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Investing For Retirement Using American Century Mutual Funds

Summary American Century offers a set of diversified mutual funds which can be successfully used for construction of investment portfolios with good withdrawal rates. A set of just three mutual funds, a bond, an equity growth, plus an equity value fund generates good returns with relatively low risk. From January 2005 to December 2014, an American Century portfolio with fixed allocation could produce a safe 5% annual withdrawal rate and 2.15% annual increase of the capital. Same portfolio with rebalancing at 25% deviation from the target allowed a safe 5% annual withdrawal rate and achieved 2.21% compound annual increase of the capital. Same portfolio with momentum-based adaptive allocation could have produced a safe 12% annual withdrawal rate and 3.51% annual increase of the capital. This article belongs to a series of articles dedicated for investing in various mutual fund families. In previous articles we reported our research on Fidelity , Vanguard , and T Rowe Price mutual fund families. The current article does the same for American Century family of mutual funds. The series of these articles is aimed at a broad spectrum of investors. They may be useful to small individual investors as well as to any large institution managing retirement accounts. We report the performance of the portfolios under two scenarios: (1) no withdrawals are made during the time interval of the study, and (2) withdrawals at a fixed rate of the initial investment are made periodically. Since this is the fourth family of mutual funds for which we are building an investment portfolio for retirement, we elaborate here upon the general methodology we use. The set of funds selected for building the portfolio should satisfy the following criteria: (1) It should include at least one bond fund. (2) It should include a few equity funds, generally between two to five. Those funds should have enough similarity and diversity. As an example, we may select one value and one growth fund. (3) Historically, the funds selected should have performed better than most other funds in their category. Applying these principles, we selected three mutual funds for inclusion in a portfolio of American Century mutual funds. They are the following: American Century Government bond fund (MUTF: CPTNX ) American Century Heritage fund (MUTF: TWHIX ) American Century Value fund (MUTF: TWVLX ) As in the previous articles, three different strategies are considered: (1) Fixed asset allocation. The portfolio is initially invested 50% in the bond fund and 50% equally divided between the two stock funds, without rebalancing. (2) Target asset allocation with rebalancing. The portfolio is initially invested 50% in the bond fund and 50% equally divided between the two stock funds and is rebalanced when the allocation to any fund deviates by 25% from its target. (3) Momentum-based adaptive asset allocation. The portfolio is at all times invested 100% in only one fund. The switching, if necessary, is done monthly at closing of the last trading day of the month. All money is invested in the fund with the highest return over the previous 3 months. The data for the study were downloaded from Yahoo Finance on the Historical Prices menu for three tickers: CPTNX, TWHIX, and TWVLX. We use the monthly price data from January 2005 to December 2014, adjusted for dividend payments. The paper is made up of two parts. In part I, we examine the performance of portfolios without any income withdrawal. In part II, we examine the performance of portfolios when income is extracted periodically from the accounts. Part I: Portfolios without withdrawals In table 1 we show the results of the portfolios managed for 10 years, from January 2005 to December 2014. Table 1. Portfolios without withdrawals 2005 – 2014. Strategy Total increase% CAGR% Number trades MaxDD% Fixed-no rebalance 103.55 7.30 0 -24.61 Target-25% rebalance 109.82 7.63 4 -22.03 Momentum-Adaptive 330.90 15.73 35 -13.97 The time evolution of the equity in the portfolios is shown in Figure 1. (click to enlarge) Figure 1. Equities of portfolios without withdrawals. Source: This chart is based on EXCEL calculations using the adjusted monthly closing share prices of securities. From figure 1 it is apparent that the rate of increase of the adaptive portfolio is substantially greater than the rate of the fixed and target allocation portfolios. Part II: Portfolios with withdrawals Assume that we invest $1,000,000 for income in retirement. We plan to withdraw monthly a fixed percentage of the initial investment. That amount is increased by 2% annually in order to account for inflation. In table 2 we show the results of the portfolios managed for 10 years, from January 2005 to December 2014. Money was withdrawn monthly at a 5% annual rate of the initial investment plus a 2% inflation adjustment. Over the 10 years from January 2005 to December 2014, a total of $535,920 was withdrawn. Table 2. Portfolios with 5% annual withdrawal rate 2005 – 2014. Strategy Total increase% CAGR% Number trades MaxDD% Fixed-no rebalance 24.03 2.15 0 -28.78 Target-25% rebalance 22.68 2.21 4 -27.04 Momentum-Adaptive 210.05 11.98 35 -16.41 The time evolution of the equity in the portfolios is shown in Figure 2. (click to enlarge) Figure 2. Equities of portfolios with 5% annual withdrawal rates. Source: This chart is based on EXCEL calculations using the adjusted monthly closing share prices of securities. To illustrate the effect of the withdrawal rates on the evolution of the capital we report simulation results for two strategies: fixed target with rebalancing and momentum-based adaptive asset allocation. In Table 3 we report the results of simulations of the fixed target portfolio with the following withdrawal rates: 0%, 5%, 6%, 8%, and 10%. The time evolution of the equity in the portfolios is shown in Figure 3. To illustrate the advantage of the adaptive allocation strategy and the effect of withdrawal rates on the evolution of the capital, we give in Table 3 the results of simulations for the following withdrawal rates: 0%, 5%, 10%, and 12%. Table 3. Adaptive Portfolios with various annual withdrawal rates 2005 – 2014. Withdrawal rate % Total increase% CAGR% MaxDD% 0 330.90 15.73 -13.97 5 210.05 11.98 -16.41 10 89.54 6.60 -20.24 12 41.20 3.51 -22.23 The time evolution of the equity in the portfolios is shown in Figure 3. (click to enlarge) Figure 3. Equities of momentum-based portfolios with various annual withdrawal rates. Source: This chart is based on EXCEL calculations using the adjusted monthly closing share prices of securities. Conclusion The set of three American Century mutual funds, selected for this study, perform well for all three strategies and generate sustainable returns at relatively low drawdowns. Between 2005 and 2015, the fixed target allocation with rebalancing was able to sustain withdrawal rates of up to 6% annually. The adaptive allocation algorithm was able to sustain withdrawal rates up to 13% annually without any decrease of capital. We must admit here that the performance of the portfolio selected in this article is by no means the best possible. Without doubt, there may be other selections that would have performed better. On the other hand, past performance does not guarantee future results. Finding the best portfolio even for a specified past time interval is a great undertaking. All we can do is to strive toward finding one of the best, not really the best. Same philosophy applies into selecting the family of funds. In an article at the end of the series we will present a comparative study of their relative performance. Disclosure: The author has no positions in any stocks mentioned, and no plans to initiate any positions within the next 72 hours. (More…) The author wrote this article themselves, and it expresses their own opinions. The author is not receiving compensation for it (other than from Seeking Alpha). The author has no business relationship with any company whose stock is mentioned in this article. Additional disclosure: This article is the fourth in a sequence on investing in mutual funds for retirement accounts. To help the reader compare the past performance of various mutual fund families, I selected a benchmark 10-year time interval starting on 1 January 2005 and ending on 31 December 2014. The article was written for educational purposes and should not be considered as specific investment advice.

Selling Stocks Is Like Football: Ohio State Coach Woody Hayes On Portfolio Management

We thinking selling stocks is like football: “There are three things that can happen when you pass the football and two of them are bad.” Investing in common stock has been very rewarding over the decades because it has been a positive sum game. Do you want to throw away one of your best long-term performers the way the Seahawks threw away the Super Bowl? “There are three things that can happen when you pass the football and two of them are bad,” observed The Ohio State University’s legendary coach Woody Hayes. All the Seahawk fans, myself included, know exactly what he is talking about since the Seahawks chose to pass the ball at the one-yard line. You can complete a pass, you can throw it for an incompletion, or you can throw it to the other team (an interception). The same thing can be said for existing common stocks in your equity portfolio. If you sell them, three things can happen and two of them are bad. First, you can sell the shares of common stock and see them greatly underperform the rest of your equity investments (NASDAQ: GOOD ). Second, you can sell the shares and see them outperform your portfolio (bad). The third thing that can happen is comprised of the first two; the expense of trading and the potential of capital gains tax are at best a necessary evil (bad). We believe as a long-duration investor, you need to understand the mathematics of common stocks. When you buy a stock and pay cash, your downside is limited to the amount invested minus the dividends collected prior to bankruptcy. On the other hand, successful common stock holdings can go up by many times what you paid for them. The Bible says that love covers a multitude of sins, and, in portfolio management, your best-performing multiple-decade winners cover a multitude of underperformance by the inevitable common stock duds. Investing in common stock has been very rewarding over the decades because it has been a positive sum game. Nobody has to lose for you to win. We at Smead Capital Management have argued that activity and its insidious cost is the enemy of the active management industry. Warren Buffett says, “Excitement and expense are the enemy of your portfolio.” A Financial Analysts Journal article from February 2013 showed that in the large-cap space, active managers averaged 62% turnover and incurred around 0.80% of annual expense. This rivals annual mutual fund expense as a cost. Every time you sell and buy a new security, you get one of the two bad outcomes, trading expense! Since we have entered a corrective period in the U.S. stock market the last five weeks, it is extremely tempting for active managers to try and guess where the winds will blow in the next three-to-six-months. Doing this would be risking the possibility of two bad outcomes. One of the stocks you were going to do the best on the over next ten years could get thrown out in an effort to maintain your comfort or the comfort of your investors. Do you want to throw away one of your best long-term performers the way the Seahawks threw away the Super Bowl? There are numerous examples in our portfolio where more active managers might trade out. Amgen (NASDAQ: AMGN ) has been a spectacular performer since the summer of 2011, rising from $52 per share to $150 as February 2, 2015. However, the biotech industry has been a very popular group and is likely overdue to disappoint investors. Racier and more exciting small biotech shares soared even more and are correcting more aggressively. Amgen reported excellent results in the fourth quarter of 2014 and raised the dividend 30% for 2015. They guided 2015 earnings estimates from $9.05 to $9.40 per share. At today’s price, this splendid company trades for 16 to 16.5 times this year’s earnings and pays a fast-growing $3.16 dividend. Based on our eight criteria for stock selection, this is a clearly superior company trading at a market multiple. There is a better than average chance that a sale would ultimately include two negatives. Home Depot (NYSE: HD ) has been a great performing stock the last six years. It trades for 20-times this fiscal year’s earnings estimate of $5.20 which ends February of 2016. The company raised the dividend from $1.16 in 2013 to $1.56 in fiscal 2014. It is our expectation that above-average dividend growth will continue for a number of years. The U.S. has been in a housing depression for the last seven years and household spending on home improvement is very low compared to the past thirty years. Residential fixed investment is as low today as a percentage of GDP as it was in the worst recession years of the 1960’s, 1970’s and 1980’s. Lastly, do you want to sell this stock before most Millennials, our largest population group, have bought their first house? Two bad things could happen! We are going to stick with Woody Hayes and give the ball to a couple of meritorious businesses which have created great wealth in the past and not run the risk of making two mistakes. We are willing to explain ourselves later at the podium if one out of the three possibilities (a temporary price drop) makes us look foolish in the short run. Disclaimer: The information contained in this missive represents SCM’s opinions, and should not be construed as personalized or individualized investment advice. Past performance is no guarantee of future results. Bill Smead, CIO and CEO, wrote this article. It should not be assumed that investing in any securities mentioned above will or will not be profitable. A list of all recommendations made by Smead Capital Management within the past twelve month period is available upon request. Disclosure: The author is long AMGN, HD. (More…) The author wrote this article themselves, and it expresses their own opinions. The author is not receiving compensation for it. The author has no business relationship with any company whose stock is mentioned in this article.

Empire District Electric’s (EDE) CEO Brad Beecher on Q4 2014 Results – Earnings Call Transcript

Empire District Electric Co (NYSE: EDE ) Q4 2014 Earnings Conference Call February 6, 2015 13:00 ET Executives Dale Harrington – Director, IR Brad Beecher – President & CEO Laurie Delano – VP, Finance & CFO Analysts Brian Russo – Ladenburg Thalmann Paul Zimbardo – UBS Michael Goldenberg – Luminus Management Tim Winter – Gabelli & Company Operator Welcome to the Empire District Electric Company Fourth Quarter 2014 Results Conference Call and Webcast. [Operator Instructions]. I would now like to turn the conference over to Dale Harrington. Please go ahead, sir. Dale Harrington Thank you, Dan and good afternoon, everyone. I would like to welcome you to our year-end 2014 earnings conference call but let me begin by introducing Brad Beecher, President and Chief Executive Officer and Laurie Delano, Vice President Finance and Chief Financial Officer who in a few moments will be providing an overview of our 2014 results and our 2015 expectations as well as some highlights on other key matters. Our press release announcing 2014 results was issued yesterday afternoon. The press release and a live webcast of this call including our slide presentation are available on our website at www.empiredistrict.com. A replay of the call will be available on our website through May 6th of this year. Before we begin I must remind you that our discussion today includes forward-looking statements and the use of non-GAAP financial measures. Slide 2 of our accompanying slide deck and the disclosures in our SEC filings present a list of some of the risks and factors that could cause future results to differ materially from our expectation. I will caution that these lists are not exhaustive and the statements made in our discussion today are subject to risks and uncertainties that are difficult to predict. Our SEC filings are also available upon request or maybe obtained from our website or from the SEC. I would also direct you to our earnings press release for further information on why we believe the presentation of estimated earnings per share impact of individual items and the presentation of gross margin each of which are non-GAAP presentations is beneficial for investors in understanding our financial results. And with that I will now turn the call over to Brad Beecher. Brad Beecher Thank you, Dale. Good afternoon everyone and thank you for joining us. 2014 was a good year for Empire shareholders. The one year total shareholder return was about 35.6%, record earnings record high stock prices, a strong balance sheet with improved retained earnings and a sustainable growing dividend that increased by 2% in the fourth quarter were highlights for the year. Today we will discuss further our financial results for the fourth quarter and 12 months ended December 31, 2014 period, recent activities impacting the company and our outlook for 2015. As shown on slide 3, yesterday we reported consolidated earnings for the fourth quarter of 2014 of 11.1 million or $0.26 per share compared to the same quarter in 2013 when earnings were 15.2 million or $0.35 per share. Earnings for the 12 months ended December 31, 2014 period were 67.1 million or a $1.55 per share. 12 months ended 2013 earnings were 63.4 million or a $1.48 per share. During their meeting yesterday the Board of Directors declared a quarterly dividend of $0.26 per share payable March 16, 2015 for shareholders of record as of March 2nd. In December we completed in-service testing for the Asbury Air Quality Control System. The Missouri Public Service Commission staff determined that as of December 15, 2014 the Asbury AQCS equipment hadn’t met the in-service criteria. The determination by the staff that the in-service criteria have been met is a vital step for the rate case we filed in Missouri on August 29th of last year. As you may recall in order for the commission staff to allow a December 31 true-up date it was required that that Asbury be in service prior to February 1, 2015. Recovery of costs associated with the Asbury AQCS is the primary component of the Missouri Case. I will remind you that we’re seeking the increased electric rates by about $24.3 million annually or about 5.5%. Missouri Commission staff has indicated in testimony filed January 29th that the true-up period for this case will in [ph] December 31, 2014. Local public hearings for this case have been scheduled for February 19 in Joplin and February 20th in Reeds Spring. The Missouri Commission has scheduled an evidentiary hearing at its offices in Jefferson City, the weeks of April 6 through 10 and April 13 through 17. In the interim the Missouri Commission staff will be conducting a construction audit and prudence review on the Asbury Project. True-up direct testimony is scheduled to be filed on April 30th and a true-up evidentiary hearing occur in May 13th. New customer rates as a result of this case will be effective no later than July 26, 2015. Initially we provided a cost estimate for the Asbury AQCS project without AFUDC of between a $112 million and a $130 million. We later updated investors that we expected to be in the bottom half of the range. Today as a result of solid project management I’m proud to report we expect cost to be around a 112 million without AFUDC and around a 120 million including AFUDC. In December we filed a request with the Kansas Corporation Commission for an environmental cost recovery rider, rates from our Kansas request will be effective no later than August 3, 2015. Additionally we plan to file a request for an environmental cost recovery rider in Arkansas later this month. In Oklahoma we filed a request on January 9th to amend our Southwest Power Pool Transmission Tariff. Our proposed amendment request the removal of a requirement to file a base rate case by July 2015. The SPP tariff was established in January 2012 to allow recovery of our Oklahoma share of transmission charges assessed by the Southwest Power Pool. A requirement of that tariff was that Empire must file a base rate case by July 2015 because of the Asbury Air Quality Control System completion in early ’15 and the Riverton 12 combined cycle [ph] conversion projects scheduled for 2016 and Oklahoma filing in 2015 would necessitate a second rate case filing in 2016. Since rate cases are costly for customers we are asking for this Oklahoma requirement to be removed. If our request is approved we would plan to file a single rate case in 2016 to capture costs from both the Asbury and Riverton projects. We announced yesterday that our 2015 earnings guidance falls within the weather normalized range of a $1.30 to a $1.45 per share down from our 2014 results of a $1.55 per share. The lower range reflects the full year of high expense primarily related to the Asbury AQCS upgrade and a new maintenance contract for the Riverton facility offset with only a partial year of new Missouri rates to recover their Asbury investment and other increased cost. I will now turn the call over to Laurie to provide additional details of our financials. Laurie Delano Thank you, Brad. Good afternoon everyone. I’m very pleased to be reviewing such positive financial results with you today, the information I would discuss today will supplement the press release we issued late yesterday and as always the earnings per share numbers referenced throughout the call are provided on an after-tax estimated basis. I will briefly touch on our 2014 fourth quarter results before I discuss our annual results. Our fourth quarter earnings of $0.26 per share reflect a more normal quarter of winter weather when compared to the previous year’s fourth quarter. They also reflect increases in operating and maintenance expenses when compared to last year. Slide 4, shows the quarter-over-quarter changes that impacted our earnings. Gross margins for revenues less fuel and purchase power expense decreased $1.5 million decreasing earnings by $0.02 per share quarter-over-quarter. We estimate the impact of the warmer weather and other volume metric factors compared to last year decreased revenue by about $3.2 million, decreasing margin by about $0.03 per share. This decrease was driven primarily by an 8.1% decrease in sales for our residential customers. Commercial sales were only down about 1%, the weather impact on commercial sales was mitigated in part of increased sales throughout our territory as well as increased sales at the New Mercy Hospital as it prepares to open in March. Increases in operating and maintenance expenses, decreased earnings about $0.06 per share driven by increased transmission operation and production maintenance expenses. Small changes in depreciation, AFUDC and other income and expense rounded out the remaining $0.01 per share decrease in earnings for the fourth quarter. Turning to our annual rates, as Brad mentioned earlier, our net income increased $3.7 million or $0.07 per share. Slide 5, provides a breakdown of the various components that resulted in this year-over-year per share increase. Consolidated gross margin increased $17.1 million over 2013 adding an estimated $0.25 per share. As shown on in the callout box on slide 5, we estimate that increased customer rates from our Missouri rate case effective in April 1 of 2013 added about $12.5 million to revenue or about $0.16 per share to margin. We estimate weather and other volume metric increases on the electric side of the business added an estimate $4.6 million to revenue year-over-year or about $0.05 per share to margin. The weather effect from the gas segment added about a penny per share. The volume metric change was driven by a combination of weather and higher commercial sales again including positive impacts from the construction of the New Mercy hospital. Increased customer accounts added an estimate $1.5 million year-over-year increasing margin about a penny per share. Changes in other miscellaneous revenues primarily related to SPP transmission revenues and non-volume fuel related items netted together rounded out the remaining increase in electric segment, revenues adding a combined net impact of $0.02 per share to margin. Increases in our consolidated operating and maintenance expense offset the positive margin impact decreasing earnings about $0.17 per share. The callout box on slide 5 provides a breakdown of this impact. As we’ve discussed on previous calls the largest individual O&M increase was for transmission operation expenses primarily related to SPP charges. This added expense reduced earnings about $0.08 per share. Increases in distribution and production maintenance along with general LIBOR cost combined to reduced earnings about $0.11 per share, other smaller cost increases reduced earnings to a total of $0.02 per share. These increases were offset by the effect of lower healthcare cost about $0.02 per share as well as the $0.02 per share positive effect of the regulatory reversal of a gain on sale of the assets that we recorded in 2013. And as you all will recall we also recorded a similar entry in 2013 for our planned disallowance. This 2013 write-off also has the impact of increasing earnings year-over-year by $0.03 per share. Continuing on with slide 5, depreciation and amortization expenses decreased earnings per share $0.05 driven by higher levels of plant and service and increased depreciation rates resulting from our April 2013 Missouri case. Increases in property taxes brought earnings down another $0.02 per share. Increased allowance for funds used during construction or AFUDC added about $0.06 per share to earnings reflecting our Asbury and Riverton construction projects. Small changes in other income and deductions in the effects of additional stock issued under our various stock plans round out the remaining $0.03 decrease in earnings per share. On our balance sheet we have $90.3 million in retained earnings as of December 31, 2014. We had $44 million of short term debt outstanding at the end of 2014 and we currently have $68 million outstanding. We received the proceeds from our $60 million private placement of first mortgage bonds on December 1. As Brad said we announced in our press release yesterday that we expect our full year 2015 weather normalized earnings to be within the range of a $1.30 to a $1.45 per share. Before I talk about the drivers for our new guidance I would like to review our actual 2014 results as compared to our original 2014 guidance. Slide 6 provides this information, in developing our 2014 guidance we assumed 30 year average weather, modest growth as Joplin continued the three building projects and the extra quarter of Missouri rates from our 2013 rate case and revenues from our 2013 Arkansas rate case filing. This was offset with a corresponding effect of increased O&M expenses. Our actual 2014 results of a $1.55 were higher than the midpoint of our original guidance range primarily due to one higher than expected electric and gas sales and two lower than expected operating and depreciation expenses. Higher sales added about $0.03 to our earnings per share on the electric side of the business, and about a penny to our gas segment results. Favorable weather and higher commercial sales again inclusive of the New Mercy hospital were the primary drivers. Decreased cost totaling $0.06 per share were driven by lower than expected generating plant operating expenses and lower than expected SPP charges. Also depreciation was lower due to the timing of various in-service dates of our construction projects. On slide 7 we highlight the drivers of our decrease in earnings expectations in 2015. First as in the past our estimates are based on normal weather with a modest positive sales growth as we have previously disclosed we still expect this growth to be at a level of less than 1% per year over the next several years. We’re also assuming our Missouri rate case will be effective as filed. We also assume our Arkansas and Kansas rate case filings will go into effect as filed. Operating and maintenance expenses will be higher primarily due to a new maintenance contract for our Riverton facility. Depreciation expense will increase reflecting the Asbury AQCS project in service for a full year and an estimated 20 year life rate and we will also see increased depreciation for assets placed in service since our last case. The impact on depreciation from the Asbury AQCS project alone is approximately $0.09 on an earnings per share basis. We will also see increases in property tax and interest expense. The higher interest expense reflects our December 2014 debt issuance and expected issuance in 2015. Our AFUDC impact will be lower in 2015 now that as Asbury is complete and in service. Other factors considered in our range are variations in customer growth and usage as well as variations in operating and maintenance expense. Again our range does not take into account any changes to our Missouri rate case filing or reflect any December 31, 2014 true-up numbers. As a reminder we have summarized the components of our Missouri rate case as currently filed on slide 8. On slide 9, we provide the historical and projected capital expenditures and net plant in-service numbers that reflect our current capital expenditure plan. No changes have been made since the update we provided last quarter. The 2015 expenditures reflect our ongoing cost for the Riverton combined cycle project. On this slide w also present our net plant levels less deferred taxes to approximate our estimated rate base. To finance these projects we expect to issue some debt financing in the middle of 2015. Right now we believe the debt offering will be in the range of $60 million but could be subject to change based on expenditure timing and other factors. This financing combined with the addition of internal equity from our dividend reinvestment and stock purchase plans and our combined build of retained earnings will help keep us near our target 50:50 debt equity capital structure. I will now turn the discussion back over to Brad. Brad Beecher Thank you, Laurie. As Laurie referenced and as shown in slide 10, in addition to the work completed in Asbury we’re moving ahead with construction at our Riverton power plant. The foundation work is complete and most of the major equipment is on-site for the Riverton Unit 12 conversion. As of December 31, our total cost of this project is 88.5 million. As a reminder we estimate our total cost of completion to be between a 165 million to a 175 million. We continue to successful execute our growth strategy to build rate base infrastructure to serve our customers and meet environmental regulations. The completion of the Asbury AQCS and on-going Riverton 12 combined cycle projects are the largest additions to these plan. Empire remains a high quality, pure play, regulated electric and natural gas utility. We’re focused on our vision of making lives better every day with reliable energy and service. We’re committed to meeting today’s energy challenges with least cost resources while ensuring reliable energy for our customers and attractive return for our shareholders and a rewarding environment for our employees. I will now turn the call back to the operator for your questions. Question-and-Answer Session Operator [Operator Instructions]. And our first question comes from Brian Russo of Ladenburg Thalmann. Please go ahead. Brian Russo When I look at kind of the midpoint of your 2015 guidance, kind of implies about an 8% earned ROE which is quite a meaningful amount of regulatory lag versus you know kind of 9-8 current allowed ROE. I just want to maybe drill deeper into the lag. I think you quantified the impact for the Asbury depreciation. Could we quantify the O&M impact as well and then kind of differentiate what structural lag versus what’s just timing lag related to your base rate cases. Laurie Delano We don’t really anticipate a huge O&M impact from the Asbury project, we will see an increase in our consumables, limestone, activated carbon and those sorts of things. However we actually recovered those back through our fuel adjustment. Obviously we will see an increase in property taxes from the Asbury project and if you look at the slide where our rate case summarization takes place you will see that we have asked for about $2.9 million in property taxes associated with that case. So that kind of gives you a feel for what that directionally might be. Brian Russo Okay, can you remind us of the lag that you experience on transmission cost and property taxes each year? Brad Beecher Today neither property taxes or transmission expenses are recovered in trackers and so they go through a normal procedure. So in this case what we’re recovering in our rates is reflective of the rates that we received in April of 2013. So, we have asked for in this current case the transmission expenses to be included in our fuel adjustment cost to help reduce that lag in the future. But that’s something that will have to be taken in account in this current case. Your other question, you had asked earlier relating to structural lag versus lag on timing of the cases. I have a hard time differentiating that, in Missouri we have a 11 month process and using this case is a good example for illustration is any – we have filed the case at the end of August of last year. We will expect rates by about July, we’re going to get a true-up through the end of the year and so that’s about as tight as we can cut it as it relates to the biggest CapEx expenditure. So we have 6 or 7 months lag on those big CapEx after they go in service before we get recovery in rates. And so that’s what we experienced on Asbury and we’re seeing today and it’s the kind of representative of the kind of lag we will see on Riverton 12 as well. Brian Russo Okay. In your last Missouri rate case you guys actually settled and rates went into effect in April. Was that several months earlier than the 11 month process or was the filing date different than this go around [ph]? Brad Beecher Brian, my memory is the rates went into effect a little bit early and when you get into settlement sometimes that’s one of the variables that we consider when we’re deciding whether to sell or not, it’s where the rates can go in a little bit early. I don’t recall the exact dates on the last case we will have to – we can dig that out later. Brian Russo Okay, so I guess if you did settled rates went into effect earlier obviously there would be less lag in ’15? Brad Beecher If that were to happen, that’s true. Brian Russo And then just back to your comment, the lag experience with Asbury this year and then the lag associated with Riverton upgrade next year. Is it kind of implied that you’re going to be experiencing similar regulatory lag in ’16 and ’15 and 2017 should be the year where we see improved returns? Brad Beecher What I was trying to get across is we’re going to have similar lag on Riverton 12 as we have on Asbury AQCS so that would say we’re going to have lag in 2016 and you can look at our CapEx forecast for ’16, ’17 and ’18 and we do drop off after Riverton 12 and that should give our shareholders a little bit of a better change to recover their allowed rate of return. Operator Our next question comes from Julien Dumoulin-Smith of UBS. Please go ahead. Paul Zimbardo It’s actually Paul Zimbardo. First question, on the estimated rate base slides, it looks like there is a little bit of a change from the last quarter, is that just bonus depreciation or something of alike? Laurie Delano For the rate base slides, yes, that would be correct. Paul Zimbardo And does that impact the rate case filing at all? Brad Beecher So, when we made the rate case filing bonus depreciation had not yet been extended and so our filing did not reflect that and same way when we put this slide together last quarter it had not yet being extended. So that accelerated depreciation will be reflected as one of the many true-ups that will happen at the end of the December 31 true-up. And as you pointed out bonus depreciation is a reduction or offset to rate base. Paul Zimbardo So a follow-up on the last question about quantifying some of those 2015 earnings driver, I apologize if I missed it, did you say what the impact of the new maintenance contract was– Laurie Delano I didn’t say but on the slide that summarizes our rate case filing assumptions, we call that out at $3.9 million. Operator [Operator Instructions]. Our next question comes from Michael Goldenberg of Luminus Management. Please go ahead. Michael Goldenberg So I want to go back to 2016, I understand 2015 is a big down year but I was under the assumption – I think we have discussed on a several occasion, you kind of always seem to point investors to when you think about long term, when you think about 2016, do rate base times equity times ROE and all these little changes in O&M are long haul, they even out and then structural lag probably should be more than let’s say a 100 bps that was kind of the impression that I think over the years have got. Is it fair to say that that may no longer be the best way to think about the company structurally? Brad Beecher If you look at the last several years for EDE we have been closer to 200 basis points regulatory lag and we have been looking at about 8% ROE in something that’s in that 10% kind of ROE range as people think about our allowed ROEs and so we have had closer to 200 basis points of lag historically. For 2014 we were at about 8.75% I think actually ROE, so we got down to about a 150 basis point to lag [inaudible]. In the big CapEx years we’re going to struggle a little bit more but as growth has come down in our industry and I’m really talking about our sales growth, it really tends to exacerbate regulatory lag when you don’t have any new kilowatt hour sales to help pay for increased expenses. Michael Goldenberg So help me understand this then, generally the way the rate cases work even with in stage with structural lag in your first year of rate case, let’s say it’s a three year cycle. Your drag is generally the lowest right when you get the rates and then I agree that if you have a lot of CapEx then by the end of year three that structural lag increases and that’s generally the way it works so. I kind of thought or was working on the assumption that if you take the period of July ’15 through June ’16, structure, that should be the time of your least drag. Is that not the right way or is the drag actually going to then get even worse? Brad Beecher I think you’re thinking about it correctly. Once our rates go into effect in ’15 until such time as we start big depreciation expense on Riverton 12 going into service, that will be the time of least regulatory lag in that kind of window, that year after you get rates and before you start depreciation and O&M on the new assets coming into service. Michael Goldenberg Okay and just to be precise, Riverton depreciation starts when? Laurie Delano Well we’re assuming that Riverton will come online in mid-2016 and so you would assume that deprecation would start immediately after it comes online Michael Goldenberg So then we would see drags of even more than 200 bps? Laurie Delano Well we haven’t really quantified that but – I mean it’s – you’re going to see the same, a little bit the same scenario again depending on what the depreciation amount is for Riverton and the other thing you see is AFUDC benefit dropping off when that plant comes into service, you know that’s happening on the Asbury project also. Brad Beecher And then as we’ve talked about earlier when the new plants come online we have got property taxes that get assessed [ph] and we have lag on property taxes as well. Michael Goldenberg But yes you get the revenue step up to make up for all of that and give you as much to the bottom-line as AFUDC used to, isn’t that the general concept, that when a plant goes into service. If everything is done ideally then revenue just increases for the amount that the expenses are and the net income stays roughly the same for a $1 off CapEx whether it’s AFUDC or cash. Laurie Delano Yes, when your rates go into effect that’s true but in those intervening months until they go into effect the time that plant comes online that’s where you’re going to drag. Michael Goldenberg And then just finally, conceptually thinking, yes it’s very good ’14 right? You made $1.55 and that’s before rate case, now you actually are going to get new rates and you do know how to CapEx and yet your earnings are going down and just judging by the structure of going into ’16 and then more depreciation. It’s hard to see how structurally putting in all this CapEx is actually – instead given the situation Missouri, does it actually incentivize investment where the company actually financially hurts from putting in more and more CapEx? Brad Beecher Well in the end our business model in Missouri is we earn a return on assets that we build to serve our customers. We’re going through structural pain and this is a perfect example, Asbury went into service. It’s been used to service customers, we’re depreciating it today and expensing it in early ’15. We’re paying property taxes, we’re paying O&M and we’re getting no recovery from customers until rates go into effect no later than July 26th and that is Missouri structural lag and it is a disincentive but it is the world that we live in. We’ve worked very, very hard in the Missouri legislature last couple of years trying to get some relief on plan in-service, trying to get relief on property taxes and we have so far being unsuccessful. Operator [Operator Instructions]. And another question just came in from Tim Winter of Gabelli & Company. Please go ahead. Tim Winter I just had one follow-up, Brad. Where is the legislation stand right now in Missouri to give property taxes and transmission expenses [ph] and whatever else included. Brad Beecher At the current time Tim to my knowledge there is not any legislation filed related to plant in-service and/or property taxes. We have got a lot of uncertainty in the state right now as the governor is got a statewide energy plan underway, I don’t know if you participated but there has been input meetings across the state and we would expect a statewide energy plan to come out sometime May kind of timeframe. We have got 111(d) and how that’s going to get finalized. So right now we’re still – I’m expecting a pretty quiet year in Jeff City, not saying that something can’t get done but I’m expecting a pretty quiet year in Jeff City, not saying that something can’t get done but I’m expecting a pretty quiet year in Jeff City as it relates to this topic. Tim Winter The statewide energy plan include something about – would address this issue? Because you’re not the only utility in the state that has this issue. Brad Beecher We’re absolutely not the only utility in the state with this issue. The statewide energy plan is comprehensive, it’s everything that you can think about from solar to distributed generation to responses and emergencies to what we need to build assets just about everything has been talked about in one work group or another. So, it’s a work in progress, it’s being led by a member of the governor staff and so we will have to see where it goes. But we certainly brought up this concern. Operator And this concludes our question and answer session. I would like to turn the conference back over to Brad Beecher for any closing remarks. Brad Beecher Thank you. Before we close I remind you that Laurie and I will be at the UBS Analyst Day in Boston on March 3rd and 4th and Laurie and Dale will be the AJA Mini-Forum in Dallas on March 17th and 18th. Also we will be saying goodbye to Jen Watson at the end of April as she has decided to retire. Jen has served Empire in the Secretary and Treasurer positions since 1995. We thank Jen for her service and wish her the best. The Board has named Dale Harrington to replace Jen as Secretary beginning May 1, 2015. Dale will also continue in this role of Director of Investor Relations. Thank you for joining us today and have a great weekend. 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. 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