatory dispute: the Public Utilities Commission of Ohio may allow the utility-related charge connected to the bailout policy. Ohio utilities and their customers remain subject to the charge approved by the commission.

The ruling does not, by itself, identify how much an individual customer will pay or describe a change to a specific household’s monthly bill. The public announcement also does not identify the full case caption, the justices’ vote breakdown or the exact mechanics of the tariff.

Why the House Bill 6 connection matters

House Bill 6 is the policy backdrop for the dispute. The law became associated with a corruption scandal, and the charge challenged in court was connected to the coal-plant bailout created through that era of state policy.

That history made the regulatory question especially consequential. The case tested whether a charge linked to the bailout could survive a legal challenge brought by opponents who warned that customers could bear about $115 million in potential overcharges.

The Supreme Court’s ruling resolves that challenge in favor of the commission’s decision. It does not resolve every question surrounding House Bill 6 or determine that the challengers’ estimate was an actual overcharge.

What happens next

The immediate legal result is that the commission-approved charge remains in effect. The state-court challenge is over unless further review is sought.

No further review deadline or additional court action was identified with the ruling. Until a further review changes the outcome, Ohio electricity customers remain affected by the charge, while the Public Utilities Commission of Ohio’s approval stands.

A July 27 report said the PSC is defending requirements connected to Oracle’s proposed data-center campus in the Port Washington area. The dispute is unfolding in Ozaukee County Circuit Court after Oracle filed a legal challenge in June 2026.

The court has not resolved Oracle’s challenge. The final amount of financial security and any eventual effect on other customers’ utility rates also remain unsettled.

Rules aimed at limiting cost shifts

The PSC adopted a large-customer rate structure and financial-security requirements for major data-center loads entering Wisconsin utility service territories. The rules are not limited to Oracle’s proposed campus or to one local project.

The commission’s position is that large electricity users should provide financial assurances for generation, transmission and other infrastructure built or planned to serve them. Those safeguards would matter if a major project is delayed, abandoned or fails to use the amount of power it was expected to consume.

PSC filings and public statements describe the requirements as protections for existing utility customers. The stated concern is that other customers could otherwise absorb costs associated with infrastructure developed for a large new load.

That issue has statewide importance as Wisconsin develops rules for exceptionally large electricity users. The outcome could influence future data-center investment, utility planning and the allocation of infrastructure risk between large projects and ordinary customers.

Commission actions in April and May

On April 24, the PSC approved changes to We Energies’ tariff for very large customers. The commission said the action responded to large data-center customers entering the utility’s territory and emphasized protections for existing customers and infrastructure costs.

The April 24 order required a large-load tariff and addressed customer contributions to statewide energy-system costs. It was part of the commission’s effort to establish how exceptionally large new electricity users would be served and how related costs would be assigned.

In a separate May 8 release, the PSC said a data-center customer would be required to contribute to statewide energy costs. The commission discussed that case at its May 7 open meeting. The exact contribution amount was not established in the official record located for this report.

Oracle’s challenge and what comes next

Oracle sued the utility regulators in June over financial requirements tied to data-center power service. Its proposed campus is in the Port Washington area. Reporting said Oracle might pause the court proceedings if the PSC revisited the decision.

On July 10, commissioners retained the credit-rating and financial-security rules, setting up continued litigation. The PSC’s latest position, reported July 27, is that the requirements should remain in place rather than be overturned or loosened while the dispute proceeds.

The case therefore remains a dispute over regulatory design, financial responsibility and future utility planning—not a final ruling on Oracle’s project. The approved sources do not establish that Oracle has abandoned the campus, and they do not establish that household utility bills will definitely rise or fall.

For Wisconsin residents and small businesses, the practical question is whether infrastructure built for unusually large electricity users can be financially secured without shifting stranded costs to other utility customers. That question remains open as the court fight advances.

The sessions were scheduled for July 21 and July 23, 2026, at the commission’s office, 1701 Prospect Avenue in Helena. The deadline for written public comments was July 28, 2026.

Review is at the utility-planning stage

The matter concerns NorthWestern Energy’s integrated resource plan, which covers a 20-year planning horizon. The Public Service Commission is the state body overseeing utility matters, and its review is part of the regulatory process for long-term utility planning.

The scheduled sessions gave members of the public an in-person Helena venue to comment during that process. Written comments provided an additional avenue for public input before the July 28 deadline.

The review can inform later commission decisions involving electricity generation, transmission and potential ratepayer impacts. Those subjects are part of the long-term planning issues identified for commission review, rather than an announced final outcome from the proceeding.

No final outcome established in available record

The available record does not establish that the commission approved or rejected NorthWestern Energy’s plan. It also does not establish a final commission decision on the integrated resource plan.

Likewise, the record does not identify the exact number or types of generation and transmission projects under review. No rate increase or decrease can be inferred from the scheduled listening sessions or the comment deadline without a commission order or a utility filing establishing that result.

The July meetings and written-comment deadline marked public-input steps in the commission’s review, not final action on the plan. Any later commission decision would be distinct from the scheduling of the Helena sessions and from comments submitted by members of the public.

Why the proceeding matters

NorthWestern Energy’s 20-year plan places long-term electricity planning before Montana’s utility regulator. The commission’s review can inform later decisions on generation and transmission, as well as decisions with potential implications for ratepayers.

For Helena residents, the scheduled sessions at the PSC office provided a local opportunity to participate in the regulatory proceeding. The formal written-comment deadline was July 28, 2026.

The session was part of the public-comment stage, not an approval or rejection of the utility’s plan. Written comments in the matter were due July 28, 2026.

Two in-person sessions in Helena

Contemporaneous reporting said the commission reduced its public-hearing schedule to two in-person sessions, both in Helena. The July 23 meeting was described as the final local listening opportunity in that schedule.

The sessions were scheduled at the PSC office, 1701 Prospect Avenue. They provided a way for Helena residents and other participants to submit input to the commission before later regulatory action.

The Montana Public Service Commission is the state regulatory body handling the proceeding. No vote total, final order, approval or rejection of NorthWestern’s plan is identified in the supplied record.

What the plan addresses

The proceeding concerns NorthWestern Energy’s integrated resource plan, which the available reporting described as a 20-year energy plan. The source packet characterizes the plan as involving the utility’s long-term generation and transmission strategy.

That makes the matter a planning proceeding rather than a documented decision in the available record to build a particular project or change customer rates. The record supports that the proceeding could have implications for future energy planning, infrastructure and utility-rate decisions in Montana, but it does not establish what those eventual outcomes would be.

In particular, the sources do not show that the plan will increase rates, require a specific generation project or produce a specified transmission project. Those distinctions remain important because public sessions and written comments are procedural steps, not final regulatory action.

Deadline passed; final outcome not established

The July 28 written-comment deadline followed the final July 23 Helena session. The supplied source review had not located a final PSC decision by Aug. 3, 2026.

That is a limitation of the available record, not proof that the commission had taken no later action. Based on the packet, it would be unsupported to say the PSC approved or rejected NorthWestern’s plan or to assign definite consequences for customers, power generation or transmission infrastructure.

The documented Helena process therefore centered on public participation in a long-range utility-planning matter. A later commission decision, if issued, would be the step that could clarify the plan’s regulatory treatment and any specific implications for Montana electricity planning.

The proceeding remains pending. The commission approved a modified District SAFE plan on March 4, 2026, authorizing $150 million over three years, but later granted reconsideration requests from the Office of the People’s Counsel, the District government and the Sierra Club. No final post-hearing decision retaining, changing or rejecting the plan has been identified as of August 1.

What is at stake

Washington Gas originally asked the commission to approve $215 million over three years for accelerated replacement of aging and leak-prone gas infrastructure. The company proposed recovering eligible costs through surcharges on customers’ gas bills.

Schwalb’s July 24 request says the commission should reject the plan because regulators need stronger cost controls, better prioritization of the highest-risk pipe and a clearer analysis of the District’s climate and electrification policies. Those are positions advanced by the attorney general and other parties, not final findings by the commission.

What the commission approved in March

On March 4, the commission approved a modified version of District SAFE for July 2026 through June 2029. The commission’s program page says the modified authorization is capped at $150 million over three years, about 30% below Washington Gas’s original request.

The modified plan includes annual spending caps, a risk-scoring process intended to prioritize the most dangerous and leak-prone pipes, and requirements that Washington Gas consider alternatives to replacement before seeking approval for particular projects. The commission also included cost-recovery conditions intended to limit ratepayer exposure.

The plan’s rollout, originally scheduled to begin July 1, was temporarily paused while the commission considered the requests for reconsideration and prepared for the new evidentiary hearing. The pause did not itself impose a new customer charge or authorize additional construction.

Why the case was reconsidered

In Order No. 22855, the commission granted the reconsideration requests and identified material factual disputes that could affect the outcome. The order specifically cited the basis for increased pipeline-replacement costs, whether District SAFE achieves the highest risk reduction for each dollar spent, and how greenhouse-gas reductions should be calculated.

The order also describes disputes over the plan’s use of the JANA risk model, non-pipeline alternatives, cost controls and surcharge recovery. The July 27-28 hearing gave the parties an opportunity to present evidence and cross-examine witnesses on the issues that remained in dispute.

The District’s objections

In its post-hearing brief, the District government asked the commission to reject District SAFE. The filing argues that the plan is too expensive, does not sufficiently focus work on the highest-risk pipe and does not adequately account for electrification, climate policy or the risk that some gas infrastructure could become underused.

The District’s filing also presents analyses asserting that replacement could take many decades at the proposed pace and cost billions of dollars if extended across the system. Those estimates and conclusions are part of the District’s arguments and supporting evidence; they are not final commission determinations.

Washington Gas’s stated rationale is that replacing aging, leak-prone infrastructure can improve gas-system safety and reliability. The PSC’s modified plan attempts to retain that safety objective while adding risk prioritization, cost controls and consideration of alternatives.

What residents could see

The immediate issue for gas customers is not a new District SAFE surcharge already appearing on bills. Any future bill effect would depend on the commission’s final action and on which costs, if any, it permits Washington Gas to recover from customers.

If replacement work ultimately proceeds, affected neighborhoods could experience construction, noise, temporary service interruptions and traffic impacts. The PSC says Washington Gas must provide notice to residents in areas affected by pipeline work.

The case also raises longer-term questions about the District’s gas system: how much customers should pay for infrastructure safety, whether replacement is the most cost-effective response to particular risks, how methane and other greenhouse-gas effects should be measured, and how new investment fits with the District’s electrification and climate goals.

What happens next

The commission must consider the hearing record and subsequent filings before deciding whether to retain, modify or reject District SAFE. Order No. 22855 sets August 11, 2026, as the deadline for post-hearing briefs and says the evidentiary record will close then.

Until the commission issues its next decision, the $150 million authorization from March should not be treated as a final post-reconsideration resolution, and Washington Gas’s original $215 million request should not be described as approved.

Sources

• D.C. PSC Washington Gas Pipeline Replacement Program
• D.C. PSC Order No. 22855
• District of Columbia Government post-hearing brief
• Axios Washington D.C. hearing report

What DIMP already requires (and what PHMSA is pushing to improve)

DIMP is part of the federal pipeline-safety framework for gas distribution systems under 49 CFR part 192, subpart P. Operators must run risk evaluations as part of DIMP, and they must also re-evaluate their DIMP at an interval based on system complexity and threat types—but not less than every five years.

In this advisory bulletin, PHMSA focuses on whether operators’ risk evaluations and related integrity decisions actually work in practice—especially for complex conditions that can compound risk.

The three effectiveness gaps PHMSA highlights

PHMSA says operators should strengthen DIMP implementation by addressing:

• High-risk infrastructure: risk evaluations should identify where genuinely high-risk conditions exist, not rely on overly simplified assumptions.
• Interactive threats: threats can combine. PHMSA emphasizes the need to consider how factors that affect likelihood and consequences can intensify each other.
• Leak-management effectiveness: leak management needs to be treated as effective protection, not just a documented program. PHMSA links this to how operators evaluate and respond to leaks over time.

PHMSA illustrates the stakes by pointing to incidents, including a February 23, 2018 Atmos Energy incident in Dallas, Texas, and a separate set of January 2024 investigation findings discussed in the notice.

Risk-model choice: PHMSA encourages probabilistic approaches

A core theme is risk-model selection. PHMSA urges operators to use the most appropriate risk models for their systems within integrity management programs, and it asks for “full consideration” of probabilistic risk models as part of that selection.

Is this a new rule or a compliance deadline?

No. PHMSA frames the document as advisory guidance issued alongside a Federal Register notice. The guidance is meant to clarify existing legal obligations and improve implementation; it is not presented as a new regulation that automatically changes enforceable requirements.

Who is affected—and what households should watch next

This notice is directed at gas distribution owners/operators. In the near term, the practical “watch next” for readers is whether local utilities update internal DIMP risk-evaluation practices and supporting leak-management procedures—particularly for interactive threats and for measuring whether leak management is genuinely effective.

• What you may notice indirectly: refinements in how companies prioritize leak detection/investigation work, and how crews plan responses for non-typical soil and other conditions that can affect leak investigation effectiveness.
• What to do as a resident: follow your utility’s instructions for gas safety, and if you suspect a leak, use the utility/emergency steps you’re given locally (rather than waiting).

What to watch from PHMSA afterward

The bulletin reinforces existing DIMP expectations while signaling where PHMSA believes implementation needs to improve. Readers can watch for whether operators adjust how they run and update DIMP risk evaluations and whether PHMSA follows up with additional guidance tied to the same effectiveness themes.

Sources

• PHMSA (Pipeline Safety) — Guidance page: Enhancing the Effectiveness of Distribution Integrity Management Programs (advisory bulletin)
• Federal Register — Pipeline Safety: Guidance for Enhancing the Effectiveness of Distribution Integrity Management Programs (2026-14071)
• GovInfo — Federal Register PDF text for 2026-14071 (PHMSA-2026-2443)

Bottom line for residents: APS says your rates are not changing now. The next key moment is when the ALJ issues a Recommended Opinion and Order (ROO), followed by ACC review and an open-meeting vote.

What changed after the July 7 hearing

Before July 7, the case focused on evidence presented during the evidentiary hearing. After that hearing concluded, the ACC says the matter moved to the next stage: the ALJ’s recommendation process. In practical terms, this is where the ALJ turns the record into a recommendation that the ACC can consider later in the decision process.

APS’s customer-facing update confirms the near-term takeaway: rates are not changing now just because the hearing stage has ended. Instead, the “what happens next” timeline becomes the primary thing customers should watch.

What the “recommendation phase” means

In ACC rate cases, the recommendation phase is not the final rate decision. The ALJ is expected to issue a Recommended Opinion and Order, which becomes the basis for what parties do next and what the ACC ultimately reviews.

That distinction matters for budgeting: while the case is moving forward, customers should avoid assuming that a recommendation automatically triggers immediate bill changes.

Key dates Phoenix-area customers should watch

• Late November 2026: The ACC says it expects the ALJ’s ROO by late November 2026.
• After the ROO: APS and other parties are expected to respond, followed by ACC review of the recommendation.
• By Dec. 31, 2026: The ACC says the deadline for the Commission to vote on the ROO during an open meeting is Dec. 31, 2026.

If the ACC approves new rates after that review, the ACC’s guidance points to early 2027 as the window when any customer impact could show up—again, contingent on final ACC action.

What customers can do now

Even though the process is moving, APS’s message for customers is clear: no immediate rate change is expected right now. For Phoenix-area households and local businesses, that means this is a “watch and plan” phase rather than an “adjust this month” phase.

As the case reaches the ROO stage and ACC review approaches, keep an eye on ACC and APS updates tied to docket milestones—those procedural markers are what separate “moving through process” from “final rate decision.”

For residents, relocators, and local businesses that budget around predictable utility costs, the most important signal in the coming months will be whether the ACC’s open-meeting vote results in approved rate changes and, if so, what timing the ACC sets for any effect.

Sources

• Arizona Corporation Commission (ACC): “What’s Next in the APS Rate Case?” (July 10, 2026)
• APS newsroom: “APS Rate Case Hearing Concludes; Process Moves to Next Phase”

For Neosho residents, the most important customer point in the PSC order is also the simplest: existing Neosho water and sewer rates are set to remain in effect until changed through a future general rate case—so rates are not automatically expected to change just because the PSC approved the agreement.

What the PSC approved in Neosho

The PSC order grants Missouri-American Water Certificates of Convenience and Necessity (CCNs) for providing water and sewer service in the approved service area around Neosho. The order also documents the agreement and the parties involved in the case.

What stays the same: Neosho rates until a future rate case

The order states that existing Neosho water and sewer rates will remain in effect until changed through a future general rate case. Residents should plan for potential transition changes, but not immediate rate changes based solely on the June 24 PSC approval.

What must happen before the deal closes

The PSC approval is a permission step—not the point where everything is automatically switched over. The order lists specific conditions Missouri-American Water must complete before it can close, including:

• Filing tariff sheets and service area maps before closing on the assets.
• Notifying the Commission when the transaction closes and providing status reports if closing is delayed.

How customers are expected to be informed

The order also spells out customer-transition expectations. Missouri-American Water is required to provide information to customers about their rights and responsibilities and to communicate details about the transition to company ownership.

The PSC additionally requires customer service training for staff handling Neosho accounts, plus sample billing statements and ongoing customer service reporting to Commission Staff following the acquisition.

• Separate books and records: Missouri-American Water must also maintain separate books and records for the Neosho systems in line with applicable accounting requirements.

Background: where this fits in the process

This PSC decision follows the earlier agreement process that led to the Missouri-American Water request for CCNs for Neosho’s water and sewer systems. The local question now shifts to the practical next steps: what residents will see as official transition communications arrive, and how the required Commission filings/notifications roll through before closing.

Until a future general rate case is decided, the order’s key consumer message remains the same: Neosho water and sewer rates are intended to stay in effect until a later general rate proceeding.

Sources

• Missouri PSC press release PR-26-81 (June 24, 2026)
• PSC EFIS docket WA-2026-0072
• Newstalk KZRG recap (June 25, 2026)