Welcome to IDACORP's second quarter 2022 earnings conference call. Today's call is being recorded and a webcast is live. A replay will be available later today and for the next 12 months on the IDACORP website. If you need assistance at any time during the presentation, please press star zero on your phone. I will now turn the call over to Justin Forsberg, Director of Investor Relations and Treasury. Thank you, Julia, and good afternoon, everyone. This morning, we issued and posted on IDACORP's website our second quarter 2022 earnings release and Form 10-Q. The slides that accompany today's call are also available on IDACORP's website. We will refer to those slides by number throughout the call today. As noted on slide two, our discussion today includes forward-looking statements, including earnings guidance and spending forecasts, which reflect our current views on what the future holds, but are subject to several risks and uncertainties, including uncertainties surrounding the impacts of future economic conditions. This cautionary note is also included in more detail for your review in our filings with the Securities and Exchange Commission. These risks and uncertainties may cause actual results to differ materially from statements made today, and we caution against placing undue reliance on any forward-looking statements. As shown on slide three, on today's call we have Lisa Grow, IDACORP's President and Chief Executive Officer, and Brian Buckham, IDACORP's Senior Vice President and Chief Financial Officer. In addition to Lisa and Brian, we have other members of our management team available for a Q&A session after Lisa and Brian provide updates. Slide four shows our quarterly financial results. IDACORP's second quarter 2022 earnings per diluted share were $1.27, a decrease of $0.11 per share from last year's second quarter, primarily reflecting the impacts of weather and partially offset by the accounting impacts related to a regulatory order. Since we planned for normal weather, a portion of the weather impacts compared to last year were expected, and it is important to acknowledge that the Jim Bridger regulatory proceeding was also included in our original guidance for the year. Recall that last year's spring was very hot and dry, and that did not repeat this year. This spring was cooler and wetter, which impacted irrigation and air conditioning loads. Year-to-date, earnings per diluted share were $2.18, a decrease of $0.09 per share from the first half of last year's weather-assisted record results. Our results over the first six months of 2022 reflect IDACORP's second highest first half in the history of the company. Today, we also raised the bottom end of our previously issued full year 2022 IDACORP earnings guidance estimate by $0.10 to the range of $4.95-$5.05 per diluted share, which would result in the 15th consecutive year of growth in earnings per share. We also affirm that we believe Idaho Power will not need to utilize any of the additional tax credits that are available to support earnings under its Idaho regulatory settlement stipulation. These estimates assume historically normal weather conditions over the balance of the year. I'll now turn the call over to Lisa. Thanks, Justin. Thanks to everyone joining us on the call today. I hope you are all having a wonderful summer. I'd like to begin with a high-level overview of some of the headlines for this quarter, specifically growth, infrastructure projects, economic conditions, and weather in our service area. These factors create both opportunities and challenges for our company. Growth continues to be a key differentiator for us. As you can see on slide five, Idaho Power's growth stayed steady at 2.6% this quarter and remains quite strong. We believe our competitive prices, outstanding reliability, and strong customer satisfaction help make our service area attractive for business and residential customers. We continue to see a robust pipeline of future projects, including speculative industrial development, existing customer expansion, and new customers in most of our customer classes. As noted on the bottom of that same slide five, the economy in Idaho Power's service area continues to outperform national trends. Moody's predicts sustained economic growth for our service area, calling for GDP growth of 3.3% in 2022 and 4.8% in 2023. Note that the 2022 GDP growth figure is a notable increase over Moody's estimate at the time of our first quarter earnings call. Also, unemployment within our service area is at 2.9%, below the 3.6% national average. More importantly, employment in our region has grown 6.7% since Q2 of last year. Perhaps not surprising, with the rapid increase in interest rates, we are seeing an easing in the record pace of building in some areas. Like Moody's, we remain bullish regarding our continued overall customer growth. Many of you may have seen The Wall Street Journal article last week about the Boise housing market prices cooling off. However, residential building permits remain historically high, and requests for new service are still robust. We believe lower housing costs may be a net positive for companies and individuals looking to relocate in the area. The affordable costs and high quality of living have been important reasons people historically have wanted to move to our service area. We have also felt the impacts of the global supply chain challenges as growth is increasing demand on already strained supplies. We've been working hard to mitigate delays on important items like transformers and cable. We are seeing some positive signs of easing supply chain pressures in some areas. Inflation is another economic challenge we are monitoring closely. Essential expenses like housing, food, gasoline represent much of the increase in inflation nationwide, and our service area is not immune to these trends. They create challenges for our customers, communities, and employees, as well as for our company. We remain focused on attracting and retaining skilled staff and are working actively to ensure our workforce continues to receive competitive wages and benefits and maintain our status as an employer of choice in an increasingly competitive job market. While we have felt the pressures on O&M that are pervasive in the macroeconomy, we remain committed to our efforts to control expenses like we've always done, and we are confident in our team's ability to remain focused on controlling costs throughout the second half of the year. As we address growth, an emphasis on reliable, affordable, clean energy to serve our growing customer base highlights the importance of ongoing projects like the Boardman to Hemingway transmission line. That line will serve as a clean energy highway across the West and also provides both reliability and resilience to the system. We're still on track to receive a permit from the state of Oregon by the end of this year, and the line is currently planned to go into service in 2026. As I mentioned last quarter, we're also planning to bring two large battery storage projects totaling 120 MW online next year to meet our capacity needs, pending approval by the Idaho Public Utilities Commission. Recall that these batteries will be the first of their kind in Idaho. We're working to address additional capacity needs in 2024 and 2025 through an ongoing RFP process, and we should have updates on that topic later this year, as right now we're still working through the process. Finally, the weather. The weather in the first two quarters has definitely given us mixed results. Results for Q1 benefited from cold weather, yet results for Q2 were challenged by a wet, cool spring, and Brian will give more details on that in a moment. The summer finally arrived in late June, and temperatures have been unseasonably warm, and we've seen a strong demand since then. We're feeling optimistic about Q3 thus far. Recall that the third quarter is generally our highest sales quarter as we serve our peak summer demand. When you combine weather, growth, infrastructure, the regional economy, and positive regulatory outcomes, we are forecasting a strong finish to 2022. Now, we've mentioned general rate case timing on prior calls, and at this point, I'd say we are continuing to analyze the timing of a case in a very dynamic environment, and we will keep you posted. With that, I will hand things over to Brian for some more details of this quarter and our expectations for the rest of the year. Brian? Thanks, Lisa, and good afternoon, everyone. I'll start my portion on slide six, where you'll see our second quarter 2022 results compared to Q2 last year. All in, I'd say we had a solid first half of the year. As Justin highlighted on slide four earlier, it's the second highest earnings for the first half of the year in our history, second only to last year. We've seen continued strong customer growth along with higher transmission wheeling revenues that resulted from energy market conditions in the West. Also, the Jim Bridger order from the Idaho Commission had a notable impact on results for the quarter. On the other hand, offsetting those benefits were the impacts of weather on sales, irrigation sales in particular, combined with higher O&M expenses compared with Q2 last year. In the table of quarter-over-quarter changes, you'll see that customer growth added $2.7 million to operating income. As Lisa noted, we expect this growth to continue as people and businesses relocate to our service area and as existing businesses expand their operations and footprint. We share the optimism in Moody's updated GDP outlook for our service area, but there's certainly been a lot of commentary nationally about a recession. If that recession currently exists or if it's yet to materialize, I do think it's helpful to remember that Idaho Power's service area saw positive customer growth even during the nationwide downturn in the aftermath of the 2008 financial crisis. With that empirical knowledge, we're optimistic regarding the potential of the cities in our service area to attract businesses and residents, despite some increasing evidence of a recession-like slowdown nationally. Back to this quarter's results, mild temperatures and higher precipitation in the second quarter drove a 36% reduction in usage per irrigation customer. It also caused a 10% reduction in usage per residential customer and a 6% decrease in commercial per customer usage. Industrial per customer usage was relatively flat for the quarter. These reductions are all compared to last year's second quarter, which by way of comparison was significantly hotter and drier than this year's Q2. We hit our all-time record peak load in June of last year. During April, May, and June of this year, cooling degree days in Boise were 59% lower and precipitation was 86% higher than the same three months last year. A fairly stark contrast in terms of weather conditions. Effectively, we're comparing to a Q2 last year that was 25% drier and 109% hotter than normal. These weather conditions all combined to cause much of the $25.9 million net usage per customer decrease in operating income. I think, notable though, despite these weather conditions in Q2, retail sales volumes increased across all of our customer classes for the full first half of the year, other than irrigation customers. That's reflective of new customers and colder weather in the first quarter of this year and demonstrates the outsized impact of irrigation usage in the second quarter. The $6.3 million increase in Idaho Power's fixed cost adjustment mechanism revenues that you see next on the table partially offset the decreases in residential and small commercial customer usage. For the year, positive second quarter FCA revenues offset the similarly sized FCA revenue decrease recorded in the first quarter. Further down, you see a $3.9 million increase in operating income from the change in net per megawatt-hour revenue. The Idaho regulatory order for the Jim Bridger Plant, which increased retail rates on June 1 this year, led to a portion of that increase. Another piece relates to the decrease in usage per customer that I just described for irrigation customers. That results from monthly fixed charges being spread over fewer megawatt hours, causing an increase in retail revenues per megawatt hour during the second quarter of this year compared with the same period last year. Next on the table, continued higher transmission wheeling revenues during Q2 of this year increased operating income by $2.9 million. Warmer weather in the Southwest U.S. and milder weather in the Pacific Northwest led to a price spread between energy market hubs, which increased wheeling activity across Idaho Power's transmission system. Wheeling customers paid 4% more for transmission wheeling, with Idaho Power's transmission tariff rate increasing in October 2021 to reflect higher transmission costs. We recently filed our draft transmission tariff rate for the next tariff year with a further slight increase in the rate. The higher other O&M expenses shown next on the table led to a $12 million decrease in operating income this quarter compared with last year's Q2. The maintenance projects at the Langley Gulch Natural Gas Plant that I mentioned last quarter contributed to the expected increase there. This was our first scheduled major maintenance for the plant since it was built about 10 years ago. Maintenance projects at the Jim Bridger Plant and on the spillway at the American Falls Hydropower Project drove additional O&M. Much of the plant maintenance doesn't recur annually, but instead it's scheduled in cycles over a period of years. We also recorded about $2 million of higher performance-based compensation accruals during Q2 of this year. Perhaps not surprisingly, we also saw inflationary pressures on labor-related costs, professional services and supplies, and on vehicle fuel. As we look ahead, I note that we performed the bulk of our plant maintenance ahead of our summer peak load-serving season, so much of the plant-related maintenance was front-loaded for 2022. With the outsized impact of O&M on the first half of the year and with that cyclical maintenance mostly out of the way, we'll remain focused on operating efficiently and managing expenses in the second half of the year. Along those lines, I'll address our updated O&M guidance shortly. The $8.8 million decrease in depreciation expense that's further down the table on slide six is where the bulk of the effect of the Jim Bridger order increased operating income for the second quarter. The order approved investments made at the plant since the last general rate case was prudently incurred through the end of 2020. Under regulatory accounting rules, that resulted in the deferral of certain Bridger-related depreciation expense for those approved assets. The order approved the collection of depreciation over an accelerated period, along with a return component through the end of the Jim Bridger collection period, which is now 2030. Looking ahead, we estimate the order will benefit after-tax net income for the full year 2023 by approximately $10 million, with the benefit declining each year thereafter until that collection period ends. A decrease in non-operating expense led to a $2.4 million increase in pre-tax earnings. That was related to higher allowance for funds used during construction and, to a lesser extent, higher investment income due to rising market interest rates and also some interest on life insurance proceeds in a Rabbi trust for a benefit plan. Finally, the decrease in income tax expense was due mostly to the net decrease in pre-tax income. All of these changes in the aggregate resulted in a decreased IDACORP's net income of $5.7 million or $0.11 per share for the quarter. You might have noted that our CapEx spending so far this year increased by 51% over what we spent during the first six months of last year. As we expected, the bulk of that additional CapEx relative to last year and relative to our historic spending levels is for our large battery storage projects and for some natural gas plant upgrades to obtain additional output and efficiency from the units. As we look at our CapEx forecast for this year, some of the potential inflationary impact is mitigated based on contracts already having been signed for the batteries and for some of the work. Ongoing inflation and elevated prices will likely continue to impact the products and services we purchase going forward, like everyone seems to be experiencing. In an inflationary environment, we'll remain thoughtful and disciplined in our capital projects and spend in how we negotiate contracts with vendors and in how we access the supply chain. With that spending in mind, I'll point you to slide seven, where you'll see that IDACORP and Idaho Power continue to maintain strong balance sheets and liquidity. In July, Moody's made its expected downgrade of both IDACORP's and Idaho Power's credit ratings. Those ratings are still slightly above those in S&P, and they remain solidly investment-grade. IDACORP's operating cash flows and liquidity position as of the end of June are also on slide seven. Cash flows from operations in the first half of the year were about $11 million lower than the same period in 2021, and the decrease was mostly related to lower operating income. The liquidity available under IDACORP's and Idaho Power's credit facilities is shown on the middle of slide seven. As we work to fund our upcoming capital plans, as we've discussed on recent earnings calls, we plan to primarily finance those projects with debt, at least until the ratio is closer to the target. This makes an equity issuance over the next 12 months unlikely and probably none in 2023. Slide eight shows our updated full-year 2022 guidance. With some regulatory uncertainties behind us, we now expect IDACORP's earnings to be in the range of $4.95-$5.05 per diluted share. This guidance assumes normal weather and economic conditions for the balance of the year. Our guidance still also assumes that Idaho Power will use no additional tax credits in 2022 under the Idaho regulatory stipulation, which, as a reminder, provides earnings support in the Idaho jurisdiction of a 9.4% return on year-end equity. We've also updated our full year O&M expectations by $10 million, to now fall in the range of $365 million-$375 million. Keeping up with the level of customer and load growth we've experienced in our service area and continued elevated prices have had an impact on that range. That said, we're confident in our ability to manage costs in the second half of the year, despite ongoing inflationary pressures. Our expectation on 2022 CapEx spending is also increased to now be in the range of $500 million-$520 million. Additional project complexity and scope have increased the cost for some of our existing projects. While we made the adjustment this quarter, we expect that we could be at the higher end of even the updated capital range for the year. Finally, given our most updated forecast of operating conditions, we refined our expectations on hydropower generation for the year. In a year like this one, we're fortunate to have a diverse portfolio of power supply resources as we've drawn on and will continue to draw on all sources through the peak summer months. On weather conditions, slide nine shows the recent outlook for precipitation and temperature from the National Oceanic and Atmospheric Administration. Current weather projections for August through October suggest we'll likely see warm, dry conditions over the rest of the summer into early autumn, which is certainly what we've experienced during July and into this week in August. With that, Lisa and I, and others on the call are happy to answer your questions. We are now ready to begin the question and answer session. If you'd like to ask a question, please do so by pressing star one on your phone. Please ensure your mute function is turned off before you ask your question. We will take as many questions as time permits on first come basis. Once again, that is star one on your phone to ask a question now. Your first question comes from Julien Dumoulin from Bank of America. Please go ahead. Hey, good afternoon, team. Thanks for the time and the opportunity. Appreciate it. Hope you guys are well. Hey, good afternoon. Hey. Just at the outset here, if I can, just perfunctory, AMT, just the situation on taxes. Would love to hear you guys read the IRA at the outset here. Are you talking about alternative minimum tax, the 15% tax that's proposed? Yeah. Yeah, exactly. I just wanted to see, like, just how you guys are reading that. I mean, I assume that's not too much of an issue for you guys, right? Our understanding of the AMT was it applied to net income exceeding $1 billion. While I would love to have that sort of net income, we're not quite there. At least at this point, unless it change, we don't think that it applies to Idaho. Totally. All right. I wanted to get that one back past me here at the outset here, if I could. Separately, more substantively, if I could, just coming back to the company, you know, obviously, you alluded to in the comments here about the rate case and perhaps providing some ongoing updates here. Again, are we to read that being ahead of plan, accelerating seemingly some of the O&M on the maintenance front, that puts you in a pretty good position vis-à-vis timeline and visibility to perhaps remain out of one? When we look at that every year to see, you know, what will give us the best result, and certainly that continues. Brian, did you want to add something to that? Yeah. I'll just mention there's a lot of factors we're looking at, Julien. You know, growth in revenues is one. Growth has kept us out of a rate case for quite a while, among some other factors. Those have been beneficial. We look at capital spend. We're looking at the timing of in-service dates for some of our projects. You know, we have the battery storage project out there now that we expect to be done next year. That's a sizable in-service project by then. Hells Canyon Complex is another one we look at. We've been watching you know, credit ratings, cash collection, interest rates. Those are all factors we've historically looked at. We're also looking at the Bridger order and the impact that has. That's a benefit from a rate case perspective. I'd say there's a lot of moving parts there from a timing perspective. I don't think we'd expect a filing this year. Perhaps, second half of next year is a possibility under some scenarios. Again, we have to look at all of those factors when we decide the timing of a case. Got it. Can you elaborate a little bit on the Bridger resolution? I mean, how much latitude that provides you here as you think about it? Yeah, we look at that in terms of just the dollar impact. One of the things we noted is that the impact next year, or at least our expected impact of that order is about $10 million. The commission determined that the investments we made at that plant from 2012 forward were prudent. Adding that into rate base was beneficial. We've got a mechanism for cash collection over a period of time for that, and then a deferral mechanism for the portion that we don't collect. We think that's a pretty constructive outcome for both us and our customers. That financial benefit of that outcome will help in our view of a rate case going forward. Got it. Lastly, just, can you provide a little bit of an update on crypto here and how you're framing those potential tailwinds? Obviously, there's been some waxing and waning. Just where do things stand, if you will, quote unquote, "today"? Adam, do you want to take that? Yeah, I'm happy to chat about that. We continue to get inquiries. I will say we haven't had any large movement in that regard. We obviously filed the speculative high density load filing with the commission. That provides some benefits, I think, and opportunities, potentially for crypto, but we haven't seen any large movements in that regard in terms of actually moving forward with projects, although we do get a fair amount of inquiries on a monthly basis. All right. Fair enough, guys. That's all I've got. Thank you. Thank you, Julien. Thanks, Julien. Your next question comes from Brian Russo from Sidoti. Please go ahead. Hi, Brian. Hey, Brian. We are not hearing you, Brian. I apologize for that. Good afternoon. Hi there. You know, given the obviously strong hydro conditions in your service terrain across the Pacific Northwest, does your guidance kind of assume kind of a normal year of irrigation sales, you know, relative to the abnormally high demand for electricity from that customer class, you know, during this time for the last few years? Well, I'll start the answer and hand it off to Adam. We don't have great water conditions in Idaho. We really are seeing our second year of drought. While it was cold and wet in May and June, it just wasn't enough to really move the dial on the drought conditions that we had the driest first quarter that, I think, on record. We're still struggling through that. You know, recall that June is when we saw last year pretty high irrigation loads because it was dry, where we didn't see that this year. I think it remains to be seen what happens in the, you know, from this point forward when the season ends, which is usually towards the end of this month, depending on the crops, can go a little bit into September. Anything that you would add? No, I think you might be referring to the Mid-Columbia, which has had a pretty good water year. That just didn't reach out to us. The one thing that has benefited for us is the fact that the power prices have been somewhat reasonable this year despite the natural gas commodity prices are obviously quite high. I think you're probably thinking about the Mid-C, which has really helped BPA's system. Yeah, we're still in drought conditions here. Brian, the one thing I'd add to that is last year we had some conversations with water conditions about possible curtailments, and there were some small scale curtailments throughout Idaho. As we look at the water forecast for this year, there's still some small prospect for curtailments, but we don't think there would be curtailments on a large scale basis for the irrigators this year. Yeah. There's been one so far, 50,000 acres, very small, so no real impact to our irrigators at this point. We're seeing some of them come off. Their crops have ripened, and so some of the water's come off already. Yeah. Okay. Got it. I see. That's all built into that 5-6.5 million MWh of hydro generation, right, below the previous level. Got it. Given the weather patterns that we are seeing in the regions west of you, are you seeing, you know, incremental transmission wheeling revenues, and any benefit of that, you know, in this third quarter? We would anticipate that. I mean, that has been something that has come to be a trend, just given the different pricing differentials between the markets. Of course, you know, looking prospectively, I try not to forecast too much because I'm generally wrong. That is a trend we've seen certainly. Yeah. What we've seen so far is the Mid-C prices have been reasonable and the liquidity's been quite good. In Palo Verde, the prices have been higher. When you see that spread, you typically see folks using our transmission system. Over the last three years, because of that, we've seen pretty significant increases in volumes each of those years. Again, we're seeing it so far this year as well. Okay, great. Despite the $10 million increase in O&M, the guidance still assumes no usage of the ADITs. You know, I'm just curious, you know, are you comfortably within your ROE band range? Does the $5 and does the top end of your range, you know, does that capture the 9.4%, or you know, is that the high end of the range? Yeah. Brian, I would say that the bottom end of our guidance is quite a ways above that 9.4% figure for the ADITC usage. Understood. Thank you. Thank you, Brian. Your next question comes from Anthony Crowdell of Mizuho. Please go ahead. Hi, Anthony. Hey, good afternoon. Ladies, good afternoon. Just hopefully one quick question. In the prepared remarks, you talked about you're evaluating the filing of a rate case. If you could talk about, I guess, what are the decisions that you're going through, and when will we know when that evaluation is finished? Brian can kind of recap what he said earlier, but we you know we are required to give a 60-day notice to the PUC before we file. You know, we've been trying to be pretty transparent as we go along. It's just right now, there are just a lot of moving parts. As Brian mentioned earlier in this call that we don't see it at the end of this year or filing this year. You know, do you wanna recap what you said before? Yeah. I'd just say one of the primary factors that we're gonna be looking at is the in-service date of some of the assets that we have. For example, the battery storage projects are, you know, it's 120 megawatts, very sizable. As those assets go into service, we have to finance those with debt. For example, we'll have additional depreciation expense associated with that. Interest expense to cover as well. As we look at some of the additional incremental costs that come with just the growth that we're seeing in our capital plan going forward, that's probably going to be the items that most likely trigger the rate case. We're actually doing some scenario planning now on what the best dates might be for bringing some of those cases. We'll have more visibility on that moving forward. At this point, we just haven't chosen a date far enough out that we haven't decided exactly when that's going to be. Again, it's those factors that I mentioned earlier that are really gonna be part of the decision. A lot of different variables that we have in mind as we look towards the general rate case filing. Great. Thanks so much. Again. Thank you. A final opportunity, press star one to signal for a question, and we'll pause for just a moment. That concludes the question and answer session for today. Ms. Grow, I will turn the conference back to you. Thank you all again for joining us this afternoon and for your continued interest in IDACORP. I wish you all a good evening and a safe and happy rest of your summer. Thank you. That concludes today's conference. Thank you for your participation.