UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
________________
Form 10-K
(Mark One) | |
þ | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
FOR THE FISCAL YEAR ENDED DECEMBER 31, 2015 | |
OR | |
¨ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
FOR THE TRANSITION PERIOD FROM TO | |
Commission file number 1-3187
______________________________
CenterPoint Energy Houston Electric, LLC
(Exact name of registrant as specified in its charter)
Texas | 22-3865106 |
(State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) |
1111 Louisiana | |
Houston, Texas 77002 | (713) 207-1111 |
(Address and zip code of principal executive offices) | (Registrant’s telephone number, including area code) |
Securities registered pursuant to Section 12(b) of the Act:
Title of each class | Name of each exchange on which registered |
9.15% First Mortgage Bonds due 2021 | New York Stock Exchange |
6.95% General Mortgage Bonds due 2033 | New York Stock Exchange |
Securities registered pursuant to Section 12(g) of the Act:
None
CenterPoint Energy Houston Electric, LLC meets the conditions set forth in general instruction I(1)(a) and (b) of Form 10-K and is therefore filing this Form 10-K with the reduced disclosure format.
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes o No þ
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes o No þ
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 þ No o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein and will not be contained, to the best of the registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. þ
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 definitions of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):
Large accelerated filer o | Accelerated filer o | Non-accelerated filer þ | Smaller reporting company o |
(Do not check if a smaller reporting company) | |||
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ
The aggregate market value of the common equity held by non-affiliates as of June 30, 2015: None
TABLE OF CONTENTS
PART I | ||
Page | ||
Item 1. | ||
Item 1A. | ||
Item 1B. | ||
Item 2. | ||
Item 3. | ||
Item 4. | Mine Safety Disclosures | |
PART II | ||
Item 5. | ||
Item 6. | ||
Item 7. | ||
Item 7A. | ||
Item 8. | ||
Item 9. | ||
Item 9A. | ||
Item 9B. | ||
PART III | ||
Item 10. | ||
Item 11. | ||
Item 12. | ||
Item 13. | ||
Item 14. | ||
PART IV | ||
Item 15. | ||
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We meet the conditions specified in General Instruction I (1)(a) and (b) of Form 10-K and are thereby permitted to use the reduced disclosure format for wholly-owned subsidiaries of reporting companies specified therein. Accordingly, we have omitted from this report the information called for by Item 10 (Directors, Executive Officers and Corporate Governance), Item 11 (Executive Compensation), Item 12 (Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters) and Item 13 (Certain Relationships and Related Transactions, and Director Independence) of Form 10-K. In lieu of the information called for by Item 6 (Selected Financial Data) and Item 7 (Management’s Discussion and Analysis of Financial Condition and Results of Operations) of Form 10-K, we have included, under Item 7, Management’s Narrative Analysis of Results of Operations to explain the reasons for material changes in the amount of revenue and expense items between 2015, 2014 and 2013.
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION
From time to time we make statements concerning our expectations, beliefs, plans, objectives, goals, strategies, future events or performance and underlying assumptions and other statements that are not historical facts. These statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. Actual results may differ materially from those expressed or implied by these statements. You can generally identify our forward-looking statements by the words “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “goal,” “intend,” “may,” “objective,” “plan,” “potential,” “predict,” “projection,” “should,” “will” or other similar words.
We have based our forward-looking statements on our management’s beliefs and assumptions based on information reasonably available to our management at the time the statements are made. We caution you that assumptions, beliefs, expectations, intentions and projections about future events may and often do vary materially from actual results. Therefore, we cannot assure you that actual results will not differ materially from those expressed or implied by our forward-looking statements.
Some of the factors that could cause actual results to differ from those expressed or implied by our forward-looking statements are described under “Risk Factors” in Item 1A and “Management’s Narrative Analysis of Results of Operations — Certain Factors Affecting Future Earnings” in Item 7 of this report, which discussions are incorporated herein by reference.
You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement, and we undertake no obligation to update or revise any forward-looking statements.
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PART I
Item 1. | Business |
OUR BUSINESS
Overview
We provide electric transmission and distribution services to retail electric providers (REPs) serving over 2.3 million metered customers in the Texas Gulf Coast area that includes the city of Houston. In this report, unless the content indicates otherwise, references to “CenterPoint Houston,” “we,” “us” or similar terms mean CenterPoint Energy Houston Electric, LLC and its subsidiaries. We are an indirect, wholly-owned subsidiary of CenterPoint Energy, Inc. (CenterPoint Energy), a public utility holding company. We have only one reportable business segment: Electric Transmission & Distribution.
Our principal executive offices are located at 1111 Louisiana, Houston, Texas 77002 (telephone number: 713-207-1111).
We make available free of charge on our parent company’s Internet website our annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 as soon as reasonably practicable after we electronically file such reports with, or furnish them to, the Securities and Exchange Commission (SEC). Our parent company’s website address is www.centerpointenergy.com. Except to the extent explicitly stated herein, documents and information on our parent company’s website are not incorporated by reference herein.
Electric Transmission & Distribution
We are a transmission and distribution electric utility that operates wholly within the state of Texas. Neither we nor any other subsidiary of CenterPoint Energy makes direct retail or wholesale sales of electric energy or owns or operates any electric generating facilities.
Electric Transmission
On behalf of REPs, we deliver electricity from power plants to substations, from one substation to another and to retail electric customers taking power at or above 69 kilovolts (kV) in locations throughout our certificated service territory. We construct and maintain transmission facilities and provide transmission services under tariffs approved by the Public Utility Commission of Texas (Texas Utility Commission).
Electric Distribution
In the Electric Reliability Council of Texas, Inc. (ERCOT), end users purchase their electricity directly from certificated REPs. We deliver electricity for REPs in our certificated service area by carrying lower-voltage power from the substation to the retail electric customer. Our distribution network receives electricity from the transmission grid through power distribution substations and delivers electricity to end users through distribution feeders. Our operations include construction and maintenance of distribution facilities, metering services, outage response services and call center operations. We provide distribution services under tariffs approved by the Texas Utility Commission. Texas Utility Commission rules and market protocols govern the commercial operations of distribution companies and other market participants. Rates for these existing services are established pursuant to rate proceedings conducted before municipalities that have original jurisdiction and the Texas Utility Commission.
ERCOT Market Framework
We are a member of ERCOT. Within ERCOT, prices for wholesale generation and retail electric sales are unregulated, but services provided by transmission and distribution companies are regulated by the Texas Utility Commission. ERCOT serves as the regional reliability coordinating council for member electric power systems in most of Texas. ERCOT membership is open to consumer groups, investor and municipally-owned electric utilities, rural electric cooperatives, independent generators, power marketers, river authorities and REPs. The ERCOT market includes most of the State of Texas, other than a portion of the panhandle, portions of the eastern part of the state bordering Arkansas and Louisiana and the area in and around El Paso. The ERCOT market represents approximately 90% of the demand for power in Texas and is one of the nation’s largest power markets. The ERCOT market included available generating capacity of over 77,000 megawatts (MW) as of December 31, 2015. Currently, there are only limited direct current interconnections between the ERCOT market and other power markets in the United States and Mexico.
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The ERCOT market operates under the reliability standards set by the North American Electric Reliability Corporation (NERC) and approved by the Federal Energy Regulatory Commission (FERC). Within ERCOT, these reliability standards are administered by the Texas Reliability Entity (TRE). The Texas Utility Commission has primary jurisdiction over the ERCOT market to ensure the adequacy and reliability of electricity supply across the state’s main interconnected power transmission grid. The ERCOT independent system operator (ERCOT ISO) is responsible for operating the bulk electric power supply system in the ERCOT market. Its responsibilities include ensuring that electricity production and delivery are accurately accounted for among the generation resources and wholesale buyers and sellers.
Our electric transmission business, along with those of other owners of transmission facilities in Texas, supports the operation of the ERCOT ISO. Our transmission business has planning, design, construction, operation and maintenance responsibility for the portion of the transmission grid and for the load-serving substations it owns, primarily within its certificated area. We participate with the ERCOT ISO and other ERCOT utilities to plan, design, obtain regulatory approval for and construct new transmission lines necessary to increase bulk power transfer capability and to remove existing constraints on the ERCOT transmission grid.
Restructuring of the Texas Electric Market
In 1999, the Texas legislature adopted the Texas Electric Choice Plan (Texas electric restructuring law). Pursuant to that legislation, integrated electric utilities operating within ERCOT were required to unbundle their integrated operations into separate retail sales, power generation and transmission and distribution companies. The legislation provided for a transition period to move to the new market structure and provided a mechanism for the formerly integrated electric utilities to recover stranded and certain other costs resulting from the transition to competition. Those costs were recoverable after approval by the Texas Utility Commission either through the issuance of securitization bonds or through the implementation of a competition transition charge as a rider to the utility’s tariff. Our integrated utility business was restructured in accordance with the Texas electric restructuring law and its generating stations were sold to third parties. Ultimately we were authorized to recover a total of approximately $5 billion in stranded costs, other charges and related interest. Most of that amount was recovered through the issuance of transition bonds by our special purpose subsidiaries. The transition bonds are repaid through charges imposed on customers in our service territory. As of December 31, 2015, approximately $2.3 billion aggregate principal amount of transition bonds were outstanding.
Customers
We serve nearly all of the Houston/Galveston metropolitan area. At December 31, 2015, our customers consisted of approximately 69 REPs, which sell electricity to over 2.3 million metered customers in our certificated service area, and municipalities, electric cooperatives and other distribution companies located outside our certificated service area. Each REP is licensed by, and must meet minimum creditworthiness criteria established by, the Texas Utility Commission.
Sales to REPs that are affiliates of NRG Energy, Inc. (NRG) represented approximately 35%, 37% and 38% of our transmission and distribution revenues in 2015, 2014 and 2013, respectively. Sales to REPs that are affiliates of Energy Future Holdings Corp. (Energy Future Holdings) represented approximately 10% of our transmission and distribution revenues in each of 2015, 2014 and 2013. Our aggregate billed receivables balance from REPs as of December 31, 2015 was $195 million. Approximately 34% and 11% of this amount was owed by affiliates of NRG and Energy Future Holdings, respectively. We do not have long-term contracts with any of our customers. We operate using a continuous billing cycle, with meter readings being conducted and invoices being distributed to REPs each business day.
Advanced Metering System and Distribution Grid Automation (Intelligent Grid)
In May 2012, we substantially completed the deployment of an advanced metering system (AMS), having installed approximately 2.2 million smart meters. To recover the cost of the AMS, the Texas Utility Commission approved a monthly surcharge payable by REPs, initially over 12 years and later reduced to six years as a result of U.S. Department of Energy (DOE) grant funds. The surcharge expired in 2015 for residential customers and is set to expire in 2016 to 2017 for non-residential customers. The surcharge amounts and duration are subject to adjustment in future proceedings to reflect actual costs incurred and to address required changes in scope.
We are also pursuing deployment of an electric distribution grid automation strategy that involves the implementation of an “Intelligent Grid” (IG) which would provide on-demand data and information about the status of facilities on our system. We expect to include the costs of the deployment in future rate proceedings before the Texas Utility Commission.
In October 2009, the DOE selected us for a $200 million grant to help fund our AMS and IG projects. We received substantially all of the $200 million of grant funding from the DOE by 2011 and used $150 million of it to accelerate completion of our deployment
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of advanced meters to 2012. We used the other $50 million from the grant for an initial deployment of an IG that covers approximately 12% of our service territory. The DOE-funded portion of the IG project was substantially completed in 2015, and the capital portion of the IG project subject to partial funding by the DOE cost approximately $140 million.
Competition
There are no other electric transmission and distribution utilities in our service area. In order for another provider of transmission and distribution services to provide such services in our territory, it would be required to obtain a certificate of convenience and necessity from the Texas Utility Commission and, depending on the location of the facilities, may also be required to obtain franchises from one or more municipalities. We know of no other party intending to enter this business in our service area at this time. Distributed generation (i.e., power generation located at or near the point of consumption) could result in a reduction of demand for our electric distribution services but has not been a significant factor to date.
Seasonality
A significant portion of our revenues is derived from rates that we collect from each REP based on the amount of electricity we deliver on behalf of such REP. Thus, our revenues and results of operations are subject to seasonality, weather conditions and other changes in electricity usage, with revenues generally being higher during the warmer months.
Properties
All of our properties are located in Texas. Our properties consist primarily of high-voltage electric transmission lines and poles, distribution lines, substations, service centers, service wires and meters. Most of our transmission and distribution lines have been constructed over lands of others pursuant to easements or along public highways and streets under franchise agreements and as permitted by law.
All of our real and tangible properties, subject to certain exclusions, are currently subject to:
• | the lien of a Mortgage and Deed of Trust (the Mortgage) dated November 1, 1944, as supplemented; and |
• | the lien of a General Mortgage (the General Mortgage) dated October 10, 2002, as supplemented, which is junior to the lien of the Mortgage. |
As of December 31, 2015, we had approximately $2.1 billion aggregate principal amount of general mortgage bonds outstanding under the General Mortgage, including $118 million held in trust to secure pollution control bonds for which CenterPoint Energy is obligated and approximately $56 million held in trust to secure pollution control bonds for which we are obligated. Additionally, as of December 31, 2015, we had approximately $102 million aggregate principal amount of first mortgage bonds outstanding under the Mortgage. We may issue additional general mortgage bonds on the basis of retired bonds, 70% of property additions or cash deposited with the trustee. Approximately $4.2 billion of additional general mortgage bonds in the aggregate could be issued on the basis of retired bonds and 70% of property additions as of December 31, 2015. We have contractually agreed that we will not issue additional first mortgage bonds, subject to certain exceptions.
Electric Lines — Overhead. As of December 31, 2015, we owned 28,474 pole miles of overhead distribution lines and 3,723 circuit miles of overhead transmission lines, including 325 circuit miles operated at 69,000 volts, 2,181 circuit miles operated at 138,000 volts and 1,217 circuit miles operated at 345,000 volts.
Electric Lines — Underground. As of December 31, 2015, we owned 23,120 circuit miles of underground distribution lines and 26 circuit miles of underground transmission lines, including two circuit miles operated at 69,000 volts and 24 circuit miles operated at 138,000 volts.
Substations. As of December 31, 2015, we owned 232 major substation sites having a total installed rated transformer capacity of 58,674 megavolt amperes.
Service Centers. We operate 14 regional service centers located on a total of 292 acres of land. These service centers consist of office buildings, warehouses and repair facilities that are used in the business of transmitting and distributing electricity.
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Franchises
We hold non-exclusive franchises from the incorporated municipalities in our service territory. In exchange for the payment of fees, these franchises give us the right to use the streets and public rights-of-way of these municipalities to construct, operate and maintain our transmission and distribution system and to use that system to conduct our electric delivery business and for other purposes that the franchises permit. The terms of the franchises, with various expiration dates, typically range from 20 to 40 years.
REGULATION
We are subject to regulation by various federal, state and local governmental agencies, including the regulations described below.
Federal Energy Regulatory Commission
We are not a “public utility” under the Federal Power Act and, therefore, are not generally regulated by the FERC, although certain of our transactions are subject to limited FERC jurisdiction. The FERC has certain responsibilities with respect to ensuring the reliability of electric transmission service, including transmission facilities owned by us and other utilities within ERCOT. The FERC has designated the NERC as the Electric Reliability Organization (ERO) to promulgate standards, under FERC oversight, for all owners, operators and users of the bulk power system (Electric Entities). The ERO and the FERC have authority to (a) impose fines and other sanctions on Electric Entities that fail to comply with approved standards and (b) audit compliance with approved standards. The FERC has approved the delegation by the NERC of authority for reliability in ERCOT to the TRE. We do not anticipate that the reliability standards proposed by the NERC and approved by the FERC will have a material adverse impact on our operations. To the extent that we are required to make additional expenditures to comply with these standards, it is anticipated that we will seek to recover those costs through the transmission charges that are imposed on all distribution service providers within ERCOT for electric transmission provided.
As a public utility holding company, under the Public Utility Holding Company Act of 2005, CenterPoint Energy and its subsidiaries, including us, are subject to reporting and accounting requirements and are required to maintain certain books and records and make them available for review by the FERC and state regulatory authorities in certain circumstances.
State and Local Regulation
We conduct our operations pursuant to a certificate of convenience and necessity issued by the Texas Utility Commission that covers our present service area and facilities. The Texas Utility Commission and certain municipalities have the authority to set the rates and terms of service provided by us under cost-of-service rate regulation. We hold non-exclusive franchises from certain incorporated municipalities in our service territory. In exchange for payment of fees, these franchises give us the right to use the streets and public rights-of-way of these municipalities to construct, operate and maintain our transmission and distribution system and to use that system to conduct our electric delivery business and for other purposes that the franchises permit. The terms of the franchises, with various expiration dates, typically range from 20 to 40 years.
Our distribution rates charged to REPs for residential customers are primarily based on amounts of energy delivered, whereas distribution rates for a majority of commercial and industrial customers are primarily based on peak demand. All REPs in our service area pay the same rates and other charges for transmission and distribution services. This regulated delivery charge includes the transmission and distribution rate (which includes municipal franchise fees), a distribution recovery mechanism for recovery of incremental distribution invested capital above that which is already reflected in the base distribution rate, a nuclear decommissioning charge associated with decommissioning the South Texas nuclear generating facility, an energy efficiency cost recovery charge, a surcharge related to the implementation of AMS and charges associated with securitization of regulatory assets, stranded costs and restoration costs relating to Hurricane Ike. Transmission rates charged to distribution companies are based on amounts of energy transmitted under “postage stamp” rates that do not vary with the distance the energy is being transmitted. All distribution companies in ERCOT pay us the same rates and other charges for transmission services.
For a discussion of certain of our ongoing regulatory proceedings, see “Management’s Narrative Analysis of Results of Operations — Liquidity and Capital Resources — Regulatory Matters” in Item 7 of this report, which discussion is incorporated herein by reference.
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ENVIRONMENTAL MATTERS
Our operations are subject to stringent and complex laws and regulations pertaining to the environment. As an owner or operator of electric transmission and distribution systems, and the facilities that support these systems, we must comply with these laws and regulations at the federal, state and local levels. These laws and regulations can restrict or impact our business activities in many ways, such as:
• | restricting the way we can handle or dispose of wastes; |
• | limiting or prohibiting construction activities in sensitive areas such as wetlands, coastal regions or areas inhabited by endangered species; |
• | requiring remedial action to mitigate environmental conditions caused by our operations or attributable to former operations; and |
• | enjoining the operations of facilities with permits issued pursuant to such environmental laws and regulations. |
In order to comply with these requirements, we may need to spend substantial amounts and devote other resources from time to time to, among other activities:
• | construct or acquire new facilities and equipment; |
• | acquire permits for facility operations; |
• | modify, upgrade or replace existing and proposed equipment; and |
• | clean or decommission waste disposal areas, fuel storage and management facilities and other locations and facilities. |
Failure to comply with these laws and regulations may trigger a variety of administrative, civil and criminal enforcement measures, including the assessment of monetary penalties, the imposition of remedial actions and the issuance of orders enjoining future operations. Certain environmental statutes impose strict, joint and several liability for costs required to clean up and restore sites where hazardous substances have been stored, disposed or released. Moreover, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of hazardous substances or other waste products into the environment.
The recent trend in environmental regulation has been to place more restrictions and limitations on activities that may affect the environment. There can be no assurance as to the amount or timing of future expenditures for environmental compliance or remediation, and actual future expenditures may be different from the amounts we currently anticipate. We try to anticipate future regulatory requirements that might be imposed and plan accordingly to maintain compliance with changing environmental laws and regulations and to ensure the costs of such compliance are reasonable.
Based on current regulatory requirements and interpretations, we do not believe that compliance with federal, state or local environmental laws and regulations will have a material adverse effect on our business, financial position, results of operations or cash flows. In addition, we believe that our current environmental remediation activities will not materially interrupt or diminish our operational ability. We cannot assure you that future events, such as changes in existing laws, the promulgation of new laws, or the development or discovery of new facts or conditions will not cause us to incur significant costs. The following is a discussion of material current environmental and safety laws and regulations that relate to our operations. We believe that we are in substantial compliance with these environmental laws and regulations.
Global Climate Change
There is increasing attention being paid in the United States and worldwide to the issue of climate change. As a result, from time to time, regulatory agencies have considered the modification of existing laws or regulations or the adoption of new laws or regulations addressing the emissions of greenhouse gases (GHG) on the state, federal, or international level. Some of the proposals would require industrial sources to meet stringent new standards that would require substantial reductions in GHG emissions. We, in contrast to some electric utilities, do not generate electricity and thus are not directly exposed to the risk of high capital costs and regulatory uncertainties that face electric utilities that burn fossil fuels to generate electricity. Nevertheless, our revenues could be adversely affected to the extent any resulting regulatory action has the effect of reducing consumption of electricity by ultimate consumers
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within our service territory. Likewise, incentives to conserve energy or use other energy sources could result in a decrease in demand for our services. At this point in time, however, it would be speculative to try to quantify the magnitude of the impacts from possible new regulatory actions related to GHG emissions, either positive or negative, on our business.
To the extent climate changes occur, our business may be adversely impacted, though we believe any such impacts are likely to occur very gradually and hence would be difficult to quantify. Warmer temperatures in our service territory may increase our revenues from transmission and distribution through increased demand for electricity for cooling. Another possible effect of climate change is more frequent and more severe weather events, such as hurricanes or tornadoes. Since many of our facilities are located along or near the Gulf Coast, increased or more severe hurricanes or tornadoes could increase our costs to repair damaged facilities and restore service to our customers. When we cannot deliver electricity to customers, or our customers cannot receive our services, our financial results can be impacted by lost revenues, and we generally must seek approval from regulators to recover restoration costs. To the extent we are unable to recover those costs, or if higher rates resulting from our recovery of such costs result in reduced demand for our services, our future financial results may be adversely impacted.
Air Emissions
Our operations are subject to the federal Clean Air Act and comparable state laws and regulations. These laws and regulations regulate emissions of air pollutants from various industrial sources and also impose various monitoring and reporting requirements. Such laws and regulations may require pre-approval for the construction or modification of certain projects or facilities expected to produce air emissions or result in the increase of existing air emissions. We may be required to obtain and strictly comply with air permits containing various emissions and operational limitations, or utilize specific emission control technologies to limit emissions. Failure to comply with these requirements could result in monetary penalties, injunctions, conditions or restrictions on operations, and potentially criminal enforcement actions. We may be required to incur certain capital expenditures in the future for air pollution control equipment in connection with obtaining and maintaining operating permits and approvals for air emissions. Under the National Emission Standards for Hazardous Air Pollutants, the Environmental Protection Agency (EPA) established maximum achievable control technology for stationary internal combustion engines (sometimes referred to as the RICE MACT rule). Back up electrical generators we use are substantially compliant with these laws and regulations.
Water Discharges
Our operations are subject to the Federal Water Pollution Control Act of 1972, as amended, also known as the Clean Water Act, and analogous state laws and regulations. These laws and regulations impose detailed requirements and strict controls regarding the discharge of pollutants into waters of the United States. The unpermitted discharge of pollutants, including discharges resulting from a spill or leak incident, is prohibited. The Clean Water Act and regulations implemented thereunder also prohibit discharges of dredged and fill material in wetlands and other waters of the United States unless authorized by an appropriately issued permit. Any unpermitted release of petroleum or other pollutants from our facilities could result in fines or penalties as well as significant remedial obligations.
Hazardous Waste
Our operations generate wastes, including some hazardous wastes, that are subject to the federal Resource Conservation and Recovery Act (RCRA), and comparable state laws, which impose detailed requirements for the handling, storage, treatment, transport and disposal of hazardous and solid waste. Ordinary industrial wastes such as paint wastes, waste solvents and laboratory wastes may be regulated as hazardous waste.
Liability for Remediation
The Comprehensive Environmental Response, Compensation and Liability Act of 1980, as amended (CERCLA), also known as “Superfund,” and comparable state laws impose liability, without regard to fault or the legality of the original conduct, on certain classes of persons responsible for the release of hazardous substances into the environment. Such classes of persons include the current and past owners or operators of sites where a hazardous substance was released and companies that disposed or arranged for the disposal of hazardous substances at offsite locations such as landfills. In the course of our ordinary operations we generate wastes that may fall within the definition of a “hazardous substance.” CERCLA authorizes the EPA and, in some cases, third parties to take action in response to threats to the public health or the environment and to seek to recover from the responsible classes of persons the costs they incur. Under CERCLA, we could be subject to joint and several liability for the costs of cleaning up and restoring sites where hazardous substances have been released, for damages to natural resources, and for the costs of certain health studies.
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Liability for Preexisting Conditions
Asbestos. Some facilities owned by CenterPoint Energy contain or have contained asbestos insulation and other asbestos-containing materials. CenterPoint Energy or its subsidiaries, including us, have been named, along with numerous others, as a defendant in lawsuits filed by a number of individuals who claim injury due to exposure to asbestos. Some of the claimants have worked at locations owned by CenterPoint Energy or us, but most existing claims relate to facilities previously owned by CenterPoint Energy’s other subsidiaries or us. In 2004, CenterPoint Energy sold its generating business, to which most of these claims relate, to a company which is now an affiliate of NRG. Under the terms of the arrangements regarding separation of the generating business from CenterPoint Energy and its sale of that business, ultimate financial responsibility for uninsured losses from claims relating to the generating business has been assumed by the NRG affiliate, but CenterPoint Energy has agreed to continue to defend such claims to the extent they are covered by insurance maintained by CenterPoint Energy, subject to reimbursement of the costs of such defense by the NRG affiliate. CenterPoint Energy anticipates that additional claims like those received may be asserted in the future. Although their ultimate outcome cannot be predicted at this time, we or CenterPoint Energy, as appropriate, intend to continue vigorously contesting claims that we do not consider to have merit and we do not expect, based on our experience to date, these matters, either individually or in the aggregate, to have a material adverse effect on our financial condition, results of operations or cash flows.
Other Environmental. From time to time we identify the presence of environmental contaminants on property where we conduct or have conducted operations. Other such sites involving contaminants may be identified in the future. We have remediated and expect to continue to remediate identified sites consistent with our legal obligations. From time to time we have received notices from regulatory authorities or others regarding our status as a potentially responsible party in connection with sites found to require remediation due to the presence of environmental contaminants. In addition, we have been named from time to time as a defendant in litigation related to such sites. Although the ultimate outcome of such matters cannot be predicted at this time, we do not expect, based on our experience to date, these matters, either individually or in the aggregate, to have a material adverse effect on our financial condition, results of operations or cash flows.
EMPLOYEES
As of December 31, 2015, we had 2,665 full-time employees, of which approximately 51% were covered by collective bargaining agreements. The collective bargaining agreement with the International Brotherhood of Electrical Workers Local 66 is scheduled to expire in May of 2016. We believe we have a good relationship with this bargaining unit and expect to negotiate a new agreement in 2016.
Item 1A. | Risk Factors |
The following, along with any additional legal proceedings identified or incorporated by reference in Item 3 of this report, summarizes the principal risk factors associated with our business.
Risk Factors Associated with Our Consolidated Financial Condition
We are an indirect, wholly-owned subsidiary of CenterPoint Energy. CenterPoint Energy can exercise substantial control over our dividend policy and business and operations and could do so in a manner that is adverse to our interests.
We are managed by officers and employees of CenterPoint Energy. Our management will make determinations with respect to the following:
• | our payment of dividends; |
• | our financings and our capital raising activities; |
• | mergers or other business combinations; and |
• | our acquisition or disposition of assets. |
Other than the financial covenant contained in our credit facility (described under “Liquidity and Capital Resources” in Item 7 of this report), which could have the practical effect of limiting the payment of dividends under certain circumstances, there are no contractual restrictions on our ability to pay dividends to CenterPoint Energy. Our management could decide to increase our dividends to CenterPoint Energy to support its cash needs. This could adversely affect our liquidity. However, under our credit facility, our
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ability to pay dividends is restricted by a covenant that debt, excluding transition and system restoration bonds, as a percentage of total capitalization may not exceed 65%.
If we are unable to arrange future financings on acceptable terms, our ability to refinance existing indebtedness could be limited.
As of December 31, 2015, we had $4.9 billion of outstanding indebtedness on a consolidated basis, which includes $2.7 billion of non-recourse transition and system restoration bonds. As of December 31, 2015, principal repayments through 2018 are limited to scheduled principal repayments on transition and system restoration bonds of approximately $1.2 billion, for which dedicated revenue streams exist. Our future financing activities may be significantly affected by, among other things:
• | general economic and capital market conditions; |
• | credit availability from financial institutions and other lenders; |
• | investor confidence in us and CenterPoint Energy and the markets in which we operate; |
• | maintenance of acceptable credit ratings by us and CenterPoint Energy; |
• | market expectations regarding our and CenterPoint Energy’s future earnings and cash flows; |
• | market perceptions of our and CenterPoint Energy’s ability to access capital markets on reasonable terms; |
• | our exposure to GenOn Energy, Inc. (GenOn) (formerly known as RRI Energy, Inc., Reliant Energy, Inc. and Reliant Resources, Inc. (RRI)), a wholly-owned subsidiary of NRG, in connection with certain indemnification obligations; and |
• | provisions of relevant tax and securities laws. |
As of December 31, 2015, we had approximately $2.1 billion aggregate principal amount of general mortgage bonds outstanding under the General Mortgage, including $118 million held in trust to secure pollution control bonds for which CenterPoint Energy is obligated and approximately $56 million held in trust to secure pollution control bonds for which we are obligated. Additionally, as of December 31, 2015, we had approximately $102 million aggregate principal amount of first mortgage bonds outstanding under the Mortgage. We may issue additional general mortgage bonds on the basis of retired bonds, 70% of property additions or cash deposited with the trustee. Approximately $4.2 billion of additional general mortgage bonds in the aggregate could be issued on the basis of retired bonds and 70% of property additions as of December 31, 2015. We have contractually agreed that we will not issue additional first mortgage bonds, subject to certain exceptions.
Our current credit ratings are discussed in “Management’s Narrative Analysis of Results of Operations — Liquidity and Capital Resources — Impact on Liquidity of a Downgrade in Credit Ratings” in Item 7 of this report. These credit ratings may not remain in effect for any given period of time and one or more of these ratings may be lowered or withdrawn entirely by a rating agency. We note that these credit ratings are not recommendations to buy, sell or hold our securities. Each rating should be evaluated independently of any other rating. Any future reduction or withdrawal of one or more of our credit ratings could have a material adverse impact on our ability to access capital on acceptable terms.
The creditworthiness and liquidity of our parent company and our affiliates could affect our creditworthiness and liquidity.
Our credit ratings and liquidity may be impacted by the creditworthiness and liquidity of our parent company and our affiliates. As of December 31, 2015, CenterPoint Energy and its subsidiaries other than us have approximately $1.5 billion principal amount of debt required to be paid through 2018. If CenterPoint Energy were to experience a deterioration in its creditworthiness or liquidity, our creditworthiness and liquidity could be adversely affected. In addition, CenterPoint Energy or its other subsidiaries or affiliates may from time to time acquire or dispose of assets or businesses or enter into joint ventures or other transactions that could adversely impact the credit capacity, credit ratings or liquidity of CenterPoint Energy or its other subsidiaries or affiliates, which, as a result, could adversely impact our credit ratings and liquidity. Also, from time to time we and other affiliates invest in or borrow funds from the money pool maintained by CenterPoint Energy. If CenterPoint Energy or the affiliates that borrow our invested funds were to experience a deterioration in their creditworthiness or liquidity, our creditworthiness, liquidity and the repayment of notes receivable from CenterPoint Energy and our affiliates under the money pool could be adversely impacted.
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Risk Factors Affecting Our Business
Rate regulation of our business may delay or deny our ability to earn a reasonable return and fully recover our costs.
Our rates are regulated by certain municipalities and the Texas Utility Commission based on an analysis of our invested capital and our expenses in a test year. Thus, the rates that we are allowed to charge may not match our costs at any given time, which is referred to as “regulatory lag.” The regulatory process by which rates are determined may not always result in rates that will produce full recovery of our costs and enable us to earn a reasonable return on our invested capital.
Disruptions at power generation facilities owned by third parties could interrupt our sales of transmission and distribution services.
We transmit and distribute to customers of REPs electric power that the REPs obtain from power generation facilities owned by third parties. We do not own or operate any power generation facilities. If power generation is disrupted or if power generation capacity is inadequate, our sales of transmission and distribution services may be diminished or interrupted, and our results of operations, financial condition and cash flows could be adversely affected.
Our revenues and results of operations are seasonal.
A significant portion of our revenues is derived from rates that we collect from each REP based on the amount of electricity we deliver on behalf of such REP. Thus, our revenues and results of operations are subject to seasonality, weather conditions and other changes in electricity usage, with revenues generally being higher during the warmer months. Unusually mild weather in the warmer months could diminish our results of operations and harm our financial condition. Conversely, extreme warm weather conditions could increase our results of operations in a manner that would not likely be annually recurring.
The AMS deployed throughout our service territory may experience unexpected problems with respect to the timely receipt of accurate metering data.
We have deployed an AMS throughout our service territory. The deployment consisted, among other elements, of replacing existing meters with new electronic meters that record metering data at 15-minute intervals and wirelessly communicate that information to us over a bi-directional communications system installed for that purpose. The AMS integrates equipment and computer software from various vendors in order to eliminate the need for physical meter readings to be taken at consumers’ premises, such as monthly readings for billing purposes and special readings associated with a customer’s change in REPs or the connection or disconnection of electric service. Unanticipated difficulties could be encountered during the operation of the AMS, including failures or inadequacy of equipment or software, difficulties in integrating the various components of the AMS, changes in technology, cyber-security issues and factors outside our control, which could result in delayed or inaccurate metering data that might lead to delays or inaccuracies in the calculation and imposition of delivery or other charges, which could have a material adverse effect on our results of operations, financial condition and cash flows.
We could be subject to higher costs and fines or other sanctions as a result of mandatory reliability standards.
The FERC has jurisdiction with respect to ensuring the reliability of electric transmission service, including transmission facilities owned by us and other utilities within ERCOT. The FERC has designated the NERC as the ERO to promulgate standards, under FERC oversight, for all owners, operators and users of the bulk power system. The FERC has approved the delegation by the NERC of authority for reliability in ERCOT to the TRE, a functionally independent division of ERCOT. Compliance with the mandatory reliability standards may subject us to higher operating costs and may result in increased capital expenditures. In addition, if we were to be found to be in noncompliance with applicable mandatory reliability standards, we could be subject to sanctions, including substantial monetary penalties.
A substantial portion of our receivables is concentrated in a small number of REPs, and any delay or default in payment could adversely affect our cash flows, financial condition and results of operations.
Our receivables from the distribution of electricity are collected from REPs that supply the electricity we distribute to our customers. As of December 31, 2015, we did business with approximately 69 REPs. Adverse economic conditions, structural problems in the market served by ERCOT or financial difficulties of one or more REPs could impair the ability of these REPs to pay for our services or could cause them to delay such payments. We depend on these REPs to remit payments on a timely basis. Applicable regulatory provisions require that customers be shifted to another REP or a provider of last resort if a REP cannot make timely payments. Applicable Texas Utility Commission regulations significantly limit the extent to which we can apply normal commercial terms or otherwise seek credit protection from firms desiring to provide retail electric service in our service territory, and we thus
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remain at risk for payments related to services provided prior to the shift to another REP or the provider of last resort. The Texas Utility Commission revised its regulations in 2009 to (i) increase the financial qualifications required of REPs that began selling power after January 1, 2009, and (ii) authorize utilities to defer bad debts resulting from defaults by REPs for recovery in a future rate case. A significant portion of our billed receivables from REPs are from affiliates of NRG and Energy Future Holdings. Our aggregate billed receivables balance from REPs as of December 31, 2015 was $195 million. Approximately 34% and 11% of this amount was owed by affiliates of NRG and Energy Future Holdings, respectively. In April 2014, Energy Future Holdings publicly disclosed that it and the substantial majority of its direct and indirect subsidiaries, excluding Oncor Electric Delivery Company LLC and its subsidiaries, filed voluntary petitions for relief under Chapter 11 of the United States Bankruptcy Code in the United States Bankruptcy Court for the District of Delaware. Any delay or default in payment by REPs could adversely affect our cash flows, financial condition and results of operations. If a REP were unable to meet its obligations, it could consider, among various options, restructuring under the bankruptcy laws, in which event such REP might seek to avoid honoring its obligations, and claims might be made by creditors involving payments we had received from such REP.
Other Risk Factors Affecting Our Business
We are subject to operational and financial risks and liabilities arising from environmental laws and regulations.
Our operations are subject to stringent and complex laws and regulations pertaining to the environment. As an owner or operator of electric transmission and distribution systems, and the facilities that support these systems, we must comply with these laws and regulations at the federal, state and local levels. These laws and regulations can restrict or impact our business activities in many ways, such as:
• | restricting the way we can handle or dispose of wastes; |
• | limiting or prohibiting construction activities in sensitive areas such as wetlands, coastal regions, or areas inhabited by endangered species; |
• | requiring remedial action to mitigate environmental conditions caused by our operations, or attributable to former operations; and |
• | enjoining the operations of facilities with permits issued pursuant to such environmental laws and regulations. |
In order to comply with these requirements, we may need to spend substantial amounts and devote other resources from time to time to:
• | construct or acquire new facilities and equipment; |
• | acquire permits for facility operations; |
• | modify or replace existing and proposed equipment; and |
• | clean or decommission waste disposal areas, fuel storage and management facilities and other locations and facilities. |
Failure to comply with these laws and regulations may trigger a variety of administrative, civil and criminal enforcement measures, including the assessment of monetary penalties, the imposition of remedial actions, and the issuance of orders enjoining future operations. Certain environmental statutes impose strict, joint and several liability for costs required to clean and restore sites where hazardous substances have been stored, disposed or released. Moreover, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of hazardous substances or other waste products into the environment.
The recent trend in environmental regulation has been to place more restrictions and limitations on activities that may affect the environment, and thus there can be no assurance as to the amount or timing of future expenditures for environmental compliance or remediation, and actual future expenditures may be greater than the amounts we currently anticipate.
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Our insurance coverage may not be sufficient. Insufficient insurance coverage and increased insurance costs could adversely impact our results of operations, financial condition and cash flows.
We currently have general liability and property insurance in place to cover certain of our facilities in amounts that we consider appropriate. Such policies are subject to certain limits and deductibles and do not include business interruption coverage. Insurance coverage may not be available in the future at current costs or on commercially reasonable terms, and the insurance proceeds received for any loss of, or any damage to, any of our facilities may not be sufficient to restore the loss or damage without negative impact on our results of operations, financial condition and cash flows.
In common with other companies in our line of business that serve coastal regions, we do not have insurance covering our transmission and distribution system, other than substations, because we believe it to be cost prohibitive. In the future, we may not be able to recover the costs incurred in restoring our transmission and distribution properties following hurricanes or other disasters through issuance of storm restoration bonds or a change in our regulated rates or otherwise, or any such recovery may not be timely granted. Therefore, we may not be able to restore any loss of, or damage to, any of our transmission and distribution properties without negative impact on our results of operations, financial condition and cash flows.
We and CenterPoint Energy could incur liabilities associated with businesses and assets that we have transferred to others.
Under some circumstances, we and CenterPoint Energy could incur liabilities associated with assets and businesses we and CenterPoint Energy no longer own. These assets and businesses were previously owned by Reliant Energy, Incorporated (Reliant Energy), our predecessor, directly or through subsidiaries and include:
• | merchant energy, energy trading and REP businesses transferred to RRI or its subsidiaries in connection with the organization and capitalization of RRI prior to its initial public offering in 2001 and now owned by affiliates of NRG; and |
• | Texas electric generating facilities transferred to a subsidiary of Texas Genco Holdings, Inc. (Texas Genco) in 2002, later sold to a third party and now owned by an affiliate of NRG. |
In connection with the organization and capitalization of RRI (now GenOn), that company and its subsidiaries assumed liabilities associated with various assets and businesses Reliant Energy transferred to them. RRI also agreed to indemnify, and cause the applicable transferee subsidiaries to indemnify, CenterPoint Energy and its subsidiaries, including us, with respect to liabilities associated with the transferred assets and businesses. These indemnity provisions were intended to place sole financial responsibility on RRI and its subsidiaries for all liabilities associated with the current and historical businesses and operations of RRI, regardless of the time those liabilities arose. If RRI (now GenOn) were unable to satisfy a liability that has been so assumed in circumstances in which Reliant Energy and its subsidiaries were not released from the liability in connection with the transfer, we and CenterPoint Energy could be responsible for satisfying the liability.
If GenOn were unable to meet its obligations, it could consider, among various options, restructuring under the bankruptcy laws, in which event GenOn might not honor its indemnification obligations and claims by GenOn’s creditors might be made against us as its former owner.
Reliant Energy and RRI (GenOn’s predecessor) are named as defendants in a number of lawsuits arising out of sales of natural gas in California and other markets. Although these matters relate to the business and operations of GenOn, claims against Reliant Energy have been made on grounds that include liability of Reliant Energy as a controlling shareholder of GenOn’s predecessor. We and CenterPoint Energy could incur liability if claims in one or more of these lawsuits were successfully asserted against us or CenterPoint Energy and indemnification from GenOn were determined to be unavailable or if GenOn were unable to satisfy indemnification obligations owed with respect to those claims.
In connection with the organization and capitalization of Texas Genco (now an affiliate of NRG), Reliant Energy and Texas Genco entered into a separation agreement in which Texas Genco assumed liabilities associated with the electric generation assets Reliant Energy transferred to it. Texas Genco also agreed to indemnify, and cause the applicable transferee subsidiaries to indemnify, CenterPoint Energy and its subsidiaries, including us, with respect to liabilities associated with the transferred assets and businesses. In many cases the liabilities assumed were obligations of ours, and we were not released by third parties from these liabilities. The indemnity provisions were intended generally to place sole financial responsibility on Texas Genco and its subsidiaries for all liabilities associated with the current and historical businesses and operations of Texas Genco, regardless of the time those liabilities arose. If Texas Genco were unable to satisfy a liability that had been so assumed or indemnified against, and provided CenterPoint Energy or Reliant Energy had not been released from the liability in connection with the transfer, we could be responsible for satisfying the liability.
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In connection with CenterPoint Energy’s sale of Texas Genco, the separation agreement was amended to provide that Texas Genco would no longer be liable for, and CenterPoint Energy would assume and agree to indemnify Texas Genco against, liabilities that Texas Genco originally assumed in connection with its organization to the extent, and only to the extent, that such liabilities are covered by certain insurance policies held by CenterPoint Energy.
CenterPoint Energy or its subsidiaries, including us, have been named, along with numerous others, as a defendant in lawsuits filed by a number of individuals who claim injury due to exposure to asbestos. Some of the claimants have worked at locations owned by CenterPoint Energy or us, but most existing claims relate to facilities previously owned by CenterPoint Energy’s other subsidiaries or us. We anticipate that additional claims like those received may be asserted in the future. Under the terms of the arrangements regarding separation of the generating business from CenterPoint Energy and its sale of that business to an affiliate of NRG, ultimate financial responsibility for uninsured losses from claims relating to the generating business has been assumed by the NRG affiliate, but CenterPoint Energy has agreed to continue to defend such claims to the extent they are covered by insurance maintained by CenterPoint Energy, subject to reimbursement of the costs of such defense by the NRG affiliate.
Cyber-attacks, physical security breaches, acts of terrorism or other disruptions could adversely impact our results of operations, financial condition and cash flows.
We are subject to cyber and physical security risks related to breaches in the systems and technology used (i) to manage operations and other business processes and (ii) to protect sensitive information maintained in the normal course of business. The operation of our electric transmission and distribution system is dependent on not only physical interconnection of our facilities, but also on communications among the various components of our system. As we deploy smart meters and the intelligent grid, reliance on communication between and among those components increases. Disruption of those communications, whether caused by physical disruption such as storms or other natural phenomena, by failure of equipment or technology, or by manmade events, such as cyber-attacks or acts of terrorism, may disrupt our ability to conduct operations and control assets. Cyber-attacks could also result in the loss of confidential or proprietary data or security breaches of other information technology systems that could disrupt operations and critical business functions, adversely affect reputation, and subject us to possible legal claims and liability. We are not fully insured against all cyber-security risks, any of which could have a material adverse effect on our results of operations, financial condition and cash flows. In addition, electrical distribution and transmission facilities may be targets of terrorist activities that could disrupt our ability to conduct our business and have a material adverse effect on our results of operations, financial condition and cash flows.
Failure to maintain the security of personally identifiable information could adversely affect us.
In connection with our business we collect and retain personally identifiable information of our customers and employees. Our customers and employees expect that we will adequately protect their personal information, and the United States regulatory environment surrounding information security and privacy is increasingly demanding. A significant theft, loss or fraudulent use of customer, employee or CenterPoint Houston data by cyber-crime or otherwise could adversely impact our reputation and could result in significant costs, fines and litigation.
Our results of operations, financial condition and cash flows may be adversely affected if we are unable to successfully operate our facilities or perform certain corporate functions.
Our performance depends on the successful operation of our facilities. Operating these facilities involves many risks, including:
• | operator error or failure of equipment or processes; |
• | operating limitations that may be imposed by environmental or other regulatory requirements; |
• | labor disputes; |
• | information technology system failures that impair our information technology infrastructure or disrupt normal business operations; |
• | information technology failure that affects our ability to access customer information or causes us to lose confidential or proprietary data that materially and adversely affects our reputation or exposes us to legal claims; and |
• | catastrophic events such as fires, earthquakes, explosions, leaks, floods, droughts, hurricanes, terrorism, pandemic health events or other similar occurrences. |
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Such events may result in a decrease or elimination of revenue from our facilities, an increase in the cost of operating our facilities or delays in cash collections, any of which could have a material adverse effect on our results of operations, financial condition and/or cash flows.
Our success depends upon our ability to attract, effectively transition and retain key employees and identify and develop talent to succeed senior management.
We depend on our senior executive officers and other key personnel. Our success depends on our ability to attract, effectively transition and retain key personnel. The inability to recruit and retain or effectively transition key personnel or the unexpected loss of key personnel may adversely affect our operations. In addition, because of the reliance on our management team, our future success depends in part on our ability to identify and develop talent to succeed senior management. The retention of key personnel and appropriate senior management succession planning will continue to be critically important to the successful implementation of our strategies.
Failure to attract and retain an appropriately qualified workforce could adversely impact our results of operations.
Our business is dependent on our ability to recruit, retain, and motivate employees. Certain circumstances, such as an aging workforce without appropriate replacements, a mismatch of existing skillsets to future needs, or the unavailability of contract resources may lead to operating challenges such as a lack of resources, loss of knowledge or a lengthy time period associated with skill development. Our costs, including costs to replace employees, productivity costs and safety costs, may rise. Failure to hire and adequately train replacement employees, including the transfer of significant internal historical knowledge and expertise to the new employees, or the future availability and cost of contract labor may adversely affect the ability to manage and operate our business. If we are unable to successfully attract and retain an appropriately qualified workforce, our results of operations could be negatively affected.
Climate change legislation and regulatory initiatives could result in increased operating costs and reduced demand for our services.
Regulatory agencies have from time to time considered adopting legislation, including the modification of existing laws and regulations, to reduce emissions of GHGs, and there has been a wide-ranging policy debate, both nationally and internationally, regarding the impact of these gases and possible means for their regulation. Following a finding by the EPA that certain GHGs represent an endangerment to human health, the EPA adopted two sets of rules regulating GHG emissions under the Clean Air Act, one that requires a reduction in emissions of GHGs from motor vehicles and another that regulates emissions of GHGs from certain large stationary sources. The EPA has also expanded its existing GHG emissions reporting requirements. These permitting and reporting requirements could lead to further regulation of GHGs by the EPA. Our electric transmission and distribution business, in contrast to some electric utilities, does not generate electricity and thus is not directly exposed to the risk of high capital costs and regulatory uncertainties that face electric utilities that burn fossil fuels to generate electricity. Nevertheless, our revenues could be adversely affected to the extent any resulting regulatory action has the effect of reducing consumption of electricity by ultimate consumers within our service territory. Likewise, incentives to conserve energy or use other energy sources could result in a decrease in demand for our services.
Climate changes could result in more frequent and more severe weather events which could adversely affect the results of operations of our business.
To the extent climate changes occur, our business may be adversely impacted, though we believe any such impacts are likely to occur very gradually and hence would be difficult to quantify with specificity. A possible climate change is more frequent and more severe weather events, such as hurricanes or tornadoes. Since our facilities are located along or near the Gulf Coast, increased or more severe hurricanes or tornadoes could increase our costs to repair damaged facilities and restore service to our customers. When we cannot deliver electricity to customers or our customers cannot receive our services, our financial results can be impacted by lost revenues, and we generally must seek approval from regulators to recover restoration costs. To the extent we are unable to recover those costs, or if higher rates resulting from our recovery of such costs result in reduced demand for our services, our future financial results may be adversely impacted.
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Aging infrastructure may lead to increased costs and disruptions in operations that could negatively impact our financial results.
We have risks associated with aging infrastructure assets. The age of certain of our assets may result in a need for replacement, or higher level of maintenance costs as a result of our risk based federal and state compliant integrity management programs. Failure to achieve timely recovery of these expenses could adversely impact revenues and could result in increased capital expenditures or expenses.
The operation of our facilities depends on good labor relations with our employees.
We have entered into and have in place a collective bargaining agreement with a labor union. The collective bargaining agreement with the International Brotherhood of Electrical Workers Local 66 is scheduled to expire in May of 2016. Any failure to reach an agreement on a new labor contract or to negotiate this labor contract might result in strikes, boycotts or other labor disruptions. These potential labor disruptions could have a material adverse effect on our business, results of operations and/or cash flows. Labor disruptions, strikes or significant negotiated wage and benefit increases, whether due to union activities, employee turnover or otherwise, could have a material adverse effect on our business, results of operations and/or cash flows.
Our businesses will continue to have to adapt to technological change and may not be successful or may have to incur significant expenditures to adapt to technological change.
We operate in businesses that require sophisticated data collection, processing systems, software and other technology. Some of the technologies supporting the industries we serve are changing rapidly. We expect that new technologies will emerge or grow that may be superior to, or may not be compatible with, some of our existing technologies, and may require us to make significant expenditures so that we can continue to provide cost-effective and reliable methods of energy delivery.
Our future success will depend, in part, on our ability to anticipate and adapt to technological changes in a cost-effective manner and to offer, on a timely basis, reliable services that meet customer demands and evolving industry standards. If we fail to adapt successfully to any technological change or obsolescence, or fail to obtain access to important technologies or incur significant expenditures in adapting to technological change, our businesses, operating results and financial condition could be materially and adversely affected.
Our merger and acquisition activities may not be successful or may result in completed acquisitions that do not perform as anticipated.
From time to time, we have made and may continue to make acquisitions of businesses and assets. However, suitable acquisition candidates may not continue to be available on terms and conditions we find acceptable. In addition, any completed or future acquisitions involve substantial risks, including the following:
•acquired businesses or assets may not produce revenues, earnings or cash flow at anticipated levels;
• | acquired businesses or assets could have environmental, permitting or other problems for which contractual protections prove inadequate; |
• | we may assume liabilities that were not disclosed to us, that exceed our estimates, or for which our rights to indemnification from the seller are limited; |
• | we may be unable to integrate acquired businesses successfully and realize anticipated economic, operational and other benefits in a timely manner, which could result in substantial costs and delays or other operational, technical or financial problems; and |
• | acquisitions, or the pursuit of acquisitions, could disrupt ongoing businesses, distract management, divert resources and make it difficult to maintain current business standards, controls and procedures. |
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We are involved in numerous legal proceedings, the outcome of which are uncertain, and resolutions adverse to us could negatively affect our financial results.
We are subject to numerous legal proceedings, the most significant of which are summarized in Note 10 of the consolidated financial statements. Litigation is subject to many uncertainties, and we cannot predict the outcome of individual matters with assurance. Final resolution of these matters may require additional expenditures over an extended period of time that may be in excess of established reserves and may have a material adverse effect on our financial results.
We are exposed to risks related to unfavorable economic conditions in our service territory.
Our business is affected by the economic climate in our service territory, which could impact our ability to grow our customer base and our rate of growth or result in reduced energy consumption by our customers. Some economic sectors important to our customer base may be affected. For example, our business is largely concentrated in Houston, Texas, where a higher percentage of employment is tied to the energy sector relative to other regions of the country. Given the significant decline in energy and commodity prices in 2015, the rate of growth in employment in Houston has declined. In the event economic conditions further decline, the rate of growth in Houston may also deteriorate. Increases in customer defaults or delays in payment due to liquidity constraints could negatively impact our cash flows and financial condition.
Our business may be adversely affected by the intentional misconduct of our employees.
We are committed to living our core values of safety, integrity, accountability, initiative and respect and complying with all applicable laws and regulations. Despite that commitment and our efforts to prevent misconduct, it is possible for employees to engage in intentional misconduct, fail to uphold our core values, and violate laws and regulations for individual gain through contract or procurement fraud, misappropriation, bribery or corruption, fraudulent related-party transactions and serious breaches of CenterPoint Energy’s Ethics and Compliance Code and Standards of Conduct/Business Ethics policy, among other policies. If such intentional misconduct by employees should occur, it could result in substantial liability, higher costs, increased regulatory scrutiny and negative public perceptions.
Item 1B. | Unresolved Staff Comments |
None.
Item 2. | Properties |
Character of Ownership
We lease or own our principal properties in fee. Most of our electric lines are located, pursuant to easements and other rights, on public roads or on land owned by others. For information regarding our properties, please read “Business — Electric Transmission & Distribution — Properties” in Item 1 of this report, which information is incorporated herein by reference.
Item 3. | Legal Proceedings |
For a discussion of material legal and regulatory proceedings affecting us, please read “Regulation” and “Environmental Matters” in Item 1 of this report, “Management’s Narrative Analysis of Results of Operations — Liquidity and Capital Resources — Regulatory Matters” in Item 7 of this report and Note 10(b) to our consolidated financial statements, which information is incorporated herein by reference.
Item 4. Mine Safety Disclosures
Not applicable.
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PART II
Item 5. | Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities |
All of our 1,000 outstanding common shares are held by Utility Holding, LLC, a wholly-owned subsidiary of CenterPoint Energy.
We paid dividends of $252 million, $-0- and $766 million on our common shares to Utility Holding, LLC in 2015, 2014 and 2013, respectively.
Our revolving credit facility contains a financial covenant which limits our consolidated debt (excluding transition and system restoration bonds) to an amount not to exceed 65% of our consolidated capitalization. This covenant could restrict our ability to distribute dividends.
Item 6. | Selected Financial Data |
The information called for by Item 6 is omitted pursuant to Instruction I(2) to Form 10-K (Omission of Information by Certain Wholly-Owned Subsidiaries).
Item 7. | Management’s Narrative Analysis of Results of Operations |
The following narrative analysis should be read in combination with our consolidated financial statements and notes contained in Item 8 of this report.
OVERVIEW
We provide electric transmission and distribution services to retail electric providers (REPs) serving over 2.3 million metered customers in the Texas Gulf Coast area that has a population of approximately six million people and includes the city of Houston.
On behalf of REPs, we deliver electricity from power plants to substations, from one substation to another and to retail electric customers in locations throughout our certificated service territory. The Electric Reliability Council of Texas, Inc. (ERCOT) serves as the regional reliability coordinating council for member electric power systems in Texas. ERCOT membership is open to consumer groups, investor and municipally-owned electric utilities, rural electric cooperatives, independent generators, power marketers, river authorities and REPs. The ERCOT market represents approximately 90% of the demand for power in Texas and is one of the nation’s largest power markets. Transmission and distribution services are provided under tariffs approved by the Public Utility Commission of Texas (Texas Utility Commission).
EXECUTIVE SUMMARY
Factors Influencing Our Business and Industry Trends
We expect our business to continue to be affected by the key factors and trends discussed below. Our expectations are based on assumptions made by us and information currently available to us. To the extent our underlying assumptions about, or interpretations of, available information prove to be incorrect, our actual results may vary materially from our expected results.
We are an electric transmission and distribution company. The majority of our revenues are generated from the transmission and delivery of electricity. We do not own or operate electric generating facilities or make retail sales to end-use electric customers. To assess our financial performance, our management primarily monitors our operating income and cash flows. Within these broader financial measures, we monitor margins, operation and maintenance expense, interest expense, capital spending and working capital requirements. In addition to these financial measures we also monitor a number of variables that management considers important to the operation of our business, including the number of customers, throughput, use per customer, and heating and cooling degree days. We also monitor system reliability, safety factors and customer satisfaction to gauge our performance.
To the extent adverse economic conditions affect our suppliers and customers, our business results may suffer. For example, our business is largely concentrated in Houston, Texas, where a higher percentage of employment is tied to the energy sector relative to other regions of the country. Although Houston, Texas has a diverse economy, employment in the energy industry remains important. Reduced demand and lower energy prices could lead to financial pressure on some of our customers who operate within the energy industry and impact the growth rate of our customer base. Given the significant decline in energy and commodity prices in 2015, the rate of growth in employment in Houston, which had been greater than the national average, has declined and is now
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more in line with the national average. We expect this trend to continue in the foreseeable future. Also, adverse economic conditions, coupled with concerns for protecting the environment, may cause consumers to use less energy or avoid expansions of their facilities, resulting in less demand for our services.
Performance of our business is significantly influenced by the number of customers and energy usage per customer. Weather conditions can have a significant impact on energy usage, and we compare our results on a weather adjusted basis. In 2015, our Houston service area experienced some of the mildest temperatures on record during November and December. In 2014, we experienced a colder than normal January and February and milder temperatures for the rest of the year, including the summer months, in the Houston area. In 2013, we experienced a colder than normal spring and very cold weather in November and December in Houston. Our long-term national trends indicate customers have reduced their energy consumption, and reduced consumption can adversely affect our results. However, due to more affordable energy prices and continued economic improvement in the area we serve, the trend toward lower usage has slowed. In our service area, we have benefited from growth in the number of customers that also tends to mitigate the effects of reduced consumption. We anticipate that this trend will continue as the region’s economies continue to grow. The profitability of our business is influenced significantly by the regulatory treatment we receive from the state and local regulators who set our electric distribution rates.
The nature of our business requires significant amounts of capital investment, and we rely on internally generated cash, borrowings under our credit facility and issuances of debt in the capital markets to satisfy these capital needs. We strive to maintain investment grade ratings for our securities in order to access the capital markets on terms we consider reasonable. A reduction in our ratings generally would increase our borrowing costs for new issuances of debt, as well as borrowing costs under our existing revolving credit facility. Disruptions in the financial markets can also affect the availability of new capital on terms we consider attractive. In those circumstances, companies like us may not be able to obtain certain types of external financing or may be required to accept terms less favorable than they would otherwise accept. For that reason, we seek to maintain adequate liquidity for our business through the existing credit facility and prudent refinancing of existing debt.
Consistent with regulatory treatment, we can defer the amount of pension expense that differs from the level of pension expense included in our base rates.
Significant Events
Brazos Valley Connection Project. In April 2015, we filed a Certificate of Convenience and Necessity (CCN) application with the Texas Utility Commission seeking approval to construct the Brazos Valley Connection (our portion of the Houston region transmission project). We proposed 32 alternative routes for the project in the application, including one route (the Recommended Route) that we identified in the application as best meeting the routing criteria used by the Texas Utility Commission in the route selection portion of CCN proceedings. The hearing on our CCN application was divided into two phases, a route-selection phase and a need phase. The route selection hearing was held on August 17 and 18, 2015. The hearing on the need for the line was held on September 2 and 3, 2015. On January 15, 2016, the Texas Utility Commission issued an order finding that the evidence presented by us, ERCOT, and others established the need for the project and approving a CCN for us to construct the Brazos Valley Connection using a modified version of the Recommended Route. A request for rehearing was filed with respect to the Texas Utility Commission’s route selection decision. That request for rehearing will be automatically deemed denied by operation of law on March 10, 2016, unless the Texas Utility Commission acts on the request before that date. The Texas Utility Commission’s order provided an estimated range of approximately $270–$310 million for the capital costs for the Brazos Valley Connection. The actual cost will depend on factors including land acquisition costs, material and construction costs and landowner elections permitted under the Texas Utility Commission’s order. We expect to complete construction of the Brazos Valley Connection by mid-2018.
Transmission Cost of Service (TCOS). On June 26, 2015, we filed an application with the Texas Utility Commission for an interim update of our TCOS seeking an increase in annual transmission revenues based on an incremental increase of $87.6 million in total rate base. The Texas Utility Commission approved our application in the third quarter of 2015, and rates became effective August 17, 2015, resulting in an increase of $13.7 million in annual transmission revenues.
On October 1, 2015, we filed an application with the Texas Utility Commission for an interim update of our TCOS seeking an increase in annual transmission revenues based on an incremental increase of $107.6 million in total rate base. The Texas Utility Commission approved our application in the fourth quarter of 2015, and rates became effective November 23, 2015, resulting in an increase of $16.8 million in annual transmission revenue.
Distribution Cost Recovery Factor (DCRF). On April 6, 2015, we filed an application with the Texas Utility Commission for a DCRF interim rate adjustment to account for changes in certain distribution-invested capital since our 2010 rate case. The application
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requested (i) an increase in annual distribution revenue of $16.7 million based on an increase in rate base from January 1, 2010 through December 31, 2014 of $417 million; and (ii) that rates become effective September 1, 2015.
On June 19, 2015, an unopposed settlement agreement was filed providing for an increase in annual distribution revenue of $13.0 million, subject to final Texas Utility Commission approval. The Texas Utility Commission approved the settlement agreement on July 30, 2015. Rates became effective September 1, 2015.
CERTAIN FACTORS AFFECTING FUTURE EARNINGS
Our past earnings and results of operations are not necessarily indicative of our future earnings and results of operations. The magnitude of our future earnings and results of our operations will depend on or be affected by numerous factors including:
• | state and federal legislative and regulatory actions or developments affecting various aspects of our business, including, among others, energy deregulation or re-regulation, health care reform, financial reform, tax legislation and actions regarding the rates we charge; |
• | timely and appropriate rate actions that allow recovery of costs and a reasonable return on investment; |
• | industrial, commercial and residential growth in our service territory and changes in market demand, including the effects of energy efficiency measures and demographic patterns; |
• | future economic conditions in regional and national markets and their effect on sales, prices and costs; |
• | weather variations and other natural phenomena, including the impact of severe weather events on operations and capital; |
• | problems with regulatory approval, construction, implementation of necessary technology or other issues with respect to major capital projects that result in delays or in cost overruns that cannot be recouped in rates; |
• | local, state and federal legislative and regulatory actions or developments relating to the environment, including those related to global climate change; |
• | the impact of unplanned facility outages; |
• | any direct or indirect effects on our facilities, operations and financial condition resulting from terrorism, cyber-attacks, data security breaches or other attempts to disrupt our business or the businesses of third parties, or other catastrophic events such as fires, earthquakes, explosions, leaks, floods, droughts, hurricanes, pandemic health events or other occurrences; |
• | our ability to invest planned capital and the timely recovery of our investment in capital; |
• | our ability to control operation and maintenance costs; |
• | actions by credit rating agencies; |
• | the sufficiency of our insurance coverage, including availability, cost, coverage and terms; |
• | the investment performance of CenterPoint Energy, Inc.’s pension and postretirement benefit plans; |
• | commercial bank and financial market conditions, our access to capital, the cost of such capital, and the results of our financing and refinancing efforts, including availability of funds in the debt capital markets; |
• | changes in interest rates or rates of inflation; |
• | inability of various counterparties to meet their obligations to us; |
• | non-payment for our services due to financial distress of our customers; |
• | timely and appropriate regulatory actions allowing securitization or other recovery of costs associated with any future hurricanes or natural disasters; |
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• | our potential business strategies, including restructurings, acquisitions or dispositions of assets or businesses, which we cannot assure you will be completed or will have the anticipated benefits to us; |
• | acquisition and merger activities involving us or our competitors; |
• | our ability to recruit, effectively transition and retain management and key employees and maintain good labor relations; |
• | the ability of GenOn Energy, Inc. (GenOn, formerly known as RRI Energy, Inc., Reliant Energy, Inc. and Reliant Resources, Inc.), a wholly-owned subsidiary of NRG Energy, Inc. (NRG), and its subsidiaries to satisfy their obligations to us, including indemnity obligations; |
• | the outcome of litigation; |
• | the ability of REPs, including REP affiliates of NRG and Energy Future Holdings Corp., to satisfy their obligations to us and our subsidiaries; |
• | changes in technology, particularly with respect to efficient battery storage or the emergence or growth of new, developing or alternative sources of generation; |
• | the timing and outcome of any audits, disputes and other proceedings related to taxes; |
• | the effect of changes in and application of accounting standards and pronouncements; and |
• | other factors we discuss under “Risk Factors” in Item 1A of this report and in other reports we file from time to time with the Securities and Exchange Commission. |
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CONSOLIDATED RESULTS OF OPERATIONS
Our results of operations are affected by seasonal fluctuations in the demand for electricity. Our results of operations are also affected by, among other things, the actions of various governmental authorities having jurisdiction over rates we charge, debt service costs, income tax expense, our ability to collect receivables from REPs and our ability to recover our regulatory assets.
The following table sets forth selected financial data for the years ended December 31, 2015, 2014 and 2013, followed by a discussion of our consolidated results of operations based on operating income. We have provided a reconciliation of consolidated operating income to net income below.
Year Ended December 31, | |||||||||||
2015 | 2014 | 2013 | |||||||||
(in millions, except throughput and customer data) | |||||||||||
Revenues: | |||||||||||
Electric transmission and distribution utility | $ | 2,365 | $ | 2,280 | $ | 2,070 | |||||
Transition and system restoration bond companies | 481 | 566 | 507 | ||||||||
Total Revenues | 2,846 | 2,846 | 2,577 | ||||||||
Expenses: | |||||||||||
Operation and maintenance, excluding transition and system restoration bond companies | 1,300 | 1,251 | 1,045 | ||||||||
Depreciation and amortization, excluding transition and system restoration bond companies | 340 | 327 | 319 | ||||||||
Taxes other than income taxes | 222 | 224 | 225 | ||||||||
Transition and system restoration bond companies | 376 | 448 | 374 | ||||||||
Total Expenses | 2,238 | 2,250 | 1,963 | ||||||||
Operating Income | 608 | 596 | 614 | ||||||||
Interest and other finance charges | (118 | ) | (109 | ) | (99 | ) | |||||
Interest on transition and system restoration bonds | (105 | ) | (118 | ) | (133 | ) | |||||
Other income, net | 21 | 14 | 33 | ||||||||
Income Before Income Taxes and Extraordinary Item | 406 | 383 | 415 | ||||||||
Income Tax Expense | 145 | 131 | 146 | ||||||||
Net Income | $ | 261 | $ | 252 | $ | 269 | |||||
Throughput (in gigawatt-hours (GWh)): | |||||||||||
Residential | 28,995 | 27,498 | 27,485 | ||||||||
Total | 84,191 | 81,839 | 79,985 | ||||||||
Number of metered customers at end of period: | |||||||||||
Residential | 2,079,899 | 2,033,027 | 1,982,699 | ||||||||
Total | 2,348,517 | 2,299,247 | 2,244,289 | ||||||||
2015 Compared to 2014. We reported operating income of $608 million for 2015, consisting of $503 million from our regulated electric transmission and distribution utility operations (TDU) and $105 million related to transition and system restoration bond companies (Bond Companies). For 2014, operating income totaled $596 million, consisting of $478 million from the TDU and $118 million related to Bond Companies.
TDU operating income increased $25 million due to the following key factors:
• | higher transmission-related revenues of $81 million, which were partially offset by increased transmission costs billed by transmission providers of $47 million; |
•customer growth of $25 million from the addition of nearly 50,000 new customers;
•higher usage of $17 million, primarily due to a return to normal weather; and
•rate relief associated with distribution capital investments of $5 million.
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These increases to operating income were partially offset by the following:
•lower equity return of $20 million, primarily related to true-up proceeds;
• | lower revenues from energy efficiency bonuses of $15 million, including a one-time energy efficiency remand bonus in 2014 of $8 million; |
•higher depreciation of $13 million; and
•lower right-of-way revenues of $7 million.
Income Tax Expense. We reported an effective tax rate of 35.7% and 34.2% for the years ended December 31, 2015 and 2014, respectively. The effective tax rate of 34.2% for 2014 was primarily attributable to a $6 million reversal of previously accrued taxes as a result of final positions taken in the 2013 income tax returns.
2014 Compared to 2013. We reported operating income of $596 million for 2014, consisting of $478 million from our TDU and $118 million related to Bond Companies. For 2013, operating income totaled $614 million, consisting of $481 million from the TDU and $133 million related to Bond Companies.
TDU operating income decreased $3 million due to the following key factors:
• | increased labor and support services costs of $21 million; |
• | increased contracts and services of $19 million; |
• | decreased usage of $11 million, primarily due to milder weather. |
• | lower right-of-way revenues of $8 million; |
• | increased depreciation of $8 million; |
• | an adjustment to our claims liability reserve of $6 million; and |
• | increased transmission costs billed by transmission providers of $168 million, which were largely offset by increased transmission-related revenues of $164 million. |
These decreases to operating income were partially offset by the following:
•customer growth of $33 million from the addition of almost 55,000 new customers;
•higher equity return of $23 million, primarily related to true-up proceeds; and
• | higher energy efficiency performance bonus of $15 million. |
Income Tax Expense. We reported an effective tax rate of 34.2% and 35.2% for the years ended December 31, 2014 and 2013, respectively. The effective tax rate of 34.2% for 2014 was primarily attributable to a $6 million reversal of previously accrued taxes as a result of final positions taken in the 2013 income tax returns.
LIQUIDITY AND CAPITAL RESOURCES
Our liquidity and capital requirements are affected primarily by our results of operations, capital expenditures, debt service requirements, tax payments, working capital needs and various regulatory actions. Our principal anticipated cash requirements during 2016 include capital expenditures of approximately $833 million and scheduled principal payments on transition and system restoration bonds of $391 million.
We expect that anticipated 2016 cash needs will be met with borrowings under our credit facility, proceeds from the issuance of general mortgage bonds, anticipated cash flows from operations and intercompany borrowings. Cash needs or discretionary financing or refinancing may result in the issuance of debt securities in the capital markets or the arrangement of additional credit
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facilities. Issuances of debt in the capital markets and additional credit facilities may not, however, be available to us on acceptable terms.
The following table sets forth our capital expenditures for 2015 and estimates of our capital expenditures for 2016 through 2020:
(in millions) | |||
2015 | $ | 934 | |
2016 | 833 | ||
2017 | 786 | ||
2018 | 735 | ||
2019 | 685 | ||
2020 | 686 | ||
Our capital expenditures are expected to be used for investment in infrastructure for our electric transmission and distribution operations. These capital expenditures are anticipated to maintain reliability and safety.
The following table sets forth estimates of our contractual obligations, including payments due by period:
Contractual Obligations | Total | 2016 | 2017-2018 | 2019-2020 | 2021 and thereafter | |||||||||||||||
(in millions) | ||||||||||||||||||||
Transition and system restoration bond debt (1) | $ | 2,674 | $ | 391 | $ | 845 | $ | 689 | $ | 749 | ||||||||||
Other long-term debt | 2,206 | — | — | 200 | 2,006 | |||||||||||||||
Interest payments - transition and system restoration bond debt (1) (2) | 367 | 95 | 146 | 76 | 50 | |||||||||||||||
Interest payments - other long-term debt (2) | 1,829 | 97 | 194 | 190 | 1,348 | |||||||||||||||
Operating leases | 1 | — | — | 1 | — | |||||||||||||||
Benefit obligations (3) | — | — | — | — | — | |||||||||||||||
Total contractual cash obligations (4) | $ | 7,077 | $ | 583 | $ | 1,185 | $ | 1,156 | $ | 4,153 | ||||||||||
(1) | Transition and system restoration charges are adjusted at least annually to cover debt service on the transition and system restoration bonds. |
(2) | We calculated estimated interest payments for long-term fixed-rate debt and term debt based on the applicable rates and payment dates. We typically expect to satisfy such interest payment obligations with cash flows from operations and short-term borrowings. |
(3) | We expect to contribute approximately $7 million to our postretirement benefits plan in 2016 to fund a portion of our obligations in accordance with rate orders or to fund pay-as-you-go costs associated with the plan. |
(4) | This table does not include estimated future payments for expected future asset retirement obligations. These payments are primarily estimated to be incurred after 2021. We record a separate liability for the fair value of these asset retirement obligations which totaled $37 million as of December 31, 2015. See Note 3(c) to our consolidated financial statements. |
Off-Balance Sheet Arrangements
Other than first mortgage bonds and general mortgage bonds issued as collateral for long-term debt of CenterPoint Energy as discussed below and operating leases, we have no off-balance sheet arrangements.
Regulatory Matters
Brazos Valley Connection Project. In July 2013, we and other transmission service providers submitted analyses and transmission proposals to ERCOT for an additional transmission path into the Houston region. In April 2014, ERCOT’s Board of Directors voted to endorse a Houston region transmission project and deemed its completion before June 2018 critical for reliability. The project will consist of (i) construction of a new double-circuit 345 kilovolt (kV) line spanning approximately 130 miles, (ii) upgrades to three substations to accommodate new connections and additional capacity, and (iii) improvements to approximately 11 miles of an existing 345 kV TH Wharton-Addicks transmission line to increase its rating. Also in April 2014, ERCOT staff determined that we would
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be the designated transmission service provider for the portion of the project between our Zenith substation and the Gibbons Creek substation owned by the Texas Municipal Power Agency, consisting of approximately 60–78 miles (depending on the route approved by the Texas Utility Commission) of 345 kV transmission line, upgrades to the Limestone and Zenith substations and upgrades to 11 miles of the 345 kV TH Wharton-Addicks transmission line (this portion of the Houston region transmission project is referred to by us as the Brazos Valley Connection). Other transmission service providers were designated by ERCOT for the portion of the project from the Gibbons Creek Substation to the Limestone Substation as well as the upgrades to the Gibbons Creek Substation. In April 2015, we filed a CCN application with the Texas Utility Commission seeking approval to construct the Brazos Valley Connection. We proposed 32 alternative routes for the project in the application, including the Recommended Route that we identified in the application as best meeting the routing criteria used by the Texas Utility Commission in the route selection portion of CCN proceedings. The hearing on our CCN application was divided into two phases, a route-selection phase and a need phase. The route selection hearing was held on August 17 and 18, 2015. The hearing on the need for the line was held on September 2 and 3, 2015. On January 15, 2016, the Texas Utility Commission issued an order finding that the evidence presented by us, ERCOT, and others established the need for the project and approving a CCN for us to construct the Brazos Valley Connection using a modified version of the Recommended Route. A request for rehearing was filed with respect to the Texas Utility Commission’s route selection decision. That request for rehearing will automatically be deemed denied by operation of law on March 10, 2016, unless the Texas Utility Commission acts on the request before that date. No party filed a request for rehearing on the order’s need decision before the deadline expired and, therefore, that decision is final and not appealable. The Texas Utility Commission’s order provided an estimated range of approximately $270–$310 million for the capital costs for the Brazos Valley Connection. The actual cost will depend on factors including land acquisition costs, material and construction costs and landowner elections permitted under the Texas Utility Commission’s order. We expect to complete construction of the Brazos Valley Connection by mid-2018.
In May 2014, several electric generators appealed the ERCOT Board of Directors’ April 2014 approval of the Houston region transmission project and the determination that the project was critical for reliability in the Houston region to the Texas Utility Commission. That appeal was denied by the Texas Utility Commission in December 2014. In March 2015, the electric generators petitioned the Texas District Court of Travis County for judicial review of the Texas Utility Commission’s denial of their appeal. That case is currently pending before that court.
Transmission Cost of Service. On November 21, 2014, we filed an application, as amended, with the Texas Utility Commission seeking an increase in annual transmission revenues based on an incremental increase in total rate base of $113.2 million. We received approval from the Texas Utility Commission during the first quarter of 2015, and rates became effective February 25, 2015, resulting in an increase of $23.5 million in annual transmission revenues.
On June 26, 2015, we filed an application with the Texas Utility Commission for an interim update of our TCOS seeking an increase in annual transmission revenues based on an incremental increase of $87.6 million in total rate base. The Texas Utility Commission approved our application in the third quarter of 2015, and rates became effective August 17, 2015, resulting in an increase of $13.7 million in annual transmission revenues.
On October 1, 2015, we filed an application with the Texas Utility Commission for an interim update of our TCOS seeking an increase in annual transmission revenues based on an incremental increase of $107.6 million in total rate base. The Texas Utility Commission approved our application in the fourth quarter of 2015, and rates became effective November 23, 2015, resulting in an increase of $16.8 million in annual transmission revenue.
Distribution Cost Recovery Factor. On April 6, 2015, we filed an application with the Texas Utility Commission for a DCRF interim rate adjustment to account for changes in certain distribution-invested capital since our 2010 rate case. The application requested (i) an increase in annual distribution revenue of $16.7 million based on an increase in rate base from January 1, 2010 through December 31, 2014 of $417 million; and (ii) that rates become effective September 1, 2015.
The DCRF application must be filed between April 1 and April 8 of any given year. The application includes recovery of specific incremental distribution-related invested capital, including poles, transformers, conductors, meters and telecommunication equipment from the previous rate case to the end of the DCRF update period, less an adjustment for the related accumulated deferred income taxes. The application includes recovery of return on investment, depreciation expense, federal income tax, and other associated taxes less an adjustment for changes in customer count and weather normalized usage during the update period. The allocation to customer classes is conducted in the same manner as current rates. Any authorized rate change is applied to all retail customers on an energy or demand charge basis, effective September 1, 2015, through a separate DCRF charge. Only four DCRF changes may be implemented between rate cases. The utility must file an earnings monitoring report (EMR) annually with the DCRF application. By law, a DCRF application will be denied if the EMR shows the utility is earning more than its authorized rate of return using 10-year weather normalized data.
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On June 19, 2015, an unopposed settlement agreement was filed providing for an increase in annual distribution revenue of $13.0 million, subject to final Texas Utility Commission approval. The Texas Utility Commission approved the settlement agreement on July 30, 2015. Rates became effective September 1, 2015.
Energy Efficiency Cost Recovery Factor (EECRF). On June 1, 2015, we filed an application with the Texas Utility Commission for an adjustment to our EECRF to recover $37.7 million in 2016, including an incentive of $6.6 million based on 2014 program performance. In October 2015, the Texas Utility Commission approved the application to recover $37.6 million. The effective date of the rate adjustment will be March 1, 2016.
Other Matters
Credit Facility
As of February 12, 2016, we had the following revolving credit facility and utilization of such facility (in millions):
Execution Date | Size of Facility | Amount Utilized at February 12, 2016 | Termination Date | ||||||||
September 9, 2011 | $ | 300 | $ | 204 | (1) | September 9, 2019 | |||||
(1) | Represents outstanding letters of credit of $4 million and outstanding bank loans of $200 million. |
Our $300 million revolving credit facility can be drawn at the London Interbank Offered Rate (LIBOR) plus 1.125% based on our current credit ratings. The revolving credit facility contains a financial covenant which limits our consolidated debt (excluding transition and system restoration bonds) to an amount not to exceed 65% of our consolidated capitalization. As of December 31, 2015, our debt (excluding transition and system restoration bonds) to capital ratio, as defined in our credit facility agreement, was 51.7%.
Borrowings under our revolving credit facility are subject to customary terms and conditions. However, there is no requirement that we make representations prior to borrowings as to the absence of material adverse changes or litigation that could be expected to have a material adverse effect. Borrowings under our revolving credit facility are subject to acceleration upon the occurrence of events of default that we consider customary. The revolving credit facility also provides for customary fees, including commitment fees, administrative agent fees, fees in respect of letters of credit and other fees. In our revolving credit facility, the borrowing spread to LIBOR and the commitment fees fluctuate based on our credit rating. We are currently in compliance with the various business and financial covenants contained in our revolving credit facility.
Securities Registered with the SEC
We have filed a shelf registration statement with the SEC registering an indeterminate principal amount of our general mortgage bonds.
Temporary Investments
As of February 12, 2016, we had no external temporary investments.
Money Pool
We participate in a money pool through which we and certain of our affiliates can borrow or invest on a short-term basis. Funding needs are aggregated and external borrowing or investing is based on the net cash position. The net funding requirements of the money pool are expected to be met with borrowings under CenterPoint Energy’s revolving credit facility or the sale of CenterPoint Energy’s commercial paper. As of February 12, 2016, we had $384 million borrowed from the money pool. The money pool may not provide sufficient funds to meet our cash needs.
Long-term Debt
Our long-term debt consists of our obligations and the obligations of our subsidiaries including transition and system restoration bonds issued by wholly-owned subsidiaries.
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As of December 31, 2015, our outstanding first mortgage bonds and general mortgage bonds aggregated approximately $2.2 billion, of which $174 million is not reflected in our consolidated financial statements. Of the $174 million, $118 million collateralized debt of CenterPoint Energy and is not reflected because of the contingent nature of the obligations and $56 million collateralized pollution control bonds that we hold for future remarketing.
The lien of the general mortgage indenture is junior to that of the mortgage pursuant to which the first mortgage bonds are issued. We may issue additional general mortgage bonds on the basis of retired bonds, 70% of property additions or cash deposited with the trustee. Approximately $4.2 billion of additional general mortgage bonds could be issued on the basis of retired bonds and 70% of property additions as of December 31, 2015. We have contractually agreed that we will not issue additional first mortgage bonds, subject to certain exceptions.
At December 31, 2015, our subsidiaries had the following aggregate principal amount of transition and system restoration bonds outstanding.
Company | Aggregate Principal Amount Outstanding | |||
(in millions) | ||||
Bond Company II | $ | 753 | ||
Bond Company III | 233 | |||
Bond Company IV | 1,273 | |||
Restoration Bond Company | 415 | |||
Total | $ | 2,674 | ||
The transition bonds and system restoration bonds are paid through the imposition of “transition” or “system restoration” charges, as defined in the Texas Public Utility Regulatory Act, which are irrevocable, non-bypassable charges payable by most of our retail electric customers to the bond company subsidiaries in order to provide recovery of authorized qualified costs. The transition and system restoration bonds are reported as our long-term debt, although the holders of these bonds have no recourse to any of our assets or revenues, and our creditors have no recourse to any assets or revenues (including, without limitation, the transition or system restoration charges) of the Bond Companies. We have no payment obligations with respect to the transition and system restoration bonds except to remit collections of transition and system restoration charges as set forth in servicing agreements between us and the Bond Companies and in an intercreditor agreement among us, the Bond Companies and other parties.
Impact on Liquidity of a Downgrade in Credit Ratings
The interest on borrowings under our credit facility is based on our credit rating. As of February 12, 2016, Moody’s Investors Service, Inc. (Moody’s), Standard & Poor’s Ratings Services (S&P), a division of The McGraw Hill Companies, and Fitch, Inc. (Fitch) had assigned the following credit ratings to our senior debt.
Moody’s | S&P | Fitch | ||||||||||
Instrument | Rating | Outlook (1) | Rating | Outlook (2) | Rating | Outlook (3) | ||||||
Senior Secured Debt | A1 | Stable | A | Negative | A | Stable | ||||||
(1) | A Moody’s rating outlook is an opinion regarding the likely direction of an issuer’s rating over the medium term. |
(2) | An S&P rating outlook assesses the potential direction of a long-term credit rating over the intermediate to longer term. |
(3) | A Fitch rating outlook indicates the direction a rating is likely to move over a one- to two-year period. |
We cannot assure that the ratings set forth above will remain in effect for any given period of time or that one or more of these ratings will not be lowered or withdrawn entirely by a rating agency. We note that these credit ratings are included for informational purposes and are not recommendations to buy, sell or hold our securities and may be revised or withdrawn at any time by the rating agency. Each rating should be evaluated independently of any other rating. Any future reduction or withdrawal of one or more of our credit ratings could have a material adverse impact on our ability to obtain short- and long-term financing, the cost of such financings and the execution of our commercial strategies.
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A decline in credit ratings could increase borrowing costs under our $300 million credit facility. If our credit ratings had been downgraded one notch by each of the three principal credit rating agencies from the ratings that existed at December 31, 2015, the impact on the borrowing costs under our credit facility would have been immaterial. A decline in credit ratings would also increase the interest rate on long-term debt to be issued in the capital markets and could negatively impact our ability to complete capital market transactions.
Cross Defaults
Under CenterPoint Energy’s $1.2 billion revolving credit facility, a payment default on, or a non-payment default that permits acceleration of, any indebtedness of borrowed money and certain other specified types of obligations (including guarantees) exceeding $75 million by us will cause a default. A default by CenterPoint Energy would not trigger a default under our debt instruments or revolving credit facility.
Possible Acquisitions or Dispositions
From time to time, we consider the acquisition or the disposition of assets or businesses. Any determination to take action in this regard will be based on market conditions and opportunities existing at the time, and accordingly, the timing, size or success of any efforts and the associated potential capital commitments are unpredictable. We may seek to fund all or part of any such efforts with proceeds from debt issuances. Debt financing may not, however, be available to us at that time due to a variety of events, including, among others, maintenance of our credit ratings, industry conditions, general economic conditions, market conditions and market perceptions.
On February 1, 2016, we announced that we are exploring the use of the real estate investment trust business model for all or part of our utility business. There can be no assurances that this evaluation will result in any specific action, and we do not intend to disclose further developments on this initiative unless and until the CenterPoint Energy Board of Directors approves a specific action or as otherwise required.
Collection of Receivables from REPs
Our receivables from the distribution of electricity are collected from REPs that supply the electricity we distribute to their customers. Adverse economic conditions, structural problems in the market served by ERCOT or financial difficulties of one or more REPs could impair the ability of these REPs to pay for our services or could cause them to delay such payments. We depend on these REPs to remit payments on a timely basis, and any delay or default in payment by REPs could adversely affect our cash flows. In the event of a REP’s default, our tariff provides a number of remedies, including our option to request that the Texas Utility Commission suspend or revoke the certification of the REP. Applicable regulatory provisions require that customers be shifted to another REP or a provider of last resort if a REP cannot make timely payments. However, we remain at risk for payments related to services provided prior to the shift to the replacement REP or the provider of last resort. If a REP were unable to meet its obligations, it could consider, among various options, restructuring under the bankruptcy laws, in which event such REP might seek to avoid honoring its obligations, and claims might be made against us involving payments we had received from such REP. If a REP were to file for bankruptcy, we may not be successful in recovering accrued receivables owed by such REP that are unpaid as of the date the REP filed for bankruptcy. However, Texas Utility Commission regulations authorize utilities, such as us, to defer bad debts resulting from defaults by REPs for recovery in future rate cases, subject to a review of reasonableness and necessity.
Other Factors that Could Affect Cash Requirements
In addition to the above factors, our liquidity and capital resources could be affected by:
• | increases in interest expense in connection with debt refinancings and borrowings under our credit facility; |
• | various legislative or regulatory actions; |
• | the ability of GenOn and its subsidiaries to satisfy their obligations in respect of GenOn’s indemnity obligations to us; |
• | the ability of REPs, including REP affiliates of NRG and Energy Future Holdings, to satisfy their obligations to us; |
• | the outcome of litigation brought by and against us; |
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• | restoration costs and revenue losses resulting from future natural disasters such as hurricanes and the timing of recovery of such restoration costs; and |
• | various other risks identified in “Risk Factors” in Item 1A of this report. |
Certain Contractual Limits on Our Ability to Issue Securities and Borrow Money
Our revolving credit facility contains a financial covenant which limits our consolidated debt (excluding transition and system restoration bonds) to an amount not to exceed 65% of our consolidated capitalization. Additionally, we have contractually agreed that we will not issue additional first mortgage bonds, subject to certain exceptions.
Relationship with CenterPoint Energy
We are an indirect, wholly-owned subsidiary of CenterPoint Energy. As a result of this relationship, the financial condition and liquidity of our parent company could affect our access to capital, our credit standing and our financial condition.
CRITICAL ACCOUNTING POLICIES
A critical accounting policy is one that is both important to the presentation of our financial condition and results of operations and requires management to make difficult, subjective or complex accounting estimates. An accounting estimate is an approximation made by management of a financial statement element, item or account in the financial statements. Accounting estimates in our historical consolidated financial statements measure the effects of past business transactions or events, or the present status of an asset or liability. The accounting estimates described below require us to make assumptions about matters that are highly uncertain at the time the estimate is made. Additionally, different estimates that we could have used or changes in an accounting estimate that are reasonably likely to occur could have a material impact on the presentation of our financial condition, results of operations or cash flows. The circumstances that make these judgments difficult, subjective and/or complex have to do with the need to make estimates about the effect of matters that are inherently uncertain. Estimates and assumptions about future events and their effects cannot be predicted with certainty. We base our estimates on historical experience and on various other assumptions that we believe to be reasonable under the circumstances, the results of which form the basis for making judgments. These estimates may change as new events occur, as more experience is acquired, as additional information is obtained and as our operating environment changes. Our significant accounting policies are discussed in Note 2 to our consolidated financial statements. We believe the following accounting policies involve the application of critical accounting estimates. Accordingly, these accounting estimates have been reviewed and discussed with the audit committee of the board of directors of CenterPoint Energy.
Accounting for Rate Regulation
Accounting guidance for regulated operations provides that rate-regulated entities account for and report assets and liabilities consistent with the recovery of those incurred costs in rates if the rates established are designed to recover the costs of providing the regulated service and if the competitive environment makes it probable that such rates can be charged and collected. We apply this accounting guidance. Certain expenses and revenues subject to utility regulation or rate determination normally reflected in income are deferred on the balance sheet as regulatory assets or liabilities and are recognized in income as the related amounts are included in service rates and recovered from or refunded to customers. Regulatory assets and liabilities are recorded when it is probable that these items will be recovered or reflected in future rates. Determining probability requires significant judgment on the part of management and includes, but is not limited to, consideration of testimony presented in regulatory hearings, proposed regulatory decisions, final regulatory orders and the strength or status of applications for rehearing or state court appeals. If events were to occur that would make the recovery of these assets and liabilities no longer probable, we would be required to write off or write down these regulatory assets and liabilities. As of December 31, 2015, we had recorded regulatory assets of $2.2 billion and regulatory liabilities of $542 million.
Impairment of Long-Lived Assets and Intangibles
We review the carrying value of our long-lived assets, including identifiable intangibles, whenever events or changes in circumstances indicate that such carrying values may not be recoverable. Unforeseen events and changes in circumstances and market conditions and material differences in the value of long-lived assets and intangibles due to changes in estimates of future cash flows, interest rates, regulatory matters and operating costs could negatively affect the fair value of our assets and result in an impairment charge.
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Fair value is the amount at which the asset could be bought or sold in a current transaction between willing parties and may be estimated using a number of techniques, including quoted market prices or valuations by third parties, present value techniques based on estimates of cash flows, or multiples of earnings or revenue performance measures. The fair value of the asset could be different using different estimates and assumptions in these valuation techniques.
Unbilled Energy Revenues
Revenues related to electricity delivery are generally recognized upon delivery to customers. However, the determination of deliveries to individual customers is based on the reading of their meters, which is performed on a systematic basis throughout the month either electronically through advanced metering system (AMS) meter communications or manual readings. At the end of each month, deliveries to non-AMS customers since the date of the last meter reading are estimated and the corresponding unbilled revenue is estimated. Information regarding deliveries to AMS customers after the last billing is obtained from actual AMS meter usage data. Unbilled electricity delivery revenue is estimated each month based on actual AMS meter data, daily supply volumes and applicable rates. As additional information becomes available, or actual amounts are determinable, the recorded estimates are revised. Consequently, operating results can be affected by revisions to prior accounting estimates.
NEW ACCOUNTING PRONOUNCEMENTS
See Note 2(l) to the consolidated financial statements, incorporated herein by reference, for a discussion of new accounting pronouncements that affect us.
OTHER SIGNIFICANT MATTERS
Pension Plans. As discussed in Note 5(a) to the consolidated financial statements, we participate in CenterPoint Energy’s qualified and non-qualified pension plans covering substantially all employees. We recorded pension cost of $36 million, $27 million and $26 million for the years ended December 31, 2015, 2014 and 2013, respectively, of which $16 million, $25 million and $21 million impacted pre-tax earnings. Our actuarially determined pension and other postemployment expense for 2015 and 2014 in excess of the amounts being recovered through rates is being deferred for rate making purposes. Pension cost for 2016 is expected to be $45 million, of which we expect $20 million to impact pre-tax earnings after effecting such deferrals, based on an expected return on plan assets of 6.25% and a discount rate of 4.40% as of December 31, 2015. Future changes in plan asset returns, assumed discount rates and various other factors related to the pension plan will impact our future pension expense and liabilities. We cannot predict with certainty what these factors will be in the future.
Item 7A. | Quantitative and Qualitative Disclosures About Market Risk |
As of December 31, 2015, we had outstanding long-term debt and lease obligations that subject us to the risk of loss associated with movements in market interest rates.
As of December 31, 2015 and 2014, we had outstanding fixed-rate debt aggregating $4.7 billion and $5.1 billion, respectively, in principal amount and having a fair value of approximately $4.9 billion and $5.4 billion, respectively. Because these instruments are fixed-rate, they do not expose us to the risk of loss in earnings due to changes in market interest rates (please read Note 8 to our consolidated financial statements). However, the fair value of these instruments would increase by approximately $143 million if interest rates were to decline by 10% from their levels as of December 31, 2015. In general, such an increase in fair value would impact earnings and cash flows only if we were to reacquire all or a portion of these instruments in the open market prior to their maturity.
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Item 8. | Financial Statements and Supplementary Data |
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Member of
CenterPoint Energy Houston Electric, LLC
Houston, Texas
We have audited the accompanying consolidated balance sheets of CenterPoint Energy Houston Electric, LLC and subsidiaries (the “Company”, an indirect wholly owned subsidiary of CenterPoint Energy, Inc.) as of December 31, 2015 and 2014, and the related statements of consolidated income, cash flows, and member’s equity for each of the three years in the period ended December 31, 2015. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of CenterPoint Energy Houston Electric, LLC and subsidiaries as of December 31, 2015 and 2014, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2015, in conformity with accounting principles generally accepted in the United States of America.
/s/ DELOITTE & TOUCHE LLP
Houston, Texas
February 26, 2016
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CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES
(An Indirect, Wholly-Owned Subsidiary of CenterPoint Energy, Inc.)
STATEMENTS OF CONSOLIDATED INCOME
Year Ended December 31, | |||||||||||
2015 | 2014 | 2013 | |||||||||
(in millions) | |||||||||||
Revenues | $ | 2,846 | $ | 2,846 | $ | 2,577 | |||||
Expenses: | |||||||||||
Operation and maintenance | 1,311 | 1,258 | 1,053 | ||||||||
Depreciation and amortization | 705 | 768 | 685 | ||||||||
Taxes other than income taxes | 222 | 224 | 225 | ||||||||
Total | 2,238 | 2,250 | 1,963 | ||||||||
Operating Income | 608 | 596 | 614 | ||||||||
Other Income (Expense): | |||||||||||
Interest and other finance charges | (118 | ) | (109 | ) | (99 | ) | |||||
Interest on transition and system restoration bonds | (105 | ) | (118 | ) | (133 | ) | |||||
Other, net | 21 | 14 | 33 | ||||||||
Total | (202 | ) | (213 | ) | (199 | ) | |||||
Income Before Income Taxes | 406 | 383 | 415 | ||||||||
Income tax expense | 145 | 131 | 146 | ||||||||
Net Income | $ | 261 | $ | 252 | $ | 269 | |||||
See Notes to Consolidated Financial Statements
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CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES
(An Indirect, Wholly-Owned Subsidiary of CenterPoint Energy, Inc.)
CONSOLIDATED BALANCE SHEETS
December 31, | |||||||
2015 | 2014 | ||||||
(in millions) | |||||||
ASSETS | |||||||
Current Assets: | |||||||
Cash and cash equivalents ($264 and $290 related to VIEs, respectively) | $ | 264 | $ | 290 | |||
Accounts and notes receivable, net ($64 and $58 related to VIEs, respectively), less bad debt reserve of $1 and $3, respectively | 234 | 237 | |||||
Accounts and notes receivable—affiliated companies | 16 | 119 | |||||
Accrued unbilled revenues | 96 | 96 | |||||
Inventory | 133 | 126 | |||||
Taxes receivable | 59 | 103 | |||||
Other ($35 and $47 related to VIEs, respectively) | 63 | 74 | |||||
Total current assets | 865 | 1,045 | |||||
Property, Plant and Equipment, net | 6,933 | 6,343 | |||||
Other Assets: | |||||||
Regulatory assets ($2,373 and $2,738 related to VIEs, respectively) | 2,211 | 2,629 | |||||
Other | 37 | 34 | |||||
Total other assets | 2,248 | 2,663 | |||||
Total Assets | $ | 10,046 | $ | 10,051 | |||
LIABILITIES AND MEMBER’S EQUITY | |||||||
Current Liabilities: | |||||||
Current portion of VIE transition and system restoration bonds long-term debt | $ | 391 | $ | 372 | |||
Accounts payable | 153 | 148 | |||||
Accounts and notes payable—affiliated companies | 348 | 121 | |||||
Taxes accrued | 100 | 104 | |||||
Interest accrued | 70 | 75 | |||||
Other | 69 | 109 | |||||
Total current liabilities | 1,131 | 929 | |||||
Other Liabilities: | |||||||
Deferred income taxes, net | 2,032 | 1,999 | |||||
Benefit obligations | 192 | 260 | |||||
Regulatory liabilities | 542 | 537 | |||||
Other | 59 | 54 | |||||
Total other liabilities | 2,825 | 2,850 | |||||
Long-Term Debt: | |||||||
VIE transition and system restoration bonds | 2,283 | 2,674 | |||||
Other long-term debt | 2,206 | 2,006 | |||||
Total long-term debt | 4,489 | 4,680 | |||||
Commitments and Contingencies (Note 10) | |||||||
Member’s Equity | 1,601 | 1,592 | |||||
Total Liabilities and Member’s Equity | $ | 10,046 | $ | 10,051 | |||
See Notes to Consolidated Financial Statements
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CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES
(An Indirect, Wholly-Owned Subsidiary of CenterPoint Energy, Inc.)
STATEMENTS OF CONSOLIDATED CASH FLOWS
Year Ended December 31, | |||||||||||
2015 | 2014 | 2013 | |||||||||
(in millions) | |||||||||||
Cash Flows from Operating Activities: | |||||||||||
Net income | $ | 261 | $ | 252 | $ | 269 | |||||
Adjustments to reconcile net income to net cash provided by operating activities: | |||||||||||
Depreciation and amortization | 705 | 768 | 685 | ||||||||
Amortization of deferred financing costs | 15 | 16 | 16 | ||||||||
Deferred income taxes | 18 | (24 | ) | (75 | ) | ||||||
Changes in other assets and liabilities: | |||||||||||
Accounts and notes receivable, net | 3 | 15 | (46 | ) | |||||||
Accounts receivable/payable–affiliated companies | 223 | 37 | (5 | ) | |||||||
Inventory | (7 | ) | (21 | ) | (11 | ) | |||||
Accounts payable | — | (3 | ) | 48 | |||||||
Taxes receivable | 44 | (103 | ) | 7 | |||||||
Interest and taxes accrued | (9 | ) | (40 | ) | 37 | ||||||
Net regulatory assets and liabilities | 3 | (28 | ) | (6 | ) | ||||||
Other current assets | (1 | ) | (2 | ) | (2 | ) | |||||
Other current liabilities | (40 | ) | (19 | ) | 16 | ||||||
Other assets | (7 | ) | 11 | (11 | ) | ||||||
Other liabilities | (1 | ) | 5 | 6 | |||||||
Other, net | — | (6 | ) | — | |||||||
Net cash provided by operating activities | 1,207 | 858 | 928 | ||||||||
Cash Flows from Investing Activities: | |||||||||||
Capital expenditures | (929 | ) | (804 | ) | (753 | ) | |||||
Decrease (increase) in notes receivable–affiliated companies | 107 | (107 | ) | 1,183 | |||||||
Decrease (increase) in restricted cash of transition and system restoration bond companies | 12 | (7 | ) | 17 | |||||||
Other, net | 1 | 1 | (2 | ) | |||||||
Net cash provided by (used in) investing activities | (809 | ) | (917 | ) | 445 | ||||||
Cash Flows from Financing Activities: | |||||||||||
Proceeds from long-term debt | — | 600 | — | ||||||||
Payments of long-term debt | (372 | ) | (537 | ) | (897 | ) | |||||
Long-term revolving credit facility | 200 | — | — | ||||||||
Dividend to parent | (252 | ) | — | (766 | ) | ||||||
Decrease in notes payable–affiliated companies | — | (3 | ) | (148 | ) | ||||||
Cash paid for debt retirements | — | (1 | ) | (2 | ) | ||||||
Debt issuance costs | — | (7 | ) | — | |||||||
Contribution from parent | — | 90 | — | ||||||||
Other, net | — | — | 1 | ||||||||
Net cash provided by (used in) financing activities | (424 | ) | 142 | (1,812 | ) | ||||||
Net Increase (Decrease) in Cash and Cash Equivalents | (26 | ) | 83 | (439 | ) | ||||||
Cash and Cash Equivalents at Beginning of the Year | 290 | 207 | 646 | ||||||||
Cash and Cash Equivalents at End of the Year | $ | 264 | $ | 290 | $ | 207 | |||||
Supplemental Disclosure of Cash Flow Information: | |||||||||||
Cash Payments: | |||||||||||
Interest, net of capitalized interest | $ | 213 | $ | 215 | $ | 238 | |||||
Income taxes | 81 | 296 | 147 | ||||||||
Non-cash transactions: | |||||||||||
Accounts payable related to capital expenditures | $ | 69 | $ | 64 | $ | 50 | |||||
See Notes to Consolidated Financial Statements
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CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES
(An Indirect, Wholly-Owned Subsidiary of CenterPoint Energy, Inc.)
STATEMENTS OF CONSOLIDATED MEMBER’S EQUITY
2015 | 2014 | 2013 | ||||||||||||||||||
Shares | Amount | Shares | Amount | Shares | Amount | |||||||||||||||
(in millions, except share amounts) | ||||||||||||||||||||
Preference Stock, none outstanding | — | $ | — | — | $ | — | — | $ | — | |||||||||||
Cumulative Preferred Stock, $0.01 par value; authorized 20,000,000 shares, none outstanding | — | — | — | — | — | — | ||||||||||||||
Common Stock, $0.01 par value; authorized 1,000,000,000 shares | ||||||||||||||||||||
Balance, beginning of year | 1,000 | — | 1,000 | — | 1,000 | — | ||||||||||||||
Balance, end of year | 1,000 | — | 1,000 | — | 1,000 | — | ||||||||||||||
Additional Paid-in-Capital | ||||||||||||||||||||
Balance, beginning of year | 1,322 | 1,232 | 1,231 | |||||||||||||||||
Contribution from parent | — | 90 | — | |||||||||||||||||
Other | — | — | 1 | |||||||||||||||||
Balance, end of year | 1,322 | 1,322 | 1,232 | |||||||||||||||||
Retained Earnings | ||||||||||||||||||||
Balance, beginning of year | 270 | 18 | 515 | |||||||||||||||||
Net income | 261 | 252 | 269 | |||||||||||||||||
Dividend to parent | (252 | ) | — | (766 | ) | |||||||||||||||
Balance, end of year | 279 | 270 | 18 | |||||||||||||||||
Total Member’s Equity | $ | 1,601 | $ | 1,592 | $ | 1,250 | ||||||||||||||
See Notes to Consolidated Financial Statements
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CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES
(An Indirect, Wholly-Owned Subsidiary of CenterPoint Energy, Inc.)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(1) | Background |
CenterPoint Energy Houston Electric, LLC (CenterPoint Houston) engages in the electric transmission and distribution business in the Texas Gulf Coast area that includes the city of Houston. CenterPoint Houston is an indirect, wholly-owned subsidiary of CenterPoint Energy, Inc. (CenterPoint Energy), a public utility holding company. As of December 31, 2015, CenterPoint Houston had the following subsidiaries: CenterPoint Energy Transition Bond Company, LLC, CenterPoint Energy Transition Bond Company II, LLC, CenterPoint Energy Transition Bond Company III, LLC, CenterPoint Energy Restoration Bond Company, LLC and CenterPoint Energy Transition Bond Company IV, LLC (Bond Company IV) (collectively, the transition and system restoration bond companies). Each is a special purpose Delaware limited liability company formed solely for the purpose of purchasing and owning transition or system restoration property through the issuance of transition bonds or system restoration bonds and activities incidental thereto.
Because CenterPoint Houston is an indirect, wholly-owned subsidiary of CenterPoint Energy, CenterPoint Houston’s determination of reportable business segments considers the strategic operating units under which CenterPoint Energy manages sales, allocates resources and assesses performance of various products and services to wholesale or retail customers in differing regulatory environments. The accounting policies of the business segments are the same as those described in the summary of significant accounting policies except that some executive benefit costs have not been allocated to CenterPoint Houston. CenterPoint Houston uses operating income as the measure of profit or loss for its business segments. CenterPoint Houston consists of a single reportable segment: Electric Transmission & Distribution.
(2) | Summary of Significant Accounting Policies |
(a) Use of Estimates
The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
(b) Principles of Consolidation
The accounts of CenterPoint Houston and its wholly-owned subsidiaries are included in CenterPoint Houston’s consolidated financial statements. All intercompany transactions and balances are eliminated in consolidation. As of December 31, 2015, CenterPoint Houston had variable interest entities (VIEs) consisting of transition and system restoration bond companies, which it consolidates. The consolidated VIEs are wholly-owned bankruptcy remote special purpose entities that were formed specifically for the purpose of securitizing transition and system restoration related property. Creditors of CenterPoint Houston have no recourse to any assets or revenues of the transition and system restoration bond companies. The bonds issued by these VIEs are payable only from and secured by transition and system restoration property and the bondholders have no recourse to the general credit of CenterPoint Houston.
(c) Revenues
CenterPoint Houston records revenue for electricity delivery under the accrual method and these revenues are recognized upon delivery to customers. Electricity deliveries not billed by month-end are accrued based on actual advanced metering system data, daily supply volumes and applicable rates.
(d) Long-Lived Assets and Intangibles
CenterPoint Houston records property, plant and equipment at historical cost. CenterPoint Houston expenses repair and maintenance costs as incurred.
CenterPoint Houston periodically evaluates long-lived assets, including property, plant and equipment, and specifically identifiable intangibles, when events or changes in circumstances indicate that the carrying value of these assets may not be
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recoverable. The determination of whether an impairment has occurred is based on an estimate of undiscounted cash flows attributable to the assets compared to the carrying value of the assets.
(e) Regulatory Assets and Liabilities
CenterPoint Houston applies the guidance for accounting for regulated operations. CenterPoint Houston’s rate-regulated subsidiaries may collect revenues subject to refund pending final determination in rate proceedings. In connection with such revenues, estimated rate refund liabilities are recorded which reflect management’s current judgment of the ultimate outcomes of the proceedings.
CenterPoint Houston recognizes removal costs as a component of depreciation expense in accordance with regulatory treatment. As of December 31, 2015 and 2014, these removal costs of $350 million and $353 million, respectively, are classified as regulatory liabilities in CenterPoint Houston’s Consolidated Balance Sheets. In addition, a portion of the amount of removal costs that relate to asset retirement obligations has been reclassified from a regulatory liability to an asset retirement liability in accordance with accounting guidance for asset retirement obligations.
(f) Depreciation and Amortization Expense
Depreciation is computed using the straight-line method based on economic lives or a regulatory-mandated recovery period. Transition and system restoration property is being amortized over the expected life of the transition and system restoration bonds (12 to 14 years), based on estimated revenue from transition or system restoration charges, interest accruals and other expenses. Other amortization expense includes amortization of regulatory assets and other intangibles.
(g) Allowance for Funds Used During Construction
Allowance for funds used during construction (AFUDC) is capitalized as a component of projects under construction and is amortized over the assets’ estimated useful lives once the assets are placed in service. AFUDC represents the composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction. Although AFUDC increases both utility plant and earnings, it is realized in cash when the assets are included in rates. During 2015, 2014 and 2013, CenterPoint Houston capitalized AFUDC interest of $8 million, $10 million and $10 million, respectively. During 2015, 2014 and 2013, CenterPoint Energy recorded AFUDC equity of $12 million, $14 million and $8 million, respectively, which is included in Other Income in its Statements of Consolidated Income.
(h) Income Taxes
CenterPoint Houston is included in the consolidated income tax returns of CenterPoint Energy. CenterPoint Houston calculates its income tax provision on a separate return basis under a tax sharing agreement with CenterPoint Energy. CenterPoint Houston uses the asset and liability method of accounting for deferred income taxes. Deferred income tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. A valuation allowance is established against deferred tax assets for which management believes realization is not considered to be more likely than not. CenterPoint Houston recognizes interest and penalties as a component of income tax expense. Current federal and certain state income taxes are payable to or receivable from CenterPoint Energy.
(i) Accounts Receivable and Allowance for Doubtful Accounts
Accounts receivable are recorded at the invoiced amount and do not bear interest. It is the policy of management to review the outstanding accounts receivable monthly, as well as the bad debt write-offs experienced in the past, and establish an allowance for doubtful accounts. Account balances are charged off against the allowance when management determines it is probable the receivable will not be recovered. The provision for doubtful accounts in CenterPoint Houston’s Statements of Consolidated Income for 2015, 2014 and 2013 was less than $1 million, $3 million and $2 million, respectively.
(j) Inventory
Inventory consists principally of materials and supplies and is valued at the lower of average cost or market. Materials and supplies are recorded to inventory when purchased and subsequently charged to expense or capitalized to plant when installed.
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(k) Statements of Consolidated Cash Flows
For purposes of reporting cash flows, CenterPoint Houston considers cash equivalents to be short-term, highly-liquid investments with maturities of three months or less from the date of purchase. In connection with the issuance of transition bonds and system restoration bonds, CenterPoint Houston was required to establish restricted cash accounts to collateralize the bonds that were issued in these financing transactions. These restricted cash accounts are not available for withdrawal until the maturity of the bonds and are not included in cash and cash equivalents. These restricted cash accounts of $35 million and $47 million as of December 31, 2015 and 2014, respectively, are included in other current assets in CenterPoint Houston’s Consolidated Balance Sheets. For additional information regarding transition and system restoration bonds, see Note 8. Cash and cash equivalents included $264 million and $290 million as of December 31, 2015 and 2014, respectively, that was held by CenterPoint Houston’s transition and system restoration bond subsidiaries solely to support servicing the transition and system restoration bonds.
(l) New Accounting Pronouncements
In February 2015, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis (ASU 2015-02). ASU 2015-02 changes the analysis that reporting organizations must perform to evaluate whether they should consolidate certain legal entities, such as limited partnerships. The changes include, among others, modification of the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities and elimination of the presumption that a general partner should consolidate a limited partnership. ASU 2015-02 does not amend the related party guidance for situations in which power is shared between two or more entities that hold interests in a VIE. ASU 2015-02 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015. CenterPoint Houston does not believe that ASU 2015-02 will have a material impact on its financial position, results of operations, cash flows and disclosures.
In April 2015, the FASB issued Accounting Standards Update No. 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Cost (ASU 2015-03). ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by ASU 2015-03. CenterPoint Houston will adopt ASU 2015-03 retrospectively on January 1, 2016, which will result in a reduction of both other long-term assets and long-term debt on its Consolidated Balance Sheets. CenterPoint Houston had debt issuance costs of $22 million and $26 million included in other long-term assets on its Consolidated Balance Sheets as of December 31, 2015 and 2014, respectively.
In April 2015, the FASB issued Accounting Standards Update No. 2015-05, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40) (ASU 2015-05). ASU 2015-05 provides guidance to customers about whether a cloud computing arrangement includes a software license. If a cloud computing arrangement includes a software license, the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses. If a cloud computing arrangement does not include a software license, the customer should account for the arrangement as a service contract. The guidance will not change a customer’s accounting for service contracts. ASU 2015-05 is effective for fiscal years, and interim periods within the fiscal years, beginning after December 15, 2015 and may be adopted either prospectively or retrospectively. CenterPoint Houston will adopt ASU 2015-05 prospectively on January 1, 2016. CenterPoint Houston does not believe that ASU 2015-05 will have a material impact on its financial position, results of operations, cash flows and disclosures.
In May 2014, the FASB issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (Topic 606) (ASU 2014-09), which supersedes most current revenue recognition guidance. ASU 2014-09 provides a comprehensive new revenue recognition model that requires revenue to be recognized in a manner that depicts the transfer of goods or services to a customer at an amount that reflects the consideration expected to be received in exchange for those goods or services. ASU 2014-09 was initially effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Early adoption is not permitted, and entities have the option of using either a full retrospective or a modified retrospective adoption approach. In August 2015, the FASB issued Accounting Standard Update No. 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date, which delays the effective date of ASU 2014-09 by one year. CenterPoint Houston is currently evaluating the impact that ASU 2014-09 will have on its financial position, results of operations, cash flows and disclosures, and will adopt ASU 2014-09 on January 1, 2018 as permitted by the new guidance.
In July 2015, the FASB issued Accounting Standards Update No. 2015-11, Inventory (Topic 330) Simplifying the Measurement of Inventory (ASU 2015-11). ASU 2015-11 changes the subsequent measurement guidance for inventory accounted for using methods other than the last in, first out (LIFO) and Retail Inventory methods. Companies will subsequently measure inventory at the lower of cost and net realizable value. Net realizable value is the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. Subsequent measurement is unchanged for inventory measured using
36
LIFO or the retail inventory method. ASU 2015-11 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016, with early adoption permitted. CenterPoint Houston does not believe that ASU 2015-11 will have a material impact on its financial position, results of operations, cash flows and disclosures.
In November 2015, the FASB issued Accounting Standards Update No. 2015-17, Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes (ASU 2015-17). ASU 2015-17 requires deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. CenterPoint Houston adopted ASU 2015-17 retrospectively starting with fiscal year 2015. As such, certain prior period amounts have been reclassified to conform to the current presentation. In the Consolidated Balance Sheet as of December 31, 2014, CenterPoint Houston reclassified $2 million from current deferred tax assets to reduce deferred income taxes within non-current liabilities. See Note 9 for additional information.
Management believes that other recently issued standards, which are not yet effective, will not have a material impact on CenterPoint Energy’s consolidated financial position, results of operations or cash flows upon adoption.
(m) Other Current Liabilities
Included in other current liabilities in the Consolidated Balance Sheets as of December 31, 2015 and 2014 was $12 million and $24 million, respectively, of customer deposits primarily held by the transition and system restoration bond companies.
(n) Environmental Costs
CenterPoint Houston expenses or capitalizes environmental expenditures, as appropriate, depending on their future economic benefit. CenterPoint Houston expenses amounts that relate to an existing condition caused by past operations that do not have future economic benefit. CenterPoint Houston records undiscounted liabilities related to these future costs when environmental assessments and/or remediation activities are probable and the costs can be reasonably estimated.
(3) | Property, Plant and Equipment |
(a) Property, Plant and Equipment
Property, plant and equipment includes the following:
Weighted Average Useful | December 31, | ||||||||
Lives (Years) | 2015 | 2014 | |||||||
(in millions) | |||||||||
Transmission | 41 | $ | 2,196 | $ | 2,057 | ||||
Distribution | 30 | 6,556 | 6,170 | ||||||
Other | 16 | 1,390 | 1,166 | ||||||
Total | 10,142 | 9,393 | |||||||
Accumulated depreciation | 3,209 | 3,050 | |||||||
Property, plant and equipment, net | $ | 6,933 | $ | 6,343 | |||||
(b) Depreciation and Amortization
The following table presents depreciation and amortization expense for 2015, 2014 and 2013:
Year Ended December 31, | |||||||||||
2015 | 2014 | 2013 | |||||||||
(in millions) | |||||||||||
Depreciation expense | $ | 316 | $ | 295 | $ | 280 | |||||
Amortization of securitized regulatory assets | 365 | 441 | 383 | ||||||||
Other amortization | 24 | 32 | 22 | ||||||||
Total depreciation and amortization | $ | 705 | $ | 768 | $ | 685 | |||||
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(c) Asset Retirement Obligations
A reconciliation of the changes in the asset retirement obligation (ARO) liability is as follows:
December 31, | |||||||
2015 | 2014 | ||||||
(in millions) | |||||||
Beginning balance | $ | 36 | $ | 33 | |||
Accretion expense | 1 | 1 | |||||
Revisions in estimates of cash flows | — | 2 | |||||
Ending balance | $ | 37 | $ | 36 | |||
CenterPoint Houston recorded AROs associated with the removal of asbestos and asbestos-containing material in its buildings, including substation building structures. CenterPoint Houston also recorded AROs relating to treated wood poles for electric distribution, distribution transformers containing PCB (also known as Polychlorinated Biphenyl), and underground fuel storage tanks. The estimates of future liabilities were developed using historical information, and where available, quoted prices from outside contractors.
The increase of $2 million in the ARO from the revision of estimate in 2014 is primarily attributable to an increase in the expected future cash flows for asbestos remediation. There were no material additions or settlements during the years ended December 31, 2015 and 2014.
(4) | Regulatory Matters |
The following is a list of regulatory assets/liabilities reflected on CenterPoint Houston’s Consolidated Balance Sheets as of December 31, 2015 and 2014:
December 31, | |||||||
2015 | 2014 | ||||||
(in millions) | |||||||
Securitized regulatory assets | $ | 2,373 | $ | 2,738 | |||
Unrecognized equity return (1) | (393 | ) | (442 | ) | |||
Unamortized loss on reacquired debt | 93 | 104 | |||||
Pension and postretirement-related regulatory asset | 50 | 107 | |||||
Other long-term regulatory assets (2) | 88 | 122 | |||||
Total regulatory assets | 2,211 | 2,629 | |||||
Estimated removal costs | 350 | 353 | |||||
Other long-term regulatory liabilities | 192 | 184 | |||||
Total regulatory liabilities | 542 | 537 | |||||
Total regulatory assets and liabilities, net | $ | 1,669 | $ | 2,092 | |||
(1) | As of December 31, 2015, CenterPoint Houston has not recognized an allowed equity return of $393 million because such return will be recognized as it is recovered in rates through 2024. During the years ended December 31, 2015, 2014 and 2013, CenterPoint Houston recognized approximately $49 million, $68 million and $45 million, respectively, of the allowed equity return. The timing of CenterPoint Houston’s recognition of the allowed equity return will vary each period based on amounts actually collected during the period. The actual amounts recovered for the allowed equity return are reviewed and adjusted at least annually by the Texas Utility Commission to correct any over-collections or under-collections during the preceding 12 months and to provide for the full and timely recovery of the allowed equity return. |
(2) | Other regulatory assets that are not earning a return were not material as of December 31, 2015 and 2014. |
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(5) | Employee Benefit Plans |
(a) Pension Plans
Substantially all of CenterPoint Houston’s employees participate in CenterPoint Energy’s non-contributory qualified defined benefit plan. Under the cash balance formula, participants accumulate a retirement benefit based upon 5% of eligible earnings and accrued interest.
CenterPoint Energy’s funding policy is to review amounts annually in accordance with applicable regulations in order to achieve adequate funding of projected benefit obligations. Pension expense is allocated to CenterPoint Houston based on covered employees. This calculation is intended to allocate pension costs in the same manner as a separate employer plan. Assets of the plan are not segregated or restricted by CenterPoint Energy’s participating subsidiaries. CenterPoint Houston recognized pension expense of $35 million, $26 million and $25 million for the years ended December 31, 2015, 2014 and 2013, respectively.
In addition to the pension plan, CenterPoint Houston participates in CenterPoint Energy’s non-qualified benefit restoration plans, which allow participants to receive the benefits to which they would have been entitled under the non-contributory pension plan except for federally mandated limits on qualified plan benefits or on the level of compensation on which qualified plan benefits may be calculated. The expense associated with the non-qualified pension plan was $1 million for each of the years ended December 31, 2015, 2014 and 2013.
(b) Savings Plan
CenterPoint Houston participates in CenterPoint Energy’s qualified savings plan, which includes a cash or deferred arrangement under Section 401(k) of the Internal Revenue Code of 1986, as amended (the Code), and an Employee Stock Ownership Plan (ESOP) under Section 4975(e)(7) of the Code. Under the plan, participating employees may contribute a portion of their compensation, on a pre-tax or after-tax basis, generally up to a maximum of 50% of eligible compensation. CenterPoint Houston matches 100% of the first 6% of each employee’s compensation contributed. The matching contributions are fully vested at all times.
Participating employees may elect to invest all (prior to January 1, 2016) or a portion of their contributions to the plan in CenterPoint Energy common stock, to have dividends reinvested in additional shares or to receive dividend payments in cash on any investment in CenterPoint Energy common stock, and to transfer all or part of their investment in CenterPoint Energy common stock to other investment options offered by the plan.
Effective January 1, 2016 the savings plan was amended to limit the percentage of future contributions that could be invested in CenterPoint Energy common stock to 25% and to prohibit transfers of account balances where the transfer would result in more than 25% of a participant’s total account balance invested in CenterPoint Energy common stock.
The savings plan has significant holdings of CenterPoint Energy common stock. As of December 31, 2015, 16,942,974 shares of CenterPoint Energy’s common stock were held by the savings plan, which represented approximately 17% of its investments. Given the concentration of the investments in CenterPoint Energy’s common stock, the savings plan and its participants have market risk related to this investment.
CenterPoint Energy allocates to CenterPoint Houston the savings plan benefit expense related to CenterPoint Houston’s employees. Savings plan benefit expense was $14 million, $13 million and $13 million for each of the years ended December 31, 2015, 2014 and 2013.
(c) Postretirement Benefits
CenterPoint Houston’s employees participate in CenterPoint Energy’s benefit plans which provide certain healthcare and life insurance benefits for retired employees on both a contributory and non-contributory basis. Employees become eligible for these benefits if they have met certain age and service requirements at retirement, as defined in the plans. Under plan amendments effective in early 1999, healthcare benefits for future retirees were changed to limit employer contributions for medical coverage. Such benefit costs are accrued over the active service period of employees.
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CenterPoint Houston is required to fund a portion of its obligations in accordance with rate orders. The net postretirement benefit cost includes the following components:
Year Ended December 31, | |||||||||||
2015 | 2014 | 2013 | |||||||||
(in millions) | |||||||||||
Service cost - benefits earned during the period | $ | 1 | $ | 1 | $ | 1 | |||||
Interest cost on accumulated benefit obligation | 13 | 14 | 13 | ||||||||
Expected return on plan assets | (6 | ) | (6 | ) | (7 | ) | |||||
Amortization of transition obligation | — | 4 | 6 | ||||||||
Amortization of prior service credit | (2 | ) | (2 | ) | (1 | ) | |||||
Amortization of loss | 3 | 1 | 4 | ||||||||
Net postretirement benefit cost | $ | 9 | $ | 12 | $ | 16 | |||||
CenterPoint Houston used the following assumptions to determine net postretirement benefit costs:
Year Ended December 31, | ||||||||
2015 | 2014 | 2013 | ||||||
Discount rate | 3.90 | % | 4.75 | % | 3.90 | % | ||
Expected return on plan assets | 5.45 | % | 6.00 | % | 6.00 | % | ||
In determining net periodic benefits cost, CenterPoint Houston uses fair value, as of the beginning of the year, as its basis for determining expected return on plan assets.
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Following are reconciliations of CenterPoint Houston’s beginning and ending balances of its postretirement benefit plan’s benefit obligation, plan assets and funded status for 2015 and 2014. The measurement dates for plan assets and obligations were December 31, 2015 and 2014.
December 31, | |||||||
2015 | 2014 | ||||||
(in millions) | |||||||
Change in Benefit Obligation | |||||||
Accumulated benefit obligation, beginning of year | $ | 347 | $ | 311 | |||
Service cost | 1 | 1 | |||||
Interest cost | 13 | 14 | |||||
Benefits paid | (17 | ) | (18 | ) | |||
Participant contributions | 3 | 3 | |||||
Medicare drug reimbursement | 1 | 1 | |||||
Plan amendment | (4 | ) | — | ||||
Actuarial (gain) loss | (61 | ) | 35 | ||||
Accumulated benefit obligation, end of year | $ | 283 | $ | 347 | |||
Change in Plan Assets | |||||||
Plan assets, beginning of year | $ | 115 | $ | 114 | |||
Benefits paid | (17 | ) | (18 | ) | |||
Employer contributions | 9 | 9 | |||||
Participant contributions | 3 | 3 | |||||
Actual investment return | — | 7 | |||||
Plan assets, end of year | $ | 110 | $ | 115 | |||
Amounts Recognized in Balance Sheets | |||||||
Other liabilities-benefit obligations | $ | (173 | ) | $ | (232 | ) | |
Net liability, end of year | $ | (173 | ) | $ | (232 | ) | |
Actuarial Assumptions | |||||||
Discount rate | 4.35 | % | 3.90 | % | |||
Expected long-term return on assets | 5.00 | % | 5.45 | % | |||
Healthcare cost trend rate assumed for the next year - Pre 65 | 6.00 | % | 7.25 | % | |||
Healthcare cost trend rate assumed for the next year - Post 65 | 5.50 | % | 8.50 | % | |||
Prescription drug cost trend rate assumed for the next year | 11.00 | % | 6.50 | % | |||
Rate to which the cost trend rate is assumed to decline (ultimate trend rate) | 5.00 | % | 5.00 | % | |||
Year that the healthcare rate reaches the ultimate trend rate | 2024 | 2024 | |||||
Year that the prescription drug rate reaches the ultimate trend rate | 2024 | 2024 | |||||
The discount rate assumption was determined by matching the projected cash flows of CenterPoint Energy’s plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.
The expected rate of return assumption was developed by a weighted-average return analysis of the targeted asset allocation of CenterPoint Energy’s plans and the expected real return for each asset class, based on the long-term capital market assumptions, adjusted for investment fees and diversification effects, in addition to expected inflation.
For measurement purposes, medical costs are assumed to increase 6.00% and 5.50% for the pre-65 and post-65 retirees during 2016, respectively, and the prescription cost is assumed to increase 11.00% during 2016, after which these rates decrease until reaching the ultimate trend rate of 5.00% in 2024.
CenterPoint Houston does not have amounts recognized in accumulated other comprehensive income related to its postretirement benefit plans as of December 31, 2015 and 2014. Unrecognized costs were recorded as a regulatory asset because CenterPoint Houston historically and currently recovers postretirement expenses in rates.
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Assumed healthcare cost trend rates have a significant effect on the reported amounts for CenterPoint Houston’s postretirement benefit plans. A 1% change in the assumed healthcare cost trend rate would have the following effects:
1% Increase | 1% Decrease | ||||||
(in millions) | |||||||
Effect on the postretirement benefit obligation | $ | 9 | $ | 8 | |||
Effect on total of service and interest cost | — | — | |||||
In managing the investments associated with the postretirement benefit plans, CenterPoint Houston’s objective is to preserve and enhance the value of plan assets while maintaining an acceptable level of volatility. These objectives are expected to be achieved through an investment strategy that manages liquidity requirements while maintaining a long-term horizon in making investment decisions and efficient and effective management of plan assets.
As part of the investment strategy discussed above, CenterPoint Houston has adopted and maintained the following asset allocation ranges for its postretirement benefit plans:
U.S. equity | 14–24% |
International equity | 3–13% |
Fixed income | 68–78% |
Cash | 0–2% |
The following tables present by level, within the fair value hierarchy, CenterPoint Houston’s postretirement plan assets as of December 31, 2015 and 2014, by asset category as follows:
Fair Value Measurements as of December 31, 2015 | |||||||||||||||
Total | Quoted Prices in Active Markets for Identical Assets (Level 1) | Significant Observable Inputs (Level 2) | Significant Unobservable Inputs (Level 3) | ||||||||||||
(in millions) | |||||||||||||||
Mutual funds (1) | $ | 110 | $ | 110 | $ | — | $ | — | |||||||
Total | $ | 110 | $ | 110 | $ | — | $ | — | |||||||
(1) | 73% of the amount invested in mutual funds was in fixed income securities; 19% was in U.S. equities and 8% was in international equities. |
Fair Value Measurements as of December 31, 2014 | |||||||||||||||
Total | Quoted Prices in Active Markets for Identical Assets (Level 1) | Significant Observable Inputs (Level 2) | Significant Unobservable Inputs (Level 3) | ||||||||||||
(in millions) | |||||||||||||||
Mutual funds (1) | $ | 115 | $ | 115 | $ | — | $ | — | |||||||
Total | $ | 115 | $ | 115 | $ | — | $ | — | |||||||
(1) | 73% of the amount invested in mutual funds was in fixed income securities; 19% was in U.S. equities and 8% was in international equities. |
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CenterPoint Houston expects to contribute $7 million to its postretirement benefits plan in 2016. The following benefit payments are expected to be paid by the postretirement benefit plan:
Postretirement Benefit Plan | |||||||
Benefit Payments | Medicare Subsidy Receipts | ||||||
(in millions) | |||||||
2016 | $ | 20 | $ | (2 | ) | ||
2017 | 21 | (2 | ) | ||||
2018 | 22 | (3 | ) | ||||
2019 | 23 | (3 | ) | ||||
2020 | 24 | (3 | ) | ||||
2021-2025 | 124 | (19 | ) | ||||
(d) Postemployment Benefits
CenterPoint Houston participates in CenterPoint Energy’s plan which provides postemployment benefits for certain former or inactive employees, their beneficiaries and covered dependents, after employment but before retirement (primarily health care and life insurance benefits for participants in the long-term disability plan). CenterPoint Houston recorded a postemployment credit of $1 million, and expenses of $1 million and $4 million for the years ended December 31, 2015, 2014 and 2013, respectively. Amounts relating to postemployment obligations included in Benefit Obligations in the accompanying Consolidated Balance Sheets as of December 31, 2015 and 2014 were $6 million and $14 million, respectively.
(e) Other Non-Qualified Plans
CenterPoint Houston participates in CenterPoint Energy’s deferred compensation plans that provide benefits payable to directors, officers and certain key employees or their designated beneficiaries at specified future dates, upon termination, retirement or death. Benefit payments are made from the general assets of CenterPoint Houston. CenterPoint Houston recorded benefit expense relating to these plans of $1 million in each of the years ended December 31, 2015, 2014 and 2013. Amounts relating to deferred compensation plans included in Benefit Obligations in the accompanying Consolidated Balance Sheets as of December 31, 2015 and 2014 were $11 million and $12 million, respectively.
(f) Other Employee Matters
As of December 31, 2015, CenterPoint Houston had 2,665 full-time employees, of which approximately 51% were subject to a collective bargaining agreement. The collective bargaining agreement with the International Brotherhood of Electrical Workers Local 66 is scheduled to expire in May of 2016. CenterPoint Houston believes it has a good relationship with this bargaining unit and expects to negotiate a new agreement in 2016.
(6) | Fair Value Measurements |
Assets and liabilities that are recorded at fair value in the Consolidated Balance Sheets are categorized based upon the level of judgment associated with the inputs used to measure their value. Hierarchical levels, as defined below and directly related to the amount of subjectivity associated with the inputs to fair valuations of these assets and liabilities, are as follows:
Level 1: Inputs are unadjusted quoted prices in active markets for identical assets or liabilities at the measurement date. The types of assets carried at Level 1 fair value are investments listed in active markets. At December 31, 2015 and 2014, CenterPoint Houston held Level 1 investments of $32 million and $43 million, respectively, which were primarily investments in money market funds and are included in other current assets in the Consolidated Balance Sheets.
Level 2: Inputs, other than quoted prices included in Level 1, are observable for the asset or liability, either directly or indirectly. Level 2 inputs include quoted prices for similar instruments in active markets, and inputs other than quoted prices that are observable for the asset or liability. CenterPoint Houston had no Level 2 assets or liabilities at either December 31, 2015 and 2014.
Level 3: Inputs are unobservable for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability. Unobservable inputs reflect CenterPoint Houston’s judgments about the assumptions market participants would use in determining fair value. CenterPoint Houston had no Level 3 assets or liabilities at either December 31, 2015 and 2014.
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CenterPoint Houston determines the appropriate level for each financial asset and liability on a quarterly basis and recognizes transfers between levels at the end of the reporting period. For the years ended December 31, 2015 and 2014, there were no transfers between levels.
Estimated Fair Value of Financial Instruments
The fair values of cash and cash equivalents and short-term borrowings are estimated to be approximately equivalent to carrying amounts and have been excluded from the table below. The fair value of each debt instrument is determined by multiplying the principal amount of each debt instrument by the market price. These assets and liabilities, which are not measured at fair value in the Consolidated Balance Sheets but for which the fair value is disclosed, would be classified as Level 1 in the fair value hierarchy.
December 31, 2015 | December 31, 2014 | ||||||||||||||
Carrying Amount | Fair Value | Carrying Amount | Fair Value | ||||||||||||
(in millions) | |||||||||||||||
Financial liabilities: | |||||||||||||||
Long-term debt, including current portion | $ | 4,880 | $ | 5,108 | $ | 5,052 | $ | 5,441 | |||||||
(7) | Related Party Transactions and Major Customers |
(a) Related Party Transactions
CenterPoint Houston participates in a money pool through which it can borrow or invest on a short-term basis. Funding needs are aggregated and external borrowing or investing is based on the net cash position. The net funding requirements of the money pool are expected to be met with borrowings under CenterPoint Energy’s revolving credit facility or the sale of CenterPoint Energy’s commercial paper. CenterPoint Houston had borrowings from the money pool of $312 million and investments in the money pool of $107 million as of December 31, 2015 and 2014, respectively, which are included in accounts and notes receivable-affiliated companies and accounts and notes payable-affiliated companies, respectively, in the Consolidated Balance Sheets. As of December 31, 2015, CenterPoint Houston’s money pool borrowings had a weighted-average interest rate of 0.80%.
For the years ended December 31, 2015, 2014 and 2013, CenterPoint Houston had affiliate related net interest income (expense) of $(1) million, less than $(1) million and $20 million, respectively.
CenterPoint Energy provides some corporate services to CenterPoint Houston. The costs of services have been charged directly to CenterPoint Houston using methods that management believes are reasonable. These methods include negotiated usage rates, dedicated asset assignment and proportionate corporate formulas based on operating expenses, assets, gross margin, employees and a composite of assets, gross margin and employees. CenterPoint Energy Resources Corp. (CERC Corp., and together with its subsidiaries, CERC) provides certain services to CenterPoint Houston. These services are billed at actual cost, either directly or as an allocation and include line locating and other miscellaneous services. Additionally, CenterPoint Houston provides a number of services to CERC. These services are billed at actual cost, either directly or as an allocation and include fleet services, shop services, geographic services, surveying and right-of-way, radio communications, data circuit management and field operations. These charges are not necessarily indicative of what would have been incurred had CenterPoint Houston not been an affiliate. Amounts charged to CenterPoint Houston for these services were as follows and are included primarily in operation and maintenance expenses:
Year Ended December 31, | ||||||||||||
2015 | 2014 | 2013 | ||||||||||
(in millions) | ||||||||||||
Corporate service charges | $ | 176 | $ | 159 | $ | 147 | ||||||
Charges from CERC for services provided | 6 | 5 | 9 | |||||||||
Billings to CERC for services provided | (18 | ) | (17 | ) | (21 | ) | ||||||
CenterPoint Houston paid dividends of $252 million, $-0- and $766 million on its common shares to Utility Holding, LLC in 2015, 2014 and 2013, respectively. In 2014, CenterPoint Energy made an equity contribution of $90 million to CenterPoint Houston.
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(b) Major Customers
CenterPoint Houston’s transmission and distribution revenues from major customers are as follows:
Year Ended December 31, | ||||||||||||
2015 | 2014 | 2013 | ||||||||||
(in millions) | ||||||||||||
Affiliates of NRG | $ | 741 | $ | 735 | $ | 658 | ||||||
Affiliates of Energy Future Holdings Corp. | $ | 220 | $ | 189 | $ | 167 | ||||||
(8) | Long-term Debt |
December 31, 2015 | December 31, 2014 | ||||||||||||||
Long-Term | Current (1) | Long-Term | Current (1) | ||||||||||||
(in millions) | |||||||||||||||
Long-term debt: | |||||||||||||||
Bank Loans | $ | 200 | $ | — | $ | — | $ | — | |||||||
First mortgage bonds 9.15% due 2021 | 102 | — | 102 | — | |||||||||||
General mortgage bonds 2.25% to 6.95% due 2022 to 2044 (2) | 1,912 | — | 1,912 | — | |||||||||||
System restoration bonds 3.46% to 4.243% due 2018 to 2022 | 365 | 50 | 415 | 48 | |||||||||||
Transition bonds 0.901% to 5.302% due 2017 to 2024 | 1,918 | 341 | 2,259 | 324 | |||||||||||
Other | (8 | ) | — | (8 | ) | — | |||||||||
Total long-term debt | $ | 4,489 | $ | 391 | $ | 4,680 | $ | 372 | |||||||
(1) | Includes amounts due or scheduled to be paid within one year of the date noted. |
(2) | Debt issued as collateral is excluded from the financial statements because of the contingent nature of the obligation. |
Transition and System Restoration Bonds. As of December 31, 2015, CenterPoint Houston had special purpose subsidiaries consisting of transition and system restoration bond companies, which it consolidates. The consolidated special purpose subsidiaries are wholly-owned bankruptcy remote entities that were formed solely for the purpose of purchasing and owning transition or system restoration property through the issuance of transition bonds or system restoration bonds and activities incidental thereto. These transition bonds and system restoration bonds are payable only through the imposition and collection of “transition” or “system restoration” charges, as defined in the Texas Public Utility Regulatory Act, which are irrevocable, non-bypassable charges payable by most of CenterPoint Houston’s retail electric customers in order to provide recovery of authorized qualified costs. CenterPoint Houston has no payment obligations in respect of the transition and system restoration bonds other than to remit the applicable transition or system restoration charges it collects. Each special purpose entity is the sole owner of the right to impose, collect and receive the applicable transition or system restoration charges securing the bonds issued by that entity. Creditors of CenterPoint Energy or CenterPoint Houston have no recourse to any assets or revenues of the transition and system restoration bond companies (including the transition and system restoration charges), and the holders of transition bonds or system restoration bonds have no recourse to the assets or revenues of CenterPoint Energy or CenterPoint Houston.
Revolving Credit Facility. As of December 31, 2015 and 2014, CenterPoint Houston had the following revolving credit facility and utilization of such facility:
December 31, 2015 | December 31, 2014 | |||||||||||||||||||||
Size of Facility | Loans | Letters of Credit | Size of Facility | Loans | Letters of Credit | |||||||||||||||||
(in millions) | ||||||||||||||||||||||
$ | 300 | $ | 200 | (1) | $ | 4 | $ | 300 | $ | — | $ | 4 | ||||||||||
(1) | Weighted average interest rate was 1.637% as of December 31, 2015. |
CenterPoint Houston’s $300 million revolving credit facility, which is scheduled to terminate on September 9, 2019, can be drawn at LIBOR plus 1.125% based on CenterPoint Houston’s current credit ratings. The revolving credit facility contains a financial covenant which limits CenterPoint Houston’s consolidated debt (excluding transition and system restoration bonds) to an amount
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not to exceed 65% of CenterPoint Houston’s consolidated capitalization. CenterPoint Houston was in compliance with all financial covenants as of December 31, 2015. As of December 31, 2015, CenterPoint Houston’s debt (excluding transition and system restoration bonds) to capital ratio, as defined in its credit facility agreement, was 51.7%.
Maturities. CenterPoint Houston has no maturities of long-term debt for 2016 through 2020 other than the maturity of $200 million of bank loans in 2019. CenterPoint Houston’s scheduled payments on transition and system restoration bonds are $391 million in 2016, $411 million in 2017, $434 million in 2018, $458 million in 2019 and $231 million in 2020.
Liens. As of December 31, 2015, CenterPoint Houston’s assets were subject to liens securing approximately $102 million of first mortgage bonds. Sinking or improvement fund and replacement fund requirements on the first mortgage bonds may be satisfied by certification of property additions. Sinking fund and replacement fund requirements for 2015, 2014 and 2013 have been satisfied by certification of property additions. The replacement fund requirement to be satisfied in 2016 is approximately $223 million, and the sinking fund requirement to be satisfied in 2016 is approximately $1.6 million. CenterPoint Houston expects to meet these 2016 obligations by certification of property additions. As of December 31, 2015, CenterPoint Houston’s assets were also subject to liens securing approximately $2.1 billion of general mortgage bonds which are junior to the liens of the first mortgage bonds.
(9) Income Taxes
The components of CenterPoint Houston’s income tax expense were as follows:
Year Ended December 31, | |||||||||||
2015 | 2014 | 2013 | |||||||||
(in millions) | |||||||||||
Current income tax expense: | |||||||||||
Federal | $ | 106 | $ | 136 | $ | 201 | |||||
State | 21 | 19 | 20 | ||||||||
Total current expense | 127 | 155 | 221 | ||||||||
Deferred income tax expense (benefit): | |||||||||||
Federal | 18 | (24 | ) | (75 | ) | ||||||
Total deferred expense (benefit) | 18 | (24 | ) | (75 | ) | ||||||
Total income tax expense | $ | 145 | $ | 131 | $ | 146 | |||||
A reconciliation of income tax expense using the federal statutory income tax rate to the actual income tax expense and resulting effective income tax rate is as follows:
Year Ended December 31, | |||||||||||
2015 | 2014 | 2013 | |||||||||
(in millions) | |||||||||||
Income before income taxes | $ | 406 | $ | 383 | $ | 415 | |||||
Federal statutory income tax rate | 35.0 | % | 35.0 | % | 35.0 | % | |||||
Expected federal income tax expense | 142 | 134 | 145 | ||||||||
Increase (decrease) in tax expense resulting from: | |||||||||||
State income tax expense, net of federal income tax | 14 | 12 | 13 | ||||||||
Decrease in settled and uncertain tax positions | — | — | (5 | ) | |||||||
Other, net | (11 | ) | (15 | ) | (7 | ) | |||||
Total | 3 | (3 | ) | 1 | |||||||
Total income tax expense | $ | 145 | $ | 131 | $ | 146 | |||||
Effective tax rate | 35.7 | % | 34.2 | % | 35.2 | % | |||||
In 2014, CenterPoint Houston recognized a $6 million reversal of previously accrued taxes as a result of final positions taken in the 2013 income tax returns. CenterPoint Houston recognized a tax benefit of $5 million from favorable audit settlements for the year ended December 31, 2013.
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The tax effects of temporary differences that give rise to significant portions of deferred tax assets and liabilities were as follows:
December 31, | |||||||
2015 | 2014 | ||||||
(in millions) | |||||||
Deferred tax assets: | |||||||
Benefits and compensation | $ | 69 | $ | 92 | |||
Loss and credit carryforwards | 6 | — | |||||
Asset retirement obligations | 13 | 12 | |||||
Other | 7 | 7 | |||||
Total deferred tax assets | 95 | 111 | |||||
Deferred tax liabilities: | |||||||
Property, plant, and equipment | 1,447 | 1,284 | |||||
Regulatory assets/liabilities, net | 680 | 826 | |||||
Total deferred tax liabilities | 2,127 | 2,110 | |||||
Net deferred tax liabilities | $ | 2,032 | $ | 1,999 | |||
Effective December 31, 2015, all deferred taxes for 2014 and 2015 are classified as noncurrent. See Note 2.
CenterPoint Houston is included in the consolidated income tax returns of CenterPoint Energy. CenterPoint Houston calculates its income tax provision on a separate return basis under a tax sharing agreement with CenterPoint Energy.
Uncertain Income Tax Positions. CenterPoint Houston reported no uncertain tax liability as of December 31, 2015 and expects no significant change to the uncertain tax liability over the next twelve months ending December 31, 2016.
Tax Audits and Settlements. CenterPoint Energy’s tax years through 2013 have been audited and settled with the Internal Revenue Service (IRS). For 2014 and 2015, CenterPoint Energy is a participant in the IRS’s Compliance Assurance Process. CenterPoint Energy has considered the effects of these examinations in its accrual for settled issues and liability for uncertain income tax positions (if any) as of December 31, 2015.
(10) | Commitments and Contingencies |
(a) Lease Commitments
CenterPoint Houston currently has obligations under non-cancelable long-term operating leases of less than $1 million per year for the years 2016 to 2020. Total lease expense for all operating leases was less than $1 million in each of the years ended December 31, 2015, 2014 and 2013.
(b) Legal and Environmental Matters
Legal Matters
Gas Market Manipulation Cases. CenterPoint Energy, CenterPoint Houston or their predecessor, Reliant Energy, Incorporated (Reliant Energy), and certain of their former subsidiaries have been named as defendants in certain lawsuits described below. Under a master separation agreement between CenterPoint Energy and a former subsidiary, Reliant Resources, Inc. (RRI), CenterPoint Energy and its subsidiaries are entitled to be indemnified by RRI and its successors for any losses, including certain attorneys’ fees and other costs, arising out of these lawsuits. In May 2009, RRI sold its Texas retail business to a subsidiary of NRG and RRI changed its name to RRI Energy, Inc. In December 2010, Mirant Corporation merged with and became a wholly-owned subsidiary of RRI, and RRI changed its name to GenOn Energy, Inc. (GenOn). In December 2012, NRG acquired GenOn through a merger in which GenOn became a wholly-owned subsidiary of NRG. None of the sale of the retail business, the merger with Mirant Corporation, or the acquisition of GenOn by NRG alters RRI’s (now GenOn’s) contractual obligations to indemnify CenterPoint Energy and its subsidiaries, including CenterPoint Houston, for certain liabilities, including their indemnification obligations regarding the gas market manipulation litigation.
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A large number of lawsuits were filed against numerous gas market participants in a number of federal and western state courts in connection with the operation of the natural gas markets in 2000–2002. CenterPoint Energy and its affiliates have since been released or dismissed from all but one such case. CenterPoint Energy Services, Inc. (CES), a subsidiary of CERC Corp., is a defendant in a case now pending in federal court in Nevada alleging a conspiracy to inflate Wisconsin natural gas prices in 2000–2002. In July 2011, the court issued an order dismissing the plaintiffs’ claims against other defendants in the case, each of whom had demonstrated Federal Energy Regulatory Commission jurisdictional sales for resale during the relevant period, based on federal preemption, and stayed the remainder of the case pending outcome of the appeals. The plaintiffs appealed this ruling to the U.S. Court of Appeals for the Ninth Circuit, which reversed the trial court’s dismissal of the plaintiffs’ claims. On April 21, 2015, the U.S. Supreme Court affirmed the Ninth Circuit’s ruling and remanded the case to the district court for further proceedings, which are now underway. CenterPoint Energy and CES intend to continue vigorously defending against the plaintiffs’ claims. CenterPoint Energy does not expect the ultimate outcome of this matter to have a material adverse effect on its financial condition, results of operations or cash flows.
Environmental Matters
Asbestos. Some facilities owned by CenterPoint Energy contain or have contained asbestos insulation and other asbestos-containing materials. CenterPoint Energy or its subsidiaries, including CenterPoint Houston, have been named, along with numerous others, as a defendant in lawsuits filed by a number of individuals who claim injury due to exposure to asbestos. Some of the claimants have worked at locations owned by CenterPoint Energy or CenterPoint Houston, but most existing claims relate to facilities previously owned by CenterPoint Energy’s other subsidiaries or CenterPoint Houston. In 2004 and early 2005, CenterPoint Energy sold its generating business, to which most of these claims relate, to a company which is now an affiliate of NRG. Under the terms of the arrangements regarding separation of the generating business from CenterPoint Energy and its sale of that business, ultimate financial responsibility for uninsured losses from claims relating to the generating business has been assumed by the NRG affiliate, but CenterPoint Energy has agreed to continue to defend such claims to the extent they are covered by insurance maintained by CenterPoint Energy, subject to reimbursement of the costs of such defense by the NRG affiliate. CenterPoint Energy anticipates that additional claims like those received may be asserted in the future. Although their ultimate outcome cannot be predicted at this time, CenterPoint Houston or CenterPoint Energy, as appropriate, intends to continue vigorously contesting claims that it does not consider to have merit and, based on its experience to date, CenterPoint Houston does not expect these matters, either individually or in the aggregate, to have a material adverse effect on its financial condition, results of operations or cash flows.
Other Environmental. From time to time, CenterPoint Houston identifies the presence of environmental contaminants on property where it conducts or has conducted operations. Other such sites involving contaminants may be identified in the future. CenterPoint Houston has and expects to continue to remediate identified sites consistent with its legal obligations. From time to time, CenterPoint Houston has received notices from regulatory authorities or others regarding its status as a potentially responsible party in connection with sites found to require remediation due to the presence of environmental contaminants. In addition, CenterPoint Houston has been named from time to time as a defendant in litigation related to such sites. Although the ultimate outcome of such matters cannot be predicted at this time, CenterPoint Houston does not expect, based on its experience to date, these matters, either individually or in the aggregate, to have a material adverse effect on its financial condition, results of operations or cash flows.
Other Proceedings
CenterPoint Houston is involved in other legal, environmental, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business. From time to time, CenterPoint Houston is also a defendant in legal proceedings with respect to claims brought by various plaintiffs against broad groups of participants in the energy industry. Some of these proceedings involve substantial amounts. CenterPoint Houston regularly analyzes current information and, as necessary, provides accruals for probable and reasonably estimable liabilities on the eventual disposition of these matters. CenterPoint Houston does not expect the disposition of these matters to have a material adverse effect on CenterPoint Houston’s financial condition, results of operations or cash flows.
(11) | Unaudited Quarterly Information |
Summarized quarterly financial data is as follows:
48
Year Ended December 31, 2015 | |||||||||||||||
First Quarter | Second Quarter | Third Quarter | Fourth Quarter | ||||||||||||
(in millions) | |||||||||||||||
Revenues | $ | 617 | $ | 705 | $ | 827 | $ | 697 | |||||||
Operating income | 101 | 158 | 244 | 105 | |||||||||||
Net income | 31 | 69 | 124 | 37 | |||||||||||
Year Ended December 31, 2014 | |||||||||||||||
First Quarter | Second Quarter | Third Quarter | Fourth Quarter | ||||||||||||
(in millions) | |||||||||||||||
Revenues | $ | 630 | $ | 698 | $ | 839 | $ | 679 | |||||||
Operating income | 106 | 145 | 232 | 113 | |||||||||||
Net income | 35 | 57 | 119 | 41 | |||||||||||
Item 9. | Changes in and Disagreements with Accountants on Accounting and Financial Disclosure |
None.
Item 9A. | Controls and Procedures |
Disclosure Controls and Procedures
In accordance with Exchange Act Rules 13a-15 and 15d-15, we carried out an evaluation, under the supervision and with the participation of management, including our principal executive officer and principal financial officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective as of December 31, 2015 to provide assurance that information required to be disclosed in our reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms and such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding disclosure.
There has been no change in our internal controls over financial reporting that occurred during the three months ended December 31, 2015 that has materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.
Management’s Annual Report on Internal Control over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting. Internal control over financial reporting is defined in Rule 13a-15(f) or 15d-15(f) promulgated under the Securities Exchange Act of 1934 as a process designed by, or under the supervision of, the company’s principal executive and principal financial officers and effected by the company’s board of directors, management and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles and includes those policies and procedures that:
• | Pertain to the maintenance of records that in reasonable detail accurately and fairly reflect the transactions and dispositions of the assets of the company; |
• | Provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and |
• | Provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the company’s assets that could have a material effect on the financial statements. |
49
Management has designed its internal control over financial reporting to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements in accordance with accounting principles generally accepted in the United States of America. Management’s assessment included review and testing of both the design effectiveness and operating effectiveness of controls over all relevant assertions related to all significant accounts and disclosures in the financial statements.
All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under the framework in Internal Control — Integrated Framework (2013), our management has concluded that our internal control over financial reporting was effective as of December 31, 2015.
This annual report does not include an attestation report of our independent registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by our independent registered public accounting firm pursuant to rules of the Securities and Exchange Commission that permit us to provide only management’s report in this annual report.
Item 9B. | Other Information |
The ratio of earnings to fixed charges as calculated pursuant to Securities and Exchange Commission rules was 2.72, 2.57, 2.67, 2.31 and 3.60 for the years ended December 31, 2015, 2014, 2013, 2012 and 2011, respectively.
PART III
Item 10. | Directors, Executive Officers and Corporate Governance |
The information called for by Item 10 is omitted pursuant to Instruction I(2) to Form 10-K (Omission of Information by Certain Wholly-Owned Subsidiaries).
Item 11. | Executive Compensation |
The information called for by Item 11 is omitted pursuant to Instruction I(2) to Form 10-K (Omission of Information by Certain Wholly-Owned Subsidiaries).
Item 12. | Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters |
The information called for by Item 12 is omitted pursuant to Instruction I(2) to Form 10-K (Omission of Information by Certain Wholly-Owned Subsidiaries).
Item 13. | Certain Relationships and Related Transactions, and Director Independence |
The information called for by Item 13 is omitted pursuant to Instruction I(2) to Form 10-K (Omission of Information by Certain Wholly-Owned Subsidiaries).
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Item 14. | Principal Accounting Fees and Services |
Aggregate fees billed to CenterPoint Houston during the fiscal years ending December 31, 2015 and 2014 by its principal accounting firm, Deloitte & Touche LLP, are set forth below.
Year Ended December 31, | |||||||
2015 | 2014 | ||||||
Audit fees (1) | $ | 743,470 | $ | 770,710 | |||
Audit-related fees (2) | 524,000 | 389,000 | |||||
Total audit and audit-related fees | 1,267,470 | 1,159,710 | |||||
Tax fees | — | — | |||||
All other fees | — | — | |||||
Total fees | $ | 1,267,470 | $ | 1,159,710 | |||
(1) | For 2015 and 2014, amounts include fees for services provided by the principal accounting firm relating to the integrated audit of financial statements and internal control over financial reporting, statutory audits, attest services, and regulatory filings. |
(2) | For 2015 and 2014, includes fees for consultations concerning financial accounting and reporting standards and various agreed-upon or expanded procedures related to accounting records to comply with financial accounting or regulatory reporting matters. |
CenterPoint Houston is not required to have, and does not have, an audit committee.
PART IV
Item 15. | Exhibits and Financial Statement Schedules |
(a)(1) Financial Statements. | |
Consolidated Balance Sheets as of December 31, 2015 and 2014 | |
(a)(2) Financial Statement Schedules for the Three Years Ended December 31, 2015 | |
The following schedules are omitted because of the absence of the conditions under which they are required or because the required information is included in the financial statements:
I, III, IV and V.
(a)(3) Exhibits.
See Index of Exhibits beginning on page 55.
51
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Member of
CenterPoint Energy Houston Electric, LLC
Houston, Texas
We have audited the consolidated financial statements of CenterPoint Energy Houston Electric, LLC and subsidiaries (the “Company”, an indirect, wholly-owned subsidiary of CenterPoint Energy, Inc.) as of December 31, 2015 and 2014, and for each of the three years in the period ended December 31, 2015, and have issued our report thereon dated February 26, 2016; such report is included elsewhere in this Form 10-K. Our audits also included the financial statement schedule of the Company listed in the index at Item 15(a)(2). This financial statement schedule is the responsibility of the Company’s management. Our responsibility is to express an opinion based on our audits. In our opinion, such financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.
/s/ DELOITTE & TOUCHE LLP
Houston, Texas
February 26, 2016
52
CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES
(An Indirect, Wholly-Owned Subsidiary of CenterPoint Energy, Inc.)
SCHEDULE II —VALUATION AND QUALIFYING ACCOUNTS
For the Three Years Ended December 31, 2015
Column A | Column B | Column C | Column D | Column E | ||||||||||||
Description | Balance At Beginning of Period | Additions Charged to Income | Deductions From Reserves (1) | Balance At End Of Period | ||||||||||||
(in millions) | ||||||||||||||||
Year Ended December 31, 2015: | ||||||||||||||||
Accumulated provisions: | ||||||||||||||||
Uncollectible accounts receivable | $ | 3 | $ | — | $ | 2 | $ | 1 | ||||||||
Year Ended December 31, 2014: | ||||||||||||||||
Accumulated provisions: | ||||||||||||||||
Uncollectible accounts receivable | $ | 3 | $ | 3 | $ | 3 | $ | 3 | ||||||||
Year Ended December 31, 2013: | ||||||||||||||||
Accumulated provisions: | ||||||||||||||||
Uncollectible accounts receivable | $ | 2 | $ | 2 | $ | 1 | $ | 3 | ||||||||
(1) | Deductions from reserves represent losses or expenses for which the respective reserves were created. In the case of the uncollectible accounts reserve, such deductions are net of recoveries of amounts previously written off. |
53
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) 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, in the City of Houston, the State of Texas, on the 26th day of February, 2016.
CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC | |
(Registrant) | |
By: | /s/ SCOTT M. PROCHAZKA |
Scott M. Prochazka | |
Manager | |
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities indicated on February 26, 2016.
Signature | Title | |
/s/ SCOTT M. PROCHAZKA | Manager and Chairman | |
(Scott M. Prochazka) | (Principal Executive Officer) | |
/s/ WILLIAM D. ROGERS | Executive Vice President and Chief Financial Officer | |
(William D. Rogers) | (Principal Financial Officer) | |
/s/ KRISTIE L. COLVIN | Senior Vice President and Chief Accounting Officer | |
(Kristie L. Colvin) | (Principal Accounting Officer) | |
54
CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC
EXHIBITS TO THE ANNUAL REPORT ON FORM 10-K
For Fiscal Year Ended December 31, 2015
INDEX OF EXHIBITS
Exhibits not incorporated by reference to a prior filing are designated by a cross (+); all exhibits not so designated are incorporated herein by reference to a prior filing as indicated.
Exhibit Number | Description | Report or Registration Statement | SEC File or Registration Number | Exhibit Reference | ||||
3(a) | Articles of Conversion of Reliant Energy, Incorporated | Form 8-K dated August 31, 2002 filed with the SEC on September 3, 2002 | 1-3187 | 3(a) | ||||
3(b) | Restated Certificate of Formation of CenterPoint Energy Houston Electric, LLC (“CenterPoint Houston”) | Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2011 | 1-3187 | 3.1 | ||||
3(c) | Amended and Restated Limited Liability Company Agreement of CenterPoint Houston | Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2011 | 1-3187 | 3.2 | ||||
4(a)(1) | Mortgage and Deed of Trust, dated November 1, 1944 between Houston Lighting and Power Company (“HL&P”) and Chase Bank of Texas, National Association (formerly, South Texas Commercial National Bank of Houston), as Trustee, as amended and supplemented by 20 Supplemental Indentures thereto | HL&P’s Form S-7 filed on August 25, 1977 | 2-59748 | 2(b) | ||||
4(a)(2) | Twenty-First through Fiftieth Supplemental Indentures to Exhibit 4(a)(1) | HL&P’s Form 10-K for the year ended December 31, 1989 | 1-3187 | 4(a)(2) | ||||
4(a)(3) | Fifty-First Supplemental Indenture to Exhibit 4(a)(1) dated as of March 25, 1991 | HL&P’s Form 10-Q for the quarter ended June 30, 1991 | 1-3187 | 4(a) | ||||
4(a)(4) | Fifty-Second through Fifty-Fifth Supplemental Indentures to Exhibit 4(a)(1) each dated as of March 1, 1992 | HL&P’s Form 10-Q for the quarter ended March 31, 1992 | 1-3187 | 4 | ||||
4(a)(5) | Fifty-Sixth and Fifty-Seventh Supplemental Indentures to Exhibit 4(a)(1) each dated as of October 1, 1992 | HL&P’s Form 10-Q for the quarter ended September 30, 1992 | 1-3187 | 4 | ||||
4(a)(6) | Fifty-Eighth and Fifty-Ninth Supplemental Indentures to Exhibit 4(a)(1) each dated as of March 1, 1993 | HL&P’s Form 10-Q for the quarter ended March 31, 1993 | 1-3187 | 4 | ||||
4(a)(7) | Sixtieth Supplemental Indenture to Exhibit 4(a)(1) dated as of July 1, 1993 | HL&P’s Form 10-Q for the quarter ended June 30, 1993 | 1-3187 | 4 | ||||
4(a)(8) | Sixty-First through Sixty-Third Supplemental Indentures to Exhibit 4(a)(1) each dated as of December 1, 1993 | HL&P’s Form 10-K for the year ended December 31, 1993 | 1-3187 | 4(a)(8) | ||||
4(a)(9) | Sixty-Fourth and Sixty-Fifth Supplemental Indentures to Exhibit 4(a)(1) each dated as of July 1, 1995 | HL&P’s Form 10-K for the year ended December 31, 1995 | 1-3187 | 4(a)(9) | ||||
4(b)(1) | General Mortgage Indenture, dated as of October 10, 2002, between CenterPoint Energy Houston Electric, LLC and JPMorgan Chase Bank, as Trustee | Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2002 | 1-3187 | 4(j)(1) | ||||
4(b)(2) | Second Supplemental Indenture to Exhibit 4(b)(1), dated as of October 10, 2002 | Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2002 | 1-3187 | 4(j)(3) | ||||
4(b)(3) | Third Supplemental Indenture to Exhibit 4(b)(1), dated as of October 10, 2002 | Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2002 | 1-3187 | 4(j)(4) | ||||
55
Exhibit Number | Description | Report or Registration Statement | SEC File or Registration Number | Exhibit Reference | ||||
4(b)(4) | Fourth Supplemental Indenture to Exhibit 4(b)(1), dated as of October 10, 2002 | Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2002 | 1-3187 | 4(j)(5) | ||||
4(b)(5) | Fifth Supplemental Indenture to Exhibit 4(b)(1), dated as of October 10, 2002 | Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2002 | 1-3187 | 4(j)(6) | ||||
4(b)(6) | Sixth Supplemental Indenture to Exhibit 4(b)(1), dated as of October 10, 2002 | Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2002 | 1-3187 | 4(j)(7) | ||||
4(b)(7) | Seventh Supplemental Indenture to Exhibit 4(b)(1), dated as of October 10, 2002 | Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2002 | 1-3187 | 4(j)(8) | ||||
4(b)(8) | Eighth Supplemental Indenture to Exhibit 4(b)(1), dated as of October 10, 2002 | Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2002 | 1-3187 | 4(j)(9) | ||||
4(b)(9) | Officer’s Certificates dated October 10, 2002, setting forth the form, terms and provisions of the First through Eighth Series of General Mortgage Bonds | CenterPoint Energy, Inc.’s (“CNP’s”) Form 10-K for the year ended December 31, 2003 | 1-31447 | 4(c)(10) | ||||
4(b)(10) | Ninth Supplemental Indenture to Exhibit 4(b)(1), dated as of November 12, 2002 | CNP’s Form 10-K for the year ended December 31, 2002 | 1-31447 | 4(e)(10) | ||||
4(b)(11) | Officer’s Certificate dated November 12, 2002 setting forth the form, terms and provisions of the Ninth Series of General Mortgage Bonds | CNP’s Form 10-K for the year ended December 31, 2003 | 1-31447 | 4(e)(12) | ||||
4(b)(12) | Tenth Supplemental Indenture to Exhibit 4(b)(1), dated as of March 18, 2003 | Form 8-K dated March 13, 2003 | 1-3187 | 4.1 | ||||
4(b)(13) | Officer’s Certificate dated March 18, 2003 setting forth the form, terms and provisions of the Tenth Series and Eleventh Series of General Mortgage Bonds | Form 8-K dated March 13, 2003 | 1-3187 | 4.2 | ||||
4(b)(14) | Eleventh Supplemental Indenture to Exhibit 4(b)(1), dated as of May 23, 2003 | Form 8-K dated May 16, 2003 | 1-3187 | 4.1 | ||||
4(b)(15) | Officer’s Certificate dated May 23, 2003 setting forth the form, terms and provisions of the Twelfth Series of General Mortgage Bonds | Form 8-K dated May 16, 2003 | 1-3187 | 4.2 | ||||
4(b)(16) | Twelfth Supplemental Indenture to Exhibit 4(b)(1), dated as of September 9, 2003 | Form 8-K dated September 9, 2003 | 1-3187 | 4.2 | ||||
4(b)(17) | Officer’s Certificate dated September 9, 2003 setting forth the form, terms and provisions of the Thirteenth Series of General Mortgage Bonds | Form 8-K dated September 9, 2003 | 1-3187 | 4.3 | ||||
4(b)(18) | Thirteenth Supplemental Indenture to Exhibit 4(b)(1), dated as of February 6, 2004 | CNP’s Form 10-K for the year ended December 31, 2005 | 1-31447 | 4(e)(16) | ||||
4(b)(19) | Officer’s Certificate dated February 6, 2004 setting forth the form, terms and provisions of the Fourteenth Series of General Mortgage Bonds | CNP’s Form 10-K for the year ended December 31, 2005 | 1-31447 | 4(e)(17) | ||||
4(b)(20) | Fourteenth Supplemental Indenture to Exhibit 4(b)(1), dated as of February 11, 2004 | CNP’s Form 10-K for the year ended December 31, 2005 | 1-31447 | 4(e)(18) | ||||
4(b)(21) | Officer’s Certificate dated February 11, 2004 setting forth the form, terms and provisions of the Fifteenth Series of General Mortgage Bonds | CNP’s Form 10-K for the year ended December 31, 2005 | 1-31447 | 4(e)(19) | ||||
56
Exhibit Number | Description | Report or Registration Statement | SEC File or Registration Number | Exhibit Reference | ||||
4(b)(22) | Fifteenth Supplemental Indenture to Exhibit 4(b)(1), dated as of March 31, 2004 | CNP’s Form 10-K for the year ended December 31, 2005 | 1-31447 | 4(e)(20) | ||||
4(b)(23) | Officer’s Certificate dated March 31, 2004 setting forth the form, terms and provisions of the Sixteenth Series of General Mortgage Bonds | CNP’s Form 10-K for the year ended December 31, 2005 | 1-31447 | 4(e)(21) | ||||
4(b)(24) | Sixteenth Supplemental Indenture to Exhibit 4(b)(1), dated as of March 31, 2004 | CNP’s Form 10-K for the year ended December 31, 2005 | 1-31447 | 4(e)(22) | ||||
4(b)(25) | Officer’s Certificate dated March 31, 2004 setting forth the form, terms and provisions of the Seventeenth Series of General Mortgage Bonds | CNP’s Form 10-K for the year ended December 31, 2005 | 1-31447 | 4(e)(23) | ||||
4(b)(26) | Seventeenth Supplemental Indenture to Exhibit 4(b)(1), dated as of March 31, 2004 | CNP’s Form 10-K for the year ended December 31, 2005 | 1-31447 | 4(e)(24) | ||||
4(b)(27) | Officer’s Certificate dated March 31, 2004 setting forth the form, terms and provisions of the Eighteenth Series of General Mortgage Bonds | CNP’s Form 10-K for the year ended December 31, 2005 | 1-31447 | 4(e)(25) | ||||
4(b)(28) | Nineteenth Supplemental Indenture to Exhibit 4(b)(1), dated as of November 26, 2008 | CNP’s Form 8-K dated November 25, 2008 | 1-31447 | 4.2 | ||||
4(b)(29) | Officer’s Certificate dated November 26, 2008 setting forth the form, terms and provisions of the Twentieth Series of General Mortgage Bonds | CNP’s Form 8-K dated November 25, 2008 | 1-31447 | 4.3 | ||||
4(b)(30) | Twentieth Supplemental Indenture to Exhibit 4(b)(1), dated as of December 9, 2008 | Form 8-K dated January 6, 2009 | 1-3187 | 4.2 | ||||
4(b)(31) | Twenty-First Supplemental Indenture to Exhibit 4(b)(1), dated as of January 9, 2009 | CNP’s Form 10-K for the year ended December 31, 2008 | 1-31447 | 4(e)(31) | ||||
4(b)(32) | Officer’s Certificate dated January 20, 2009 setting forth the form, terms and provisions of the Twenty-First Series of General Mortgage Bonds | CNP’s Form 10-K for the year ended December 31, 2008 | 1-31447 | 4(e)(32) | ||||
4(b)(33) | Twenty-Second Supplemental Indenture to Exhibit 4(b)(1), dated as of August 10, 2012 | CNP’s Form 10-K for the year ended December 31, 2012 | 1-31447 | 4(e)(33) | ||||
4(b)(34) | Officer’s Certificate, dated August 10, 2012 setting forth the form, terms and provisions of the Twenty-Second Series of General Mortgage Bonds | CNP’s Form 10-K for the year ended December 31, 2012 | 1-31447 | 4(e)(34) | ||||
4(b)(35) | Twenty-Third Supplemental Indenture, dated as of March 17, 2014, to the General Mortgage Indenture, dated as of October 10, 2002, between CenterPoint Houston and the Trustee | CNP’s Form 10-Q for the quarter ended March 31, 2014 | 1-31447 | 4.1 | ||||
4(b)(36) | Officer’s Certificate, dated as of March 17, 2014, setting forth the form, terms and provisions of the Twenty-Third Series of General Mortgage Bonds | CNP’s Form 10-Q for the quarter ended March 31, 2014 | 1-31447 | 4.11 | ||||
4(c) | $300,000,000 Credit Agreement dated as of September 9, 2011 among CenterPoint Houston, as Borrower, and the banks named therein | CNP’s Form 8-K dated September 9, 2011 | 1-31447 | 4.2 | ||||
4(d) | First Amendment to Credit Agreement, dated as of September 9, 2013, among CenterPoint Houston, as Borrower, and the banks named therein | CenterPoint Houston’s Form 8-K dated September 9, 2013 | 1-3187 | 4.2 | ||||
4(e) | Second Amendment to Credit Agreement, dated as of September 9, 2014, among CenterPoint Houston, as Borrower, and the banks named therein | CenterPoint Houston’s Form 8-K dated September 10, 2014 | 1-3187 | 4.2 | ||||
57
Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, CenterPoint Houston has not filed as exhibits to this Form 10-K certain long-term debt instruments, including indentures, under which the total amount of securities authorized does not exceed 10% of the total assets of CenterPoint Houston and its subsidiaries on a consolidated basis. CenterPoint Houston hereby agrees to furnish a copy of any such instrument to the SEC upon request.
Exhibit Number | Description | Report or Registration Statement | SEC File or Registration Number | Exhibit Reference | ||||
10 | City of Houston Franchise Ordinance | CNP’s Form 10-Q for the quarter ended June 30, 2005 | 1-31447 | 10.1 | ||||
+12 | Computation of Ratios of Earnings to Fixed Charges | |||||||
+23 | Consent of Deloitte & Touche LLP | |||||||
+31.1 | Rule 13a-14(a)/15d-14(a) Certification of Scott M. Prochazka | |||||||
+31.2 | Rule 13a-14(a)/15d-14(a) Certification of William D. Rogers | |||||||
+32.1 | Section 1350 Certification of Scott M. Prochazka | |||||||
+32.2 | Section 1350 Certification of William D. Rogers | |||||||
+101.INS | XBRL Instance Document | |||||||
+101.SCH | XBRL Taxonomy Extension Schema Document | |||||||
+101.CAL | XBRL Taxonomy Extension Calculation Linkbase Document | |||||||
+101.DEF | XBRL Taxonomy Extension Definition Linkbase Document | |||||||
+101.LAB | XBRL Taxonomy Extension Labels Linkbase Document | |||||||
+101.PRE | XBRL Taxonomy Extension Presentation Linkbase Document | |||||||
58
Exhibit 12
CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES
(AN INDIRECT WHOLLY OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)
COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES
Year Ended December 31, | |||||||||||||||||||
2015 (1) | 2014 (1) | 2013 (1) | 2012 (1) | 2011 (1) | |||||||||||||||
(in millions) | |||||||||||||||||||
Income before extraordinary item | $ | 261 | $ | 252 | $ | 269 | $ | 279 | $ | 488 | |||||||||
Income taxes | 145 | 131 | 146 | 113 | 248 | ||||||||||||||
Capitalized interest | (8 | ) | (10 | ) | (10 | ) | (6 | ) | (4 | ) | |||||||||
398 | 373 | 405 | 386 | 732 | |||||||||||||||
Fixed charges, as defined: | |||||||||||||||||||
Interest | 223 | 227 | 232 | 288 | 277 | ||||||||||||||
Capitalized interest | 8 | 10 | 10 | 6 | 4 | ||||||||||||||
Interest component of rentals charged to operating expense | — | — | — | — | — | ||||||||||||||
Total fixed charges | 231 | 237 | 242 | 294 | 281 | ||||||||||||||
Earnings, as defined | $ | 629 | $ | 610 | $ | 647 | $ | 680 | $ | 1,013 | |||||||||
Ratio of earnings to fixed charges | 2.72 | 2.57 | 2.67 | 2.31 | 3.60 | ||||||||||||||
(1) | Excluded from the computation of fixed charges for the years ended December 31, 2015, 2014, 2013, 2012, and 2011 is interest expense of $-0-, interest expense of $-0-, interest income of less than $1 million, interest income of $8 million and interest income of $12 million, respectively, which is included in income tax expense. |
Exhibit 23
CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
We consent to the incorporation by reference in Registration Statement No. 333-193695-02 on Form S-3 of our reports dated February 26, 2016, relating to the consolidated financial statements and financial statement schedule of CenterPoint Energy Houston Electric, LLC and subsidiaries appearing in this Annual Report on Form 10-K of CenterPoint Energy Houston Electric, LLC for the year ended December 31, 2015.
/s/ DELOITTE & TOUCHE LLP
Houston, Texas
February 26, 2016
Exhibit 31.1
CERTIFICATIONS
I, Scott M. Prochazka, certify that:
1. | I have reviewed this annual report on Form 10-K of CenterPoint Energy Houston Electric, LLC; |
2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
(a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
(b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
(c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
(d) | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5.The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
(a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
(b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: February 26, 2016
/s/ Scott M. Prochazka | |
Scott M. Prochazka | |
Chairman (Principal Executive Officer) | |
Exhibit 31.2
CERTIFICATIONS
I, William D. Rogers, certify that:
1.I have reviewed this annual report on Form 10-K of CenterPoint Energy Houston Electric, LLC;
2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
(a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
(b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
(c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
(d) | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5.The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
(a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
(b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: February 26, 2016
/s/ William D. Rogers | |
William D. Rogers | |
Executive Vice President and Chief Financial Officer | |
Exhibit 32.1
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO SECTION 906
OF THE SARBANES-OXLEY ACT OF 2002
In connection with the Annual Report of CenterPoint Energy Houston Electric, LLC (the “Company”) on Form 10-K for the year ended December 31, 2015 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, Scott M. Prochazka, Chairman (Principal Executive Officer), certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:
1.The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and
2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
/s/ Scott M. Prochazka | |
Scott M. Prochazka | |
Chairman (Principal Executive Officer) | |
February 26, 2016 | |
Exhibit 32.2
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO SECTION 906
OF THE SARBANES-OXLEY ACT OF 2002
In connection with the Annual Report of CenterPoint Energy Houston Electric, LLC (the “Company”) on Form 10-K for the year ended December 31, 2015 (the “Report”), as filed with the Securities and Exchange Commission on the date hereof, I, William D. Rogers, Chief Financial Officer, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:
1.The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and
2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
/s/ William D. Rogers | |
William D. Rogers | |
Executive Vice President and Chief Financial Officer | |
February 26, 2016 | |