UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

FORM 10-Q 

 

(Mark One)

☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June  30, 2014

 

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 

Commission file number 1-8644 

IPALCO ENTERPRISES, INC.
(Exact name of registrant as specified in its charter) 

 

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes ☐   No ☑

(Registrant is a voluntary filer that has filed all applicable reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months)

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ☑  No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐   No ☑ 

At August 6, 2014,  89,685,177 shares of IPALCO Enterprises, Inc. common stock were outstanding. All of such shares were owned by The AES Corporation.

THE REGISTRANT MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTIONS H(1)(a) AND (b) OF FORM 10-Q AND IS THEREFORE FILING THIS FORM WITH THE REDUCED DISCLOSURE FORMAT

 

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IPALCO ENTERPRISES, INC.

QUARTERLY Report on Form 10-q 

For Quarter Ended June 30, 2014

 

Table of Contents

 

 

 

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CAUTIONARY NOTE REGARDING FORWARD‑LOOKING STATEMENTS

 

This Quarterly Report on Form 10-Q includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934, as amended (“Exchange Act”) including, in particular, the statements about our plans, strategies and prospects under the heading “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part I – Financial Information of this Form 10-Q. Forward-looking statements involve many risks and uncertainties and express an expectation or belief and contain a projection, plan or assumption with regard to, among other things, our future revenues, income, expenses or capital structure. Such statements of future events or performance are not guarantees of future performance and involve estimates, assumptions and uncertainties. The words “could,” “may,” “predict,” “anticipate,” “would,” “believe,” “estimate,” “expect,” “forecast,” “project,” “objective,” “intend,” “continue,” “should,” “plan,” and similar expressions, or the negatives thereof, are intended to identify forward-looking statements unless the context requires otherwise.

 

Some important factors that could cause our actual results or outcomes to differ materially from those discussed in the forward-looking statements include, but are not limited to:

 

 

Most of these factors affect us through our consolidated subsidiary Indianapolis Power & Light Company (“IPL”). All such factors are difficult to predict, contain uncertainties that may materially affect actual results and many are beyond our control. Except as required by the federal securities laws, we undertake no obligation to publicly update or review any forward-looking information, whether as a result of new information, future events or otherwise. If one or more forward-looking statements are updated, no inference should be drawn that additional updates will be made with respect to those or other forward-looking statements.

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PART I – financial information

 

ITEM 1. financial statementS 

 

 

 

 

 

 

 

 

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IPALCO ENTERPRISES, INC. and SUBSIDIARIES

Notes to Unaudited Condensed Consolidated Financial Statements

 

For a list of certain abbreviations or acronyms used in the Notes to Unaudited Condensed Consolidated Financial Statements, see “Item 1B. Defined Terms” included in Part I – Financial Information of this Form 10-Q.

 

1. ORGANIZATION

 

IPALCO Enterprises, Inc. (“IPALCO”) is a holding company incorporated under the laws of the state of Indiana. IPALCO is a wholly-owned subsidiary of The AES Corporation (“AES”). IPALCO was acquired by AES in March 2001. IPALCO owns all of the outstanding common stock of its subsidiaries. Substantially all of IPALCO’s business consists of the generation, transmission, distribution and sale of electric energy conducted through its principal subsidiary, Indianapolis Power & Light Company (“IPL”). IPL was incorporated under the laws of the state of Indiana in 1926. IPL has more than 470,000 retail customers in the city of Indianapolis and neighboring cities, towns and communities, and adjacent rural areas all within the state of Indiana, the most distant point being approximately forty miles from Indianapolis. IPL has an exclusive right to provide electric service to those customers. IPL owns and operates two primarily coal-fired generating plants, one combination coal and gas-fired plant and two combustion turbines at a separate site that are all used for generating electricity. IPL’s net electric generation design  capability for winter and summer is 3,241 Megawatts (“MW”) and 3,123 MW, respectively.  

 

2. Summary of significant accounting policies

 

The accompanying Unaudited Condensed Consolidated Financial Statements (the “Financial Statements”) include the accounts of IPALCO, IPL and Mid-America Capital Resources, Inc., a non-regulated wholly-owned subsidiary of IPALCO. All significant intercompany amounts have been eliminated. The accompanying Financial Statements are unaudited; however, they have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and in conjunction with the rules and regulations of the Securities and Exchange Commission. Accordingly, they do not include all of the disclosures required by accounting principles generally accepted in the United States of America for annual fiscal reporting periods. In the opinion of management, all adjustments of a normal recurring nature necessary for fair presentation have been included. The electric utility business is affected by seasonal weather patterns throughout the year and, therefore, the operating revenues and associated operating expenses are not generated evenly by month during the year. These unaudited Financial Statements have been prepared in accordance with the accounting policies described in IPALCO’s Annual Report on Form 10-K for the year ended December 31, 2013 (“2013 Form 10-K”) and should be read in conjunction therewith. Certain prior period amounts have been reclassified to conform to current year presentation.

 

Use of Management Estimates

 

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires that management make certain estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements. The reported amounts of revenues and expenses during the reporting period may also be affected by the estimates and assumptions that management is required to make. Actual results may differ from those estimates.

 

New Accounting Pronouncements

 

In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-08,  “Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity,”  effective for annual and interim periods beginning after December 15, 2014. ASU 2014-08 updates the definition of discontinued operations by limiting discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have (or will have) a major effect on an entity’s operations and financial results. In addition, an entity will be required to expand disclosures for discontinued operations by providing more information about the assets, liabilities, revenues and expenses of discontinued operations both on the face of the financial statements and in the notes to the financial statements. For the disposal of an individually significant component of an entity that does not qualify for discontinued operations reporting, such entity will be required to disclose the pretax profit or loss of the component in the  notes to the financial statements. This ASU is not expected to have a material effect on our overall results of operations, financial position or cash flows.

 

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In May 2014, the FASB issued ASU 2014-09 “Revenue from Contracts with Customers (Topic 606),” effective for annual and interim periods beginning after December 15, 2016, with retrospective application. The core principle of this ASU is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. Because the guidance in this ASU is principles-based, it can be applied to all contracts with customers regardless of industry-specific or transaction-specific fact patterns. Additionally, the guidance requires improved disclosures to help users of financial statements better understand the nature, amount, timing, and uncertainty of revenue that is recognized. We have not yet determined the extent, if any, to which our overall results of operations, financial position or cash flows may be affected by the implementation of this accounting standard.

 

 

3. FAIR VALUE MEASUREMENTS

 

Fair Value Hierarchy

 

FASB Accounting Standards Codification (“ASC”) 820 defined and established a framework for measuring fair value and expanded disclosures about fair value measurements for financial assets and liabilities that are adjusted to fair value on a recurring basis and/or financial assets and liabilities that are measured at fair value on a nonrecurring basis, which have been adjusted to fair value during the period. In accordance with ASC 820, we have categorized our financial assets and liabilities that are adjusted to fair value, based on the priority of the inputs to the valuation technique, following the three-level fair value hierarchy prescribed by ASC 820, as follows:

 

Level 1 - unadjusted quoted prices for identical assets or liabilities in an active market.

 

Level 2 - inputs from quoted prices in markets where trading occurs infrequently or quoted prices of instruments with similar attributes in active markets.

 

Level 3 - unobservable inputs reflecting management’s own assumptions about the inputs used in pricing the asset or liability.

 

As of June  30, 2014 and December 31, 2013, all of IPALCO’s financial assets or liabilities adjusted to fair value on a recurring basis (excluding pension assets – see Note 6, “Pension and Other Postretirement Benefits”) were considered Level 3, based on the above fair value hierarchy. These primarily consisted of financial transmission rights, which are used to offset MISO congestion charges. Because the benefit associated with financial transmission rights is a flow-through to IPL’s jurisdictional customers, IPL records a regulatory liability matching the value of the financial transmission rights.  In addition, IPALCO had one financial asset, a nonutility investment accounted for using the cost method of accounting, which is measured at fair value on a nonrecurring basis, again using Level 3 measurements.  No adjustments were made to this asset during the periods covered by this report. All of these financial assets and liabilities were not material to the Financial Statements in the periods covered by this report, individually or in the aggregate.

 

Whenever possible, quoted prices in active markets are used to determine the fair value of our financial instruments. Our financial instruments are not held for trading or other speculative purposes. The estimated fair value of financial instruments has been determined by using available market information and appropriate valuation methodologies. However, considerable judgment is required in interpreting market data to develop the estimates of fair value. Accordingly, the estimates presented herein are not necessarily indicative of the amounts that we could realize in a current market exchange. The use of different market assumptions and/or estimation methodologies may have a material effect on the estimated fair value amounts.

 

Cash Equivalents

 

As of June  30, 2014 and December 31, 2013, our cash equivalents consisted of money market funds. The fair value of cash equivalents approximates their book value due to their short maturity (Level 1), which was $17.4 million and $5.4 million as of June  30, 2014 and December 31, 2013, respectively.

 

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Indebtedness

 

The fair value of our outstanding fixed-rate debt has been determined on the basis of the quoted market prices of the specific securities issued and outstanding. Because trading of our debt occurs somewhat infrequently, we consider the fair values to be Level 2. Accordingly, the purpose of this disclosure is not to approximate the value on the basis of how the debt might be refinanced.

 

The following table shows the face value and the fair value of fixed-rate and variable-rate indebtedness for the periods ending: 

 

 

 

The difference between the face value and the carrying value of this indebtedness represents unamortized discounts of $4.8 million and $3.6 million at June  30, 2014 and December 31, 2013, respectively.

 

4. SHAREHOLDER’S EQUITY

 

On June 27, 2014, IPALCO received an equity capital contribution of $106.4 million from AES for funding needs related to IPL’s environmental and replacement generation projects.  IPALCO then made the same equity capital contribution to IPL.

 

5. INDEBTEDNESS

 

Line of Credit

 

In May 2014, IPL entered into an amendment and restatement of its 5-year $250 million revolving credit facility (the “Credit Agreement”) with a syndication of banks. This Credit Agreement is an unsecured committed line of credit to be used (i) to finance capital expenditures, (ii) to refinance indebtedness under the existing credit agreement, (iii) to support working capital and (iv) for general corporate purposes. This agreement matures on May 6, 2019, and bears interest at variable rates as described in the Credit Agreement. It includes an uncommitted $150 million accordion feature to provide IPL with an option to request an increase in the size of the facility at any time during the term of the agreement, subject to approval by the lenders.  Prior to execution, IPL and IPALCO had existing general banking relationships with the parties in this agreement. As of June  30, 2014 and December 31, 2013, IPL had no outstanding borrowings on the committed line of credit.

 

IPL First Mortgage Bonds

 

In June 2014, IPL issued $130 million aggregate principal amount of first mortgage bonds, 4.50% Series, due June 2044. Net proceeds from this offering were approximately $126.8 million, after deducting the initial purchasers’ discounts and fees and expenses for the offering payable by IPL. The net proceeds from the offering will be used (i) to finance a portion of IPL’s construction program, (ii) to finance a portion of IPL’s capital costs related to environmental and replacement generation projects and (iii) for other general corporate purposes. 

 

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6. PENSION AND OTHER POSTRETIREMENT BENEFITS

 

The following table (in thousands) presents information for the six months ended June  30, 2014, relating to the Employees’ Retirement Plan of Indianapolis Power & Light Company and the Supplemental Retirement Plan of Indianapolis Power & Light Company  (the “Pension Plans”):

 

Pension Expense

 

The following table presents net  periodic benefit cost information relating to the Pension Plans combined:

 

 

 

In addition, IPL provides postretirement health care benefits to certain active or retired employees and the spouses of certain active or retired employees. These postretirement health care benefits and the related obligation were not material to the Financial Statements in the periods covered by this report.

 

 

 

7. COMMITMENTS AND CONTINGENCIES

 

Legal Loss Contingencies

 

IPALCO and IPL are involved in litigation arising in the normal course of business. While the results of such litigation cannot be predicted with certainty, management believes that the final outcome will not have a material adverse effect on IPALCO’s results of operations, financial condition, or cash flows. Amounts accrued or expensed for legal or environmental contingencies collectively during the periods covered by this report have not been material to the Financial Statements of IPALCO.

 

Environmental Loss Contingencies

 

We are subject to various federal, state, regional and local environmental protection and health and safety laws and regulations governing, among other things, the generation, storage, handling, use, disposal and transportation of hazardous materials; the emission and discharge of hazardous and other materials into the environment; and the health and safety of our employees. These laws and regulations often require a lengthy and complex process of obtaining and renewing permits and other governmental authorizations from federal, state and local agencies. Violation of these laws, regulations or permits can result in substantial fines, other sanctions, permit revocation and/or facility shutdowns. We cannot assure that we have been or will be at all times in full compliance with such laws, regulations and permits.

 

New Source Review

 

In October 2009, IPL received a Notice of Violation (“NOV”) and Finding of Violation from the U.S. Environmental Protection Agency (“EPA”) pursuant to the U.S. Clean Air Act (“CAA”) Section 113(a). The NOV alleges violations of the CAA at IPL’s three primarily coal-fired electric generating facilities dating back to 1986. The alleged violations primarily pertain to Prevention of Significant Deterioration and nonattainment New Source Review requirements under the CAA. Since receiving the letter, IPL management has met with the EPA staff regarding possible resolutions of the NOV. At this time, we cannot predict the ultimate resolution of this matter. However, settlements and litigated outcomes of similar cases have required companies to pay civil penalties, install additional pollution control technology on coal-fired electric generating units, retire existing generating units, and invest in additional environmental projects. A similar outcome in this case could have a material impact on our business. We would seek recovery of any operating or capital expenditures related to air pollution control

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technology to reduce regulated air emissions; however, there can be no assurances that we would be successful in that regard. IPL has recorded a contingent liability related to this matter.

 

8. INCOME TAXES

 

On March 25, 2014, the State of Indiana enacted Senate Bill 001, which phases in an additional 1.6% reduction to the state corporate income tax rate that was initially being reduced by 2% in accordance with Indiana Code 6-3-2-1. While the statutory state income tax rate remains at 7.25% for the calendar year 2014, the deferred tax balances were adjusted according to the anticipated reversal of temporary differences. The change in required deferred taxes on plant and plant-related temporary differences resulted in a reduction to the associated regulatory asset of $5.6 million. The change in required deferred taxes on non-property-related temporary differences which are not probable to cause a reduction in future base customer rates resulted in a tax benefit of $1.2 million.

 

IPALCO’s effective combined state and federal income tax rates  were 34.8% and 33.0% for the three and six months ended June  30, 2014, respectively, as compared to 39.2% and 38.1% for the three and six months ended June  30, 2013, respectively. The decrease in the effective tax rates versus the comparable periods  was primarily the result of the $1.2 million state income tax benefit described above and an increase in the allowance for equity funds used during construction in 2014.

 

9. RELATED PARTY TRANSACTIONS

 

In December 2013, an agreement was signed, effective January 1, 2014, whereby AES U.S. Services, LLC (the “Service Company”) is to provide services including accounting, legal, human resources, information technology and other corporate services on behalf of companies that are part of the AES U.S. Strategic Business Unit (“U.S. SBU”), including among other companies, IPALCO and IPL. The Service Company allocates the costs for these services based on cost drivers designed to result in fair and equitable allocations. This includes ensuring that the regulated utilities served, including IPL, are not subsidizing costs incurred for the benefit of non-regulated businesses. Total costs incurred by the Service Company during the first six months of 2014 on behalf of IPALCO were $13.6 million. IPALCO had a prepaid balance of $6.6 million to the Service Company as of June 30, 2014.  

 

10. SEGMENT INFORMATION

 

Operating segments are components of an enterprise for which separate financial information is available and is evaluated regularly by the chief operating decision maker in assessing performance and deciding how to allocate resources. Substantially all of our business consists of the generation, transmission, distribution and sale of electric energy conducted through IPL which is a vertically integrated electric utility. IPALCO’s reportable business segments are utility and nonutility. The nonutility category primarily includes the $400 million of 7.25% Senior Secured Notes due April 1, 2016, and the $400 million of 5.00% Senior Secured Notes due May 1, 2018; approximately $6.2 million and $6.9 million of nonutility cash and cash equivalents, as of June  30, 2014 and December 31, 2013, respectively; short-term and long-term nonutility investments of $5.1 million and $5.0 million at June  30, 2014 and December 31, 2013, respectively; and income taxes and interest related to those items. Nonutility assets represented less than 1% of IPALCO’s total assets as of June  30, 2014 and December 31, 2013. Net income for the utility segment was $51.2 million and $46.9 million for the six-month periods ended June 30, 2014 and 2013, respectively, and $19.8 million and $17.8 million for the three-month periods ended June  30, 2014 and 2013, respectively. The accounting policies of the identified segments are consistent with those policies and procedures described in the summary of significant accounting policies. Intersegment sales, if any, are generally based on prices that reflect the current market conditions.

 

 

 

 

 

 

 

 

 

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ITEM 1B. DEFINED TERMS

 

 

 

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 

The following discussion and analysis should be read in conjunction with the  Financial Statements and the notes thereto included in “Item 1. Financial Statements” included in Part I – Financial Information of this Form 10-Q. The following discussion contains forward-looking statements. Our actual results may differ materially from the results suggested by these forward-looking statements. Please see “Cautionary Note Regarding Forward – Looking Statements” at the beginning of this Form 10-Q. For a list of certain abbreviations or acronyms used in this discussion, see “Item 1B. Defined Terms” included in Part I – Financial Information of this Form 10-Q.

 

RESULTS OF OPERATIONS

 

The electric utility business is affected by seasonal weather patterns throughout the year and, therefore, the operating revenues and associated expenses are not generated evenly by month during the year. 

 

Comparison of three months ended June  30, 2014 and three months ended June  30, 2013

 

Utility Operating Revenues

 

Utility operating revenues during the three months ended June  30,  2014 increased by $14.6 million compared to the same period in 2013, which resulted from the following changes (dollars in thousands):

 

 

 

 

The increase in retail revenues of $17.5 million was primarily due to a net increase in the weighted average price per kilowatt hours (“kWh”) sold ($17.4 million), while retail volumes were flat. The $17.4 million increase in the weighted average price of retail kWh sold was primarily due to increases in fuel revenues of $14.4 million and environmental rate adjustment mechanism revenues of $2.8 million. The increase in fuel revenues was partially offset by increases in purchased power and fuel costs as described below. Likewise, the vast majority of the increases in environmental rate adjustment mechanism revenues are offset by increased operating expenses.  

 

The decrease in wholesale revenues of $3.3 million was primarily due to  a 12% decrease in the quantity of kWh sold ($2.9 million) as IPL’s coal-fired generation has been called upon by MISO to produce electricity less often during the second quarter of 2014 versus the comparable period. This was primarily due to an increase in outage rates during the second quarter of 2014 versus the comparable period. Our ability to be dispatched in the MISO market is

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primarily impacted by the locational marginal price of electricity and variable generation costs. The amount of electricity available for wholesale sales is impacted by our retail load requirements, our generation capacity and unit availability.

 

Utility Operating Expenses

 

The following table illustrates our primary operating expense changes from the three months ended June  30,  2013 to the three months ended June  30,  2014 (in millions):

 

 

The $8.3 million increase in purchased power costs was primarily due to a 48% increase in the market price of purchased power ($8.8 million).  The market price of purchased power is influenced primarily by changes in the market price of delivered fuel (primarily natural gas), the price of environmental emissions allowances, the supply of and demand for electricity, and the time of day in which power is purchased. In the comparable periods, the increase in natural gas prices had the largest impact on the market price of purchased power. The volume of power we purchase each period is primarily influenced by our retail demand, our generating unit capacity and outages as well as that at times it is less expensive for us to buy power in the market than to produce it ourselves.

 

The $4.0 million decrease in pension expenses, which is included in “Other operating expenses” on our Unaudited Condensed Consolidated Statements of Income, is primarily due to a $3.3 million decrease in the recognized actuarial loss.

 

The $3.8 million increase in fuel costs is primarily due to fuel price increases of $7.7 million as the result of variances between estimated fuel costs in our Fuel Adjustment Clause (“FAC”) and actual fuel costs. We are generally permitted to recover underestimated fuel costs to serve our retail customers in future rates through the FAC proceedings and, therefore, the costs are deferred when incurred and amortized into expense in the same period that our rates are adjusted to reflect these costs. Partially offsetting this increase was a $4.1 million decrease in the quantity of fuel consumed as the result of a decrease in wholesale sales volume in the comparable periods.

 

Maintenance expenses increased $3.7 million versus the comparable period primarily due to increased outages. The increase in depreciation and amortization costs of $0.9 million was primarily due to additional assets placed in service.

 

 

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Comparison of six months ended June  30, 2014 and six months ended June  30, 2013

 

Utility Operating Revenues

 

Utility operating revenues during the six months ended June  30,  2014 increased by $42.9 million compared to the same period in 2013, which resulted from the following changes (dollars in thousands):

 

 

 

 

The increase in retail revenues of $40.3 million was primarily due to a net increase in the weighted average price per kWh sold ($23.3 million) and a  4% increase in the volume of  kWh sold ($17.0 million). The $23.3 million increase in the weighted average price of retail kWh sold was primarily due to increases in fuel revenues of $32.0 million,  Demand Side Management (“DSM”) program rate adjustment mechanism revenues of $4.3 million, and environmental rate adjustment mechanism revenues of $1.2 million;  partially offset by unfavorable block rate and other retail variances of $14.1 million. The increase in fuel revenues was partially offset by increases in purchased power costs as described below. Likewise, the vast majority of the increase in DSM rate adjustment mechanism revenues was offset by increased operating expenses. The unfavorable block rate variances were mostly attributed to our declining block rate structure, which generally provides for residential and commercial customers to be charged a lower per kWh rate at higher consumption levels. Therefore, as volumes increase, the weighted average price per kWh decreases. The $17.0 million increase in the volume of electricity sold was primarily due to colder temperatures in our service territory during the first quarter of 2014 versus the comparable period (as demonstrated by the 16% increase in heating degree days, as shown above).

 

The increase in wholesale revenues of $1.7 million was primarily due to a 20% increase in the weighted average price per kWh sold ($6.9 million) partially offset by a 13% decrease in the quantity of kWh sold ($5.2 million). We believe the higher market prices in 2014 were heavily influenced by the impact the colder temperatures had on demand for electricity in the MISO wholesale market. Our ability to be dispatched in the MISO market is primarily impacted by the locational marginal price of electricity and variable generation costs. The amount of electricity available for wholesale sales is impacted by our retail load requirements, our generation capacity and unit availability. 

 

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Utility Operating Expenses

 

The following table illustrates our primary operating expense changes from the six months ended June  30, 2013 to the six months ended June  30, 2014 (in millions):

 

 

 

The $22.8 million increase in purchased power costs was primarily due to a 33% increase in the market price of purchased power ($18.9 million) and a 6% increase in the volume of power purchased during the period ($2.1 million). The market price of purchased power is influenced primarily by changes in the market price of delivered fuel (primarily natural gas), the price of environmental emissions allowances, the supply of and demand for electricity, and the time of day in which power is purchased. In the comparable periods, the increase in natural gas prices, which we believe were heavily influenced by the 16% increase in heating degree days, had the largest impact on the market price of purchased power. The volume of power we purchase each period is primarily influenced by our retail demand, our generating unit capacity and outages as well as that at times it is less expensive for us to buy power in the market than to produce it ourselves. During the comparable periods, retail sales increased, which accounted for the majority of the increase in purchased power volume.

 

Maintenance expenses increased $10.6 million versus the comparable period primarily due to the timing and duration of major generating unit overhauls and increased outages, as well as higher storm-related operating expenses of $3.8 million largely due to winter storms at the beginning of the year.

 

The $7.9 million decrease in pension expenses, which is included in “Other operating expenses” on our Unaudited Condensed Consolidated Statements of Income, is primarily due to a $6.5 million decrease in the recognized actuarial loss.

 

The increase in DSM program costs of $4.4 million, which are recoverable through customer rates, is attributed to the continued implementation of IPL’s energy efficiency program initiatives. The increase in DSM program costs is correlated to an increase in DSM program rate adjustment mechanism retail revenues. 

 

The $2.1 million increase in fuel costs is primarily due to fuel price increases of $2.3 million as the result of variances between estimated fuel costs in our FAC and actual fuel costs. We are generally permitted to recover underestimated fuel costs to serve our retail customers in future rates through the FAC proceedings and, therefore, the costs are deferred when incurred and amortized into expense in the same period that our rates are adjusted to reflect these costs.

 

The increase in depreciation and amortization costs of $1.9 million was primarily due to additional assets placed in service.

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LIQUIDITY AND CAPITAL RESOURCES

 

As of June  30, 2014, we had unrestricted cash and cash equivalents of $127.8 million and available borrowing capacity of $249.3 million under our $250 million unsecured revolving credit facility after outstanding borrowings and existing letters of credit. All of IPL’s long-term borrowings must first be approved by the IURC and the aggregate amount of IPL’s short-term indebtedness must be approved by the Federal Energy Regulatory Commission (“FERC”). We have approval from the FERC to borrow up to $500 million of short-term indebtedness outstanding at any time through July 28, 2016. In December 2013, we received an order from the IURC granting us authority through December 31, 2016 to, among other things, issue up to $425 million in aggregate principal amount of long-term debt (inclusive of $130 million of IPL first mortgage bonds issued in June 2014), refinance up to $171.9 million in existing indebtedness, and have up to $500 million of long-term credit agreements and liquidity facilities outstanding at any one time. We also have restrictions on the amount of new debt that may be issued due to contractual obligations of AES and by financial covenant restrictions under our existing debt obligations. We do not believe such restrictions will be a limiting factor in our ability to issue debt in the ordinary course of prudent business operations.

 

We believe that existing cash balances, cash generated from operating activities and borrowing capacity on our committed credit facility will be adequate for the foreseeable future to meet anticipated operating expenses, interest expense on outstanding indebtedness and recurring capital expenditures, and to pay dividends to AES. Sources for principal payments on outstanding indebtedness and nonrecurring capital expenditures are expected to be obtained from: (i) existing cash balances; (ii) cash generated from operating activities; (iii) borrowing capacity on our committed credit facility; and (iv) additional debt financing. In addition, due to current and expected future environmental regulations, it is expected that equity capital will continue to be used as a significant funding source. AES has approved significant equity investments in IPL for its proposed nonrecurring capital expenditures from 2013 through 2017; however, AES is under no contractual obligation to provide such equity capital and there can be no assurance we will receive capital contributions in the amounts, or at the times, funding may be required. On June 27, 2014, IPALCO received an equity capital contribution of $106.4 million from AES for funding needs related to IPL’s environmental and replacement generation projects.  IPALCO then made the same equity capital contribution to IPL.

 

Line of Credit

 

In May 2014, IPL entered into an amendment and restatement of its 5-year $250 million revolving credit facility (the “Credit Agreement”) with a syndication of banks. This Credit Agreement is an unsecured committed line of credit to be used (i) to finance capital expenditures, (ii) to refinance indebtedness under the existing credit agreement, (iii) to support working capital and (iv) for general corporate purposes. This agreement matures on May 6, 2019, and bears interest at variable rates as described in the Credit Agreement. It includes an uncommitted $150 million accordion feature to provide IPL with an option to request an increase in the size of the facility at any time during the term of the agreement, subject to approval by the lenders. Prior to execution, IPL and IPALCO had existing general banking relationships with the parties in this agreement. As of June 30, 2014 and December 31, 2013, IPL had no outstanding borrowings on the committed line of credit.

 

IPL First Mortgage Bonds

 

In June 2014, IPL issued $130 million aggregate principal amount of first mortgage bonds, 4.50% Series, due June 2044. Net proceeds from this offering were approximately $126.8  million, after deducting the initial purchasers’ discounts and fees and expenses for the offering payable by IPL. The net proceeds from the offering will be used (i) to finance a portion of IPL’s construction program, (ii) to finance a portion of IPL’s capital costs related to environmental and replacement generation projects and (iii) for other general corporate purposes. 

 

Capital Requirements

 

Capital Expenditures

 

Our construction program is composed of capital expenditures necessary for prudent utility operations and compliance with environmental laws and regulations, along with discretionary investments designed to replace aging equipment or improve overall performance. Our capital expenditures totaled $118.0 million and $86.0 million for the six-month periods ended June  30, 2014 and 2013, respectively.  The increase in capital expenditures of $32.0 million in 2014 versus 2013 was primarily driven by spending to comply with our environmental construction

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program. Construction expenditures during the first six months of 2014 and 2013 were financed primarily with internally generated cash provided by operations,  borrowings on our credit facility, long-term borrowings, and in 2014 with an equity capital contribution from AES.

 

Our capital expenditure program, including development and permitting costs, for the three-year period from 2014 to 2016 is currently estimated to cost approximately $453 million (excluding environmental compliance and replacement generation costs). It includes approximately $255 million for additions, improvements and extensions to transmission and distribution lines, substations, power factor and voltage regulating equipment, distribution transformers and street lighting facilities. The capital expenditure program also includes approximately $163 million for power plant-related projects and $35 million for other miscellaneous equipment.

 

In addition to the amounts listed above, IPL plans to spend an additional $385 million for the three-year period from 2014 to 2016 to comply with the Mercury and Air Toxics Standards (“MATS”) rule (IPL plans to spend a total of $511 million for this project, including amounts already expended). IPL also plans to spend $626 million on replacement generation costs through 2017 as a result of the retirement of existing facilities not equipped with advanced environmental control technologies required to comply with existing and expected regulations. Of this amount, $611 million is projected to be spent in the three-year period from 2014 to 2016. In addition, IPL will incur significant costs for compliance with other environmental regulations, including the National Pollutant Discharge Elimination System (“NPDES”) permit program under the U.S. Clean Water Act (“CWA”). The costs for NPDES are still being reviewed and are expected to be material during the forecast period. 

 

Common Stock Dividends

 

All of IPALCO’s outstanding common stock is held by AES. During the first six months of 2014 and 2013, we paid $42.8 million and $29.9 million, respectively, in dividends to AES. Future distributions will be determined at the discretion of our board of directors and will depend primarily on dividends received from IPL. Dividends from IPL are affected by IPL’s actual results of operations, financial condition, cash flows, capital requirements, regulatory considerations, and such other factors as IPL’s board of directors deems relevant.

 

Pension Funding

 

We contributed $54.1 million and $49.7 million to the Pension Plans during the first six months of 2014 and 2013, respectively. We currently do not expect to make additional pension funding payments in 2014. Funding for the qualified Employees’ Retirement Plan of Indianapolis Power & Light Company is based upon actuarially determined contributions that take into account the amount deductible for income tax purposes and the minimum contribution required under the Employee Retirement Income Security Act of 1974, as amended by the Pension Protection Act of 2006, as well as targeted funding levels necessary to meet certain thresholds.

 

Regulatory Matters

 

MISO Real Time Revenue Sufficiency Guarantee

 

MISO collects Revenue Sufficiency Guarantee (“RSG”) charges from market participants to pay for generation dispatched when the costs of such generation are not recovered in the market clearing price. Over the past several years, there have been disagreements between interested parties regarding the calculation methodology for RSG charges and how such charges should be allocated to the individual MISO participants, including IPL. Under the methodology currently in effect, RSG charges have little effect on IPL’s financial statements as the vast majority of such charges are considered to be fuel costs and are recoverable through IPL’s FAC, while the remainder are being deferred for future recovery in accordance with generally accepted accounting principles. However, the IURC’s orders in IPL’s FAC 77, 78 and 79 proceedings approved IPL’s FAC factor on an interim basis, subject to refund, pending the outcome of a FERC proceeding regarding RSG charges and any subsequent appeals therefrom. In a  recent FAC proceeding, IPL requested that the subject to refund designation be removed and that FAC 77, 78 and 79 proceedings be made final with no modifications. In February 2014, the IURC issued an order approving IPL’s request.

 

Demand-Side Management

 

In March 2014, legislation, referred to as the Senate Enrolled Act 340 (“SEA 340”), was approved that effectively ended the IURC’s energy efficiency targets established in a 2009 statewide Generic DSM Order. Although SEA 340

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puts an end to established efficiency targets, IPL will continue to offer cost-effective energy efficiency and demand response programs as one of many resources to meet future demand for electricity.

 

Environmental Matters

 

We are subject to various federal, state, regional and local environmental protection and health and safety laws and regulations governing, among other things, the generation, storage, handling, use, disposal and transportation of hazardous materials; the emission and discharge of hazardous and other materials into the environment; and the health and safety of our employees. These laws and regulations often require a lengthy and complex process of obtaining and renewing permits and other governmental authorizations from federal, state and local agencies. Violation of these laws, regulations or permits can result in substantial fines, other sanctions, and permit revocation and/or facility shutdowns.

 

MATS

 

Several lawsuits challenging the MATS rule have been filed by other parties and consolidated into a single proceeding before the U.S. Court of Appeals for the District of Columbia Circuit. In April 2014, the U.S. Court of Appeals issued an opinion upholding the MATS rule. Numerous states and two trade groups have petitioned the U.S. Supreme Court to review this opinion; however, it is unclear whether this opinion will be successfully appealed. We currently cannot predict the outcome of this litigation, or its impact, if any, on our MATS compliance planning.

 

On June  20, 2014, IPL contemporaneously filed a waiver request or in the alternative, a complaint with the FERC requesting a waiver or changes to MISO rules that will allow IPL to keep 216 MW of reliable capacity available at its Eagle Valley generating station from June 1, 2015,  through April 15, 2016. Both of these filings request that the FERC either waive or reform certain requirements of the MISO tariff for failing to address the specific circumstances resulting  from compliance with MATS. IPL maintains that MISO has not addressed several aspects of the issue created by the disconnect between the MATS compliance deadline and the end of the MISO planning year for capacity purposes (the difference between April 16, 2016, and June 1, 2016).

 

Unit Retirements and Replacement Generation

 

In addition to the generating units IPL retired in the second quarter of 2013, IPL has several other generating units that we expect to retire or refuel by 2017. These units are primarily coal-fired and represent 472 MW of net capacity in total. To replace this generation, IPL filed a petition and case-in-chief with the IURC in April 2013 seeking a Certificate of Public Convenience and Necessity (“CPCN”) to build a 550 to 725 MW combined cycle gas turbine (“CCGT”) at its Eagle Valley Station site in Indiana and to refuel Harding Street Station Units 5 and 6 from coal to natural gas (about 100 MW net capacity each). In May 2014, IPL received an order on the CPCN from the IURC authorizing the refueling project and granting approval to build a 644 to 685 MW CCGT at a total budget of $649 million. The current estimated cost of these projects is $626 million. IPL was granted authority to accrue post in-service allowance for debt and equity funds used during construction and to defer the recognition of depreciation expense of the CCGT and refueling project until such time that we are allowed to collect both a return and depreciation expense on the CCGT and refueling project. The CCGT is expected to be placed into service in April 2017, and the refueling project is expected to be completed in early 2016. The costs to build and operate the CCGT and for the refueling project, other than fuel costs, will not be recoverable by IPL through rates until the conclusion of a base rate case proceeding with the IURC after the assets have been placed in service.

 

Environmental Wastewater Requirements

 

In August 2012, the Indiana Department of Environmental Management (“IDEM”) issued NPDES permits to the IPL Petersburg, Harding Street, and Eagle Valley generating stations, which became effective in October 2012. NPDES permits regulate specific industrial wastewater and storm water discharges to the waters of Indiana under Section 402 of the Federal Water Pollution Control Act or Federal Clean Water Act (“CWA”). These permits set new water quality-based levels of acceptable metal effluent water discharges for the Petersburg and Harding Street facilities, as well as monitoring and other requirements designed to protect aquatic life, with full compliance with the new metal effluent limitations required by October 2015. In April 2013, IPL received an extension to the compliance deadline through September 2017 for IPL’s Harding Street and Petersburg facilities by agreed orders with IDEM.

 

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IPL is conducting studies to determine what operational changes and/or additional equipment will be required to comply with the new limitations. In developing its compliance plans, IPL must make assumptions about the outcomes of future Federal rulemakings with respect to coal combustion residuals (expected in December 2014), cooling water intake and wastewater effluents (expected in September 2015).  We will seek and expect to recover through our environmental rate adjustment mechanism, any operating or capital expenditures related to compliance with these NPDES permit requirements. Recovery of these costs is expected to be sought through an Indiana statute that allows for 80% recovery of qualifying costs through a rate adjustment mechanism with the remainder recorded as a regulatory asset to be considered for recovery in the next base rate case proceeding; however, there can be no assurances that we will be successful in that regard. In light of the uncertainties at this time, we cannot predict the impact of these permit requirements on our consolidated results of operations, cash flows, or financial condition, but it is expected to be material.

 

In June 2013, the EPA published proposed rules, commonly known as “Effluent Limitation Guidelines” or “ELGs,” to reduce toxic pollutants discharged into waterways by power plants. The proposed ELGs are intended to update the existing technology-based rules for controlling the discharge of pollutants from various waste streams associated with steam electric generating facilities. It is too early to determine whether the final version of the ELGs will materially impact IPL or its current or future NPDES permits. Under a consent decree, the EPA is required to finalize the ELGs by September 2015.

 

In June 2014, the EPA along with the U.S. Army Corps of Engineers issued a proposed rule defining the waters of the U.S. This rulemaking has the potential to impact all programs under the CWA. Expansion of regulated waterways is possible based on initial review of the proposal, which may impact several permitting programs. Although we cannot at this time determine the timing or impact of compliance with any new regulations, more stringent regulations could have a material impact on our operations and/or consolidated financial results.

 

Climate Change Legislation and Regulation

 

The EPA issued proposed carbon dioxide emissions rules for existing power plants on June 2, 2014. Under the proposed rule, called the Clean Power Plan, states would be judged against state-specific carbon dioxide emissions targets beginning in 2020, with an expected total U.S. power section emissions reduction of 30% from 2005 levels by 2030. For Indiana specifically, the Clean Power Plan proposes 2020-2029 interim reduction goals and proposed 2030 final reduction goals of 1,607 pounds of carbon dioxide per megawatt hour and 1,531 pounds of carbon dioxide per megawatt hour, respectively. The proposed rule requires states to submit implementation plans to meet the standards set forth in the rule by June 30, 2016, with the possibility of one or two-year extensions under certain circumstances. The proposed rule will be subject to a public comment process during the course of this year, after which time the EPA is expected to finalize it by President Obama’s June 1, 2015 deadline. Among other things, we could be required to make efficiency improvements to our existing facilities. However, it is too soon to determine what the rule, and Indiana’s corresponding state implementation plan, will require once both are finalized, whether they will survive judicial and other challenges, and if so, whether and when the rule and Indiana’s corresponding state implementation plan would materially impact our business, operations or financial condition. 

 

In addition, in October 2013, the U.S. Supreme Court granted certiorari for several cases that address the EPA’s authority to issue Greenhouse Gas (“GHG”) Prevention of Significant Deterioration (“PSD”) permits under Section 165 of the CAA. In June 2014, the U.S. Supreme Court ruled that the EPA had exceeded its statutory authority in issuing the so-called “Tailoring Rule” under Section 165 of the CAA by regulating all sources that emitted GHGs. However, the U.S. Supreme Court also held that the EPA could impose GHG Best Achievable Control Technology (“BACT”) requirements for sources already required to implement PSD for other pollutants. Therefore, if future modifications to IPL’s sources require PSD review for other pollutants, it may also trigger GHG BACT requirements. The EPA has issued guidance on what BACT entails for the control of GHG and individual states are now required to determine what controls are required for facilities within their jurisdiction on a case-by-case basis.

 

There is some uncertainty with respect to the impact of GHG rules on IPL. The Tailoring Rule will not require us to implement BACT until we construct a new major source or make a major modification of an existing major source, and the proposed New Source Performance Standards (“NSPS”) will not require us to comply with an emissions standard until we construct a new electric generating unit. The planned CCGT at Eagle Valley is expected to comply with the applicable BACT requirements under the Tailoring Rule and the proposed NSPS limit. We do not have any other major modifications of an existing source or plans to construct a new major source at this time. In light of these uncertainties, we cannot predict the impact of the EPA’s current and future GHG regulations on our consolidated results of operations, cash flows, or financial condition, but they could be material.

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Cross-State Air Pollution Rule

 

In April 2014, the U.S. Supreme Court reversed a 2012 decision by the D.C. Circuit Court that had vacated the Cross-State Pollution Rule (“CSAPR”) and remanded the case back to the D.C. Circuit Court for further proceedings consistent with the U.S. Supreme Court decision. In June 2014, the U.S. Department of Justice, on behalf of the EPA, filed a motion with the D.C. Circuit Court to lift the current stay on CSAPR. Assuming CSAPR is reinstated, the EPA is expected to establish new effective dates for compliance with the required reduced emissions levels. We are unable to determine the full impact of the reinstatement of CSAPR until the D.C. Circuit Court and the EPA take further action. The timeline for further proceedings is currently unknown; however, we believe the rule may have a material impact on IPL.

 

Coal Combustion Byproducts

 

In the course of operating our coal-fired generating facilities, we produce coal combustion byproducts (“CCB”), including fly ash and bottom ash. In 2010, the EPA proposed a rule to regulate CCB, which we believe might require additional CCB handling, processing and storage equipment, or both. The EPA has agreed to issue a final rule by December 2014. While we cannot at this time estimate the impact and costs associated with future regulations of CCB, we believe the impact on our operations and consolidated financial results could be material.

 

Cooling Water Intake Regulations

 

We use water as a coolant at our generating facilities. Under the CWA, cooling water intake structures are required to reflect the Best Technology Available (“BTA”) for minimizing adverse environmental impact. On May 19, 2014, the EPA announced its final standards to protect fish and other aquatic organisms drawn into cooling water systems at large power plants and other industrial facilities. The standards, based on Section 316(b) of the CWA, require subject facilities to choose amongst seven BTA options to reduce fish impingement. In addition, facilities that withdraw water from a source water body above a minimum volume and utilize at least 25% of the withdrawn water for cooling purposes must conduct studies to assist permitting authorities to determine whether and what site-specific controls, if any, would be required to reduce entrainment of aquatic organisms. This decision process would include public input as part of permit renewal or permit modification. It is possible this process could result in the need to install closed-cycle cooling systems (closed-cycle cooling towers), or other technology. Finally, the standards require that new units added to an existing facility are required to reduce both impingement and entrainment that achieves one of two alternatives under national BTA standards for entrainment. It is not yet possible to predict the total impacts of this recent final rule at this time, including any challenges to such final rule and the outcome of any such challenges. However, if additional capital expenditures are necessary, they could be material. We would seek recovery of these capital expenditures; however, there is no guarantee we would be successful in that regard.

 

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK 

 

Not applicable pursuant to General Instruction H of the Form 10-Q.

 

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ITEM 4. CONTROLS AND PROCEDURES

 

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in the reports that we file or submit under the Securities Exchange Act of 1934, is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms, and that such information is accumulated and communicated to the principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosures.

 

Evaluation of Disclosure Controls and Procedures

 

We carried out an evaluation, under the supervision and with the participation of our management, including the principal executive officer and principal financial officer, of the effectiveness of our “disclosure controls and procedures” (as defined in the Exchange Act Rules 13a-15(e) and 15-d-15(e)), as required by paragraph (b) of the Exchange Act Rules 13a-15 or 15d-15, as of June 30, 2014. Our management, including the principal executive officer and principal financial officer, is engaged in a comprehensive effort to review, evaluate and improve our controls; however, management does not expect that our disclosure controls or our internal controls over financial reporting will prevent all errors and all fraud. A control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the control system’s objectives will be met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. In addition, any evaluation of the effectiveness of controls is subject to risks that those internal controls may become inadequate in future periods because of changes in business conditions, or that the degree of compliance with the policies or procedures deteriorates. We have interests in certain unconsolidated entities. As we do not control or manage these entities, our disclosure controls and procedures with respect to such entities is generally more limited than those we maintain with respect to our consolidated subsidiaries. 

 

Based upon the controls evaluation performed, the principal executive officer and principal financial officer have concluded that as of June 30, 2014, our disclosure controls and procedures were effective to provide reasonable assurance that material information relating to us and our consolidated subsidiaries is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms and that such information is accumulated and communicated to the principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosures.

 

Changes in Internal Controls

 

In the course of our evaluation of disclosure controls and procedures, management considered certain internal control areas in which we have made and are continuing to make changes to improve and enhance controls. Based upon that evaluation, the principal executive officer and principal financial officer concluded that there were no changes in our internal controls over financial reporting identified in connection with the evaluation required by paragraph (d) of the Exchange Act Rules 13a-15 or 15d-15 that occurred during the six months ended June  30, 2014 that have materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.  

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PART II – Other Information

 

ITEM 1. Legal proceedings

 

Please see Note 6, “Commitments and Contingencies” to the Financial Statements for a summary of significant legal proceedings involving us. We are also subject to routine litigation, claims and administrative proceedings arising in the ordinary course of business, none of which we believe, based on currently available information, will result in a material adverse effect on our results of operations, financial condition, or cash flows. 

 

ITEM 1a.  risk factors

 

There have been no material changes to the risk factors as previously disclosed in the 2013 Form 10-K. 

 

ITEM 2. unregistered sales of equity securities and use of proceeds

 

Not applicable pursuant to General Instruction H of the Form 10-Q.

 

Item 3. defaults upon senior securities

 

Not applicable pursuant to General Instruction H of the Form 10-Q. 

 

ITEM 4.  MINE SAFETY DISCLOSURES

 

Not applicable.

 

ITEM 5.  Other information

 

None.

 

ITEM 6. EXHIBITS

 

 

 

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SIGNATURES

 

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

 

IPALCO ENTERPRISES, INC.

(Registrant)

 

 

Date: August 6, 2014/s/ Craig L. Jackson

Craig L. Jackson

Chief Financial Officer

(Principal Financial Officer) 

 

 

Date: August 6, 2014/s/ Kurt A. Tornquist

Kurt A. Tornquist

Controller

(Principal Accounting Officer) 

 

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Exhibit 31.1

 

Certification Pursuant to Rule 13a-14(a) or 15d-14(a) of the Securities Exchange Act of 1934

 

 

I, Kenneth J. Zagzebski, certify that:

 

 

 

Date: August 6, 2014/s/ Kenneth J. Zagzebski

Kenneth J. Zagzebski

Chief Executive Officer

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Exhibit 31.2

 

Certification Pursuant to Rule 13a-14(a) or 15d-14(a) of the Securities Exchange Act of 1934

 

 

I, Craig L. Jackson, certify that:

 

 

 

Date: August 6, 2014/s/ Craig L. Jackson

Craig L. Jackson

Chief Financial Officer

 

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Exhibit 32

 

Certification Pursuant to Rule 13a-14(b) or 15d-14(b) of the Securities Exchange Act of 1934 and Pursuant to Section 1350 of Chapter 63 of Title 18 of the United States Code as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

 

The certification set forth below is being submitted in connection with the Quarterly Report on Form 10-Q for the period ended June  30, 2014 (the “Report”) for the purpose of complying with Rule 13a-14(b) or Rule 15d-14(b) of the Securities Exchange Act of 1934 and Section 1350 of Chapter 63 of Title 18 of the United States Code.

 

Kenneth J. Zagzebski, Chief Executive Officer and Craig L. Jackson, Chief Financial Officer of IPALCO Enterprises, Inc. (“IPALCO”), each certifies that, to the best of his knowledge:

 

 

Date: August 6, 2014                                                                   /s/ Kenneth J. Zagzebski

Kenneth J. Zagzebski

Chief Executive Officer

 

 

 

Date: August 6, 2014                                                                   /s/ Craig L. Jackson      

Craig L. Jackson

Chief Financial Officer

 

A signed original of this written statement required by Section 906 has been provided to IPALCO and will be retained by IPALCO and furnished to the Securities and Exchange Commission or its staff upon request.

 

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