Portland General Electric Q3 2023 Earnings Call Transcript

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Provided by Quartr
October 27, 2023

There are 11 speakers on the call.

Operator

Good morning, everyone, and welcome to Portland General Electric Company's Third Quarter 2023 Earnings Results Conference Call. Today is Friday, October 27, 2023. This call is being recorded. And as such, all lines have been placed on mute to prevent any background noise. After the speakers' remarks, there will be a question and answer period.

Operator

For opening remarks, I will turn the conference over to Portland General Electric's Manager of Investor Relations, Nick White. Please go ahead, sir.

Speaker 1

Thank you, Latif. Good morning, everyone. I'm happy you can join us today. Before we begin this morning, I would like to remind you that we have prepared a presentation to supplement our discussion, which we will be referencing throughout the call. The slides are available on our website at investors.

Speaker 1

Portlandgeneral.com. Referring to Slide 2, some of our remarks this morning will constitute forward looking statements. We caution you that such statements involve inherent risks and uncertainties and actual results may differ materially from our expectations. For a description of some of the factors that can cause actual results to differ materially, please refer to our earnings press release and our most recent periodic reports on Forms 10 ks and 10 Q, which are available on our website. Leading our discussion today are Maria Pope, President and CEO and Joe Terpich, Senior Vice President of Finance and CFO.

Speaker 1

Following their prepared remarks, we will open the line for your questions. Now, it is my pleasure to turn the call over to Maria.

Speaker 2

Thank you, Nick, and good morning. Thank you all for joining us today. Beginning with Slide 4, I'll start by discussing our results for the quarter and speak to the key drivers as well as our outlook for the balance of the year. For the Q3, we reported GAAP net income of $47,000,000 or $0.46 Per diluted share. This compares with Q3 2022 results of $58,000,000 or $0.65 per diluted share.

Speaker 2

Clearly, it was a tough quarter. The key drivers include: 1st, continued load growth from industrial customers offset by reductions in residential and commercial usage, partially driven by cooler weather overall. And second, volatile power costs from a major heat event in mid August, which resulted in transmission congestion issues and a significant spike in energy costs. I will touch on each in turn. Turning to Slide 5, We continue to see solid growth from industrial customers, particularly data centers.

Speaker 2

However, this growth is chunky and we saw modest growth in the Q3. Overall, through the 1st 9 months of the year, industrial load has grown over 6.5% compared to 2022. We foresee continued growth in the 4th quarter and potentially even higher industrial growth in the coming years. With strong legislative tailwinds at both the state and federal level, there is significant government support through grants and other incentives focused on the semiconductor sector. 15% of U.

Speaker 2

S. Semiconductor manufacturing occurs in our state, largely within PGE service territory. The sector will benefit not only from the Federal Chips Act, but from the $240,000,000 that the Oregon legislature has allocated to 15 semiconductor companies. As a result of these investments, state officials are projecting over $40,000,000,000 in new Oregon projects and over 6,000 new jobs. Recent expansion announcements have been made by Intel, Microchip and Analog Devices.

Speaker 2

In the Q3, we also saw modest reductions in residential and commercial energy use compared to last year, driven by cooler weather in the late summer as well as energy efficiency, rooftop solar and overall distributed energy adoption. Given lower than planned 3rd quarter loads, we have revised our full year 2023 Growth guidance to 2% weather adjusted, consistent with our long term expectations. The second driver of 3rd quarter results was higher power costs stemming from the record breaking heat event. PTE set a new peak load that surpassed our previous summer peak by 6%. During this time, we also witnessed day ahead Mid Columbia peak pricing of nearly $1,000 per megawatt hour given significant transmission issues and constraints.

Speaker 2

Our generation plants performed well, Very well and we're well integrated with our contracted energy supply. We also saw meaningful customer demand response reductions. Even still, our overall purchase power and fuel expense increased significantly. I want to thank and recognize Our PTE colleagues who helped ensure that customers continue to receive safe, reliable and uninterrupted power throughout the heat wave. Given the impact of power costs on our Q3 results, we are narrowing our guidance range for the year.

Speaker 2

We now expect 2023 results to be in the range of $2.60 to $2.65 per share as compared to the previous range of $2.60 to $2.75 per share. We anticipate 4th quarter results to improve as a result of normalized power cost conditions. Just as a reminder, 4th quarter 2022 regional gas prices peaked to over $55 per MMBtu and average midsea power prices rose to $2.65 excuse me, dollars 2.65 per megawatt hour. Additionally, while year to date power cost performance has been challenging relative to the annual update tariff or AUT, We anticipate a more favorable resource mix and market conditions through the Q4. And finally, we expect continued effective O and M cost management and to hit our 2023 targets.

Speaker 2

Phil will walk through our trajectory for Q4 in more detail. Overall, our capital programs are on track with Clearwater Wind expected to come online later this year and continued progress on our previously announced battery storage projects. These are in addition to our base capital work that support customer growth as well as grid improvements focused on greater safety as well as reliability and extreme weather resilience. 2 other significant highlights from the Q3 include, including our 2024 rate case negotiations and the announcement of several federal grants which will enable the acceleration of new technologies and transmission construction. I'll start with our GRC, which we are very pleased to conclude with parties and await a commission order expected in the coming weeks.

Speaker 2

Overall, we settled recovery of ongoing capital investments, operating and maintenance costs notably wildfire vegetation management expenses And importantly, risk reduction in our power cost recovery framework, an important first step in addressing our PKM mechanism, which Joe will touch on in his remarks. We also maintained a fifty-fifty capital structure and a 9.5% ROE. Additionally, we received approval to amortize $27,000,000 in wildfire deferrals and collect forecasted Wildfire mitigation costs under the automatic adjustment clause. Lastly, federal grants. We are pleased and excited with the 3 Department of Energy announcements that build upon the work we're doing to advance the clean energy transition and in collaboration with our regional partners.

Speaker 2

First, DOE announced a $250,000,000 grant to support upgrading The Bethel Roundview transmission line from 230 kV to 500 kV in partnership with the Confederated Tribes of the Warm Springs. The tribes have been our partner and co owner of the 500 Megawatt Pelton Round Butte hydro projects along the Deschutes River for decades. 2nd, AGE, Utilidata and NVIDIA has consortium that was awarded $50,000,000 grant for smart chip grid project to improve visibility, reliability and overall grid management. And lastly, the Pacific Northwest Hydrogen Association's hub is one of 7 projects nationwide to move forward to the next step and negotiations with DOE. PGE is contributing our former Boardman Coal Plant site and water rights for the green hydrogen production facility.

Speaker 2

We also look forward to an offtake agreement and working on green hydrogen power generation. These award selections represent just the start. Near term capital will be determined in 2024 as negotiations proceed. We are still pursuing additional projects and opportunities and have submitted over $65,000,000 in incremental grants to support another $125,000,000 in additional projects as well as have other projects in the pipeline. These projects represent growing momentum in the region that will create meaningful benefits for customers and communities for years to come.

Speaker 2

In summary, despite challenging operating conditions in the 3rd quarter, We made important progress towards strengthening key cost recovery mechanisms as part of the constructive GRC settlement. Our entire team is laser focused on execution for the remainder of the year. Our long term growth plan is increasingly well established, underpinned by investments to meet growing customer needs, ensuring grid resilience and leading the clean energy transition. Our recent regulatory progress and ongoing capital investment reinforces our confidence at our long term earnings growth rate of 5 to 7% in 2024 and beyond. With that, I'll turn it over to Joe, who will walk you through our financial results.

Speaker 2

Thank you.

Speaker 3

Thank you, Maria, and good morning, everyone. I'll cover our Q3 results before providing updates on our rate case, capital investments and liquidity and financing. Moving to Slide 6, our 3rd quarter results reflect dynamic load and customer composition, Challenging weather and power market conditions, continued emphasis on grid resiliency and execution of our capital plan. The economy in our service territory continues to display strength. As Maria noted, regional economists anticipate significant investment in our area, particularly focused on semiconductor manufacturing.

Speaker 3

Many large high-tech companies in our footprint have signaled upcoming growth projects that could result in sizable economic benefits to our region. Unemployment in our region was 3.4% as of September, Below the national average of 3.8 percent, industrial load growth continued, albeit at a more moderate rate than witnessed in the 1st and second quarters, which we see as a short term deviation on a long term industrial growth trend. Total Q3 2023 Loads increased by 0.2% weather adjusted compared to Q3 2022. On a non weather adjusted basis, Total load decreased 0.9% year over year as weather was less severe across the full quarter despite a hotter August. Q3 2022average temperatures were the hottest on record for the Q3 in our region.

Speaker 3

We continue to see significant heat this summer, but we saw a milder weather in September, which had 35% fewer cooling degree days than compared to 2022. Residential load decreased 2.5 percent or 0.5% weather adjusted compared to Q3 2022, Fewer cooling degree days and increased energy efficiency and distributed energy resource adoption contributed to this decrease. Residential customer growth increased 0.7%. Commercial load decreased 2.1% or 1.2% weather adjusted as we also witnessed increased penetration of energy efficiency and DERs among commercial customers. Industrial load growth continued in Q3 2023 increasing 2.5% or 2.7% weather adjusted.

Speaker 3

As Maria mentioned, we view this moderation compared to previous quarters as temporary and anticipate a continuation of the growth cycle that we have been observing in recent years. 3rd quarter Power market conditions remain challenging in 2023 with resource scarcity during the peak period surrounding the August heat event having an acute impact on the quarter. I'll now cover our financial performance quarter over quarter. We experienced an $0.18 decrease in Total revenues driven by a 0.9% decrease in total deliveries combined with unfavorable changes in the average price of deliveries due to lower residential and commercial loads. Q3 2022 power cost conditions were also challenging and $0.27 of the quarter over quarter earnings change is attributable to Power cost headwinds in 2022 that we normalize for this comparison.

Speaker 3

Current year power costs were also elevated, driving a $0.07 EPS decrease in the quarter, reflecting costs that were higher than anticipated in our annual update tariff. There was a $0.02 decrease in EPS from higher operating expenses, net of deferral related items, primarily driven by higher generation and grid We also saw a $0.06 impact from depreciation and amortization expense due to higher plant balances year over year, A $0.03 decrease from the impact of higher interest expense due to higher long term debt balances and short term debt balances carried for a part of the 3rd quarter. A $0.07 decrease due to the dilutive impact of draws on the equity forward sale, which last occurred in mid July. Finally, we had a $0.03 decrease from other items, which included $0.08 of a decrease in other income due to prior year medical Planned buyout gain did not reoccur, partially offset by $0.03 increase from higher AFUDC from clean energy and base capital project and $0.02 increase from higher returns on non qualified benefit trust and other miscellaneous items. Turning to Page 7 for a summary of our 2024 general rate case to date, which remains subject to OPUC approval.

Speaker 3

As Maria highlighted earlier, we are pleased to reach a constructive settlement on the remaining items, including recovery of recent capital investments and operating costs to maintain the system Reliability and resiliency. Given the frequency and magnitude of extreme weather and resource constraints in our region, including the August heat event, The reliability contingency event provision represents a constructive solution to our power cost recovery framework. This update better reflects the impact of climate change and dynamic regional markets that we have been historically experiencing. Additionally, steps in the docket will continue in the coming weeks, including annual power cost updates in November. A commission decision is expected by December, but could come sooner for rates effective January 1, 2024.

Speaker 3

On to Slide 8, which shows our current capital forecast through 2027. We are continuing to evaluate emerging transmission projects that Maria and I mentioned in the Q2 call and plan to provide a robust capital forecast update on the Q4 call in February. I will also note that the PGE portion of projects receiving grant funds is not yet reflected in these figures as scoping and negotiations are ongoing. We will reflect these projects in our forecast once final plans have crystallized. The 2023 RFP has worked through preliminary administrative steps and is expected to officially launch to the market in the coming weeks.

Speaker 3

Its submissions are in early 2024 with submission of a project shortlist anticipated in the first half of next year. Project selection will take place shortly after in mid-twenty 24. Turning to Slide 9 for a summary of our liquidity and capital finance Our equity sorry, our liquidity and financing. Our strong balance sheet, investment grade credit ratings and stable credit Outlook remains unchanged from our previous disclosures. Total available liquidity as of September 30, 2023 is 925,000,000 In mid August, we amended our existing revolving credit facility to extend the maturity, while also upsizing from $650,000,000 to $750,000,000 to provide additional flexibility.

Speaker 3

We also executed a $500,000,000 first mortgage bond purchase agreement in late August, including $300,000,000 of that that was issued as of September 30 with the remaining $200,000,000 to be issued under a delayed draw feature in the Q4. As I said previously, we issued the remaining $92,000,000 under the equity forward facility in July and we continue to have the equity market availability under our ATM program. PGE has entered into forward sales agreements for 58,000,000 of the total $300,000,000 of the ATM as of the Q3. We remain confident in our balance sheet and our ability to access the capital markets and continued strong interest from both debt and equity investors in recent offerings. Careful dilution management remains an important focus as we continue to track towards our authorized fifty-fifty capital structure over time and maintain flexibility in financing options.

Speaker 3

Our results in the Q3 continue to reflect our investment year thesis as we execute to establish a sturdy growth foundation for PGE. They also reflect ongoing challenges that we are all working to diligently manage through year end. Some of the headwinds we have faced Q3 are expected to dissipate in the last 3 months of the year, including in power cost. Turning to Slide 10 for our outlook for the Q4. As Maria touched on earlier, indicators point to a more reasonable power market condition, especially compared to Q4 2022, which saw cold weather, pipeline disruptions and regional gas storage anomalies drive Pacific Northwest Gas and Power Prices to Extreme Levels.

Speaker 3

Due to these factors, 4th quarter power costs were meaningfully higher then considered in the AUT baseline, which is represented in the chart. We expect impacts of load growth, Depreciation, interest expense and dilution observed year to date to continue. Operating cost execution remains a critical component of our plan and all corners of our business are leaning in to drive savings and results. Given these efforts, we expect our 4th quarter O and M to come in below our current full year run rate. Finally, we expect an improved resource mix compared to our AUT expectations that will allow us to make up ground in our annual power cost position.

Speaker 3

This includes better availability of generating resources, improved plant outage expectations and portfolio optimization that allows strategic dispatch of our generation fleet. Due to load results in the 3rd quarter being below expectation, we are revising our 2023 full year weather adjusted load growth guidance from 2.5% to 3% to 2%, which is in line with our long term expectation. We continue to have strong visibility to incoming projects concentrated among digital and high-tech customers, which are continuing their growth path. As such, we remain confident in the load profile in our area and are reiterating our long term load growth guidance of 2% through 2027. As Maria noted earlier, we are narrowing our full year earnings guidance to $2.60 to $2.65 per diluted share to reflect power cost challenges experienced in the Q3.

Speaker 3

We have sharpened our load expectations for Q4 and anticipate power cost and O and M execution will drive and solid service territory fundamentals give us renewed confidence in reaching our earnings growth guidance of 5% to 7% in 2024 and beyond. As we enter the final months of 2023, our ongoing focus of providing clean, reliable and affordable energy remains unchanged. We look forward to furthering this quarter mission, which will enable prolonged value for our customers, communities and shareholders. And now, operator, we are ready for questions.

Operator

Thank Please standby while we compile

Speaker 4

the Q and A roster.

Operator

Our first question comes from the line of Shar Pourreza of Guggenheim Partners.

Speaker 3

Good morning, John.

Speaker 5

Good morning, Maria. Good morning, Joe.

Speaker 6

Good morning. Joe, you discussed getting,

Speaker 7

I guess, a little bit more in the weeds On the CapEx profile and longer term spending run rate, right, regardless of the RFPs. I know, obviously, we're going to get an update in 4Q, but you've been in the For a few months now, and we're still kind of looking at that declining CapEx profile on the slides. Can you just maybe elaborate on what you mean by robust? I mean, is it fair to assume that $800,000,000 run rate will step up materially? Just directionally how we should think about it as we head into the Q4?

Speaker 7

Thanks.

Speaker 3

So, thanks, Shar. So, The way I look at it is, so when we say more robust, I think we would like to provide more transparency as we work through 24 and the further years of our base business, the transmission that Maria had mentioned before, as well as what I'll call The potential for the opportunities be it the RFPs that we've spoken to and the grants. It would not Unreasonable to say there's some upward pressure there, but Char, that's what we're waiting for is as we get through the rate case outcome here and get a little more clarity on the transmission plan and the grants that we hopefully can give a little more of a Transparent longer view of the possibilities as opposed to what is as you see there a relatively flat plan. And in part that will also weigh into that as it relates to that base, I should say is the most how the most recent IRP that has come out impacts Our base capital as it relates to supporting renewables as well.

Speaker 7

Got it. And then just on the financing side, Joe, just Obviously, I guess, how should we think about the forward equity financing for any sort of wins under the next RFP round, I think it's awarded next year, right? So you have an ATM now, is that kind of the avenue you're going to look at this point?

Speaker 3

Yes, I think we continue to evaluate based on the expectations and the outcomes that will come from the RFP, our approaches, but I mean I think an approach that starts with a base of having an ATM to support us, right. We can we currently as much as we have About $250,000,000 left to issue, right? The cash flows of the ATM are still we haven't yielded any from so far, but We'll continue to evaluate the ATM as it relates to supporting our business from a base, a transmission and others and then evaluating on an episodic basis based on Size of the any of these significant wins that could come from an RFP.

Speaker 7

Okay, got it. And then lastly, just for me is maybe just Tied a little bit deeper into the power cost aspect of the settlement, I guess how do you see the mechanism you got for, let's just say, extreme events as actually insulating the EPS volatility? For example, like how would it have impacted this quarter if you had it in place that past August? Thanks.

Speaker 3

And then so the mechanism itself is not finalized as of yet, but based on our understanding, so The definition of an event, there would be 3 items that would come into play as evaluating the if there was an event, which would be The day ahead mid Columbia index price, PG's eligibility to request resource adequacy assistance and then A neighboring balancing authority that's publicly declared an event. So those are sort of what we believe the definitions would be. Jared, if we applied those, we do believe the heat event that occurred in August would have triggered that definition. We'd also believe that if we were to look to the prior years, there was a significant collection of events that not just the seed event, if we were looking to 2022 2021, there are several events that would meet that. So we do believe that a portion of our costs that are incurred in this current year would have been defined to pull into that.

Speaker 3

We're not Because the commission hasn't issued an order and we haven't finalized, we're not at the point of declaring what that value or average would be. But once the orders come down and we have That clarity will consider discussing what that average impact would have been over the last number of years here, potentially as we get to year end. But there is is there something there? Yes. Are these events something that occur at least annually or so?

Speaker 3

Yes. Okay, perfect. Thank you, guys. We'll see you in a couple of weeks. Appreciate it.

Speaker 3

Thank you.

Speaker 2

Thank you.

Operator

Thank you. Our next question comes from the line of Richard Sunderland of JPMorgan.

Speaker 3

Good morning.

Speaker 8

Good morning. Can you hear me?

Speaker 2

Yes. Yes.

Speaker 8

Great. Thanks for the time today. A lot of helpful color on the quarter and looking to 4Q here as well. Maybe starting on the O and M, but just wanted to make sure I was parsing this correctly. It sounds like you were standing up some savings specifically to help this year.

Speaker 8

Is that the case? And How does that flow through versus, I guess, effectively your plan at the start of the year? And then just to be more precise on kind of 'twenty three versus beyond, Are any of these savings kind of structural in the 2024 and more long term?

Speaker 2

So Joe, you want to take this one?

Speaker 3

Sure. Good morning, Richard. So as it relates to O and M, so yes, we do believe some work that we've been doing throughout the year, when I Throughout the year, more think that April and beyond, will yield some benefits to us financially as reducing us below our run rate that we're currently at We did see a sort of a reduction in our what I'll call our overspend to expectation in the Q3, but we were still over, but We expect in the Q4 we will yield some O and M savings. Those O and M savings are meant to be like A structural going forward management of our cost, I mean, so we would expect to have that the same structure in place. These are not one time items to achieve benefits for the year, but more structural items as we relate to changing the way we manage our costs and run our business, going forward.

Speaker 3

So we would expect that to continue.

Speaker 2

Richard, one of the things as you look at our external statements, I think it's important that we acknowledge that there's a couple of things going on. The first is you can see the amortization of deferrals from the ice storm, wildfire events, prior PKAM years and other things Are increasing that O and M line. But so our ongoing wildfire Prevention work, all of the mitigation we do, the interaction we do with the U. S. Forest Service and local entities, really around vegetation management and others.

Speaker 2

And through this rate case, there were some really important mechanisms that were put in place. That combined with what Joe was speaking of in terms of the ongoing alignment Reduction in our costs, quite frankly, just driving efficiencies using technology better. You can see we've had planned availability most recently at the 90 6 percentile rate and our flow status rate was just 1.7%. That was a huge contributor particularly to the 3rd quarter. We can see in our distribution system, work order output is a 12% improvement year over year.

Speaker 2

We're seeing for customers that are crew alignment in scheduling restoration priorities and Our duration of impacting events was an improvement of 13% and overall 1,300,000 Customer minute outages excuse me customer outage minutes were saved just from 2020 2. So there's a real impact not only to our cost structure and to better operations, but to serving our customers more reliably With power that they've come to expect as we've seen increasing amounts of extreme events throughout our area.

Speaker 8

Understood. That was very helpful color. Maybe zooming out to a high level and Maria, you brought this up in terms The wildfire work, but could you speak a little bit to sort of what you're focused on and what Your work with the industry is focused on in terms of wildfires overall is an industry issue. It's It's been obviously hugely topical this summer and for prior years. Just curious if there's anything you can share in terms of where you and EEI are focused on this front currently?

Speaker 2

Sure. It's a good question. And let me Turn first to ourselves internally. We have absolutely improved our practices, better use of technology and some Truly cutting edge technologies where we are able to share that access with other Hardee's, whether it be forest agencies, the national, the state and the local entities, where we're working in conjunction on vegetation management. The Ag Bill that's working its way through Congress, I think is a really good example, where we've includes timber and debris removal on an expedited basis.

Speaker 2

We've also had permit reform in particular with the U. S. Forest Service reducing permits from several years down to months and really accelerated our collaboration and our improved practices. As we look both at the state level and the federal level, clearly we need to do more. It's a high priority across the industry and as well as with regulators.

Speaker 2

And so I think you'll see increased actions coming that really support the ongoing reliability and Important service that utilities provide.

Speaker 8

Got it. Thank you. And maybe one last one for me. The state and federal work you cited around the semiconductors industry and then your latest IRP update, Is that all harmonized or is there even some elements of this that have emerged that are additive to that outlook as you recently refreshed it?

Speaker 2

So I think the use of the word harmonize is a really interesting term. We are seeing the pace of change And clearly the programs that we've seen come out of the federal government Department of Energy that supports transmission, Better use of a smart grid and our partnerships between tribes all the way to NVIDIA are really making a difference. But you take a look at the CHIPS Act and then what the state of Oregon has done through the Semiconductor Task Force And the legislature's appropriation of $240,000,000 of matching funds. You can find on the state website the 15 companies that will receive funds raising ranging from just a couple of $1,000,000 to $115,000,000 Those projects, some of which are included in our forecast, but the majority are not. And if you look at that list, about 85% of those projects are actually in Portland General Electric Service Territory.

Speaker 2

So for the next decade, it is a tremendous opportunity for the company, for the region and is also combined with Pretty extensive workforce support and investment in our universities, really focusing in on an important reassuring of Our technical strength as a country and just as a reminder, 15% of semiconductor manufacturing is in this region. So it's a real strength for our state and for the company.

Speaker 8

Great. Thank you very much for the time today.

Speaker 2

Thank you.

Operator

Thank you. Our next question comes from the line of Julien Dumoulin Smith of Bank of America.

Speaker 9

Hey, good morning, team.

Speaker 3

Good morning.

Speaker 5

Hey, thank you guys. Appreciate it.

Speaker 3

Let me perhaps let's pick up

Speaker 5

on that last question there quickly. How do you think about tying the sort of the timeline between having a more normalized 2% here in the current year to kind of getting up to some of the higher levels that you talked about earlier, just a moment ago with some of the benefits from the CHIPS Act and at the same time still having that 2% long term. I mean, So how do you see the profile of that sales growth and the confidence for I think previously when we connected some really strong commentary around customer growth sustaining itself in addition to sale weather adjusted sales growth sustaining itself here in the medium term? I don't want to put words in your mouth.

Speaker 2

Yes. No, no, it's interesting. We look at it as building blocks and I think there's rarely been a period of time of so much change and opportunity. So first of all, we are a state and a region that has benefited from in migration and while that has paused Most recently, we can continue to see really strong like blocking and tackling economic growth across our service territory. What we also are seeing is increased data centers and the continued digital expansion.

Speaker 2

One of the things that's important about that is that many of those facilities are built, but not yet built out. And so the infrastructure is there and you'll see the capacity built out over the coming months quarters. And then finally, the longer term and really significant opportunities comes in the manufacturing side of things. And this is everyone From silicon manufacturers all the way down to semiconductor manufacturers, to those who were really helping with the tools and cutting edge development like a Lam Research or Like a Lam Research or a Metro Graphics or others. And there's quite a bit of opportunity that will that we some of which we can see today and are already serving and much of which will come out over the number of quarters, years And actually even through the decade.

Speaker 2

It's truly game changing for the state as well as for us as a utility to be able to serve such growth.

Speaker 5

Yes. Maybe just to clarify that, you're not pulling back on any of your earlier comments in light of the 2020?

Speaker 2

No, you know what I think? Yes. No, we aligned our 2023 number really with our long term guidance of 2%. I think it's we feel very confident in the 2% number and I think my comments underlie optimism for even higher growth than that.

Speaker 5

Okay. All right. Fair enough. I'm just trying to tease the near term for the long term here. And then if you can, I mean, speaking about kind of reconciling 'twenty three against the longer How about 'twenty three and the levers that you've pulled here to keep it at the lower end despite the litany of More weather related pressures here as you alluded to earlier?

Speaker 5

Is there a read into 'twenty four that we should be aware of? I know you provided some commentary in the remarks, But is there any kind of direct read through whether it's O and M or otherwise in terms of pull forward, that the 2024 we should just be ready for?

Speaker 2

Yes. No, I think as Joe outlined, we have really focused cost management efforts on how we Manage the business, stay very cognizant to customer prices, and drive efficiencies across our organization. But we remain confident in the long term growth rate of 5% to 7%. And as we've always said, 2023 was an investment year.

Speaker 5

Got it. But no hesitation on 2024 in turn from what I can tell?

Speaker 2

No, not at all.

Speaker 5

Okay, wonderful. Thank you so much. All right, you guys take care.

Speaker 2

Thank you. You too.

Operator

Thank you. Our next question comes from the line of Nicholas Campanella of Barclays.

Speaker 10

Hey, thanks for taking my questions. Good morning. Good morning. I guess just on the revenue increase to 391,000,000 I know that there's a lot of moving pieces with power costs and you called out the $183,000,000 for power costs. But is the net of those two numbers, That's what's falling to the bottom line or is that too simplistic?

Speaker 3

I think I'm not sure I would do that math on the net of the power cost. And specifically, we're talking about 2024 here. Yes. But I think The performance of what will fall to the bottom line is obviously our load recovery, our return on the assets Here as we build to 'twenty four, I mean the rate case overall and the net outcome that we have, we're pretty satisfied that it was a really constructive Dialogue and the case itself fits within our what I'll call our calculus to Maria's comments of our long term growth plan.

Speaker 10

Great. Great. And then, could you just expand a little on why load and demand mix was an issue for Q3, but what's just driving your confidence level for the Q4? I'm sorry if I missed that.

Speaker 3

So I think as it relates specifically to the Q3, right, the mix shift was away from the residential commercial Heading towards the larger and it's really due to 2 things that occur more the one that occurs more in the summer period and one overall. 1 is energy efficiency. Well, we had a little more penetration on energy efficiency at that commercial and that residential level, but also and more the There was rooftop solar penetration that was occurring at both that commercial and that residential level that was pushing down the overall load. The customer growth continues to be as we had anticipated. I believe we had 0.7% customer growth, but it's just That pressure from the energy efficiency and the DER penetration that are driving it.

Speaker 10

Okay, great. And then just One more, Joe, just on the equity. I thought that you said that you would pull the full ATM down by the end of the year. If I'm wrong, please correct me. But just As an aside, how do you kind of think about on this current CapEx plan with the equity announced to date, Your ability to get to the 50% or is there more that needs to that we need to be thinking about?

Speaker 10

Thank you.

Speaker 3

So, all right, thank you. Specifically as it relates The ATM, we have not pulled down on the ATM as a follow. So what we have entered into is about we have I believe we disclosed $58,000,000 of the ATM we have entered into agreements on, none of which we have closed upon. So from a cash flow standpoint, right, the entire ATM is outstanding with 2 40 ish million is left to take into the market. As it relates to Could you say your second part of your question again just to make sure I don't answer it as it relates to the capital?

Speaker 10

I just wanted to be sure, are you leaving it open to whether or not You would pull that down by the end of the year or can that be further feathered into 'twenty four and beyond?

Speaker 3

I would say that The ATM that we have in the our equity needs are complete for this year and the ATM would be open for next year. We don't have any at least current needs and we obviously would always be opportunistic with our equity, but we do not have any current needs

Speaker 9

Thank you.

Operator

Thank you. Our next question comes from the line of Greg Orrill of UBS.

Speaker 2

Hi, guys.

Speaker 5

Good morning. Hey, good morning.

Speaker 4

So two parts. First, just how do Regarding the $0.27 to $0.32 driver on the current year, the variable power costs, How do you think about putting that range in place? What kind of gets you there? And then secondly, how are you thinking about the level of ownership in renewables in your RFP and just maybe not a number, but sort of appetite for ownership, I guess?

Speaker 2

Okay. So let me take your first Jen, and then your second and if I don't do an adequate job, Joe can fill in. So with regards to power costs, the $0.27 to 0.3 Roughly about half of that, I would call sort of structural. And you can see that In the AUT numbers, we can see it in what we sort of have already in place for the quarter. The other part is really the work that we do every day and the work that we can see and that would not be unusual for those kind of activities to yield those kind of results for what is a pretty challenging Q4 and a lot of work that we have to do.

Speaker 2

We feel confident that we'll get there. With regards to the RFP, the RFP will be issued shortly. We will put in a short list of opportunities that the company would hope to be able to participate in. Those have a little bit of a different timing just to make sure that there is Full transparency, but we're looking for the final RFP to be out by the end of this year. The first half, Probably the shortlist will be submitted by that time.

Speaker 2

And we would hope that by the end of 2024, we would have finished some negotiations, obviously, over By an independent evaluator to make sure that we are driving the lowest cost, least risk projects for our customers. And we've been pretty fortunate so far with regards to the company's ownership projects and That has really been, being able to drive competitive costs, be able to manage risks, And quite frankly have very good partners as we move forward. So we would hope to have the same circumstances as we enter into 2024 and beyond. Clearly, there's a lot of opportunities.

Speaker 10

Appreciate it.

Speaker 3

Thank

Operator

you. Our next question comes from the line of Andrew Levi of Heif Hedge Asset Management.

Speaker 2

Hi, guys. Good morning, Andy.

Speaker 3

Can you hear me?

Speaker 6

Hey, how are you?

Speaker 2

We can.

Speaker 6

Okay, that's good. All is a good thing. Just a few questions, if you don't mind. Just on the August that hurt things a little bit for the quarter. If you had this settlement on the PCAM in place, just for that event, not for the quarter, but just for that event, How would that have kind of played out and how would we think about the numbers?

Speaker 6

Again, it's more of a guesstimate by you guys, but I'm just curious.

Speaker 3

So Andy, good morning. So we are back to what I said earlier, so we do believe the obvious event would be would meet the definition, although that definition is still to be finalized by the commission order. Each event here is unique, but to your comment and we're not assigning numbers here yet, but there would there be some I I hate to be so vague, but would there be some impact to our results this year? If it was treated positively, yes. And this event was not an even though each event is unique, not uncommon, over the last from 2020 to 2022, there were about 15 events that we believe would meet the definition of an RCE over about 40 days.

Speaker 3

So Andy, for right now, I would say that we believe there would have been Some positive impact to the results for the quarter, if this meets the definition, but we'd like to wait and see and make sure we're aligned on that definition and calculation with the commission's order before we sort of declare what the result would or could have been.

Speaker 2

Andy, this is a solid first Steph, as we work to have power cost mechanism that is comparable to other utilities across the country. Okay.

Speaker 6

And I guess that's something for the next rate filing as well to try to improve once again. And my second question is around transmission CapEx. And obviously, we have to wait for the 4th quarter. You talked about a robust update on the CapEx in general. But can you just talk about your transmission strategy and how that may Ultimately, play into the RFPs and how much capital you kind of want to deploy from one to the other and with transmission CapEx being a little bit more predictable, because obviously there are no RFPs involved.

Speaker 2

Sure. Well, thank you. And clearly, we're Similar to other utilities across the country, we look at increased electricity use, growing service territory and renewable development. Transmission is an important component. When we look at our transmission strategy in particular, The core of our projects that we're looking at are actually within our service territory or adjacent to our service territory.

Speaker 2

Many of them are reconductoring, most of them use existing rights of way. And so they're relatively lower risk, Easier to execute projects. And as we build those out and better understand Of the significant growth in customer usage, we will have more announcements as we move forward. We're very encouraged as well by the discussions at the Federal level with regards to facilitating faster transmission fighting and making all of the permitting Easier to do. There's no question that we need to build transmission and whether it is the Pelton Round Butte line in partnership with the With the confederate tribes of the warm springs or reconductoring and within service territory work.

Speaker 2

It's a really important opportunity as we move forward. And we will have a decade of projects in front of us that will enhance our overall reliability.

Speaker 6

Okay. And I just wanted to get back to TCAM because honestly, I'm pretty honest, right? A couple of people hit me up here on my IB. So I just wanted to make sure there's no confusion. So The $0.07 hit or $0.07 negative variable quarter over quarter from net variable power costs, You're not saying that that PKAN mechanism That has been modified, but only have helped by 0 point 0 $7 or should we not is that not like apples to apples that negative And how that's peak in.

Speaker 6

Without getting into the details of it, like, because I think some people are kind of looking at it where Just straight apples to apples, I'm guessing it's not that simple.

Speaker 3

No. Andy, so as you know, each year the PKM, we set Our baseline and that $0.07 year over year is just really our relative performance in the quarter to the baseline. So it Is potentially any impact of the heat event inside of that performance, but that is in no way meant to identify that. It is just the overall The design by quarter of how the AUT identified net variable power cost to our performance. So there is no direct linkage.

Speaker 6

Right. And then as you get into the Q4, that's part of the reason why there's such a large benefit because there was Such a large hit last year and now you're getting recovery of that this year.

Speaker 3

Right. As a reminder, so as it Relates to year to date as we disclosed in the 10 Q, we are $28,000,000 above the baseline. Part of what drives the 4th quarter through That resource availability mix is an expectation that we will move from being above the baseline to some amount below the baseline by the end of the year.

Speaker 6

Okay. And then I guess part of it is also fuel as well, right, for the Q4, right?

Speaker 3

The key to the Q4 here is the expectations of resource mix, What we'll consider normal wind, normal weather, normal what we'll call normal market pricing and that all will allow us to optimize our portfolio and help us to move within the PKAN band between the above to below.

Speaker 6

I mean, it seems like you guys are in great shape heading into 'twenty four. I mean, beyond this rate case settlement that hopefully gets approved, We've had modifications. You've got top line growth, robust CapEx opportunities and And our commission that's been very supportive and you guys working well with them. I mean, I don't see anything on the negative side. I don't know if you guys do it any differently, but

Speaker 3

Andy, we continue right. The rate case outcome, we would agree it was very constructive. The growth opportunities that we have previously spoken to are continue to be supported. And when I say growth on the investment side, either through the IRP update or through some of the most recent grants that there's clearly the opportunities and Our sort of a longer term growth plan, the facts that came out during the quarter continue to validate that point.

Speaker 6

Okay. People are getting tired of hearing me ask questions, so I'm going to move on. But have a great weekend, guys.

Speaker 3

Thank you, Andy.

Speaker 2

Thanks, Andy.

Operator

Thank you. Our next question comes from the line of Travis Miller of Morningstar Inc. Please go ahead, Travis.

Speaker 9

Thank you. Hi.

Speaker 2

Good morning, Travis.

Speaker 9

Good morning. A quick follow on to some of the discussion early. The decoupling Mechanism that was in the settlement, how would that have affected some of the variability in the earnings or just financials in general This year and Q3.

Speaker 2

It's a good question. And in the Q3 where we did see lower residential and small Commercial energy usage, it would have had an impact. We have had a decoupling mechanism previously And this decoupling mechanism is a good first step in improving how it's looked. I'd also say, that weather, has had a significant impact on the Q3, and that would not have been included.

Speaker 9

Okay. Okay. Very good. And then again related, are there capital investments that you can make over the next couple of years that might reduce either the variability in some of those extreme events or in general power cost variability On the capital side, any thoughts?

Speaker 2

Yes, absolutely. And as we look at on the power cost side, I mentioned we had a Solid first step with regards to the PKAM. We've also invested significantly in our processes, our people, our systems. We have more work to do, but it is making a difference and we're able to update our annual update tariffs with those annually when we don't have a rate case. We've also have additional capacity contracts and our 3 battery storage projects, which are progressing quite well, We'll have a significant impact on our ability to be able to balance between days, not necessarily provide longer term reliability, But certainly, more price stability around power costs.

Speaker 2

All of them are important. And I would add that Region continues to move forward with day ahead market discussions as well as resource adequacy discussions through the Western Power Pool. So all of those things taken together will improve the situation.

Speaker 9

Okay, great. That's great. Thanks.

Speaker 2

Thank you.

Operator

Thank you. I would now like to turn the call back over to Maria Pope for closing remarks. Madam?

Speaker 2

Thank you very much. We appreciate your interest in Portland General Electric. We look forward to connecting with everyone soon, in particular those who will be at the

Operator

This concludes today's conference call. Thank you for participating. You may now disconnect.

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Earnings Conference Call
Portland General Electric Q3 2023
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