Mar 24, 2025 Public Utilities Board on 2025-03-24 9:00 AM

Good morning and welcome to the Public Utility Board meeting of Monday, March 24th, 2025. I'd like to call this meeting to order. Are there any presentations from members of the public? Nothing? Okay. Then we'll move on to the consent agenda. Would anyone like to, any of the members like to pull any of the items from the consent agenda? I'd like to pull item B, Zimboy. None others? If so, we'll entertain a motion on items A, C, and D. I move to approve items A, C, and D. We'll move to a motion from Ms. Parker. Second. Second from Mr. Rayner. All those in favor please say aye. Aye. Any opposed, sign the same. All right, item B. Good morning board members. Scott Feddick, senior project manager at Capital Projects, here to answer any questions. I didn't see any detail on the work that's going to be performed. I just saw the three different items that you were going to have from the budgets. Sure. So it's primarily for added scope. So we had additional sewer line like on Bradshaw. We found where we needed to add another 120 feet or so of sewer line that needed to be added to make that infrastructure whole again instead of leaving old infrastructure that was there. We also had some sewer on Walnut Street that needed to be added. We had some parks that asked us to add a little additional sewer and a water service over on Sycamore for the new splash pad. We also had Myrtle Street. We found that the sewer was very shallow, old clay needed to be replaced as well. So that was also added in. So it's primarily added scope for infrastructure that wasn't found and we found in the field during the project that needed to be replaced. Okay. So these are just things that have already been performed now we got to fund them, right? Yes, sir. Okay. All right. I don't know if we're going to need to vote on it then, but I guess we will. Entertain a motion. Move approval. Second. We have a motion and a second. All those in favor, please say aye. Aye. Any opposed? Sign the same. None. Thank you very much. All right. Next we'll go to items for individual consideration. First one is item A, which is consider approval of a February 24th, 25 minutes. I'll move approval once I get my microphone on. Thank you. We have a motion. Do we have a second? Second. We have a second. Thank you very much. All those in favor, please say aye. Aye. Any opposed? Sign the same. It passes unanimously. Item B, consider approval of the March 10, 2025 minutes. So moved. We have a motion. I'll second. We got a second for Mayor and thank you very much. All those in favor, please say aye. Aye. Any opposed? Sign the same. Items for individual consideration. Item C, consider recommending adoption of an ordinance of the City of Denton, Texas establishing the schedule of rates for electric service, amending the energy cost adjustment and transmission cost recovery factor schedules, providing for a repealer, providing for a severability clause and providing effective dates for this ordinance and the schedule of rates. Good morning, members of PUB, Viz Popentaval, ADF Finance here to discuss ECA and TCRF. So just to go over some current policy and what we're currently doing now with the ECA, it allows us for quarterly adjustment, which we look out at a six-month timeframe and also the buffer is plus or minus $5 million. Now for the TCRF or the transmission cost recovery factor, it allows us to look at it quarterly and really target the zero dollars at the end of the year. So I want to list out some things that currently go on with the current policy. So for the ECA, fuel costs vary substantially throughout the year. Depending on the time of year, the six-month outlook could trigger an adjustment that would need to be reversed the following quarter. This will become pronounced when core's retail load come online, and really to smooth out the variability and normalize the seasonality of the load and pricing, we want to move to a 12-month outlook, basically looking at 12-month versus six-month, and also the next big thing is to increase the plus or minus $5 million to $10 million, basically. Now we're going to talk about the TCRF or the transmission cost recovery factor. The target here is still going to be zero balance during the first to second quarter, though, but you'll get closer to September, there could be variability. There could be triggering large rate change. And also, every March, the TCRF expense factor changes based on the ERCOT grid improvements made by the four CPs, basically. And one of our recommendations is to smooth out that increase of the variability and normalize the change to the TCRF expense factor. And also, the next big thing is to move to a 12-month outlook, just like the ECA. So this graph here kind of gives us a picture of what it would look like if we keep it at the current policy and also move to the 12-month policy. So if you look at the current policy, by December, that negative could be up to $50 million. So if we move to the 12-month policy, our plus or minus would be closer to that $5 million range. And the next one is the TCRF. So this one right now is less volatile. And if you look at it, if we keep at the current policy, it's at a $1.2 million. And if you look at the 12-month, it's closer to that million-dollar range. So here is just some forecast performance of how we perform throughout the last year. So expenses were lowered due to great performance by the DEC revenue and the EMO office market trade. And that's that left graph. And then on the right graph, you can see revenue tracks closely with the megawatt sales. So this is another graph that we can see the performance. So megawatt hour sales were higher than forecast during the last month of the FY '24 and the first two months of the FY '25. That's on the left side. So now looking at the right graph, seasonality variability of megawatt sales across the system would naturally result in relatively large swings in fund balance up and down throughout the year. Because of higher than forecasted sales and great performance of the DEC and the EMO, the cumulative account balance has grown higher than forecasted. So now the recommendation by D&E general manager and finance is to keep the ECA at the same current rate. And like I said before on a previous slide, we want to move that outlook to a 12-month, but also increase it to a plus or minus 10 versus a 5 million. And then the TCRF, basically keep the rate the same, but also move it to a 12-month outlook. Any questions? Thank you, Chair. So I think there's a philosophical question here. There is a seasonality to energy price, and that's fuel. But that's also just like there's less demand any time outside of summer. So just in general, futures hedges are cheaper. And so do we want to levelize the annual cost of electricity? Do we want to like take a 12-month average, a 12-month target, let the account fill up in the winter because prices are generally cheaper, and then drain in the summer? Or do we want to have a seasonal price where energy costs more in the summer, so we charge -- D&E charges a little more in the summer, and energy costs a little less in the winter on average, so we charge a little less in the winter? I think that's a question for the board. It's easier to plan if the rates are flatter, but it might incentivize -- people with electric heat are subsidizing people with air conditioners because their electric heat actually costs a little bit less to run -- costs D&E less to run in the winter, and D&E is kind of building up a little bit of that reserve. And then come summer, that air conditioning is whenever the average prices are higher. So I think there's just that concept that we need to think about in this 12-month outlook. So I mean, for us from D&E, and finance, we want to kind of just use that stabilized rate, and then just look at that 12-month. It's almost looking like average billing, so -- It's always been the goal, yeah, but what you're asking for is just a little bit longer period of time to look at it, and try to get that average out. That's your goal, is to have a consistency of electric rates. Correct. And Tony can come up and speak a little bit more on that, too. Tony pointed to the D&E general manager. I certainly understand what you're saying, Mr. Taylor. I think based on the number of phone calls and, you know, parking lot conversations I have with people, you know, their request, by and large, is to keep these rates as stable as possible, and not see the large types of increases that we've seen. And certainly, you're very well aware, we've did a cumulative 25 percent rate increase pretty much all at once. And so while people, I think, understand that costs go up, they're certainly asking us to try to keep things as level as possible, and that's why, you know, principally, we've made this recommendation, so. No, no. I actually agree with what the recommendation is. Okay. Mr. Ray. So I have a question. On the 12 months, I understand you're getting the extra months, which helps the average out versus just six months at a pop, but I was curious about the $10 million. On one of those charts, it looked like that the $10 million still did not cover the expenses that could be occurring. So I'm just curious as to where'd you come up with the $10 million? What justifies that number? So the $10 million, we're just trying to find a buffer to see what we can have plus or minus. So we're thinking that would cover a lot of the expenses in the summer months. So does that tie in with what your thoughts were, that $10 million covering the summer? So what happens during the winter? Does that help with your thought process? Well, no, and I think it's with that, we need, if we want to have a pretty flat rate through the year, then we need a big enough bank account, like savings account, stored up in the winter to make it through the hot summer generally. So you know, and I think this chart is good. I just want to point out that every quarter, so April, you know, or March, June, October, we would adjust rates. So it shows like this really precipitous drop. If we went with the quarterly, what would happen is come June, we'd be raising rates. We'd drop rates today, and then we'd raise rates in June, and like is that, you know, the stability might be more important than the most accurate representation of today's energy. Who's using the energy. Yeah. I would probably agree with that because there you are, Tony had made the comment, you know, we already had quite a bump, and if they want consistency, what we just discussed wasn't that consistency. Yeah. We need to help people with their budget. So I appreciate that. Oh, where'd he go? Oh, thank you for that conversation on that. Good morning, Mr. Chair, Bill Shepard, DME. I just wanted to address your comment, too, and just bring your attention to, if you do look at that right-hand column there, I don't know if you can see my mouse, the right-hand column, you'll see that we do fluctuate above and below that 10 million target. But the target that we're looking for is that 12th month of the forecast. So if on that 12th month of the forecast we vary by plus or minus $10 million, then we'll come to you with a recommended change. So that being said, in the future, as we bring more and more load online, you know, given our native growth as well as our core growth, we might be coming back to you and say, let's move that buffer to 15 or 20 million. But maintaining the current policy, obviously we're not going to stay with that red. We're going to be pumping up the price. Correct. Correct. Well, if we maintain the current policy, we would be looking at that red line. So we would make a big adjustment now to maintain policy, and then next month we'd be asking for a huge change to get us back out of the red. We don't like the negative part. It's OK if we have a little buffer on the top, but below is where we do not want to be because that means a big increase to get our customers back online. Thanks, Bill. So I did have just a follow up on this, so I read that as-- so plus or minus 10 million means approximately 10 million, or does it mean 10 million plus to 10 million minus? Approximately 10 million plus to 10 million minus. So if I was coming up to you and this bottom December row on the right-hand column was $11 million, then we'd probably be talking about a reduction to get us back into that sweet spot. OK. Thank you. Any further discussion on that? Yeah. One more. Mr. Newcomb. So January 25, we're sitting at 11 and 1/2. At the end of December, we're looking at 4 and 1/2. Are we looking at a rate increase to get back to 10 million in 3/4 from now? No. I mean-- Or can we carry-- or could we theoretically can carry for the next 12 months after that from where we end at 4 and 1/2? So we should be good right now because of the seasonality. Because right now, January to December is the 12-month outlook. So we're saying if these kilowatts projection hold true, this is where we would be at December for both policies. So we would re-evaluate and look at the kilowatting usage every quarter to try to meet that plus or minus 10. This is current projection right now. And you'll be doing a 12-month look out every quarter? Yes. Exactly. So it's a rolling 12-months. Yes. Does that get you? I guess I'd like to see even 2024 to see where we ended to get to where we started. Were we at 4 and 1/2 and then we came into the year at 11 and 1/2? How does that work in order to get to the buffer we need in the summer to get us through the winter without raising rates there during the summer again? I have on my mind, just like y'all, the last rate increase we did. And I don't want to ratchet it up again and possibly again. We'll keep cranking that deck up and that'll help. So that's a great observation that you made. And I'll just bring your attention to the chart here on the bottom right. We really performed very well the first quarter of the year. So that's why we were able to maintain that lower level throughout the rest of our forecast period. Now, that being said, next time we come to you, we'll have another four or five months of actuals that we'll map against our 12-month outlook and see if we need to make an adjustment up or down. So as of right now, the picture looks pretty good if we stick on forecast and forecast maintains what we're hoping it's going to do. But that can obviously change the next time we get several more months of actuals in. OK. Any further discussion? Then we will entertain a motion. So I guess I asked the big question at the beginning of this, so I'll make the motion. I do think that the levelized cost makes sense and that stable rates are important. You know, I think there might be a little bit of, you know, we're buffering in the winter to ride through summer, but I think that that might be in the best interest of our citizens. So I'll move approval of this item. We have a motion. Do we have a second? Second. Oh, go ahead. Yeah. Let's get somebody new here. I'll second. I'll second. Thank you. We have a motion and a second. All those in favor, please say aye. Aye. Any opposed, sign the same. It doesn't appear to be any, it passes unanimously. OK. Next item is item D, consider recommending adoption of an ordinance for the City of Denton, the Texas Home Rural Municipal Court, authorizing the City Manager to execute a contract with North Star Energy Solutions LLC with DME for approximately $22 million. Good morning. Mark Zimmer, DME Engineering. For your consideration, this morning there was a contract for substation construction services. DME has several approved substation construction projects in the approved CIP that require substation construction services. These services include foundation, installation, conduit installation, steel erection and bus installation. On this slide is a listing of the projects per year and the cost for each project included in this contract as well as a map showing the general location of these projects. So DME prepared RFP to solicit the substation construction services. Seven bids were received and evaluated on safety, quality, schedule and price. As you see here, North Star Energy Solutions was evaluated the highest overall value to the city. So DME recommends a word of contract with North Star Energy Solutions LLC for substation construction services, not to exceed $22 million. We're to the questions portion. This is just a standard substation. It's not a GIS substation. That's correct. Yes, ma'am. Just kind of a one-off question, how does a firm get a one in safety and does that come from our experience with them or I don't know. I didn't like that. I don't know. That just struck me. Yes, it was based on whatever they put in their bid. So we have to evaluate based on what they put in their bid and they had a safety issue. Do they submit a safety plan with their bid? They do. They do and a safety record. Who built your last substation? The one that currently I built, Hickory GI substation, was done by Beta Engineering. All the previous substations were done by North Star. Is North Star a part of somebody else? They used to be a camfer. They're part of Quanta. They're a Crawford group, too. I'm not sure about that. No? Yeah. Okay. It seems like we should be asking more of it. I don't get anything. It's kind of straightforward. 22 million. Let's go. The one that has an asterisk at the bottom of the page. I haven't been on this committee as long as some of you. Is that an acceptable asterisk? T-cost is -- you know what T-cost is a thing, transmission cost of service. That's what we'll get back by transmitting the electricity no matter who produces it. So, others help pay for it. Thank you. We'll increase our revenue. In that regard, how much is much? How much of this total will be recoverable? Do we know how much is much? We do have the totals. I don't have them here for you today, but all the transmission part of these projects is recoverable. There's some distribution component to these projects, too, which we cannot submit their T-costs. But I can get you that information. So yeah, I highly recommend you -- if you're not -- if you have -- if you want to understand more about transmission cost of service, just sit with a DME group and talk about it because it's pretty much the most important revenue that these guys get. It keeps -- you know, it's the reason we do spend money on ourselves and we don't have an outside party in here building substations and transmission lines, because we think we can do it ourselves and we think we can function that way. And I will say this, I'm not sure we're the most efficient, but we certainly -- having a public utility, a public electricity company is a better service to this community than the other ones. All you got to do is watch the news to figure that out. So anyway, that was my soapbox. Anyway, any further discussion? >> Thank you. >> Not entertaining. Motion to approve? >> So moved. >> We have a motion. >> Second. >> We have two seconds. Pick one. Cassie? One of these two gentlemen over here, Mr. Thomas or Dev, I need a one. 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