Hey there! If you’ve ever been curious about what actually happens behind the scenes when your city’s utilities plan their budgets and future infrastructure, I’ve got you covered. I spent my Monday morning on July 14, 2025, sitting in the Council Work Session Room at Denton City Hall, and I wanted to walk you through exactly how the Public Utilities Board meeting unfolded.
We kicked off right at 9:00 AM. Once the board confirmed a quorum, we were officially in session. The room had that familiar, focused municipal-meeting energy: staff members organizing packets, board members settling in, and the agenda clearly laid out. The first block was the Consent Agenda, which typically handles routine contracts and ordinances. Items B, C, and D—which covered a new supervisory control system for Solid Waste, a contract amendment for ArcFM software with Schneider Electric, and a fully managed AWS cloud environment with CyberTech—sailed through with a unanimous vote (motion by Mr. Nukus, seconded by Ms. Parker). Item A, however, was pulled for discussion. It dealt with rejecting competitive proposals for the Denton Renewable Resource Plan Whitepaper. The board really emphasized the need to establish clear goals and gather public input before selecting resources, ideally looking out on a 15-to-20-year planning horizon. After that focused exchange, it was approved unanimously.
Next, we approved the June 23 minutes with another unanimous vote, then moved into Management Reports. Staff noted that thanks to HB 1522 compliance, agendas will now be posted by Tuesday instead of Thursday, giving the public a bit more lead time. They also laid out the budget timeline: preliminary presentations today, full budgets and rate ordinances returning on July 28 for the board’s recommendation to City Council, a citywide workshop on August 9, and final adoption on September 16.
This is where things got substantive. Staff walked us through the FY 2025–26 preliminary utility budgets using a zero-based approach—meaning no new FTEs were requested, and the focus is squarely on existing capital projects, core services, debt reduction, and revenue diversification. Here’s how it broke down department by department: - Solid Waste saw a 4.2% budget increase but no base rate hike, thanks to nearly $980K in identified reductions. They’re intentionally drawing down their fund balance to fund vehicle acquisitions. - Denton Municipal Electric (DME) had the steepest jump at 34.2%, driven by power purchase forecasts. Still, no base rate increase is proposed. They’re trimming $3.3 million and leaving six vacancies unfilled to help balance the books. - Customer Service proposed a $2.90 flat convenience fee to recover about $1.3 million in annual credit card processing costs. The board had a thoughtful discussion about equity impacts, recurring payment exemptions, and whether they could incentivize lower-cost e-checks. Staff will research regulatory feasibility and report back. - Water is looking at a 6.3% budget increase with a 3% rate hike for residential and commercial users (wholesale rates would see a much larger jump). - Wastewater needs an 11% rate increase to fund major infrastructure, but those rates are expected to step down in subsequent years, with WIFIA financing and impact fees helping to offset costs. - Drainage is holding steady with a 3.6% budget increase and no rate hike, using a $1.3M reserve transfer for channel rehabilitation. Overall, staff noted the average residential bill would only increase about $6.19, and commercial about $9.43, keeping Denton competitive with peer cities.
After the regular meeting wrapped, we transitioned into a Work Session focused on the future of Denton’s power grid. The conversation centered on whether the city should acquire 300 to 600 MW of quick-start dispatchable generation (possibly paired with batteries) or delay the decision while waiting for the Integrated Resource Plan to complete in 18–24 months. Staff highlighted that the Denton Energy Center has generated roughly $260 million in gross margin since 2018, offsetting about $60 million annually in power purchase costs.
The board really leaned into long-term strategy here. There was a lot of discussion about ERCOT market volatility, data center growth, and the rapid private investment flowing into solar and battery storage. Concerns were raised about locking into long-term debt for a 30-year gas generation asset when the market is shifting so quickly, even referencing the TMPA lignite coal plant as a historical cautionary tale. AI-driven energy demand came up too, prompting recommendations to keep all options on the table, including nuclear like Small Modular Reactors, even though current Texas projects aren’t yet scaled to meet immediate needs. A recent battery storage RFP pulled in 60 proposals, suggesting potential market oversaturation that could actually create smart procurement opportunities down the line. Staff confirmed there’s no immediate deal on the table, but they’ll present viable opportunities as they emerge.
As the meeting drew to a close, the board agreed to keep exploring generation options, provide feedback on the preliminary rates and convenience fee proposal, and wait for staff to return on July 28 with the full budget packages. The room cleared out with that familiar mix of civic engagement and quiet reflection that always follows a substantive public meeting.
Thanks for letting me share the inside scoop! If you’re ever curious how your local utilities balance budgets, plan for future energy demand, or navigate rate changes, it’s definitely worth tuning in. I’ll catch you at the next one!