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Item 1.	Business

•	CenterPoint Energy Houston Electric, LLC (CenterPoint Houston), which engages in the electric transmission and distribution business in the Texas Gulf Coast area that includes the city of Houston; and

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CenterPoint Energy Resources Corp. (CERC Corp. and, together with its subsidiaries, CERC), which owns and operates natural gas distribution systems (NGD). A wholly-owned subsidiary of CERC Corp. offers variable and fixed-price physical natural gas supplies primarily to commercial and industrial customers and electric and gas utilities. As of December 31, 2015, CERC Corp. also owned approximately 55.4% of the limited partner interests in Enable, which owns, operates and develops natural gas and crude oil infrastructure assets.

•	our Code of Ethics for our Chief Executive Officer and Senior Financial Officers;

•	our Ethics and Compliance Code;

•	our Corporate Governance Guidelines; and

•	the charters of the audit, compensation and governance committees of our Board of Directors.

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•	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.

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•	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;

•	enjoining the operations of facilities with permits issued pursuant to such environmental laws and regulations; and

•	impacting the demand for our services by directly or indirectly affecting the use or price of natural gas.

•	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.

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Item 1A.	Risk Factors

•	general economic and capital market conditions;

•	credit availability from financial institutions and other lenders;

•	investor confidence in us and the markets in which we operate;

•	maintenance of acceptable credit ratings;

•	market expectations regarding our future earnings and cash flows;

•	market perceptions of our ability to access capital markets on reasonable terms;

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•	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;

•	incremental collateral that may be required due to regulation of derivatives; and

•	provisions of relevant tax and securities laws.

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•	the fees and gross margins it realizes with respect to the volume of natural gas, NGLs and crude oil that it handles;

•	the prices of, levels of production of, and demand for natural gas, NGLs and crude oil;

•	the volume of natural gas, NGLs and crude oil it gathers, compresses, treats, dehydrates, processes, fractionates, transports and stores;

•	the relationship among prices for natural gas, NGLs and crude oil;

•	cash calls and settlements of hedging positions;

•	margin requirements on open price risk management assets and liabilities;

•	the level of competition from other midstream energy companies;

•	adverse effects of governmental and environmental regulation;

•	the level of its operation and maintenance expenses and general and administrative costs; and

•	prevailing economic conditions.

•	the level and timing of its capital expenditures;

•	the cost of acquisitions;

•	its debt service requirements and other liabilities;

•	fluctuations in its working capital needs;

•	its ability to borrow funds and access capital markets;

•	restrictions contained in its debt agreements;

•	the amount of cash reserves established by its general partner; and

•	other business risks affecting its cash levels.

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•	the availability and cost of capital;

•	prevailing and projected commodity prices, including the prices of natural gas, NGLs and crude oil;

•	demand for natural gas, NGLs and crude oil;

•	levels of reserves;

•	geological considerations;

•	environmental or other governmental regulations, including the availability of drilling permits and the regulation of hydraulic fracturing; and

•	the availability of drilling rigs and other costs of production and equipment.

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•	Enable’s joint venture partners may share certain approval rights over major decisions;

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•	Enable’s joint venture partners may not pay their share of the joint venture’s obligations, leaving Enable liable for their shares of joint venture liabilities;

•	Enable may be unable to control the amount of cash it will receive from the joint venture;

•	Enable may incur liabilities as a result of an action taken by its joint venture partners;

•	Enable may be required to devote significant management time to the requirements of and matters relating to the joint ventures;

•	Enable’s insurance policies may not fully cover loss or damage incurred by both Enable and its joint venture partners in certain circumstances;

•	Enable’s joint venture partners may be in a position to take actions contrary to its instructions or requests or contrary to its policies or objectives; and

•	disputes between Enable and its joint venture partners may result in delays, litigation or operational impasses.

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•	the ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may be impaired or the financing may not be available on favorable terms, if at all;

•	a portion of cash flows will be required to make interest payments on the debt, reducing the funds that would otherwise be available for operations, future business opportunities and distributions;

•	Enable’s debt level will make it more vulnerable to competitive pressures or a downturn in its business or the economy generally; and

•	Enable’s debt level may limit its flexibility in responding to changing business and economic conditions.

•	permit its subsidiaries to incur or guarantee additional debt;

•	incur or permit to exist certain liens on assets;

•	dispose of assets;

•	merge or consolidate with another company or engage in a change of control;

•	enter into transactions with affiliates on non-arm’s length terms; and

•	change the nature of its business.

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•	develop a baseline plan to prioritize the assessment of a covered pipeline segment;

•	identify and characterize applicable threats that could impact a high consequence area;

•	improve data collection, integration, and analysis;

•	repair and remediate pipelines as necessary; and

•	implement preventive and mitigating action.

•	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;

•	enjoining the operations of facilities with permits issued pursuant to such environmental laws and regulations; and

•	impacting the demand for our services by directly or indirectly affecting the use or price of natural gas.

•	construct or acquire new facilities and equipment;

•	acquire permits for facility operations;

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•	modify or replace existing and proposed equipment; and

•	clean or decommission waste disposal areas, fuel storage and management facilities and other locations and facilities.

•	damage to pipelines and plants, related equipment and surrounding properties caused by hurricanes, tornadoes, floods, fires and other natural disasters, acts of terrorism and actions by third parties;

•	inadvertent damage from construction, vehicles, farm and utility equipment;

•	leaks of natural gas, NGLs, crude oil and other hydrocarbons or losses of natural gas, NGLs and crude oil as a result of the malfunction of equipment or facilities;

•	ruptures, fires and explosions; and

•	other hazards that could also result in personal injury and loss of life, pollution and suspension of operations.

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•	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.

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•	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;

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•	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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•	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 or Enable 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 or Enable 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

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•	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.

Item 1B.	Unresolved Staff Comments

Item 2.	Properties

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Item 3.	Legal Proceedings

Item 4.	Mine Safety Disclosures

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Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

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(1)	As of December 31, 2015, we owned approximately 55.4% of the limited partner interests in Enable Midstream Partners, LP (Enable), an unconsolidated subsidiary that we account for on an equity basis. This amount includes $1,846 million of non-cash impairment charges related to Enable.

(2)	As of December 31, 2014, we owned approximately 55.4% of the limited partner interests in Enable and 0.1% of Southeast Supply Header (SESH), each an unconsolidated subsidiary, that we accounted for on an equity basis.

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(3)	Following the formation of Enable on May 1, 2013, Enable owned substantially all of our former Interstate Pipelines and Field Services business segments, except for our retained 25.05% interest in SESH. As of December 31, 2013, we owned approximately 58.3% of the limited partner interests in Enable.

(4)	2011 Income before Extraordinary Item includes a $224 million after-tax ($0.53 and $0.52 per basic and diluted share, respectively) return on true-up balance related to a portion of interest on the appealed true-up amount.

(5)	Calculated using Income before Extraordinary Item.

Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations

•	CenterPoint Energy Houston Electric, LLC (CenterPoint Houston), which engages in the electric transmission and distribution business in the Texas Gulf Coast area that includes the city of Houston; and

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CenterPoint Energy Resources Corp. (CERC Corp. and, together with its subsidiaries, CERC), which owns and operates natural gas distribution systems. A wholly-owned subsidiary of CERC Corp. offers variable and fixed-price physical natural gas supplies primarily to commercial and industrial customers and electric and gas utilities. As of December 31, 2015, CERC Corp. also owned approximately 55.4% of the limited partner interests in Enable, which owns, operates and develops natural gas and crude oil infrastructure assets.

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•	the performance of Enable, the amount of cash distributions we receive from Enable, and the value of our interest in Enable, and factors that may have a material impact on such performance, cash distributions and value, including factors such as:

◦	competitive conditions in the midstream industry, and actions taken by Enable’s customers and competitors, including the extent and timing of the entry of additional competition in the markets served by Enable;

◦

the timing and extent of changes in the supply of natural gas and associated commodity prices, particularly prices of natural gas and NGLs, the competitive effects of the available pipeline capacity in the regions served by Enable, and the effects of geographic and seasonal commodity price differentials, including the effects of these circumstances on re-contracting available capacity on Enable’s interstate pipelines;

◦	the demand for crude oil, natural gas, NGLs and transportation and storage services;

◦	environmental and other governmental regulations, including the availability of drilling permits and the regulation of hydraulic fracturing;

◦	recording of non-cash goodwill, long-lived asset or other than temporary impairment charges by or related to Enable;

◦	changes in tax status;

◦	access to debt and growth capital; and

◦	the availability and prices of raw materials and services for current and future construction projects;

•	state and federal legislative and regulatory actions or developments affecting various aspects of our businesses (including the businesses of Enable), including, among others, energy deregulation or re-regulation, pipeline integrity and safety, health care reform, financial reform, tax legislation and actions regarding the rates charged by our regulated businesses;

•	timely and appropriate rate actions that allow recovery of costs and a reasonable return on investment;

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•	industrial, commercial and residential growth in our service territories 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;

•	our ability to mitigate weather impacts through normalization or rate mechanisms, and the effectiveness of such mechanisms;

•	the timing and extent of changes in commodity prices, particularly natural gas, and the effects of geographic and seasonal commodity price differentials;

•	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 businesses 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 our 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;

•	effectiveness of our risk management activities;

•	timely and appropriate regulatory actions allowing securitization or other recovery of costs associated with any future hurricanes or natural disasters;

•	our potential business strategies, including restructurings, joint ventures and 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 or Enable’s ability to recruit, effectively transition and retain management and key employees and maintain good labor relations;

•	the ability of GenOn Energy, Inc. (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, or obligations in connection with the contractual arrangements pursuant to which we are their guarantor;

•	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;

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•	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 effective tax rates;

•	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.

•	a $1,941 million decrease in equity earnings of unconsolidated affiliates, which included impairment charges of $1,846 million, discussed further in Note 9 to our consolidated financial statements; and

•	a $256 million increase in the loss on our marketable securities.

•	a $712 million decrease in income tax expense;

•	a $160 million increase in the gain on our indexed debt securities;

•	a $13 million decrease in interest expense related to our transition and system restoration bonds; and

•	an $10 million increase in other income.

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•	a $196 million decrease in income tax expense discussed below;

•	a $120 million increase in equity earnings of unconsolidated affiliates;

•	a $107 million decrease in the loss on our indexed debt securities;

•	a $13 million decrease in interest expense; and

•	a $12 million increase in other income.

•	a $75 million decrease in operating income (discussed below by segment); and

•	a $73 million decrease in the gain on our marketable securities.

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(1)	Represents the amount necessary to pay interest on the transition and system restoration bonds.

•	higher transmission-related revenues of $81 million, which were partially offset by increased transmission costs billed by transmission providers of $47 million;

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•	lower revenues from energy efficiency bonuses of $15 million, including a one-time energy efficiency remand bonus in 2014 of $8 million;

•	higher energy efficiency performance bonus of $15 million.

•	increased labor and support services costs of $21 million;

•	increased contracts and services of $19 million;

•	lower right-of-way revenues of $8 million;

•	increased depreciation of $8 million;

•	an adjustment to our claims liability reserve of $6 million;

•	decreased usage of $5 million, primarily due to milder weather; and

•	increased transmission costs billed by transmission providers of $168 million, which were largely offset by increased transmission-related revenues of $164 million.

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•	decreased usage of $25 million as a result of warmer weather compared to the prior year, partially mitigated by weather hedges and weather normalization adjustments;

•	higher depreciation and amortization of $22 million; and

•	increase in taxes of $2 million.

•	rate increases of $23 million;

•	increased economic activity across our footprint of $7 million, including the addition of approximately 30,000 customers; and

•	increased other revenue of $5 million.

•	increased usage of $16 million as a result of colder weather compared to the prior year, partially mitigated by weather hedges and weather normalization adjustments;

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•	rate increases of $37 million; and

•	increased economic activity across our footprint of $10 million, including the addition of approximately 36,000 customers.

•	increased contractor expense of $10 million, including pipeline integrity work;

•	higher depreciation and amortization of $16 million;

•	increase in taxes of $7 million; and

•	increased other operating expenses of $6 million.

(1)	These numbers do not include approximately 9,700 and 8,800 natural gas customers as of December 31, 2014 and 2013, respectively, that are under residential and small commercial choice programs invoiced by their host utility.

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(1)	These amounts include our share of Enable’s impairment of goodwill and long-lived assets and the impairment of our equity method investment in Enable totaling $1,846 million during the year ended December 31, 2015. This impairment is offset by $213 million of earnings for the year ended December 31, 2015.

(2)	We contributed our remaining 0.1% interest in SESH to Enable on June 30, 2015.

(3)	On April 16, 2014, Enable completed its initial public offering and, as a result, our limited partner interest in Enable was reduced from approximately 58.3% to approximately 54.7%. On May 30, 2014, we contributed to Enable our 24.95% interest in SESH, which increased our limited partner interest in Enable from approximately 54.7% to approximately 55.4% and reduced our interest in SESH to 0.1%.

(4)	Represents our 58.3% limited partner interest in Enable and our 25.05% interest in SESH for the eight months ended December 31, 2013.

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•	capital expenditures of approximately $1.4 billion;

•	scheduled principal payments on transition and system restoration bonds of $391 million;

•	investment in Enable’s Series A Preferred Units of $363 million;

•	maturing senior notes of $325 million;

•	acquisition of the retail commercial and industrial businesses of Continuum for $77.5 million plus working capital;and

•	dividend payments on CenterPoint Energy common stock and interest payments on debt.

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(1)

2.0% Zero-Premium Exchangeable Subordinated Notes due 2029 (ZENS) obligations are included in the 2021 and thereafter column at their contingent principal amount as of December 31, 2015 of $705 million.  These obligations are exchangeable for cash at any time at the option of the holders for 95% of the current value of the reference shares attributable to each ZENS ($805 million as of December 31, 2015), as discussed in Note 10 to our consolidated financial statements.

(2)	We calculated estimated interest payments for long-term debt as follows: for fixed-rate debt and term debt, we calculated interest based on the applicable rates and payment dates; for variable-rate debt and/or non-term debt, we used interest rates in place as of December 31, 2015. We typically expect to settle such interest payments with cash flows from operations and short-term borrowings.

(3)	For a discussion of operating leases, please read Note 14(c) to our consolidated financial statements.

(4)	In 2016, we are not required to make contributions to our qualified pension plan. We expect to contribute approximately $8 million and $16 million, respectively, to our non-qualified pension and postretirement benefits plans in 2016.

(5)	For a discussion of other commodity commitments, please read Note 14(a) to our consolidated financial statements.

(6)	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 $195 million as of December 31, 2015. See Note 3(c) to our consolidated financial statements.

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(1)	Based on the consolidated debt to capitalization covenant in our revolving credit facility and the revolving credit facility of each of CenterPoint Houston and CERC Corp., we would have been permitted to utilize the full capacity of such revolving credit facilities, which aggregated $2.1 billion at December 31, 2015.

(2)	Represents outstanding commercial paper of $820 million and outstanding letters of credit of $6 million.

(3)	Represents outstanding letters of credit of $4 million and outstanding bank loans of $200 million.

(4)	Represents outstanding commercial paper of $16 million and outstanding letters of credit of $2 million.

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(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.

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•	cash collateral requirements that could exist in connection with certain contracts, including our weather hedging arrangements, and gas purchases, gas price and gas storage activities of our Natural Gas Distribution and Energy Services business segments;

•	acceleration of payment dates on certain gas supply contracts, under certain circumstances, as a result of increased gas prices and concentration of natural gas suppliers;

•	increased costs related to the acquisition of natural gas;

•	increases in interest expense in connection with debt refinancings and borrowings under credit facilities;

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•	various legislative or regulatory actions;

•	incremental collateral, if any, that may be required due to regulation of derivatives;

•	the ability of GenOn and its subsidiaries to satisfy their obligations in respect of GenOn’s indemnity obligations to us and our subsidiaries or in connection with the contractual obligations to a third party pursuant to which our subsidiary is their guarantor;

•	the ability of REPs, including REP affiliates of NRG and Energy Future Holdings Corp., to satisfy their obligations to us and our subsidiaries;

•	slower customer payments and increased write-offs of receivables due to higher gas prices or changing economic conditions;

•	the outcome of litigation brought by and against us;

•	contributions to pension and postretirement benefit plans;

•	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 Part I of this report.

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•	Interest rate risk primarily results from exposures to changes in the level of borrowings and changes in interest rates.

•	Equity price risk results from exposures to changes in prices of individual equity securities.

•	Commodity price risk results from exposures to changes in spot prices, forward prices and price volatilities of commodities, such as natural gas, natural gas liquids and other energy commodities.

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•	CenterPoint Energy Houston Electric, LLC (CenterPoint Houston), which engages in the electric transmission and distribution business in the Texas Gulf Coast area that includes the city of Houston; and

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CenterPoint Energy Resources Corp. (CERC Corp. and, together with its subsidiaries, CERC), which owns and operates natural gas distribution systems (NGD). A wholly-owned subsidiary of CERC Corp. offers variable and fixed-price physical natural gas supplies primarily to commercial and industrial customers and electric and gas utilities. As of December 31, 2015, CERC Corp. also owned approximately 55.4% of the limited partner interests in Enable, which owns, operates and develops natural gas and crude oil infrastructure assets.

(a)	Use of Estimates

(b)	Principles of Consolidation

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(c)	Revenues

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(1)	Amounts presented are net of accumulated goodwill impairment charge of $252 million.

(1)

As of December 31, 2015, CenterPoint Energy 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 Energy’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.

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(2)	NGD’s actuarially determined pension and other postemployment expense in excess of the amount being recovered through rates is being deferred for rate making purposes. Deferred pension and other postemployment expenses of $5 million as of December 31, 2015 were not earning a return.

(3)	Other regulatory assets that are not earning a return were not material as of December 31, 2015 and 2014.

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(1)	During the fourth quarter of 2014, CenterPoint Energy recognized a curtailment pension loss of $6 million related to employees seconded to Enable. Substantially all of the seconded employees became employees of Enable effective January 1, 2015.

(2)

A one-time, non-cash settlement charge is required when lump sum distributions or other settlements of plan benefit obligations during a plan year exceed the service cost and interest cost components of net periodic cost for that year.  Due to the amount of lump sum payment distributions from the non-qualified pension plan during the year ended December 31, 2015, CenterPoint Energy recognized a non-cash settlement charge of $10 million.  This charge is an acceleration of costs that would otherwise be recognized in future periods.

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(1)	Total other comprehensive income (loss) related to the re-measurement of pension, postretirement and other postemployment plans.

(2)	These accumulated other comprehensive components are included in the computation of net periodic cost.

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(1)	60% of the amount invested in common collective trust funds was in fixed income securities, 11% was in U.S. equities, 23% was in international equities and 2% was in emerging market equities.

(2)	58% of the amount invested in mutual funds was in international equities, 28% was in emerging market equities and 14% was in U.S. equities.

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(1)	61% of the amount invested in common collective trust funds was in fixed income securities, 14% was in U.S. equities, 22% was in international equities and 3% was in emerging market equities.

(2)	57% of the amount invested in mutual funds was in international equities, 30% was in emerging market equities and 13% was in U.S. equities.

(1)	72% of the amount invested in mutual funds was in fixed income securities, 20% was in U.S. equities and 8% was in international equities.

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(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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(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 767 billion cubic feet (Bcf) or a net 112 Bcf long position.  Of the net long position, basis swaps constitute 133 Bcf.

(2)

Natural gas contracts are presented on a net basis in the Consolidated Balance Sheets. Natural gas contracts are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within the Consolidated Balance Sheets. The net of total non-trading derivative assets and liabilities was a $109 million asset as shown on CenterPoint Energy’s Consolidated Balance Sheets (and as detailed in the table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above offset by collateral netting of $56 million.

(3)	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.

(1)	Gross amounts recognized include some derivative assets and liabilities that are not subject to master netting arrangements.

(2)	The derivative assets and liabilities on the Consolidated Balance Sheets exclude accounts receivable or accounts payable that, should they exist, could be used as offsets to these balances in the event of a default.

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(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 804 Bcf or a net 60 Bcf long position.  Of the net long position, basis swaps constitute 127 Bcf.

(2)

Natural gas contracts are presented on a net basis in the Consolidated Balance Sheets. Natural gas contracts are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within the Consolidated Balance Sheets. The net of total non-trading derivative assets and liabilities was a $111 million asset as shown on CenterPoint Energy’s Consolidated Balance Sheets (and as detailed in the table below), and was comprised of the natural gas contracts derivative assets and liabilities separately shown above, offset by collateral netting of $64 million.

(3)	Derivative Assets and Derivative Liabilities include no material amounts related to physical forward transactions with Enable.

(1)	Gross amounts recognized include some derivative assets and liabilities that are not subject to master netting arrangements.

(2)	The derivative assets and liabilities on the Consolidated Balance Sheets exclude accounts receivable or accounts payable that, should they exist, could be used as offsets to these balances in the event of a default.

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(1)	The Gains (Losses) in Expense: Natural Gas includes $-0- and $2 million during the years ended December 31, 2015 and 2014, respectively, related to physical forwards purchased from Enable.

(1)

“Investment grade” is primarily determined using publicly available credit ratings and considers credit support (including parent company guarantees) and collateral (including cash and standby letters of credit). For unrated counterparties, CenterPoint Energy determines a synthetic credit rating by performing financial statement analysis and considers contractual rights and restrictions and collateral.

(2)	End users are comprised primarily of customers who have contracted to fix the price of a portion of their physical gas requirements for future periods.

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(1)	Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of $56 million posted with the same counterparties.

(2)	Natural gas derivatives include no material amounts related to physical forward transactions with Enable.

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(1)	Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of $64 million posted with the same counterparties.

(2)	Natural gas derivatives include no material amounts related to physical forward transactions with Enable.

(1)	During 2015, 2014 and 2013, CenterPoint Energy did not have significant Level 3 purchases or sales.

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•	volume weighted average quoted price of Enable’s common units;

•	recent market transactions of comparable companies; and

•	EBITDA to total enterprise multiples for comparable companies.

•	Enable’s forecasted cash distributions;

•	projected cash flows of incentive distribution rights;

•	forecasted growth rate of Enable’s cash distributions; and

•	determination of the cost of equity, including market risk premiums.

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(1)	CenterPoint Energy disposed of its remaining interest in SESH on June 30, 2015.

(1)	CenterPoint Energy contributed a 24.95% interest in SESH to Enable on May 30, 2014 and its remaining interest in SESH to Enable on June 30, 2015.

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(1)

Equity in earnings of unconsolidated affiliates includes CenterPoint Energy’s share of Enable earnings adjusted for the amortization of the basis difference of CenterPoint Energy’s original investment in Enable and its underlying equity in net assets of Enable. The basis difference is being amortized over approximately 33 years, the average life of the assets to which the basis difference is attributed.

(2)	These amounts include CenterPoint Energy’s share of Enable’s impairment of goodwill and long-lived assets and the impairment of CenterPoint Energy’s equity method investment in Enable totaling $1,846 million during the year ended December 31, 2015. This impairment is offset by $213 million of earnings for the year ended December 31, 2015.

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(1)	CenterPoint Energy contributed a 24.95% interest in SESH to Enable on each of May 1, 2013 and May 30, 2014 and its remaining interest in SESH to Enable on June 30, 2015.

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(1)	Includes amounts due or exchangeable within one year of the date noted.

(2)	CenterPoint Energy’s ZENS obligation is bifurcated into a debt component and an embedded derivative component. For additional information regarding ZENS, see Note 10(b). As ZENS are exchangeable for cash at any time at the option of the holders, these notes are classified as a current portion of long-term debt.

(3)	$118 million of these series of debt were secured by general mortgage bonds of CenterPoint Houston as of both December 31, 2015 and 2014.

(4)	Classified as long-term debt because the termination date of the facility that backstops the commercial paper is more than one year from the date noted.

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(1)	Weighted average interest rate was 0.79% and 0.63% as of December 31, 2015 and 2014, respectively.

(2)	Weighted average interest rate was 1.637% as of December 31, 2015.

(3)	Weighted average interest rate was 0.81% and 0.68% as of December 31, 2015 and 2014, respectively.

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(1)	2,349,000 incremental shares from assumed conversions of restricted stock have not been included in the computation of diluted earnings (loss) per share for the year ended December 31, 2015, as their inclusion would be anti-dilutive.

(1)	Quarterly earnings (loss) per common share are based on the weighted average number of shares outstanding during the quarter, and the sum of the quarters may not equal annual earnings (loss) per common share.

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(2)	CenterPoint Energy recognized $862 million ($537 million after tax) in impairment charges related to Enable during the three months ended September 30, 2015.

(3)	CenterPoint Energy recognized $984 million ($620 million after tax) in impairment charges related to Enable during the three months ended December 31, 2015.

(4)	CenterPoint Energy recognized a $29 million deferred income tax benefit upon completion of its tax basis balance sheet review.

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(1)	CenterPoint Houston’s transmission and distribution revenues from major customers are as follows:

(2)	Midstream Investments’ equity earnings (losses) are as follows:

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(1)	These amounts include CenterPoint Energy’s share of Enable’s impairment of goodwill and long-lived assets and the impairment of CenterPoint Energy’s equity method investment in Enable totaling $1,846 million during the year ended December 31, 2015. This impairment is offset by $213 million of earnings for the year ended December 31, 2015.

(3)	Included in total assets of Other Operations as of December 31, 2015, 2014 and 2013, are pension and other postemployment related regulatory assets of $814 million, $795 million and $627 million, respectively.

(4)

Interstate Pipelines recorded equity income of $7 million in the year ended December 31, 2013 from its interest in SESH, a jointly-owned pipeline. These amounts are included in Equity in earnings of unconsolidated affiliates under the Other Income (Expense) caption.  As discussed above, effective May 1, 2013, CenterPoint Energy reports equity earnings associated with its interest in Enable and equity earnings associated with its interest in SESH under its Midstream Investments segment, and no longer has an Interstate Pipelines reporting segment prospectively.

(5)	Results reflected in the year ended December 31, 2013 represent only January 2013 through April 2013.

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Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

Item 9A.	Controls and Procedures

•	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.

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Item 9B.	Other Information

Item 10.	Directors, Executive Officers and Corporate Governance

Item 11.	Executive Compensation

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Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

Item 13.	Certain Relationships and Related Transactions, and Director Independence

Item 14.	Principal Accounting Fees and Services

Item 15.	Exhibits and Financial Statement Schedules

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(1)	Weighted average interest rate was 0.79% and 0.63% as of December 31, 2015 and 2014, respectively.

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(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.

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•	Mr. Carroll's annual base salary is increased from $600,000 to $625,000 effective as of April 1, 2016 and continuing thereafter until the termination of Mr. Carroll's service as Executive Chairman of the Board or as otherwise modified by the Board;

•	Mr. Carroll’s long-term incentive compensation target is increased from a target equal to 200% of base salary to a target equal to 300%.

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(1)	the Vesting Date(s) on which the units are paid under Section 3 hereof for the number of units indicated in the Award Notice assuming continuous Employment by the Participant as of such Vesting Date(s); or

(2)	in the case of the Participant’s death or Separation from Service due to Disability or Retirement prior to the Vesting

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(1)	the Vesting Date(s) on which the units are paid under Section 3 hereof for the number of units indicated in the Award Notice assuming continuous Employment by the Participant as of such Vesting Date(s); or

(2)	in the case of the Participant’s death or Separation from Service due to Disability or Retirement prior to the Vesting

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•	Supplemental annual retainer of $20,000 for serving as a chairman of the Audit Committee or Compensation Committee; and

•	Mr. Prochazka’s short-term incentive target was increased from 100% to 110%; and

•	no changes to the 75% short-term incentive target for each of Messrs. Rogers, Bridge and McGoldrick.

•	Mr. Prochazka’s long-term incentive target was increased from 300% to 390%;

•	Mr. Rogers long-term incentive target was increased from 140% to 170%; and

•	no changes to the 160% long-term incentive target for each of Messrs. Bridge and McGoldrick.

(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 $3 million, interest income of $6 million, interest income of $11 million and interest income of $12 million respectively, which is included in income tax expense.

(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

(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.

(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

(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.