Good day, and welcome to the Ormat Technologies Inc. Second Quarter 2020 Earnings Conference Call. [Operator Instructions]. I would now like to turn the conference over to Rob Fink of FNK Investor Relations. Please go ahead, sir.

Thank you, operator. Hosting the call today are Doron Blachar, Chief Executive Officer; Assaf Ginzburg, Chief Financial Officer; and Smadar Lavi, Vice President of Corporate Finance and Investor Relations. Before beginning, we would like to remind you that the information provided during this call may contain forward-looking statements related to current expectations, estimates, forecasts and projections about future events that are forward-looking as defined in the Private Securities Litigation Reform Act of 1995. These forward-looking statements generally relate to the company's plans, objectives and expectations for future operations and are based on management's current estimates and projections, future results or trends. Actual future results may differ materially from those projected as a result of certain risks and uncertainties. For a discussion of such risks and uncertainties, please view the Risk Factors section as described in Ormat Technology's annual report on Form 10-K and quarterly reports on Form 10-Q that are filed with the SEC. In addition, during the call, the company will present non-GAAP financial measures such as adjusted EBITDA. Reconciliations to the most directly comparable GAAP measures and management's reasons for presenting such information are set forth in the press release that was issued last night as well as in the slides posted on the company's website. Because these measures are not calculated in accordance with GAAP, they should not be considered in isolation from the financial statements prepared in accordance with GAAP. Before I turn the call over to management, I'd like to remind everyone that a slide presentation accompanying this call may be accessed on the company's website at ormat.com under the Presentation link that's found on the Investor Relations tab. With all that said, I'd now like to turn the call over to Doron Blachar. Doron, the call is yours.

Thank you, Rob, and good morning, everyone. Thank you for joining us today. I'm excited to speak with you today as the CEO of Ormat, a position I assumed on July 1. Starting with Slide 5. Our second quarter was another solid quarter for Ormat with $23 million net income, higher gross margins and $97.9 million second quarter adjusted EBITDA led by improved profitability of our electricity segment. I am extremely proud of how our team is operating through the challenges of the COVID-19 environment. While we continue with our efforts to minimize the COVID-19 implications on our business, our first priority from the beginning of this pandemic was to make sure that all of our employees are safe and they are able to navigate this crisis unharmed. On the electricity segment, we were able to successfully complete the enhancement of Steamboat Hills, increasing our portfolio by 19 megawatts to 933 megawatts, and also made significant progress to bring Puna back online. Our ability to complete and progress with the development of projects derives from our unique capabilities as a vertically integrated company. The pandemic has delayed the awarding of contracts for large projects in our product segment. However, our product segment is currently on track to meet its revenue forecast for the full year 2020. We are continuing our efforts to grow our electricity segment, as I will elaborate later on the call, and not only are we on track to meet our 2022 megawatt growth goals, we are also laying the foundation to enable us to continue our growth path in 2023 and beyond. Now I will turn the call over to Assaf Ginzburg, who joined Ormat in early May as our new Chief Financial Officer, for a review of the financial results before I provide an update on our operations. Assaf, welcome.

Thank you, Doron. I'm excited to join Ormat. Let me start a review of the results on Slide 7. Total revenues for the second quarter of 2020 were $175 million, down 5%. Our cost of revenue decreased 8% to $110 million in the second quarter of 2020. The net result was a slight decrease in gross profit of $0.2 million. Moving to Slide 8 for more details on the electricity segment. Revenue in our electricity segment was $129 million for the second quarter of 2020 and represented 74% of total revenue. This was slightly down from the $129.1 million or 70% of total revenue in the same period last year. This quarter, Olkaria complex revenue was impacted by curtailment from an undisclosed customer, mainly due to COVID-19 reduction in demand. This reduction was offset by improved generation in other power plants that were upgraded recently. Cost of revenue this quarter was reduced mainly by $1.3 million decrease in lease expenses due to termination of Puna's lease transaction and lower O&M expenses in other power plants. The cost of revenue this quarter includes business interruption insurance income of $2.7 million related to Puna compared to $6.9 million included in the same period last year. Turning to Slide 9. During the second quarter of 2020, product segment revenues decreased 16% to $43.7 million or 25% of total revenue. On Slide 10, the Energy Storage and Management Services segment contributed $2.5 million of revenue for the second quarter of 2020 compared to $3 million last year. This decrease was mainly driven by the impact of COVID-19 on the frequency regulation market prices. Moving to Slide 11 for a discussion of our total gross profit and margin. The second quarter 2020 consolidated gross margin was 37.4% compared to gross margin of 35.4% for the second quarter of 2019. The increase in gross margin and profit was driven by improved margin of the electricity segment. On Slide 12, the gross margin for the electricity segment expanded year-over-year to 44.1% compared to 42.8% for the second quarter last year. The increase is mainly due to improved performance of our operating power plants. The product segment gross margin was 20.6% in the second quarter of 2020, similar to last year. We expect 2020 annual margin in this segment to be in line with this quarter. The storage segment margin improved but still reported a negative gross margin, as we anticipated. Our recent announcement of closing the Pomona transaction reiterates our commitment to grow and improve the profitability of this segment. Turning to Slide 13. SG&A expenses for the second quarter of 2020 were $16.2 million compared to $17.5 million for the second quarter of 2019. The decrease was mostly due to $1.3 million from the sale of concessions, business interruption recovery of $0.6 million relating to the Puna Power Plant and a decrease in professional fees, travel costs, partially offset by higher sales commissions. Turning to Slide 14. Operating income for the second quarter of 2020 was $48.1 million compared to $46.9 million for the second quarter of 2019, an increase of 2.5%. On Slide 15, you can see the breakdown of the operating income by segment. As we continue to grow our stable electricity segment, we expect it to take a larger portion of our operating income. Turning to Slide 16. Net interest expense for the second quarter of 2020 was $19.8 million, a decrease of $1.7 million. Higher capitalized interest, in addition to lower tax equity-related interest expense, was partially offset by interest related to the fact we have chosen due to COVID-19 to increase long-term debt levels and maintain higher cash levels. Now turning to Slide 17. The provision for the income tax for the second quarter of 2020 was $11.8 million or an effective tax rate of 33.3% compared to an income tax benefit of $3.5 million for the second quarter. Income tax benefit for the second quarter of 2019 included a one-time tax benefit of $13.3 million, which was excluded from our adjusted EPS. Turning to Slide 18. Net income attributable to the company's shareholders was $23 million or $0.45 per diluted share compared to $33.9 million or $0.66 per diluted share for the second quarter of 2019. Adjusted net income to the company's shareholders in the second quarter of last year, netting of the one-time tax benefit I mentioned earlier, was $20.6 million or $0.40 per diluted share. Reconciliation of adjusted net income and adjusted EPS are provided in the appendix slide. Turning to Slide 19. Adjusted EBITDA was $97.9 million for the second quarter of 2020, up from $94.9 million in the second quarter last year. Reconciliation of the EBITDA and adjusted EBITDA are provided in the appendix slide. Turning now to Slide 20. Cash and restricted cash as of June 30 was $250 million compared to $153 million as of December 31, 2019. A strong cash flow generation on this slide demonstrates our enhanced ability to reinvest in the business to support our growth. Our long-term and short-term debt as of June 30 was $1.35 billion, net of deferred financing costs. Its payment schedule is presented on the next slide. The average interest rate on this debt was 5.03%. In order to support Ormat's growth plan, since March 31, 2020, we have raised over $400 million of long-term debt, including the recent bond offering of $290 million closed in July '20, that is expected to reduce our overall interest rate. Our net debt as of June 30, 2020, was $1.1 billion. On August 1, 2020, the company's Board of Directors declared, approved and authorized payment of a quarterly dividend of $0.11 per share pursuant to the company's dividend policy. The dividend will be paid on September 1, 2020, to shareholders of record as of close of business day on August 18, 2020. That concludes my overview. Now I will turn the call back to Doron for an operational and business update and closing remarks. Doron?

Thank you, Assaf. Turning to Slide 23 for a look at generation. Power generation in our power plants declined by 4.7% to 1.44 million megawatt hours in the second quarter of 2020. This decline is attributable to several factors including the curtailment of our generation in our Olkaria power plant in Kenya and lower generation in our old facilities due to lower demand in the natural gas pipeline, both mainly due to COVID-19. The impact of the curtailment in Kenya is limited as the Olkaria PPA secured the vast majority of our revenues with fixed capacity payments unrelated to the electricity actually consumed. The force majeure letter we received from KPLC in April had an immaterial impact on our revenue as agreed by KPLC. On another topic in Kenya, as we reported before, we received from the local Kenya Revenue Authority, the KRA, three assessments related to tax audit for the year 2013 to 2017. We are in discussions with the KRA on each of these assessments, and we are happy to update that the KRA agreed to reduce the third assessment from $17 million to less than $3 million, including fines and penalties. With respect to the other two assessments, the COVID-19 slowed down the discussions. However, we are continuing an open dialogue with the KRA, and we, together with our advisers, still believe that our tax position for the issues raised under these assessments are more likely than not sustainable based on technical merits under Kenyan tax law. Another encouraging update we have, this time in Honduras, where we have an overdue invoice of $20 million for the period between September 2018 and April 2019. Over the last several weeks, our customer has had some discussions with several IPPs, including us regarding paying the $20 million over a few installments. Having said that, we are in a unique COVID-19 environment that may impact this process. Let me now turn to Slide 24. As of today, the recommissioning efforts at Puna continue. We completed the construction of the substation and await HELCO to complete its scope of work in the substation. HELCO received the necessary permits from Hawaii PUC to build the transmission lines and started constructing the line. We expect this work to be completed by the end of the third quarter. On the field side, we connected the production well to the power plant and continued drilling new wells. We expect initial power generation in the fourth quarter with gradual increase of generation to 29 megawatts by the end of this year. Turning to Slide 25. We continue with our work to bring online new projects. This quarter, we completed our work at Steamboat Hills, increasing the complex capacity by 19 megawatts to 34 megawatts. We continue our work in Heber to increase the capacity of the complex by 11 megawatts. Manufacture and construction of the new equipment is ongoing. As you can see in the list, successful exploration work enabled us to advance the Tungsten 2 project that will add 11 megawatts during 2022. As I mentioned in my opening remarks, we are continuing our efforts to grow our more profitable electricity segment, and we are on track with our development to add 160 to 180 megawatts by the end of 2022, with allocated manufacturing, exploration, and capital resources to continue our growth in 2023 and beyond, by enhancing existing operating assets and developing new internal projects in the U.S. and globally that will increase our profitability. As Assaf mentioned in his remarks, we raised over $400 million in long-term debt to support these efforts. Turning to Slide 26 for an update on our backlog. As of August 3, 2020, our product segment backlog was $66 million. We believe that the decline in the backlog resulted in part from the impact of COVID-19 and the current concern of potential customers to enter into large commitments at this time. We anticipate continued weakness in our product backlog as a result. At this stage, we expect significantly lower revenues from the product segment in 2021. The vertical integration structure of our business model enables us to shift our manufacturing capacity to focus on internal initiatives to support our electricity segment growth. We started to see this shift already in the second quarter, generating approximately $50 million of internal revenues that are eliminated in the consolidation, the highest level of quarterly intersegment revenue in the last 5 years. Turning to Slide 27 for an update on our Energy Storage and Management Services. In April this year, we announced that our 10-megawatt Rabbit Hill storage facility in Texas commenced operation, providing ancillary service and energy optimization to the wholesale market managed by ERCOT. We continue our efforts to expand our storage portfolio. In July, we completed our acquisition of the Pomona 20-megawatt battery storage facility for a total net purchase price of $43.9 million. The Pomona facility has been in commercial operation since the end of 2016, under a 10-year energy storage resource adequacy agreement with Southern California Edison company. This facility is our first battery storage asset in operation in California, increasing our existing operating portfolio to 73 megawatts and 136-megawatt hours and added to our battery storage assets in New Jersey, New England, and Texas. At the Valecito project in California, we are progressing with a small delay in permitting, interconnection, and EPC work due to the COVID-19 outbreak. We continue to participate in new RFPs to further develop our pipeline projects and aim for a target of 100 to 150 megawatts to be commissioned by the end of 2022. Turning to Slide 28. Our expected capital spend for the rest of the year includes approximately $120 million for capital expenditure for construction of new projects and enhancements to our existing power plants that management released for construction. In addition, we estimate an additional $87 million for exploration and development that was not yet released for full construction, maintenance of capital expenditures, including our work at the Puna power plant, construction and development of storage projects, and enhancement to our production facility, as detailed on the slide. In the aggregate, we estimate total expenditure for the remainder of 2020 to be approximately $207 million. Please turn to Slide 29 for a discussion of our 2020 guidance. We are narrowing the upper end of the guidance for the full year 2020. We expect total revenues between $710 million and $725 million, with electricity segment revenues between $550 million and $560 million. We continue to expect product segment revenues between $140 million and $150 million. Revenues for Energy Storage and demand response activities are expected to be between $15 million and $17 million. Adjusted EBITDA is now expected to be between $400 million and $410 million. We expect annual adjusted EBITDA attributable to minority interest to be approximately $27 million. As a summary, the steps we took together with the inherent stable and long-term contracted portfolio of our electricity segment have enabled us to ease the impact of the COVID-19 pandemic at this time. And we are on track with our plans to expand our more profitable electricity segment, which is taking an increased portion of our revenues and EBITDA. This concludes our prepared remarks. Now I would like to open the call for questions. Operator, please.

[Operator Instructions]. And our first question will come from Noah Kaye with Oppenheimer.

Maybe if we can just start with the project development. It looks like as we sort of adjust for Steamboat Hills, which has come online, the expansion plans through 2022 are largely unchanged. I'm just wondering kind of in this environment and certainly with the PTC benefit, where do you see opportunities to accelerate the pace of development? Is it more domestic U.S. focus for international? Just can you give us some more color on how you see the pace of development?

Well, first, we've added Tungsten 2 to the list as an expansion to one of our existing projects. We are working today on advancing exploration. We are working today on several greenfields in the U.S. We also have some additional enhancements to our power plants that we have today in the U.S. So the current 2021 and 2022 growth is focused on the U.S. mainly and as you said, on the PTC eligibility. So we do expect the next projects in the U.S. to be eligible for PTC when they come online in the next 2 to 4 years. Globally, we're also aiming to interest in Indonesia and Norwegian projects that we have invested in last year and are doing exploration today. The exploration is moving quite well. We've finished drilling one well over there and we're drilling a second well there. We expect that, if all the exploration finishes successfully, to be part of the growth beyond 2022.

Okay. So quite a number of activities going on there. Just -- I'm not sure I quite fully caught it, but Kenya tax resolution. So this was on the [undiscernible] letter preliminary finding that they reduced it from $17 million down to $3 million? Is that correct?

Yes.

Okay. Can you give us an update on the other two letters?

The other two letters, like in every IRS or KRA audit, there are ongoing discussions. We as well as our legal and auditors feel that our position is exactly technically correct according to the Kenyan tax law. So there are ongoing discussions. The discussions are a bit slower because of COVID. I think now in August, Kenya is opening its borders, and maybe we'll be able to expedite the discussions.

Okay. Terrific. And then last one from me. We had seen that some of the thermal power producers in Kenya had obviously received the force majeure. There's some discussions with Kenya Power & Light about those contracts. I guess it would be helpful for us and for investors if you could just give an update on any discussions you are having with the utility about the contract. It seems like there's an immaterial impact in the short term from these curtailments. But just wondering if there's anything you can share with us around some of the long-term contracts themselves.

Sure. So as you said, we have a long-term contract with KPLC. At the end of last quarter, we received the force majeure letter, and we analyzed it as immaterial. This quarter, we have discussed with KPLC, and they actually agree to our position that it is totally immaterial and it's already reflected in the numbers. We don't have any discussions with KPLC on our PPA or on pricing. There are some other PPAs that are much higher than ours, and the only discussion we had was on the force majeure that was determined to be totally immaterial.

[Operator Instructions]. Our next question will come from Mark Strouse with JPMorgan.

Just kind of a follow-up on Noah's question. Just to be clear, so are you still receiving payments from your counterparties in Kenya and Honduras? And kind of a related question is just looking at the accounts receivable was kind of flattish quarter-over-quarter, but the DSOs keep going up. Just any color on that trend? And what are your expectations going forward?

We are being paid in Kenya as well as in Honduras. We have ongoing payments in both countries. KPLC has been slowing its payments for the last, I think, 2 years, but they keep on paying. In the quarter as well in July, we continued to receive payments for due amounts. Honduras is paying regularly. And as I mentioned, we have in Honduras the $20 million debt from the end of '18, beginning of '19. We are in discussions with NA and actually NA is in discussion with us as well as other IPPs. NA is the Honduran electricity company in order to pay this amount in the coming weeks in a few installments. So we expect this amount to be paid over time.

Okay. And then, again, I apologize if I missed this. But just the slightly reduced outlook for the electricity segment revenues, is that driven primarily by Olkaria or Puna or anything else to call out?

It's mainly due to the COVID-19 uncertainty and the curtailments that we had in Kenya and the low gas in the pipeline in the ore.

[Operator Instructions]. Our next question will come from Jeff Osborne with Cowen & Company.

Just a couple of questions on my end. Could you touch on the product orders, you referenced COVID, which is understandable for delays. I'm just trying to get a sense of the particular projects that you were bidding that are delayed. Is there financing delays, regulatory delays? We're just not seeing that type of acuteness, for example, in the wind industry, where turbine makers are still signing contracts. So I'm just curious why geothermal seems to be hit a bit more acutely?

So what we actually see delays in the decision-making process, not in the regulatory environment, at least in New Zealand, where we operate, in the Philippines, and in Mexico where we have projects. The one country that has regulatory delays is Turkey. Turkey had a feed-in tariff that ends October of this year. They were supposed to issue some new regulations at the beginning of the year, which what we understand due to COVID were delayed. They have a few projects basically ready to be released if there are going to be some new regulations. We hope that the regulations in Turkey will come up, and then there will be some more projects in Turkey. In other places, it's mainly the customers' decision to wait to see how COVID-19 is settling.

Got it. That's very helpful. Two other quick ones here. On the storage side, where you're talking about adding $100 million to $150 million, can you just give us a sense of what the pipeline is there? Certainly, companies like Fluence and NextEra and Tesla have quite a bit of activity going on as well. So I'm just trying to get a sense of your pipeline. And then, b, why you folks would win versus others?

I think in the storage part, we are active in a few of the markets: PGM, Texas, California, and as you said, there's quite a lot of activity, quite a lot of RFPs going out and the need for energy storage is very big in California. We have a few locations that we're working under interconnections. Once we get the interconnections, we can bid them into the RFPs and start building them and operating in the market. We've answered those RFPs in Hawaii, and we've been shortlisted on some, so there's quite a lot of activity going on. There are obviously quite a lot of players, but the amount of RFPs and the need for energy storage is very substantial.

Got it. And then the last one, can you just remind us how we should think about Puna with the 29 megawatts for 2021? So obviously, very little revenue this year, but can you just remind us when it was operational? What the revenue and EBITDA profile was? And then given the reconstruction and the new cost points, I wasn't sure if what happened in the past is comparable to what we should anticipate for 2021 and beyond?

In the past, we had 38 megawatts, revenue was around $38 million to $40 million and EBITDA was about $20 million. So obviously, if it will go to 29 megawatts compared to the 38, it will be a bit lower. The pricing in Puna, for the first 25 megawatts, are avoided costs. These relate to the avoided costs in HELCO, mainly oil and diesel pricing. So this changes over time. If you look into more details, I think today the avoided costs are quite similar to the beginning of 2018.

[Operator Instructions]. And our next question will come from Gerry Sweeney with ROTH Capital.

A couple of quick follow-up questions. Just on the electricity in terms of take-or-pay. I know the U.S. is take-or-pay, especially with Puna -- new Puna agreement. You've talked about Olkaria in Kenya. Your 90% is, I guess, levered to capacity, 10% to production. What about other facilities on a global basis? Are they take-or-pay as well? Or are there any others that have some variability in their PPAs?

All the others in Honduras, Guatemala, and Guadeloupe, all of them are take-or-pay.

Okay. And then just speaking on Honduras. I know on the last call, I'm not sure if I missed it anywhere, but they did send a force majeure letter with very little details on any linkage to anything or revenue or any specific revenue numbers. Has anything come about from that letter? Or has that moved to the background?

No, we didn't have any follow-up discussions with them or anything. They continue to take the electricity and pay the bills. So there's nothing to follow up.

Yes. That's fine. And then just one more on the Kenya tax issue. I know, I guess the three assessments, one assessment on $17 million to $3 million. Reading the Q, I think there was a couple of different numbers over time, but what is the outstanding principal and penalties on the other two assessments? I believe all three were $219 million in the last Q, but could you just update us as to whether -- I didn't see the Q out today yet.

The outstanding principal is about $157 million. So if you add the previous assessment it was about $160 million. That's the principal. And then there are also penalties and interest, but that's obviously subject to further discussion. The first two are about $257 million, it has penalties and interest of about $40-something million. And the third one, as we said, was $17 million, which went down to $3 million.

[Operator Instructions]. This concludes our question-and-answer session as well as our conference call for today. Thank you for attending today's presentation. You may now disconnect.