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Northwest Natural Gas’ (NWN) CEO Gregg Kantor on Q3 2015 Results – Earnings Call Transcript

Northwest Natural Gas Company (NYSE: NWN ) Q3 2015 Earnings Conference Call November 3, 2015, 11:00 am ET Executives Nikki Sparley – IR Gregg Kantor – CEO Greg Hazelton – SVP & CFO Analysts Spencer Joyce – Hilliard Lyons Operator Good day and welcome to the Northwest Natural Gas Third Quarter Earnings Conference Call. All participants will be in listen-only mode. [Operator Instructions]. After today’s presentation, there will be an opportunity to ask questions. [Operator Instructions]. Please note that this event is being recorded. I would now like to turn the conference over to Nikki Sparley. Please go ahead. Nikki Sparley Thank you, Kasia. Good morning, everyone, and welcome to our third quarter 2015 earnings call. As a reminder some of the things that will be said this morning contains forward-looking statements. They are based on management’s assumptions, which may or may not come true. You should refer to the language at the end of our press release for the appropriate cautionary statements and also our SEC filings for additional information. We expect to file our 10-Q later today. As mentioned, this teleconference is being recorded and will be available on our website following the call. Please note these conference calls are designed for the financial community. If you are an investor and have questions, please contact me directly at (503) 721-2530. Media may contact, Melissa Moore, at (503) 220-2436. Speaking this morning are Gregg Kantor, Chief Executive Officer and Greg Hazelton, Senior Vice President and Chief Financial Officer. Mr. Kantor and Mr. Hazelton have some opening remarks and then will be available to answer your questions. Also joining us today are other members of our executive team, who are available to help answer any questions you may have. With that, I will turn it over to Mr. Kantor for his opening remarks. Gregg Kantor Thanks, Nikki. Good morning, everyone and welcome to our third quarter earnings call. I’ll start today with highlights from the period and then turn it over to Greg Hazelton to cover the financial details. Finally, I will wrap up the call with a brief update on our regulatory proceedings and our priorities for the remainder of the year. Let me begin with the quarterly financial results. We had a solid performance with higher utility margin and lower expenses in the period. Margin gains were largely from customer growth which increased to 1.5% from 1.3% last year. This growth rate translated into an additional 10,500 new customers on a rolling 12-month basis. On the expense front, we reduced O&M levels by almost $1 million on a quarter-over-quarter basis and I’m proud of the work we have done this year to control costs after the negative financial impacts of a record warm winter and a significant regulatory disallowance. As we look forward, there are several factors that suggest our local economy continues to experience solid growth. For example, in Portland Metro area about 40,000 new jobs have been added year-over-year which equates to over a 3% increase. And Oregon’s average wage today is the highest it has been relative to the national average in at least a generation according to the Oregon Office of Economic Analysis. Another metric of economic growth obviously is the unemployment rate which in September fell to 5.2% in the Portland Metro area from 5.9% last year. Also in the period home sales were up about 25% in Portland and average home prices increased by almost 6% compared to the third quarter of 2014. In Vancouver, Washington, home sales were up about 13% in the quarter compared to last year and average home prices were up just over 8%. All of these factors are signs that our local economy continues to move in the right direction. Due to following natural gas prices over the past year, we filed and received approval for a 7% rate reduction for Oregon residential customers, and a 14% reduction for Washington residential customers during the quarter. This decrease means our customers will be paying less for their natural gas this winter than they have in the past 15 years. Currently natural gas has up to a 60% price advantage over electricity and oil for home heating in our service territory. And this price advantage coupled with the environmental benefits of natural gas continue to boost our competitive position. Let me comment now on two other developments during the quarter. First, in September the Oregon commission adopted an all party settlement that determines how we would recover cost associated with seven wells we drilled under our amended gas reserves agreement. This $10 million additional investment, like our original investment with Encana, provides a long-term price protection for Oregon utility customers. Under the order, this investment will be recovered at a rate of about $0.47 per therm. We are pleased with this collaborative settlement and the positive conclusion to the dock. Going forward, we are working with the commission and other gas utilities in Oregon on a policy docket that will explore commodity hedging, including what world gas reserve should play. Finally this morning, I’m proud to report in September we learned that for that sixth time in nine years, we ranked first in the Annual J.D. Power Residential Customer Satisfaction Study for natural gas utilities in the west. In addition, we have strengths among the top two highest scoring utilities in the nation eight out of the last 10 years. These results reflect our continued commitment to operate reliably, safely, and with high quality customer service in the communities we serve. With that, let me turn it over to Greg to cover the financial details. Greg Hazelton Thank you, Gregg, and good morning everyone. Turning to our results for the third quarter we reported improved performance with a consolidated net loss of $6.7 million or $0.24 per share versus a loss of $8.7 million or $0.32 per share for the same period last year. As a reminder, a majority of our business was seasonal in nature. And the third quarter typically realized the loss due to decreased heating requirements impacting customer usage. Year-to-date earnings through September were $0.88 per share on net income of $24 million compared to $1.11 per share in net income of $30.2 million for the same period last year. As previously discussed in the first quarter, the company recorded a $15 million pretax or $9.1 million after tax environmental disallowance related to the February OPUC Order. This charge is included in O&M expense. Excluding the charge, year-to-date consolidated earnings were $1.21 per share or $33.1 million. This reflects a $2.9 million increase in net income from last year primarily driven by higher utility margins and an increase in other income. At our utility, we reported a net loss of $7.5 million for the quarter, an improvement of $1.3 million from the prior year. Results were driven by higher utility margin, lower O&M expense, and decreased interest expense. For the nine months period, utility net income was $23.1 million or a decrease of $6.4 million from last year, mainly due to the environmental charge. Excluding the disallowance, utility net income increased $2.7 million year-over-year. Positive year-to-date drivers included higher utility margins and increase in other income, lower interest expense; these were partially offset by an increase in O&M expense. Utility margin for the quarter increased $1.5 million driven by customer growth and gains from gas cost incentive sharing. And as you may recall, utility margin for the year-to-date period was impacted by warm weather in our service territory during our peak heating season in the first quarter. Overall average temperatures for the first nine months of the year were 15% warmer than 2014, and 22% warmer than normal. Total gas deliveries decreased almost 10% and gross revenues were down 4% during the year-to-date period. Although our utility margin is generally protected from the weather, we do have about 11% of our customers in Washington who do not have weather normalization, and 7% of our Oregon customers are left out of the weather normalization program. In spite of the weather driven decline in volumes and gross revenues, net margins increased $2.7 million mainly due to continued customer growth and gains from gas cost, incentive sharing mechanism, as we took the advantage of lower gas prices to achieve savings for our customers. Moving to our gas storage segment, net income for the quarter increased approximately $800,000 compared to the prior year. The increase was driven by higher operating revenues from slightly higher contract prices for the 2015/2016 gas storage year and a reduction in operating expenses at our Gill Ranch facility. For the first nine months, net income for gas storage was over $800,000, an increase of nearly $400,000 from the prior year. Results included a reduction in operating expenses and interest expense, partially offset by a decrease in operating revenues due to lower contract prices during the first quarter of 2015 at Gill Ranch. As Gregg mentioned earlier with regards to consolidated O&M, as a result of our cost control initiatives undertaken to partially offset the environmental write-off and record warm weather, we achieved a decrease of over $900,000 in O&M expense versus last year. For the nine months period, however excluding the regulatory disallowance, O&M expense increased $3.4 million. The increase was primarily due to utility payroll and benefit increases which included a new Union labor contract that was effective June 1, 2014. Partially offsetting the increase in payroll costs were lower repair and power cost at our Gill Ranch facility. For the first nine months, other income increased $4.9 million compared to last year, primarily due to the recognition of $5.3 million of equity earnings on deferred environmental expenditures as a result of the February environmental order. Over the last 12 months, the utility redeemed $40 million of debentures without reissuance using environmental insurance proceeds to pay down the maturing long-term debt balances and defer new issuances of long-term debt. Consequently interest expense decreased nearly $700,000 for the quarter and $3 million for the first nine months of the year. Cash flow from operating activities for the first nine months of 2015 was $173 million compared to $215 million a year ago. Last year’s cash flow was significantly enhanced by $102 million of insurance recoveries partially offset by other working capital changes. Finally, today the company has reaffirmed its 2015 guidance for reported earnings in the range of $1.77 to $1.97 per share which includes the $15 million pretax charge. Our adjusted guidance for 2015 excluding the charge remains unchanged at $2.10 per share to $2.30 per share. The company’s guidance assumes continued customer growth from our utility segment, average weather conditions going forward, slow recovery of the gas storage market, and no significant changes in prevailing legislative and regulatory policies or outcomes. With that, I will turn it back over to Gregg for his concluding remarks. Gregg Kantor Thanks, Greg. At this point in the year, our focus is two-fold. First, we will be moving toward a decision on our open environmental compliance proceedings. And at the same time, we will continue to work necessary to advance our growth initiatives. As you know, in the first quarter, we received the Commission’s decision on our environmental cost recovery mechanism and the application of an earnings test to environmental expenditures. As part of the decision, the OPUC required a compliance filing that describes how we would implement their order. We submitted a revised compliance filing at the end of September and we’re currently working through the review process with OPUC staff and other parties. We believe the two main issues in question are whether the company is required to forego recovery of interest on the original regulatory disallowance and on how certain costs are allocated between Oregon and Washington. The filing will be subject to final commission approval which we expect early in 2016. On our growth initiatives, we’ve been working with the Oregon Commission and parties on a Carbon Solutions Program under Oregon’s greenhouse gas reduction legislation. As we’ve discussed before, Senate Bill 844 allows the OPUC to incent natural gas utilities to undertake projects that will reduce greenhouse gas emissions. Our first proposal was submitted in June and is designed to further the use of combined heat and power in Oregon, a goal that the state has had for a number of years. Under our CHP proposal, industrial and commercial customers in the market could submit CHP projects for consideration. In our view, this is an important effort that could provide a significant carbon reduction benefit for our customers and for Oregon. The OPUC has set a schedule for review of our CHP filing that calls for a decision early in 2016. And we’re currently working with parties on a number of items including the proper level of incentives and how to measure the carbon emissions. Now let me give you a quick update on the potential expansion projects at our underground storage facility in Mist, Oregon. As you know, last December, we received approval from Portland General Electric to move forward with the permitting and land acquisition work required for the expansion project. The project would require no notice storage services to PGE’s — I’m sorry to provide no notice storage service to PGE’s natural gas fired generating plants at Fort Westwood. It would include a new reservoir, providing up to 25 billion cubic feet of available storage, an additional compressor station, and a new pipeline. In April, we submitted an application to the Oregon Energy Facility Siting Council for an amendment to our existing Mist site certificate, a step required to support the expansion. And in early October, we held a public open house with the local community near the expansion site and received positive feedback from attendees. The next step in the process will occur when the Department of Energy and Siting Council publish a proposed order later this year. Between now and the issuance of that proposed order, we will continue to work with both organizations to address any questions about our filing. And our team also continues to work on obtaining other required permits and property rights. Assuming successful and timely completion of those items, the current estimated cost of the expansion is approximately $125 million with a potential in-service date in the 2018/2019 winter season, again depending on the permitting process and the construction schedule. I will end my comments today by noting that in quarter, our Board approved a dividend increase making this the 60th consecutive year of increasing dividends paid. It is a record of which we are very proud. And with that thanks for joining us this morning and now I will open it up for questions. Question-and-Answer Session Operator We will now begin the question-and-answer session. [Operator Instructions]. Our first question comes from Spencer Joyce of Hilliard Lyons. Please go ahead. Spencer Joyce Hi good morning guys. Great quarter here. Gregg Kantor Thank you. Thank you, good morning Spencer. Spencer Joyce Just a couple of real quick ones from me. First want to go back and talk about the $13 million of environmental cost that we’re going to be able to start recovering in Oregon, I guess beginning just a couple of days ago on November 1. I guess first question is this going to be strictly a cash flow statement item or will we see this flow also through the income statement part one there. And then part two, I guess this recovery subject to a final review. Are we pretty comfortable with the $13 million or can you kind of put odds on the likelihood we see some change to that number? Greg Hazelton Spencer, this is Greg Hazelton. I will take those questions in order. First of all the recovery of the $13 million, we will see an increase in revenue for that amount and you’ll see an offsetting increase in expense or amortization. As we have reported as an operating expense as we amortize the deferred balance. So the net-net would be it will be a positive cash flow perspective but net zero from an income or net income perspective. Spencer Joyce Okay, perfect. That’s what somewhat what I assume there. Greg Hazelton Sure. Now we’re collecting the $13 million which has been authorized this is not something that’s subject to refund, this is something that we’re collecting amortizing those balances any adjustments to collections on a — of deferred balances would be done on a perspective basis as we go through each calendar year. Gregg Kantor And once it gets put into the PGA, we’re collecting it has — those are dollars that have been approved for collection by the commission and there is no second look at it, right. Spencer Joyce Okay, perfect. I guess totally separately jumping up to the O&M lines, a real nice quarter here sounds like you’ve got a couple of cost tailwinds there. I would expect some of those to perhaps show up in Q4 and may be into early next year as well any color there, I know it’s somewhat baked into guidance. But I know previous quarters, we have talked a little bit about some increased cost or maintenance cost or some of the storage facilities, it seems like that may be unwinding a bit, but just any additional color to help us model that O&M over the next few quarters? Greg Hazelton Yes I think may be a couple of things would be helpful here. Gill Ranch, we had about $1.8 million recorded last year on the storage segment which increased Gill Ranch’s O&M which we wouldn’t expect to be repeated this year or something that would be recurring. As we think about O&M or generally, we have implemented cost controls to try to offset some of the impact for weather and the write-off, frankly coming off ’14, which was actually a pretty, we had a pretty low level of O&M expense that year based on FTEs and so forth. So we’re coming off a pretty low base. From a budgeting perspective, we actually expect it to be up fairly significantly year-over-year in the 7% area. In fact that we’ve held it to relatively close to flat year-over-year is acknowledgement of the effort that we’ve taken this year which are probably not sustainable next year. At some point, we have to have — we have to adjust staffing, we have to reflect increases in cost that are baked into third-party expenditures and other things. So I would say if you look at our — if you look year-over-year, if you think our O&M of $121 million which is reported year-to-date and we adjust out of that the about $16 million in write-off, environmental write-off and other adjustments. And then, if we look at some of the baked in increases that we had to offset which included bargaining unit labor increases and compensation increases. Again we’ve kept that flat relative to last year. So that in total that gets you somewhere in the $4 million plus area in terms of savings that we’ve been able to achieve which are baked into our forecast numbers. Spencer Joyce Okay, perfect, great color there. That’s all I had. Thanks guys. Operator [Operator Instructions]. Gregg Kantor Okay, doesn’t seem to be any additional questions. I want to end by thanking you all again for joining us this morning and for your interest in our company. We appreciate it. Take care. Greg Hazelton Thank you. Operator The conference is now concluded. Thank you for attending today’s presentation. You may now disconnect. Copyright policy: All transcripts on this site are the copyright of Seeking Alpha. However, we view them as an important resource for bloggers and journalists, and are excited to contribute to the democratization of financial information on the Internet. (Until now investors have had to pay thousands of dollars in subscription fees for transcripts.) So our reproduction policy is as follows: You may quote up to 400 words of any transcript on the condition that you attribute the transcript to Seeking Alpha and either link to the original transcript or to www.SeekingAlpha.com. All other use is prohibited. THE INFORMATION CONTAINED HERE IS A TEXTUAL REPRESENTATION OF THE APPLICABLE COMPANY’S CONFERENCE CALL, CONFERENCE PRESENTATION OR OTHER AUDIO PRESENTATION, AND WHILE EFFORTS ARE MADE TO PROVIDE AN ACCURATE TRANSCRIPTION, THERE MAY BE MATERIAL ERRORS, OMISSIONS, OR INACCURACIES IN THE REPORTING OF THE SUBSTANCE OF THE AUDIO PRESENTATIONS. IN NO WAY DOES SEEKING ALPHA ASSUME ANY RESPONSIBILITY FOR ANY INVESTMENT OR OTHER DECISIONS MADE BASED UPON THE INFORMATION PROVIDED ON THIS WEB SITE OR IN ANY TRANSCRIPT. USERS ARE ADVISED TO REVIEW THE APPLICABLE COMPANY’S AUDIO PRESENTATION ITSELF AND THE APPLICABLE COMPANY’S SEC FILINGS BEFORE MAKING ANY INVESTMENT OR OTHER DECISIONS. If you have any additional questions about our online transcripts, please contact us at: transcripts@seekingalpha.com . Thank you!

BlackRock Launches Double-Smart-Beta ETF Suite

5 new smart-beta ETFs launched by iShares. IShares adds another layer of smart-beta to currency-hedged ETFs. Minimum volatility helps further stabilize returns on already-popular ETFs. By Remzi Gokmen and Tom Lydon Blackrock has added to it’s iShares ETF suite by bulking up its smart-beta offerings with 5 new ETFs. The new exchange traded funds look to double their smart-beta approach by combining the minimum volatility strategy with a currency-hedged one. Their minimum volatility ETFs aim to curb some of the spikes that occur in a up and down market while staying invested while the currency-hedging approach has exploded this year with the forex market at heightened volatility and the dollar appreciating and cutting into investor’s international returns. Below are the names and tickers for the new suite. All will trade on the BATS exchange. iShares Currency Hedged MSCI ACWI Minimum Volatility ETF (BATS: HACV ) iShares Currency Hedged MSCI EAFE Minimum Volatility ETF (BATS: HEFV ) iShares Currency Hedged MSCI EM Minimum Volatility ETF (BATS: HEMV ) iShares Currency Hedged MSCI Europe Minimum Volatility ETF (BATS: HEUV ) iShares Currency Hedged MSCI Europe Small-Cap ETF (BATS: HEUS ) Robert Nestor, Managing Director and Head of iShares Smart Beta Strategy at Blackrock, said: Our minimum volatility suite allows investors the opportunity to gain broad market exposure and the potential for long-term growth, with the potential for less risk. Extending the suite to include currency hedged funds means those investors looking for broad minimum volatility exposure now have the added flexibility to do so on a hedged or unhedged basis, depending on their preferences. The iShares minimum volatility suite has enjoyed a great year with $2.8bn of net inflows this year and a total of $15.1bn in assets under management. iShares expansion into the smart-beta space has been exponential as they now have $125bn in assets under management in their smart beta products globally. The ETFs will track MSCI indexes that their minimum volatility cousins are already indexing. Diana Tidd, Managing Director and Global Head of MSCI Equity Index Products said: With the continued growth of global investing, the importance of managing currency exposures has moved to the forefront of many investors’ minds. Likewise, a growing number of investors are targeting specific factor exposures such as low volatility. MSCI’s Minimum Volatility 100% Hedged to USD Indexes reflect the performance of the combination of these two investment strategies. We are pleased BlackRock has further expanded their suite of iShares ETFs based on MSCI Minimum Volatility Indexes. The lone product in the suite that doesn’t feature a minimum volatility approach is HEUS. HEUS takes a small-cap spin to their European currency-hedged strategy. Small-caps tend to surge in recovery environments and Mario Draghi’s recent economic stimulus measure’s may stoke smaller enterprises’ growth. A snapshot of a popular iShares minimum volatility ETF shows some good signs. HEMV will duplicate the results of the iShares MSCI Europe Minimum Volatility ETF (NYSEARCA: EUMV ) with the currency-hedged spin, and EUMV kicked above its 200 day moving average in the October rally. (click to enlarge)

ALLETE’s (ALE) CEO Al Hodnik on Q3 2015 Results – Earnings Call Transcript

ALLETE, Inc. (NYSE: ALE ) Q3 2015 Results Earnings Conference Call November 3, 2015 10:00 AM ET Executives Al Hodnik – Chairman, President and CEO Steve DeVinck – SVP and CFO Analysts Chris Turnure – JP Morgan Paul Ridzon – KeyBanc Brian Russo – Ladenburg Thalmann Jay Dobson – Wunderlich Operator Good day ladies and gentlemen and welcome to the ALLETE Third Quarter 2015 Financial Results Call. Today’s call is being recorded. Certain statements contained in this conference call that are not descriptions of historical facts are forward-looking statements, such as terms defined in the Private Securities Litigation Reform Act of 1995. Because such statements can include risks and uncertainties, actual results may differ materially from those expressed or implied by such forward-looking statements. Factors that could cause results to differ materially from those expressed or implied by such forward-looking statements include, but are not limited to, those discussed in filings made by the company with the Securities and Exchange Commission. Many of the factors that will determine the company’s future results are beyond the ability of management to control or predict. Listeners should not place undue reliance on forward-looking statements, which reflect management’s views only as the date hereof. The company undertakes no obligation to revise or update any forward-looking statements or to make any other forward-looking statements whether as a result of new information, future events, or otherwise. For opening remarks and introduction, I’d now like to turn the conference over to ALLETE President and Chief Executive Officer, Alan R. Hodnik. Please go ahead, sir. Al Hodnik Good morning everyone. Joining me today is ALLETE’s Chief Financial Officer, Steve DeVinck. I am pleased to report that ALLETE earned $1.23 per share for the quarter on net income of $60.4 million, a 27% increase over the third quarter of 2014. Higher income at ALLETE Clean Energy and at Minnesota Power were primary drivers of the earnings increase for the period. Our strategy continues to gain traction, with regulated operations delivering well on the broad foundation of our financial results and the energy infrastructure and related services businesses providing solid complementary earnings in the quarter. Based on our earnings through the first nine months of the year, and our expectations for the fourth quarter, we are increasing our full year earnings per share to a new guidance range of $3.35 to $3.50 per share. Steve will walk you through the financials in just a moment. But before he does, I would like to update you on ALLETE’s progress on several fronts and also provide a few observations regarding ALLETE’s Clean Power plan relative positioning and on the status of Minnesota Power’s Taconite customers. We have been answering our nation’s call to bring about cleaner energy forms for several years now. While we do not have all the details of the recently released clean power plan fully sorted out, and knowing full well that next steps at various state levels will greatly influence final outcome, we believe ALLETE’s regulated businesses and our energy infrastructure and related services businesses are reasonably well positioned. ALLETE, as you know, sees its geographic positioning in mineral rich Minnesota and next to wind rich North Dakota and hydro rich Canada as most strategic. ALLETE Clean Energy, an established clean energy player, is already contributing to ALLETE’s bottom line, including the Thunder Spirit outcome this year. Minnesota Power, through its Bison investments owns and operates the largest wind farm in North Dakota and has the necessary landowner relations and transmission to expand it further. The Great Northern Transmission initiative effectively marries high quality North Dakota wind to run at River Canadian Hydro, all of it carbon free, and soon poised to be delivered on a new $300 million to $400 million 500-KV transmission line to Minnesota and the Upper Midwest. Minnesota Power is significantly less carbon intense than it was a few years back, and while there are much to do with the transition in details to work on through the clean power plan, including Minnesota’s framework for compliance, we believe it’s energy forward integrated resource plan positions it well relative to the CPP and relative to future growth for ALLETE. ALLETE Clean Energy is already well established with a significant portfolio of carbon free wind generation, all under contract, and is in the process of completing a large wind project in North Dakota, from Montana Dakota Utilities. The CPP may provide additional opportunities for ALLETE Clean Energy, as other energy companies seek solutions to reduce our carbon footprint through contracted renewable energy deliveries or the construction of renewable generation facilities. I am very excited about the potential for U.S. Water Services, which we acquired on February 10th of this year. U.S. Water has been successfully integrated into the ALLETE family, and provides integrated water solutions to industrial customers throughout the United States. When reflecting upon climate related issues such as water scarcity, water conservation and water reuse, we believe U.S. Water is well positioned and will continue to build on its demonstrated track record of customer growth, customer retention and reoccurring revenues. Minnesota Power is making significant progress on two large capital projects in support of their Energy Forward plan, namely the Boswell Unit for environmental retrofit and the Great Northern Transmission line. Relative to Boswell Unit 4, the generating unit is now up and online as planned, and the environmental upgrade project nearly complete. Minnesota Power is on schedule with approximately $207 million spent through the end of the third quarter, on a total project estimate of $260 million. We expect to complete the upgrade in the first quarter of 2016. Customer billing rates for the environmental improvement rider were approved by the Minnesota Public Utilities Commission in an order dated August 24th, 2015. Regarding the Great Northern Transmission line, the U.S. Department of Energy and the Minnesota Department of Commerce, recently issued the final environmental impact statement. The issuance of the FEIS clears the way for a route permit decision by the Minnesota Public Utilities Commission in early 2016. As part of the project, Manitoba Hydro must also obtain regulatory and governmental approval related to a new transmission line in Canada. In September, Manitoba Hydro submitted the final preferred route and EIS for their transmission line in Canada to Manitoba Conservation and water stewardship for regulatory approval. Upon receipt of all applicable permits and approvals, construction of the Great Northern Transmission line is expected to begin by 2017 and to be completed in 2020. On the large power customer front, Minnesota Power’s customer that serve the steelmaking industry, continue to be challenged by elevated levels of steel imports and low steel prices. In August of this year, Cliffs Natural Resources temporarily idled its United Taconite Plant in Eveleth, Minnesota, citing high levels of inventories, lower demand from its customers, and the high rate of imported steel. At that time, Cliffs indicated the idling provided an opportunity to start reworking the plant, to produce a fully fluxed taconite pellet. That new product will replace a flux pellet, now made at Cliffs Empire operation in Michigan, which is scheduled to shut down in late 2016 or early 2017. In the third quarter of 2015, United States Steel Corporation returned its Minntac plant to full production. Minntac is the largest pellet producing facility in Northeastern Minnesota. The smaller United States Steel Keetac plant, which has been idled all summer, remains idle. As disclosed last quarter, Minnesota Power’s large power customers, which include those customers I just referenced, nominated at approximately 80% of full demand level for September, and approximately 90% of full demand levels for the fourth quarter. These power demand levels are fully reflected in our updated earnings guidance. Minnesota Power also serves a large base of wholesale customers, and I am pleased to report that in September, Minnesota Power amended its wholesale electric contracts, with 14 wholesale municipal customers, extending the contract terms for those customers through December 31, 2024. I will have some additional comments after Steve walks you through the quarterly financial results. Steve? Steve DeVinck Thanks Al and good morning everyone. Before I begin, I encourage you to refer to the 10-Q we filed this morning, for more details on the quarter. I would like to point out, that we have updated our reportable segment presentation this quarter. We will now present three reportable segments, regulated operations, ALLETE Clean Energy and U.S. Water Services. For the third quarter of 2015, ALLETE reported earnings of $1.23 per share on net income of $60.4 million and operating revenue of $462.5 million. This compares with $0.97 per share on net income of $41.6 million and operating revenue of $288.9 million in 2014. This year’s quarterly results included acquisition transaction fees of $0.02 per share related to an acquisition at ALLETE Clean Energy. Earnings from ALLETE’s regulated operations segment, which includes Minnesota Power, Superior Water Light and Power and our investment in the American Transmission Company, were $43.8 million compared with $40.9 million in 2014, an increase of $2.9 million. This year’s results reflect increases in production tax credits and power marketing margins, partially offset by increased depreciation and interest expense. Operating revenue from this segment, decreased $5.6 million or 2% from 2014, primarily due to lower fuel adjustment cost recoveries, partially offset by higher power marketing prices. Fuel cost recoveries were down due to lower fuel and purchase power expenses, resulting from lower purchased power prices and fewer kilowatt hour sales. Despite a 1.1% decrease in kilowatt hour sales, electric sales revenue increased $5.4 million, due in part to higher contracted power marketing sales prices. In addition, revenue from industrial customers did not necessarily decline in proportion to the decline in kilowatt hour sales, as power nominations for the quarter were similar to the same period in 2014. On the expense side, transmission services expense increased $2 million or 17% from 2014, primarily due to higher MISO related expenses. Operating and maintenance expense decreased $1.4 million or 2% from the same quarter last year, primarily due to lower salary and wage expenses. Depreciation and amortization expense increased $5.1 million or 18% from 2014, primarily due to additional property, plant and equipment in service. Interest expense increased $1.1 million or 9% over the same quarter in 2014, primarily due to higher average long term debt balances. Income tax expense decreased $4.1 million or 31% from 2014, primarily due to increased production tax credits, as a result of the completion of the Bison 4 Wind Energy Center in December of 2014. Before I move on from the regulated businesses, I want to emphasize that we continue to focus on cost containment at Minnesota Power. Despite known operating and maintenance expense increases for the 200 megawatt Bison 4 Wind Facility, placed in service at the end of last year, insurance and healthcare costs, as well as interest rate driven defined benefit plan expense increases, I am pleased regulated operations, operating and maintenance expense is lower than 2014. We are reducing cost at Minnesota Power, to reduce rate increases per customers, improve our return on equity over time, and manage through the impact of temporary cyclicality facing our customers in taconite mining. I will now share a few highlights from our ALLETE Clean Energy segment. Net income from this segment increased $12.7 million over the same quarter of 2014. Net income in 2015 included $12.3 million after tax or $0.25 per share, due to the recognition of earnings from the development and construction of a wind facility, under the percentage of completion method of accounting. The development and construction of the wind facility is expected to be completed in December of 2015, and will be sold to Montana-Dakota utilities for approximately $200 million. The third quarter of 2015 also reflects an additional $1.3 million related to the operations of wind energy facilities acquired late last year and earlier this year. In 2015, net income also included $900,000 of after-tax expense or $0.02 per share for acquisition costs relating to the acquisition of Armenia Mountain in July of 2015. Operating revenue increased $144.3 million from 2014, primarily due to $135.9 million related to the MDU project. Acquisitions late in 2014 and earlier this year also contributed to the increase. As you will recall, ALLETE acquired U.S. Water Services on February 10th of this year. U.S. Water is a leader in integrated water management to a growing number of industrial and commercial customers throughout the United States. For the third quarter of 2015, U.S. Water had net income of $1 million on total revenues of $36.1 million. Net income included $600,000 of after-tax expense relating to purchase accounting for inventories and sales backlog. The total impact of this purchase accounting adjustment is $2.5 million after-tax and is expected to be fully recognized by the first quarter of 2016. The corporate and other segment, which includes results from BNI Coal, ALLETE Properties and other miscellaneous corporate income and expenses, reported a $2.2 million increase in net income from the same quarter in 2014, primarily due to lower state income tax expense. ALLETE’s effective tax rate in the third quarter of 2015 was 19.3% compared to 24.4% for the same period last year. The reduction is primarily due to increased production tax credits. We anticipate the effective rate for 2015 will be approximately 20%. ALLETE’s cash flow continues to be strong. Year-to-date we generated $254.6 million of cash from operating activities, and we carried a 47% debt-to-capital ratio at quarter end. As Al mentioned earlier, ALLETE’s full year’s earnings guidance has been increased to a range of between $3.35 to $3.50 per share, which reflects ALLETE Clean Energy’s stronger project management performance on the MDU Wind project, along with lower operating and maintenance expense at Minnesota Power. ALLETE’s full year earnings guidance includes the impact of lower power nominations for Minnesota Power’s large power customers. Our guidance excludes acquisition transaction costs and the impact, if any, of pending regulatory outcomes. Just to note, if we were to exclude the projected ALLETE Clean Energy fee for the MDU development project, we expect to be within our original guidance range of $3 to $3.20 per share. Al? Al Hodnik Thank you, Steve. I am quite pleased with our financial and operational performance year-to-date. Looking ahead at the remainder of 2015, we will report the results of our taconite customer nominations for the first four months of 2016, around December 1st. Consistent with the past several years, we will initiate our 2016 earnings guidance in mid-December. I will make a couple final comments on the new customer front, before we take your question. Essar Steel Minnesota continues to report progress on its construction activity, with recent statements of Essar indicating that more than 700 construction workers are on the site, along with another 125 permanent positions at Essar’s Nashwauk and Hibbing offices. Essar officials reiterated their commitment to completing construction of the facility and beginning production of taconite pellets by the end of 2016. As you know, Minnesota Power will provide electric service to the Nashwauk Public Utilities Commission for the 110 megawatts of new electric load under contract. PolyMet expects the release of the final environmental impact statement in the federal register and Minnesota Environmental Quality Board Monitor some time this month. Following publication, the final environmental impact statement requires an adequacy decision by the Minnesota Department of Natural Resources, as well as records of decision by various federal agencies, before final action could be taken on the required permits to construct and operate the mining operation. PolyMet has stated it could be online by early 2017, and Minnesota Power has a 10 year 50-megawatt contract in place to serve this mining operation. I am fully confident that ALLETE remains on-track to meet our long term earnings growth objective of 5%, which also supports a sustainable and growing dividend. I look forward to 2016, as we continue to execute our long term strategy. At this point, I will ask the operator to open up the lines for your questions. Question-and-Answer Session Operator Thank you. [Operator Instructions]. And the first question is from Chris Turnure with JP Morgan. Please go ahead. Chris Turnure Good morning guys. Al Hodnik Good morning, Chris. Chris Turnure I was wondering if you could give us a little sense of magnitude, and give us some perspective on the muni contracts that you recently re-signed until the middle of next decade. Just kind of how big are they, how much do they mean to you, and how do they work structurally? Are they fixed price deals that you guys are just going to lock down for how many years, or are they variable and you pass-through fuel expenses, etcetera? Steve DeVinck Yeah, this is Steve. So we are obviously pleased with that extension and our customers are as well. And it is slightly different. There is a fixed demand piece, which covers our fixed charges, which has a modest cap and floor [ph], and there is an energy piece that is variable, and the variability in that does provide some protection to the company for changes in fuel and purchase power prices. It also provides variability for changes in environmental regulation, that the company may have to comply with. So all-in, it’s a nice 10-year extension, we feel good about wrapping those customers up, and we feel good about the pricing that it’s good for them and good for us. Chris Turnure Okay. And do you have a sense of the percentage of total gross margin at the utility business, that it is [ph]? Steve DeVinck We have not historically disclosed customer gross margins by customer class. Chris Turnure Okay. And then, if we kind of strip out the impact of any changes to electric load, kind of into next year and into 2017 as well. Can you just give us your latest thoughts on rate based growth there and earned ROE? Steve DeVinck Yeah. So in terms of our ROE, we expect this year to be somewhere between 8% and 8.5%. Next year, excluding the impacts of a rate case, should we file a rate case, we would expect anywhere between 8% and 9%, depending on industrial load. With respect to our rate case, we have stated that our strategy is to improve Minnesota Power’s return on equity over time, through cost containment and more clarity on load growth. We remain committed to that plan. We are pleased with cost control efforts to-date, most of which will impact 2016 and 2017, even though we are beginning to see some of the benefits in 2015. Clarity on load, both existing and potential new customer, will evolve over the remainder of this year into early next year. Our current regulatory framework does not allow for recovery of temporary, short term reductions in industrial sales. Recovery of longer term or permanent loss of industrial sales can be pursued in a general rate case. Consistent with our Energy Forward strategy, we have a commitment to one-third coal based generation in our energy supply mix. With the completion of the Boswell Unit 4 environmental retrofit project, we will be seeking a life extension of the Boswell station, consistent with the remaining useful life of the environmental retrofit. We anticipate filing a depreciation life extension in the near future. The annual benefit is anticipated to be approximately $20 million in reduced annual depreciation expense. The ultimate outcome of depreciation related filings will have a significant impact on the timing of our next general rate case proceeding. We will also be filing a proposal to implement recent Minnesota legislation regarding competitive rates for large industrial customers. Decisions on this revenue neutral rate design change, will also impact the timing of our next rate case. Chris Turnure Okay. Can you just give a little bit more color on that depreciation item, and the potential timing of that, and when you are thinking you will hear a regulatory outcome? Steve DeVinck Yeah. So we intend to file that here relatively soon. I would expect that we will have a regulatory decision on that some time early next year. Chris Turnure Okay. And it would take effect to write away and hit your — or help your 2016 number potentially? Steve DeVinck That’s what we will be seeking. Chris Turnure Great. Thanks a lot guys. Al Hodnik Thanks Chris. Operator Your next question comes from Paul Ridzon with KeyBanc. Please go ahead. Paul Ridzon Just to follow-up on that depreciation; so you would keep that benefit until your next rate case? Steve DeVinck Hi Paul, it’s Steve. We would keep approximately two-thirds of that. Approximately one-third of that would result in customer rate reductions through our current cost recovery rider we have for the Boswell 4 environmental retrofit. Paul Ridzon Kind of switching gears, what are your latest thoughts on appetite for the Florida real estate, where does that stand? Steve DeVinck No material changes in activity at ALLETE Properties. We do expect we had a small sale in the third quarter. We had another small sale in October, and we expect to have some sales in the fourth quarter of this year. We do expect ALLETE Properties to have a modest loss this year, somewhere probably around $1 million or so. Paul Ridzon Any early look at what 2016 could look like? Steve DeVinck No. Other than — we are pleased with the progress we are making on our cost control efforts at Minnesota Power; I will say that, and of course we will be issuing guidance here in the middle of December, as we normally do. Paul Ridzon I did not see as one of the drivers of Minnesota Power current cost recovery. I’d imagine, there is probably some incremental capital at Boswell 4. Do you have much of that added to the quarter? Steve DeVinck I do. It was a significant driver year-to-date. It was just less material for the third quarter. And the reason for that is, as we ramp up capital expenditures, including as we ramped up during 2014, the difference year-over-year is more material earlier in the year than later in the year. So you will see in our 10-Q for our year-to-date results, current cost recovery rider revenue was more of a material increase. Paul Ridzon Did that goal extent into the fourth one, that phenomena? Steve DeVinck Yes. Paul Ridzon Okay. And then finally, was there — Essar should ramp up by the end of 2016, is that new language? Al Hodnik This is Al, Paul, good morning to you. I don’t think that’s new language. We are taking that rate from there, public statements, so they haven’t changed their views on where they are at with their construction schedule, they would be producing some pellets by late-late in the 2016 timeframe, off into early 2017. So that’s directly from them. Paul Ridzon Okay. Thank you for the update. Al Hodnik Thanks Paul. Operator And the next questioner is Brian Russo with Ladenburg Thalmann. Please go ahead. Brian Russo Hi, good morning. Al Hodnik Good morning Brian. Brian Russo The $0.12 sense increase in the midpoint of your upper end revised 2015 guidance; could you kind of break that down, as to what — maybe incremental margin on the wind project, versus your previous disclosures and reverse the O&M cost controls or anything else driving that $0.12 increase that might be sustainable versus kind of one time? Steve DeVinck Good morning Brian, this is Steve. Very roughly it’s about 50-50, equally split between those two components. Brian Russo Okay. So $0.06 on the wind farm and $0.06 on O&M? Steve DeVinck Very roughly, that’s in the ballpark. Brian Russo Okay, great. And then, correct if I am interpreting this wrong, but when you look at the 10-Q subsidiary disclosures for U.S. Water, for the nine months to $86 million in revenue, $1.5 million in net income, but then we could — I guess, theoretically add back $2.5 million of amortization of intangibles, which would be completed by the first quarter of 2016. So kind of a normalized starting run rate for net income for the nine months is more like $4 million? Steve DeVinck So your concept is right. The number is slightly up. The $2.5 million is for the entire amount, which will be amortized from the date of acquisition through the first quarter of next year. Year-to-date, the amount is in our 10-Q, and it was somewhere around $1.5 million. Brian Russo Okay. Got it. So nine months adjusted income, excluding the amortization is $3 million? Steve DeVinck Correct. Brian Russo Okay, great. And remind us, what’s the revenue growth rate on U.S. Water? Steve DeVinck Well, we do expect a good significant growth at U.S. Water, both organically and also through the ability to have some strategic tuck-in acquisitions periodically and over time, in the purchase price range of say $10 million to $50 million. So we are excited about it and expect good growth. Brian Russo Okay, great. So just to be clear, after the first quarter of 2016, we should start to see more meaningful earnings contribution from U.S. Water to the consolidate earnings stream, correct? Steve DeVinck So purchase accounting requires the identification of intangibles. Some intangibles have a very short amortization life; and what we are pointing out with the inventory and sales backlog are those intangibles that have a relatively short life, and you hit on that, that’s $2.5 million throughout the first year of our ownership. So that will go away. Brian Russo Okay. And would you be able to provide us with some sort of net operating income as a percent of revenues or some sort of financial ratio to help us model that going forward? Steve DeVinck Our disclosure will evolve over time, and I am sure you will appreciate one of the factors we have to take into consideration as competitive information and just the competition in total. So we will be evolving over time, but I am sure you can appreciate that we also have our eye on competitive information. Brian Russo Understood. Any update on the ACE project pipeline? Al Hodnik Well it continues to work off of a pretty healthy pipeline of opportunities. Some of that existing before, some that are likely to be generated, I think, as this CPP evolution continues in various states. Obviously, on the Upper Midwest has gotten slightly more challenged, with respect to CPP, in terms of what it has to do, and there are lots of things to play out, obviously, with the states and the way they do their implementation plans, and I suppose some litigation as well. But we think that the CPP overall is good for business for ALLETE Clean Energy over the long haul. And no specifics at this point in time to reveal on additional projects, but the pipeline is a reasonable pipeline of opportunities to sort out. Brian Russo Okay. And then just lastly, I think you mentioned a target ROE of between 8% and 9% in 2016. Is that before or after the depreciation study? Steve DeVinck That is before. Brian Russo Great. Thank you. Steve DeVinck Thanks Brian. Operator [Operator Instructions]. The next question is from Jay Dobson with Wunderlich. Jay Dobson Hey good morning Al, good morning Steve. Al Hodnik Good morning Jay. Jay Dobson Quick question to drill down a little into the cost savings at the utility. I recall you had sort of two distinct efforts going on sort of your ongoing — sort of shorter term efforts, and then a very specific longer term effort. Can you give us a little sense as to sort of the successes you have in there, and sort of what we are in the third quarter, is that more sort of the shorter term efforts, or is that the beginning of sort of the efforts or the fruits of the efforts that are going to bear in 2016 and beyond? Steve DeVinck Hi Jay. This is Steve. What we are beginning to see in 2015, is the beginning of our efforts, of which most of the benefit we will see in 2016 and 2017. We are driving efficiencies across the organization at Minnesota Power, without jeopardizing safety or reliability. We are getting efficiencies for example, in the use of our fleet. We are reducing headcount at Minnesota Power and seeing the related salary, benefit and employee expenses that come with that. And that’s so far in 2015, despite, and I mentioned this, known increases around some areas that were uncontrollable to us. So it’s a broad initiative covering the entire organization. I am pleased with where it’s at, and you will see more of an impact, as we move forward. Jay Dobson That’s great. Thanks very much for that clarity. And then to the tax rate that you saw? I mean, it sounded like that was all associated with PTCs and tax rates always move around, its actually moved up a little bit this year because of the Thunder Spirit game you have booked. But if we were to look out to 2016, appreciating, having given guidance, there is no reason to think without forecasting how the wind is going to blow, the PTCs or that benefit should cease in year end 2015? Steve DeVinck That’s correct. We expect to have very substantial production tax credits through the middle of the next decade. Jay Dobson That’s great. Thanks very much. I appreciate the clarity. Al Hodnik Thanks Jay. Operator Next, we have a follow-up from Paul Ridzon with KeyBanc. Please go ahead. Paul Ridzon First part, U.S. Water, you said that some of the depreciation of the intangibles would probably make it neutral for the first couple of years, but it sounds like that improves a little bit. Is that fair? Steve DeVinck Yeah. What we said is, it won’t have a material impact on 2015 earnings. But it’s probably in line with our expectations in terms of the intangibles. Paul Ridzon But once we have lapped to the first quarter, then we will start to see it get a little better? Steve DeVinck Yeah. And again it’s at $2.5 million, which will be fully amortized by the first quarter of next year. Paul Ridzon And have you set any O&M reduction targets that you can share? Steve DeVinck No. I can’t be that specific. Paul Ridzon Okay. Thanks again. Al Hodnik Thanks. Operator And I am showing no more questions in the queue. And we would like to turn the call back for any further remarks. Well, Steve and I want to thank you for your time this morning. We look forward to seeing many of you in the next week actually, at EEI Financial, and you know, on the road, when we come out to further share our story and success here at ALLETE. Thank you and have a good day. Operator Ladies and gentlemen, thank you for joining us today. This does conclude the program, and you may all disconnect. Everyone have a wonderful day.