Edgar Filing: CENTERPOINT ENERGY INC

CNP_10Q_3.31.2012

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

__________________

FORM 10-Q



(Mark One)
þ	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

	FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2012



o	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 1-31447

_____________________________________

CenterPoint Energy, Inc.

(Exact name of registrant as specified in its charter)



Texas	74-0694415
(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)

_____________________________________

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 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 þ	Accelerated filer o	Non-accelerated filer o	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

As of April 16, 2012, CenterPoint Energy, Inc. had 427,298,767 shares of common stock outstanding, excluding 166 shares held as treasury stock.

CENTERPOINT ENERGY, INC.

QUARTERLY REPORT ON FORM 10-Q

FOR THE QUARTER ENDED MARCH 31, 2012

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PART I.	FINANCIAL INFORMATION

Item 1.	Financial Statements	1

	Condensed Statements of Consolidated Income
	Three Months Ended March 31, 2011 and 2012 (unaudited)	1

	Condensed Statements of Consolidated Comprehensive Income
	Three Months Ended March 31, 2011 and 2012 (unaudited)	2

	Condensed Consolidated Balance Sheets
	December 31, 2011 and March 31, 2012 (unaudited)	3

	Condensed Statements of Consolidated Cash Flows
	Three Months Ended March 31, 2011 and 2012 (unaudited)	5

	Notes to Unaudited Condensed Consolidated Financial Statements	6

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	19

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	31

Item 4.	Controls and Procedures	32

PART II.	OTHER INFORMATION

Item 1.	Legal Proceedings	33

Item 1A.	Risk Factors	33

Item 5.	Other Information	33

Item 6.	Exhibits	34

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 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.

The following are some of the factors that could cause actual results to differ materially from those expressed or implied in forward-looking statements:


•	state and federal legislative and regulatory actions or developments affecting various aspects of our business, including, among others, energy deregulation or re-regulation, pipeline integrity and safety, health care reform, financial reform and tax legislation;


•	state and federal legislative and regulatory actions or developments relating to the environment, including those related to global climate change;


•	timely and appropriate rate actions and increases, allowing recovery of costs and a reasonable return on investment;


•	the timing and outcome of any audits, disputes and other proceedings related to taxes;


•	problems with 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;


•	industrial, commercial and residential growth in our service territory and changes in market demand, including the effects of energy efficiency measures and demographic patterns;


•	the timing and extent of changes in commodity prices, particularly natural gas and natural gas liquids, and the effects of geographic and seasonal commodity price differentials, including the effects of these circumstances on re-contracting available capacity on our interstate pipelines;


•	the timing and extent of changes in the supply of natural gas, particularly supplies available for gathering by our field services business and transporting by our interstate pipelines, including the impact of natural gas prices on the level of drilling and production activities in the regions we serve;


•	competition in our mid-continent region footprint for access to natural gas supplies and markets;


•	weather variations and other natural phenomena;


•	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;


•	the impact of unplanned facility outages;


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


•	changes in interest rates or rates of inflation;


•	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;


•	actions by credit rating agencies;


•	effectiveness of our risk management activities;


•	inability of various counterparties to meet their obligations to us;


•	non-payment for our services due to financial distress of our customers;


•	the ability of GenOn Energy, Inc. (formerly known as RRI Energy, Inc., Reliant Energy, Inc. and Reliant Resources, Inc.) 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 ability of retail electric providers (REPs), including REP affiliates of NRG Energy, Inc. and REP affiliates of Energy Future Holdings Corp., which are CenterPoint Energy Houston Electric, LLC’s two largest customers, to satisfy their obligations to us and our subsidiaries;


•	the outcome of litigation brought by or against us;


•	our ability to control costs;


•	the investment performance of our pension and postretirement benefit plans;


•	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; and


•	other factors we discuss in “Risk Factors” in Item 1A of Part I of our Annual Report on Form 10-K for the year ended December 31, 2011, which is incorporated herein by reference, and other reports we file from time to time with the Securities and Exchange Commission.

You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement.

iii

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PART I. FINANCIAL INFORMATION

Item 1. FINANCIAL STATEMENTS

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(In Millions, Except Per Share Amounts)

(Unaudited)



	Three Months Ended
	March 31,
	2011			2012

Revenues	$	2,587		$	2,084

Expenses:
Natural gas	1,476			969
Operation and maintenance	439			455
Depreciation and amortization	201			224
Taxes other than income taxes	107			98
Total	2,223			1,746
Operating Income	364			338

Other Income (Expense):
Gain on marketable securities	32			46
Loss on indexed debt securities	(23		)	(33		)
Interest and other finance charges	(116		)	(110		)
Interest on transition and system restoration bonds	(33		)	(37		)
Equity in earnings of unconsolidated affiliates	6			9
Other, net	5			6
Total	(129		)	(119		)

Income Before Income Taxes	235			219
Income tax expense	87			72
Net Income	$	148		$	147

Basic Earnings Per Share	$	0.35		$	0.34

Diluted Earnings Per Share	$	0.35		$	0.34

Dividends Declared Per Share	$	0.1975		$	0.2025

Weighted Average Shares Outstanding, Basic	425			426

Weighted Average Shares Outstanding, Diluted	427			428

See Notes to Interim Condensed Consolidated Financial Statements

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CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(In Millions)

(Unaudited)



	For the Three Months Ended
	March 31,
	2011		2012
Net income	$	148	$	147
Other comprehensive income:
Adjustment related to pension and other postretirement plans (net of tax of $2 and $2)	2		2
Total	2		2
Comprehensive income	$	150	$	149

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CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In Millions)

(Unaudited)

ASSETS



	December 31, 2011		March 31, 2012
Current Assets:
Cash and cash equivalents ($220 and $109 related to VIEs at December 31, 2011 and March 31, 2012, respectively)	220		1,096
Investment in marketable securities	386		432
Accounts receivable, net ($52 and $64 related to VIEs at December 31, 2011 and March 31, 2012, respectively)	773		713
Accrued unbilled revenues	326		168
Natural gas inventory	187		87
Materials and supplies	166		168
Non-trading derivative assets	87		84
Prepaid expenses and other current assets ($42 and $56 related to VIEs at December 31, 2011 and March 31, 2012, respectively)	192		220
Total current assets	2,337		2,968

Property, Plant and Equipment:
Property, plant and equipment	16,868		17,073
Less accumulated depreciation and amortization	4,466		4,561
Property, plant and equipment, net	12,402		12,512

Other Assets:
Goodwill	1,696		1,696
Regulatory assets ($2,289 and $3,899 related to VIEs at December 31, 2011 and March 31, 2012, respectively)	4,619		4,524
Non-trading derivative assets	20		18
Investment in unconsolidated affiliates	472		474
Other	157		159
Total other assets	6,964		6,871

Total Assets	$	21,703	$	22,351

See Notes to Interim Condensed Consolidated Financial Statements

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CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS – (continued)

(In Millions)

(Unaudited)

LIABILITIES AND SHAREHOLDERS’ EQUITY



	December 31, 2011			March 31, 2012
Current Liabilities:
Short-term borrowings	$	62		$	9
Current portion of VIE transition and system restoration bonds long-term debt	307			380
Current portion of indexed debt	131			133
Current portion of other long-term debt	46			496
Indexed debt securities derivative	197			230
Accounts payable	560			366
Taxes accrued	207			164
Interest accrued	164			126
Non-trading derivative liabilities	46			18
Accumulated deferred income taxes, net	507			532
Other	366			281
Total current liabilities	2,593			2,735


Other Liabilities:
Accumulated deferred income taxes, net	3,832			3,944
Non-trading derivative liabilities	6			5
Benefit obligations	1,065			1,066
Regulatory liabilities	1,039			1,071
Other	305			239
Total other liabilities	6,247			6,325

Long-term Debt:
VIE transition and system restoration bonds	2,215			3,686
Other	6,426			5,319
Total long-term debt	8,641			9,005

Commitments and Contingencies (Note 11)

Shareholders’ Equity:
Common stock (426,030,345 shares and 427,294,767 shares outstanding at December 31, 2011 and March 31, 2012, respectively)	4			4
Additional paid-in capital	4,120			4,122
Retained earnings	231			291
Accumulated other comprehensive loss	(133		)	(131		)
Total shareholders’ equity	4,222			4,286

Total Liabilities and Shareholders’ Equity	$	21,703		$	22,351

See Notes to Interim Condensed Consolidated Financial Statements

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CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(In Millions)

(Unaudited)



	Three Months Ended March 31,
	2011			2012
Cash Flows from Operating Activities:
Net income	$	148		$	147
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	201			224
Amortization of deferred financing costs	7			8
Deferred income taxes	80			64
Unrealized gain on marketable securities	(32		)	(46		)
Unrealized loss on indexed debt securities	23			33
Write-down of natural gas inventory	—			4
Equity in earnings of unconsolidated affiliates, net of distributions	(3		)	2
Changes in other assets and liabilities:
Accounts receivable and unbilled revenues, net	48			193
Inventory	181			94
Taxes receivable	134			—
Accounts payable	(168		)	(172		)
Fuel cost over (under) recovery	13			(43		)
Non-trading derivatives, net	—			(3		)
Margin deposits, net	36			14
Interest and taxes accrued	(59		)	(87		)
Net regulatory assets and liabilities	17			42
Other current assets	23			(7		)
Other current liabilities	(32		)	(57		)
Other assets	2			2
Other liabilities	7			8
Other, net	1			4
Net cash provided by operating activities	627			424

Cash Flows from Investing Activities:
Capital expenditures	(333		)	(264		)
Increase in restricted cash of transition and system restoration bond companies	—			(15		)
Investment in unconsolidated affiliates	(3		)	(4		)
Cash received from U.S. Department of Energy grant	32			—
Other, net	(4		)	(9		)
Net cash used in investing activities	(308		)	(292		)

Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	(53		)	(53		)
Payments of commercial paper, net	(5		)	(285		)
Proceeds from long-term debt	550			1,695
Payments of long-term debt	(766		)	(526		)
Cash paid for debt exchange	(58		)	—
Debt issuance costs	(9		)	(8		)
Payment of common stock dividends	(84		)	(87		)
Proceeds from issuance of common stock, net	2			2
Other, net	—			6
Net cash provided by (used in) financing activities	(423		)	744

Net Increase (Decrease) in Cash and Cash Equivalents	(104		)	876
Cash and Cash Equivalents at Beginning of Period	199			220
Cash and Cash Equivalents at End of Period	$	95		$	1,096

Supplemental Disclosure of Cash Flow Information:
Cash Payments:
Interest, net of capitalized interest	$	186		$	178
Income tax refunds, net	(160		)	(8		)
Non-cash transactions:
Accounts payable related to capital expenditures	87			88

See Notes to Interim Condensed Consolidated Financial Statements

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CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


(1)	Background and Basis of Presentation

General. Included in this Quarterly Report on Form 10-Q (Form 10-Q) of CenterPoint Energy, Inc. are the condensed consolidated interim financial statements and notes (Interim Condensed Financial Statements) of CenterPoint Energy, Inc. and its subsidiaries (collectively, CenterPoint Energy). The Interim Condensed Financial Statements are unaudited, omit certain financial statement disclosures and should be read with the Annual Report on Form 10-K of CenterPoint Energy for the year ended December 31, 2011 (CenterPoint Energy Form 10-K).

Background. CenterPoint Energy, Inc. is a public utility holding company. CenterPoint Energy’s operating subsidiaries own and operate electric transmission and distribution facilities, natural gas distribution facilities, interstate pipelines and natural gas gathering, processing and treating facilities. As of March 31, 2012, CenterPoint Energy’s indirect wholly owned subsidiaries included:


•	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

•

CenterPoint Energy Resources Corp. (CERC Corp. and, together with its subsidiaries, CERC), which owns and operates natural gas distribution systems (Gas Operations). Subsidiaries of CERC Corp. own interstate natural gas pipelines and gas gathering systems and provide various ancillary services. 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 March 31, 2012, CenterPoint Energy had five 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 Energy 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 Energy.

Basis of Presentation. The preparation of financial statements in conformity with generally accepted accounting principles (U.S. GAAP) 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.

CenterPoint Energy’s Interim Condensed Financial Statements reflect all normal recurring adjustments that are, in the opinion of management, necessary to present fairly the financial position, results of operations and cash flows for the respective periods. Amounts reported in CenterPoint Energy’s Condensed Statements of Consolidated Income are not necessarily indicative of amounts expected for a full-year period due to the effects of, among other things, (a) seasonal fluctuations in demand for energy and energy services, (b) changes in energy commodity prices, (c) timing of maintenance and other expenditures and (d) acquisitions and dispositions of businesses, assets and other interests.

For a description of CenterPoint Energy’s reportable business segments, see Note 13.


(2)	New Accounting Pronouncements

In May 2011, the Financial Accounting Standards Board (FASB) issued new accounting guidance to achieve common fair value measurements and disclosure requirements in U.S. GAAP and International Financial Reporting Standards (IFRS). Some of the provisions of the new accounting guidance include requiring (1) that only non-financial assets should be valued based on a determination of their best use, (2) disclosure of quantitative information about unobservable inputs used in Level 3 fair value measurements and (3) disclosure of the level within the fair value hierarchy for each class of assets or liabilities not measured at fair value in the statement of financial position but for which the fair value is disclosed. This new guidance was effective for interim and annual periods beginning after December 15, 2011. CenterPoint Energy’s adoption of this new guidance did not have an impact on its financial position, results of operations or cash flows. See Note 6 for the required disclosures.

In June 2011, the FASB issued new accounting guidance on the presentation of comprehensive income. The new guidance is

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intended to improve the overall quality of financial reporting by increasing the prominence of items reported in other comprehensive income and aligning the presentation of other comprehensive income in financial statements prepared in accordance with U.S. GAAP with those prepared in accordance with IFRS. The new guidance requires an entity to present the total of comprehensive income, the components of net income and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. This new guidance was effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. Adoption of this new guidance did not have an impact on CenterPoint Energy’s financial position, results of operations or cash flows.

In September 2011, the FASB issued new accounting guidance that is intended to simplify how entities test goodwill for impairment. The new accounting guidance permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test. If, after performing the qualitative assessment, it is determined that the fair value of a reporting unit is more likely than not less than its carrying value, then the quantitative two-step goodwill impairment test that exists under current U.S. GAAP must be performed; otherwise, goodwill is deemed to not be impaired and no further testing is required. An entity has the unconditional option to bypass the qualitative assessment and proceed directly to the quantitative assessment. This new guidance is effective for annual and interim goodwill impairment tests performed for fiscal years beginning after December 15, 2011. CenterPoint Energy’s adoption of this new guidance did not have an impact on its financial position, results of operations or cash flows.

In December 2011, the FASB issued new accounting guidance that will require disclosure of information about offsetting and related arrangements to enable users of its financial statements to understand the effect of those arrangements on its financial position. The new disclosure requirements mandate that entities disclose both gross and net information for instruments and transactions eligible for offset in the statement of financial position as well as disclosure of collateral received and posted in connection with these instruments. This new guidance is effective for annual reporting periods beginning on or after January 1, 2013, and interim periods therein, with retrospective application required. CenterPoint Energy expects that the adoption of this new guidance will not have a material impact on its financial position, results of operations or cash flows.

Management believes the impact of 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.


(3)	Employee Benefit Plans

CenterPoint Energy’s net periodic cost includes the following components relating to pension and postretirement benefits:



	Three Months Ended March 31,
	2011						2012
	Pension Benefits ⁽¹⁾			Postretirement Benefits			Pension Benefits ⁽¹⁾			Postretirement Benefits
	(in millions)
Service cost	$	8		$	—		$	9		$	—
Interest cost	25			6			25			6
Expected return on plan assets	(29		)	(2		)	(30		)	(2		)
Amortization of prior service credit	1			1			2			1
Amortization of net loss	14			—			15			1
Amortization of transition obligation	—			2			—			2
Net periodic cost	$	19		$	7		$	21		$	8

________________


(1)	Net periodic cost in these tables is before considering amounts subject to overhead allocations for capital expenditure projects or for amounts subject to deferral for regulatory purposes.

CenterPoint Energy expects to contribute approximately $125 million to its pension plans in 2012, of which approximately $3 million was contributed during the three months ended March 31, 2012. A contribution of approximately $43 million was made in April 2012.

CenterPoint Energy expects to contribute approximately $18 million to its postretirement benefits plan in 2012, of which approximately $4 million was contributed during the three months ended March 31, 2012.

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(4)	Regulatory Accounting

As of March 31, 2012, CenterPoint Energy has not recognized an allowed equity return of $592 million because such return will be recognized as it is recovered in rates. During the three months ended March 31, 2011 and 2012, CenterPoint Houston recognized approximately $3 million and $8 million, respectively, of the allowed equity return not previously recognized.


(5)	Derivative Instruments

CenterPoint Energy is exposed to various market risks. These risks arise from transactions entered into in the normal course of business. CenterPoint Energy utilizes derivative instruments such as physical forward contracts, swaps and options to mitigate the impact of changes in commodity prices and weather on its operating results and cash flows. Such derivatives are recognized in CenterPoint Energy’s Condensed Consolidated Balance Sheets at their fair value unless CenterPoint Energy elects the normal purchase and sales exemption for qualified physical transactions. A derivative may be designated as a normal purchase or sale if the intent is to physically receive or deliver the product for use or sale in the normal course of business.

CenterPoint Energy has a Risk Oversight Committee composed of corporate and business segment officers that oversees all commodity price, weather and credit risk activities, including CenterPoint Energy’s marketing, risk management services and hedging activities. The committee’s duties are to establish CenterPoint Energy’s commodity risk policies, allocate board-approved commercial risk limits, approve the use of new products and commodities, monitor positions and ensure compliance with CenterPoint Energy’s risk management policies and procedures and limits established by CenterPoint Energy’s board of directors.

CenterPoint Energy’s policies prohibit the use of leveraged financial instruments. A leveraged financial instrument, for this purpose, is a transaction involving a derivative whose financial impact will be based on an amount other than the notional amount or volume of the instrument.


(a)	Non-Trading Activities

Derivative Instruments. CenterPoint Energy enters into certain derivative instruments to manage physical commodity price risks and does not engage in proprietary or speculative commodity trading. These financial instruments do not qualify or are not designated as cash flow or fair value hedges.

During the three months ended March 31, 2011, CenterPoint Energy recorded decreased natural gas revenues from unrealized net losses of $17 million and decreased natural gas expense from unrealized net gains of $15 million, resulting in a net unrealized loss of $2 million. During the three months ended March 31, 2012, CenterPoint Energy recorded decreased natural gas revenues from unrealized net losses of $5 million and decreased natural gas expense from unrealized net gains of $4 million, resulting in a net unrealized loss of $1 million.

Weather Hedges. CenterPoint Energy has weather normalization or other rate mechanisms that mitigate the impact of weather on its gas operations in Arkansas, Louisiana, Oklahoma and a portion of Texas. The remaining Gas Operations jurisdictions do not have such mechanisms. As a result, fluctuations from normal weather may have a significant positive or negative effect on Gas Operations’ results in the remaining jurisdictions and in CenterPoint Houston’s service territory.

CenterPoint Energy enters into heating-degree day swaps to mitigate the effect of fluctuations from normal weather on its results of operations and cash flows for the winter heating season. The swaps have limits and are based on ten-year normal weather. During the three months ended March 31, 2011 and 2012, CenterPoint Energy recognized a loss of $5 million and a gain of $6 million, respectively, related to these swaps. Weather hedge gains and losses are included in revenues in the Condensed Statements of Consolidated Income.

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(b)	Derivative Fair Values and Income Statement Impacts

The following tables present information about CenterPoint Energy’s derivative instruments and hedging activities. The first two tables provide a balance sheet overview of CenterPoint Energy’s Derivative Assets and Liabilities as of December 31, 2011 and March 31, 2012, while the last table provides a breakdown of the related income statement impacts for the three months ended March 31, 2011 and 2012.



Fair Value of Derivative Instruments
		December 31, 2011
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value (2) (3)		Derivative Liabilities Fair Value (2) (3)
		(in millions)
Natural gas derivatives (1)	Current Assets	$	88	$	1
Natural gas derivatives (1)	Other Assets	20		—
Natural gas derivatives (1)	Current Liabilities	15		110
Natural gas derivatives (1)	Other Liabilities	—		13
Indexed debt securities derivative	Current Liabilities	—		197
Total		$	123	$	321

________________


(1)	Natural gas contracts are subject to master netting arrangements and are presented on a net basis in the Condensed Consolidated Balance Sheets. This netting causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within the Condensed Consolidated Balance Sheets.


(2)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 633 billion cubic feet (Bcf) or a net 84 Bcf long position. Of the net long position, basis swaps constitute 74 Bcf and volumes associated with price stabilization activities of the Natural Gas Distribution business segment constitute 6 Bcf.


(3)	The net of total non-trading derivative assets and liabilities is a $55 million asset as shown on CenterPoint Energy’s Condensed Consolidated Balance Sheets, and is comprised of the natural gas contracts derivative assets and liabilities separately shown above offset by collateral netting of $56 million.



Fair Value of Derivative Instruments
		March 31, 2012
Total derivatives not designated as hedging instruments	Balance Sheet Location	Derivative Assets Fair Value (2) (3)		Derivative Liabilities Fair Value (2) (3)
		(in millions)
Natural gas derivatives (1)	Current Assets	$	85	$	1
Natural gas derivatives (1)	Other Assets	18		—
Natural gas derivatives (1)	Current Liabilities	14		68
Natural gas derivatives (1)	Other Liabilities	1		12
Indexed debt securities derivative	Current Liabilities	—		230
Total		$	118	$	311

________________


(1)	Natural gas contracts are subject to master netting arrangements and are presented on a net basis in the Condensed Consolidated Balance Sheets. This netting causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within the Condensed Consolidated Balance Sheets.


(2)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling 608 Bcf or a net 127 Bcf long position. Of the net long position, basis swaps constitute 78 Bcf.


(3)	The net of total non-trading derivative assets and liabilities is a $79 million asset as shown on CenterPoint Energy’s Condensed Consolidated Balance Sheets, and is comprised of the natural gas contracts derivative assets and liabilities separately shown above offset by collateral netting of $42 million.

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For CenterPoint Energy’s price stabilization activities of the Natural Gas Distribution business segment, the settled costs of derivatives are ultimately recovered through purchased gas adjustments. Accordingly, the net unrealized gains and losses associated with these contracts are recorded as net regulatory assets. Realized and unrealized gains and losses on other derivatives are recognized in the Condensed Statements of Consolidated Income as revenue for physical natural gas sales derivative contracts and as natural gas expense for financial natural gas derivatives and other physical natural gas derivatives. Unrealized gains and losses on indexed debt securities are recorded as Other Income (Expense) in the Condensed Statements of Consolidated Income.



Income Statement Impact of Derivative Activity
		Three Months Ended March 31,
Total derivatives not designated as hedging instruments	Income Statement Location	2011			2012
		(in millions)
Natural gas derivatives	Gains (Losses) in Revenue	$	5		$	51
Natural gas derivatives (1)	Gains (Losses) in Expense: Natural Gas	(37		)	(81		)
Indexed debt securities derivative	Gains (Losses) in Other Income (Expense)	(23		)	(33		)
Total		$	(55	)	$	(63	)

________________


(1)	The Gains (Losses) in Expense: Natural Gas includes $(45) million and $(38) million of costs in 2011 and 2012, respectively, associated with price stabilization activities of the Natural Gas Distribution business segment that will be ultimately recovered through purchased gas adjustments.


(c)	Credit Risk Contingent Features

CenterPoint Energy enters into financial derivative contracts containing material adverse change provisions. These provisions could require CenterPoint Energy to post additional collateral if the Standard & Poor’s Ratings Services or Moody’s Investors Service, Inc. credit ratings of CenterPoint Energy, Inc. or its subsidiaries are downgraded. The total fair value of the derivative instruments that contain credit risk contingent features that are in a net liability position at December 31, 2011 and March 31, 2012 was $39 million and $13 million, respectively. The aggregate fair value of assets that were posted as collateral was less than $1 million at both December 31, 2011 and March 31, 2012. If all derivative contracts (in a net liability position) containing credit risk contingent features were triggered at December 31, 2011 and March 31, 2012, $38 million and $13 million, respectively, of additional assets would be required to be posted as collateral.


(6)	Fair Value Measurements

Assets and liabilities that are recorded at fair value in the Condensed 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 generally are exchange-traded derivatives and equity securities.

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. Fair value assets and liabilities that are generally included in this category are derivatives with fair values based on inputs from actively quoted markets. A market approach is utilized to value CenterPoint Energy’s Level 2 assets or liabilities.

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 Energy’s judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. CenterPoint Energy develops these inputs based on the best information available, including CenterPoint Energy’s own data. A market approach is utilized to value CenterPoint Energy’s Level 3 assets or liabilities. Currently, CenterPoint Energy’s Level 3 assets and liabilities are comprised of physical forward contracts and options. Level 3 physical forward contracts are valued using a discounted cash flow model which includes illiquid forward price curve locations, for both paper basis and physical index premiums, as an unobservable input. Level 3 physical forward contracts are valued using a discounted cash flow model which includes illiquid forward price curve locations (ranging from $1.47-$4.46 per mmbtu) as an unobservable input. Level 3 options are valued through Black-Scholes (including forward start) option models which include option volatilities (ranging from 0-86%) as an unobservable input. CenterPoint Energy’s Level 3 derivative assets and liabilities consist of both long and short positions (forwards and options)

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and their fair value is sensitive to forward prices and volatilities. If forward prices decrease, CenterPoint Energy’s long forwards lose value whereas its short forwards gain in value. If volatility decreases, CenterPoint Energy’s long options lose value whereas its short options gain in value.

CenterPoint Energy 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. CenterPoint Energy also recognizes purchases of Level 3 financial assets and liabilities at their fair market value at the end of the reporting period.

The following tables present information about CenterPoint Energy’s assets and liabilities (including derivatives that are presented net) measured at fair value on a recurring basis as of December 31, 2011 and March 31, 2012, and indicate the fair value hierarchy of the valuation techniques utilized by CenterPoint Energy to determine such fair value.



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments ⁽¹⁾			Balance as of December 31, 2011
			Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments ⁽¹⁾			Balance as of December 31, 2011
	(in millions)
Assets
Corporate equities	$	387	$	—	$	—	$	—		$	387
Investments, including money market funds (2)	56		—		—		—			56
Natural gas derivatives	1		112		10		(16		)	107
Total assets	$	444	$	112	$	10	$	(16	)	$	550
Liabilities
Indexed debt securities derivative	$	—	$	197	$	—	$	—		$	197
Natural gas derivatives	19		101		4		(72		)	52
Total liabilities	$	19	$	298	$	4	$	(72	)	$	249

________________


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


(2)	Excludes money market fund investments included in Cash and cash equivalents.



	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments ⁽¹⁾			Balance as of March 31, 2012
			Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Netting Adjustments ⁽¹⁾			Balance as of March 31, 2012
	(in millions)
Assets
Corporate equities	$	434	$	—	$	—	$	—		$	434
Investments, including money market funds (2)	70		—		—		—			70
Natural gas derivatives	2		109		7		(16		)	102
Total assets	$	506	$	109	$	7	$	(16	)	$	606
Liabilities
Indexed debt securities derivative	$	—	$	230	$	—	$	—		$	230
Natural gas derivatives	17		60		4		(58		)	23
Total liabilities	$	17	$	290	$	4	$	(58	)	$	253

________________


(1)	Amounts represent the impact of legally enforceable master netting agreements that allow CenterPoint Energy to settle positive and negative positions and also include cash collateral of $42 million posted with the same counterparties.


(2)	Excludes money market fund investments included in Cash and cash equivalents.

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The following tables present additional information about assets or liabilities, including derivatives that are measured at fair value on a recurring basis for which CenterPoint Energy has utilized Level 3 inputs to determine fair value:



	Fair Value Measurements Using Significant Unobservable Inputs (Level 3)
	Derivative Assets and Liabilities, net
	Three Months Ended March 31,
	2011		2012
	(in millions)
Beginning balance	$	3	$	6
Total unrealized gains ⁽¹⁾	3		2
Total settlements ⁽¹⁾	—		(4		)
Transfers out of Level 3	—		(1		)
Ending balance ⁽²⁾	$	6	$	3
The amount of total gains for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date	$	4	$	—

________________


(1)	CenterPoint Energy did not have Level 3 unrealized gain (losses) or settlements related to price stabilization activities of the Natural Gas Distribution business segment for either the three months ended March 31, 2011 or 2012.


(2)	During both the three months ended March 31, 2011 and 2012, CenterPoint Energy did not have Level 3 purchases, sales or significant transfers into Level 3.

Estimated Fair Value of Financial Instruments

The fair values of cash and cash equivalents, investments in debt and equity securities classified as “available-for-sale” and “trading” and short-term borrowings are estimated to be approximately equivalent to carrying amounts and have been excluded from the table below. The fair values of non-trading derivative assets and liabilities and CenterPoint Energy’s 2.00% Zero-Premium Exchangeable Subordinated Notes due 2029 indexed debt securities derivative are stated at fair value and are 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 Condensed Consolidated Balance Sheets but for which the fair value is disclosed, would be classified as Level 1 in the fair value hierarchy.



	December 31, 2011				March 31, 2012
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)
Financial liabilities:
Long-term debt	$	8,994	$	10,049	$	9,881	$	10,898


(7)	Goodwill

Goodwill by reportable business segment as of both December 31, 2011 and March 31, 2012 is as follows (in millions):



Natural Gas Distribution	$	746
Interstate Pipelines	579
Competitive Natural Gas Sales and Services	335
Field Services	25
Other Operations	11
Total	$	1,696

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(8)	Capital Stock

CenterPoint Energy, Inc. has 1,020,000,000 authorized shares of capital stock, comprised of 1,000,000,000 shares of $0.01 par value common stock and 20,000,000 shares of $0.01 par value preferred stock. At December 31, 2011, 426,030,511 shares of CenterPoint Energy, Inc. common stock were issued and 426,030,345 shares were outstanding. At March 31, 2012, 427,294,933 shares of CenterPoint Energy, Inc. common stock were issued and 427,294,767 shares were outstanding. Outstanding common shares exclude 166 treasury shares at both December 31, 2011 and March 31, 2012.


(9)	Short-term Borrowings and Long-term Debt


(a)	Short-term Borrowings

Inventory Financing. Gas Operations has entered into asset management agreements associated with its utility distribution service in Arkansas, north Louisiana and Oklahoma that extend through March 2015. Pursuant to the provisions of the agreements, Gas Operations sells natural gas and agrees to repurchase an equivalent amount of natural gas during the winter heating seasons at the same cost, plus a financing charge. These transactions are accounted for as a financing and they had an associated principal obligation of $62 million and $9 million as of December 31, 2011 and March 31, 2012, respectively.


(b)	Long-term Debt

Transition Bonds. In January 2012, CenterPoint Energy Transition Bond Company IV, LLC, a new special purpose subsidiary of CenterPoint Houston, issued $1.695 billion of transition bonds in three tranches with interest rates ranging from 0.9012% to 3.0282% and final maturity dates ranging from April 15, 2018 to October 15, 2025. The transition bonds will be repaid over time through a charge imposed on customers in CenterPoint Houston’s service territory.

Pollution Control Bonds. In February 2012, CenterPoint Energy purchased $275 million aggregate principal amount of pollution control bonds issued on its behalf at 100% of their principal amount plus accrued interest pursuant to the mandatory tender provisions of the bonds. The purchased pollution control bonds will remain outstanding and may be remarketed. Prior to the purchase, the pollution control bonds had fixed interest rates ranging from 5.15% to 5.95%. Additionally, in March 2012, CenterPoint Energy redeemed $100 million aggregate principal amount of pollution control bonds issued on its behalf at 100% of their principal amount plus accrued interest pursuant to the optional redemption provisions of the bonds. The redeemed pollution control bonds had a fixed interest rate of 5.25%.

Revolving Credit Facilities. As of December 31, 2011 and March 31, 2012, CenterPoint Energy, CenterPoint Houston and CERC Corp. had the following revolving credit facilities and utilization of such facilities (in millions):



			December 31, 2011						March 31, 2012
	Size of Facility		Loans		Letters of Credit		Commercial Paper		Loans		Letters of Credit		Commercial Paper
CenterPoint Energy	$	1,200	$	—	$	16	$	—	$	—	$	13	$	—
CenterPoint Houston	300		—		4		—		—		4		—
CERC Corp.	950		—		—		285		—		—		—
Total	$	2,450	$	—	$	20	$	285	$	—	$	17	$	—

CenterPoint Energy’s $1.2 billion credit facility, which is scheduled to terminate September 9, 2016, can be drawn at the London Interbank Offered Rate (LIBOR) plus 175 basis points based on CenterPoint Energy’s current credit ratings. The facility contains a debt (excluding transition and system restoration bonds) to earnings before interest, taxes, depreciation and amortization (EBITDA) covenant (as those terms are defined in the facility). The facility allows for a temporary increase of the permitted ratio in the financial covenant from 5 times to 5.5 times if CenterPoint Houston experiences damage from a natural disaster in its service territory and CenterPoint Energy certifies to the administrative agent that CenterPoint Houston has incurred system restoration costs reasonably likely to exceed $100 million in a consecutive twelve-month period, all or part of which CenterPoint Houston intends to seek to recover through securitization financing. Such temporary increase in the financial covenant would be in effect from the date CenterPoint Energy delivers its certification until the earliest to occur of (i) the completion of the securitization financing, (ii) the first anniversary of CenterPoint Energy’s certification or (iii) the revocation of such certification.

CenterPoint Houston’s $300 million credit facility, which is scheduled to terminate September 9, 2016, can be drawn at LIBOR plus 150 basis points based on CenterPoint Houston’s current credit ratings. The facility contains a debt (excluding transition and

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system restoration bonds) to total capitalization covenant which limits debt to 65% of the borrower’s total capitalization.

CERC Corp.’s $950 million credit facility, which is scheduled to terminate September 9, 2016, can be drawn at LIBOR plus 150 basis points based on CERC Corp.’s current credit ratings. The facility contains a debt to total capitalization covenant which limits debt to 65% of CERC’s total capitalization.


(10)	Income Taxes

CenterPoint Energy reported an effective tax rate of 33% for the three months ended March 31, 2012 compared to 37% for the same period in 2011. The decrease in the effective tax rate of 4% was primarily due to a $10 million reduction to the uncertain tax liability related to a settlement with the Internal Revenue Service (IRS) of CenterPoint Energy’s consolidated federal income tax returns for tax years 2006 and 2007.

The following table summarizes CenterPoint Energy’s unrecognized tax benefits (expense) at December 31, 2011 and March 31, 2012:



	December 31, 2011			March 31, 2012
	(in millions)
Unrecognized tax benefits (expense)	$	51		$	(2	)
Portion of unrecognized tax benefits that, if recognized, would reduce the effective income tax rate	21			15
Interest accrued on unrecognized tax benefits	(1		)	(10		)

CenterPoint Energy does not expect the amount of unrecognized tax benefits to change significantly over the 12 months ending March 31, 2013.

CenterPoint Energy is currently under examination by the IRS for tax years 2008 and 2009 and is at various stages of the examination process.


(11)	Commitments and Contingencies


(a)	Natural Gas Supply Commitments

Natural gas supply commitments include natural gas contracts related to CenterPoint Energy’s Natural Gas Distribution and Competitive Natural Gas Sales and Services business segments, which have various quantity requirements and durations, that are not classified as non-trading derivative assets and liabilities in CenterPoint Energy’s Condensed Consolidated Balance Sheets as of December 31, 2011 and March 31, 2012 as these contracts meet the exception to be classified as “normal purchases contracts” or do not meet the definition of a derivative. Natural gas supply commitments also include natural gas transportation contracts that do not meet the definition of a derivative. As of March 31, 2012, minimum payment obligations for natural gas supply commitments are approximately $226 million for the remaining nine months in 2012, $418 million in 2013, $337 million in 2014, $211 million in 2015, $149 million in 2016 and $251 million after 2016.


(b)	Long-Term Gas Gathering and Treating Agreements

CenterPoint Energy Field Services, LLC (CEFS) has long-term agreements with an indirect wholly-owned subsidiary of Encana Corporation (Encana) and an indirect wholly-owned subsidiary of Royal Dutch Shell plc (Shell) to provide gathering and treating services for their natural gas production from certain Haynesville Shale and Bossier Shale formations in Texas and Louisiana.

Under the long-term agreements, Encana or Shell may elect to require CEFS to expand the capacity of its gathering systems by up to an additional 1.3 Bcf per day. CEFS estimates that the cost to expand the capacity of its gathering systems by an additional 1.3Bcf per day would be as much as $440 million. Encana and Shell would provide incremental volume commitments in connection with an election to expand system capacity.

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(c)	Legal, Environmental and Other Regulatory 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 are named as defendants in certain lawsuits described below. Under a master separation agreement between CenterPoint Energy and a former subsidiary, RRI Energy, Inc. (RRI), CenterPoint Energy and its subsidiaries are entitled to be indemnified by RRI and its successors for any losses, including attorneys’ fees and other costs, arising out of these lawsuits. In May 2009, RRI sold its Texas retail business to a subsidiary of NRG Energy, Inc. (NRG) and 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). Neither the sale of the retail business nor the merger with Mirant Corporation 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, nor does it affect the terms of existing guaranty arrangements for certain GenOn gas transportation contracts discussed below.

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’s former affiliate, RRI, was a participant in gas trading in the California and Western markets. These lawsuits, many of which have been filed as class actions, allege violations of state and federal antitrust laws. Plaintiffs in these lawsuits are seeking a variety of forms of relief, including, among others, recovery of compensatory damages (in some cases in excess of $1 billion), a trebling of compensatory damages, full consideration damages and attorneys’ fees. CenterPoint Energy and/or Reliant Energy were named in approximately 30 of these lawsuits, which were instituted between 2003 and 2009. CenterPoint Energy and its affiliates have been released or dismissed from all but two of such cases. 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 the other defendants in the case, each of whom had demonstrated FERC jurisdictional sales for resale during the relevant period, based on federal preemption. The plaintiffs have appealed this ruling to the United States Court of Appeals for the Ninth Circuit. Additionally, CenterPoint Energy was a defendant in a lawsuit filed in state court in Nevada that was dismissed in 2007, but in March 2010 the plaintiffs appealed the dismissal to the Nevada Supreme Court. CenterPoint Energy believes that neither it nor CES is a proper defendant in these remaining cases and will continue to pursue dismissal from those cases. CenterPoint Energy does not expect the ultimate outcome of these remaining matters to have a material impact on its financial condition, results of operations or cash flows.

Natural Gas Measurement Lawsuits. CERC Corp. and certain of its subsidiaries are defendants in two mismeasurement lawsuits brought against approximately 245 pipeline companies and their affiliates pending in state court in Stevens County, Kansas. In one case (originally filed in May 1999 and amended four times), the plaintiffs purport to represent a class of royalty owners who allege that the defendants have engaged in systematic mismeasurement of the volume of natural gas for more than 25 years. The plaintiffs amended their petition in this suit in July 2003 in response to an order from the judge denying certification of the plaintiffs’ alleged class. In the amendment, the plaintiffs dismissed their claims against certain defendants (including two CERC Corp. subsidiaries), limited the scope of the class of plaintiffs they purport to represent and eliminated previously asserted claims based on mismeasurement of the British thermal unit (Btu) content of the gas. The same plaintiffs then filed a second lawsuit, again as representatives of a putative class of royalty owners in which they assert their claims that the defendants have engaged in systematic mismeasurement of the Btu content of natural gas for more than 25 years. In both lawsuits, the plaintiffs seek compensatory damages, along with statutory penalties, treble damages, interest, costs and fees. In September 2009, the district court in Stevens County, Kansas, denied plaintiffs’ request for class certification of their case and, in March 2010, denied the plaintiffs’ request for reconsideration of that order. The time for seeking review of the district court’s decision has now passed.

CERC believes that there has been no systematic mismeasurement of gas and that these lawsuits are without merit. CERC and CenterPoint Energy do not expect the ultimate outcome of the lawsuits to have a material impact on the financial condition, results of operations or cash flows of either CenterPoint Energy or CERC.

Environmental Matters

Manufactured Gas Plant Sites. CERC and its predecessors operated manufactured gas plants (MGPs) in the past. In Minnesota, CERC has completed remediation on two sites, other than ongoing monitoring and water treatment. There are five remaining sites in CERC’s Minnesota service territory. CERC believes that it has no liability with respect to two of these sites.

At March 31, 2012, CERC had accrued $13 million for remediation of these Minnesota sites and the estimated range of

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possible remediation costs for these sites was $6 million to $41 million based on remediation continuing for 30 to 50 years. The cost estimates are based on studies of a site or industry average costs for remediation of sites of similar size. The actual remediation costs will be dependent upon the number of sites to be remediated, the participation of other potentially responsible parties (PRPs), if any, and the remediation methods used. The Minnesota Public Utility Commission provided for the inclusion in rates of approximately $285,000 annually to fund normal on-going remediation costs. As of March 31, 2012, CERC had collected $5.6 million from insurance companies to be used to mitigate future environmental costs.

In addition to the Minnesota sites, the United States Environmental Protection Agency and other regulators have investigated MGP sites that were owned or operated by CERC or may have been owned by one of its former affiliates. CERC and CenterPoint Energy do not expect the ultimate outcome of these investigations will have a material adverse impact on the financial condition, results of operations or cash flows of either CenterPoint Energy or CERC.

Asbestos. Some facilities owned by CenterPoint Energy contain or have contained asbestos insulation and other asbestos-containing materials. CenterPoint Energy or its subsidiaries 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 subsidiaries of CenterPoint Energy, but most existing claims relate to facilities previously owned by CenterPoint Energy’s subsidiaries. CenterPoint Energy anticipates that additional claims like those received may be asserted in the future. 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. Although their ultimate outcome cannot be predicted at this time, CenterPoint Energy intends to continue vigorously contesting claims that it does not consider to have merit and does not expect, based on its experience to date, these matters, either individually or in the aggregate, to have a material adverse effect on CenterPoint Energy’s financial condition, results of operations or cash flows.

Other Environmental. From time to time CenterPoint Energy identifies the presence of environmental contaminants on property where its subsidiaries conduct or have conducted operations. Other such sites involving contaminants may be identified in the future. CenterPoint Energy has and expects to continue to remediate identified sites consistent with its legal obligations. From time to time CenterPoint Energy has received notices from regulatory authorities or others regarding its status as a PRP in connection with sites found to require remediation due to the presence of environmental contaminants. In addition, CenterPoint Energy 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 Energy does not expect, based on its experience to date, these matters, either individually or in the aggregate, to have a material adverse effect on CenterPoint Energy’s financial condition, results of operations or cash flows.

Other Proceedings

CenterPoint Energy 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. Some of these proceedings involve substantial amounts. CenterPoint Energy regularly analyzes current information and, as necessary, provides accruals for probable liabilities on the eventual disposition of these matters. CenterPoint Energy does not expect the disposition of these matters to have a material adverse effect on CenterPoint Energy’s financial condition, results of operations or cash flows.


(d)	Guaranties

Prior to the distribution of CenterPoint Energy’s ownership in RRI to its shareholders, CERC had guaranteed certain contractual obligations of what became RRI’s trading subsidiary. When the companies separated, RRI agreed to secure CERC against obligations under the guaranties RRI had been unable to extinguish by the time of separation. Pursuant to such agreement, as amended in December 2007, RRI (now GenOn) agreed to provide to CERC cash or letters of credit as security against CERC’s obligations under its remaining guaranties for demand charges under certain gas transportation agreements if and to the extent changes in market conditions expose CERC to a risk of loss on those guaranties based on an annual calculation, with any required collateral to be posted each December. The undiscounted maximum potential payout of the demand charges under these transportation contracts, which will be in effect until 2018, was approximately $86 million as of March 31, 2012. Market conditions in the fourth quarters of 2010 and 2011 required posting of security under the agreement, and GenOn has posted approximately $28 million of collateral as of March 31, 2012. If GenOn should fail to perform the contractual obligations, CERC could have to honor its guarantee and, in such event, collateral provided as security may be insufficient to satisfy CERC’s obligations.

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(12)	Earnings Per Share

The following table reconciles numerators and denominators of CenterPoint Energy’s basic and diluted earnings per share calculations:



	Three Months Ended March 31,
	2011		2012
	(in millions, except share and per share amounts)
Basic earnings per share calculation:
Net income	$	148	$	147

Weighted average shares outstanding	425,018,000		426,499,000

Basic earnings per share:
Net income	$	0.35	$	0.34

Diluted earnings per share calculation:
Net income	$	148	$	147

Weighted average shares outstanding	425,018,000		426,499,000
Plus: Incremental shares from assumed conversions:
Stock options ⁽¹⁾	461,000		240,000
Restricted stock	1,936,000		1,753,000
Weighted average shares assuming dilution	427,415,000		428,492,000

Diluted earnings per share:
Net income	$	0.35	$	0.34

________________


(1)	Options to purchase 111,760 shares were outstanding for the three months ended March 31, 2011, but were not included in the computation of diluted earnings per share because the options’ exercise price was greater than the average market price of the common shares for the respective periods.


(13)	Reportable Business Segments

CenterPoint Energy’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. CenterPoint Energy uses operating income as the measure of profit or loss for its business segments.

CenterPoint Energy’s reportable business segments include the following: Electric Transmission & Distribution, Natural Gas Distribution, Competitive Natural Gas Sales and Services, Interstate Pipelines, Field Services and Other Operations. The electric transmission and distribution function (CenterPoint Houston) is reported in the Electric Transmission & Distribution business segment. Natural Gas Distribution consists of intrastate natural gas sales to, and natural gas transportation and distribution for, residential, commercial, industrial and institutional customers. Competitive Natural Gas Sales and Services represents CenterPoint Energy’s non-rate regulated gas sales and services operations. The Interstate Pipelines business segment includes the interstate natural gas pipeline operations. The Field Services business segment includes the non-rate regulated natural gas gathering, processing and treating operations. Other Operations consists primarily of other corporate operations which support all of CenterPoint Energy’s business operations.

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Financial data for business segments are as follows (in millions):



	For the Three Months Ended March 31, 2011
	Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Total Assets as of December 31, 2011
Electric Transmission & Distribution	$	489	⁽¹⁾	$	—		$	101		$	11,221
Natural Gas Distribution	1,207			5			142			4,636
Competitive Natural Gas Sales and Services	697			9			10			1,089
Interstate Pipelines	113			34			76			3,867
Field Services	78			12			36			1,894
Other Operations	3			—			(1		)	2,318			⁽²⁾
Eliminations	—			(60		)	—			(3,322		)
Consolidated	$	2,587		$	—		$	364		$	21,703



	For the Three Months Ended March 31, 2012
	Revenues from External Customers			Net Intersegment Revenues			Operating Income		Total Assets as of March 31, 2012
Electric Transmission & Distribution	$	531	⁽¹⁾	$	—		$	107	$	11,001
Natural Gas Distribution	849			5			121		4,518
Competitive Natural Gas Sales and Services	520			5			1		1,031
Interstate Pipelines	82			45			60		3,884
Field Services	99			6			47		1,902
Other Operations	3			—			2		2,292			⁽²⁾
Eliminations	—			(61		)	—		(2,277		)
Consolidated	$	2,084		$	—		$	338	$	22,351

________________

(1)

Sales to affiliates of NRG in the three months ended March 31, 2011 and 2012 represented approximately $126 million and $140 million, respectively, of CenterPoint Houston’s transmission and distribution revenues. Sales to affiliates of Energy Future Holdings Corp. in the three months ended March 31, 2011 and 2012 represented approximately $40 million and $36 million, respectively, of CenterPoint Houston’s transmission and distribution revenues.


(2)	Included in total assets of Other Operations as of December 31, 2011 and March 31, 2012 are pension and other postemployment related regulatory assets of $796 million and $783 million, respectively.


(14)	Subsequent Events

On April 26, 2012, CenterPoint Energy’s board of directors declared a regular quarterly cash dividend of $0.2025 per share of common stock payable on June 8, 2012, to shareholders of record as of the close of business on May 16, 2012.

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Item 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS OF CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

The following discussion and analysis should be read in combination with our Interim Condensed Financial Statements contained in this Form 10-Q and our Annual Report on Form 10-K for the year ended December 31, 2011 (2011 Form 10-K).

EXECUTIVE SUMMARY

Recent Events

Debt Financing Transactions

In January 2012, CenterPoint Energy Transition Bond Company IV, LLC (Bond Company IV), a new special purpose subsidiary of CenterPoint Energy Houston Electric, LLC (CenterPoint Houston), issued $1.695 billion of transition bonds in three tranches with interest rates ranging from 0.9012% to 3.0282% and final maturity dates ranging from April 15, 2018 to October 15, 2025. Through the issuance of these transition bonds, CenterPoint Houston recovered an additional true-up balance of $1.695 billion (the Recoverable True-Up Balance), less approximately $10.4 million of offering expenses. The transition bonds will be repaid over time through a charge imposed on customers in CenterPoint Houston’s service territory.

In February 2012, we purchased $275 million aggregate principal amount of pollution control bonds issued on our behalf at 100% of their principal amount plus accrued interest pursuant to the mandatory tender provisions of the bonds. The purchased pollution control bonds will remain outstanding and may be remarketed. Prior to the purchase, the pollution control bonds had fixed interest rates ranging from 5.15% to 5.95%. Additionally, in March 2012, we redeemed $100 million aggregate principal amount of pollution control bonds issued on our behalf at 100% of their principal amount plus accrued interest pursuant to the optional redemption provisions of the bonds. The redeemed pollution control bonds had a fixed interest rate of 5.25%.

CONSOLIDATED RESULTS OF OPERATIONS

All dollar amounts in the tables that follow are in millions, except for per share amounts.



	Three Months Ended March 31,
	2011			2012
Revenues	$	2,587		$	2,084
Expenses	2,223			1,746
Operating Income	364			338
Interest and Other Finance Charges	(116		)	(110		)
Interest on Transition and System Restoration Bonds	(33		)	(37		)
Equity in Earnings of Unconsolidated Affiliates	6			9
Other Income, net	14			19
Income Before Income Taxes	235			219
Income Tax Expense	87			72
Net Income	$	148		$	147

Basic Earnings Per Share	$	0.35		$	0.34

Diluted Earnings Per Share	$	0.35		$	0.34

Three months ended March 31, 2012 compared to three months ended March 31, 2011

We reported consolidated net income of $147 million ($0.34 per diluted share) for the three months ended March 31, 2012 compared to $148 million ($0.35 per diluted share) for the same period in 2011. The decrease in net income of $1 million was primarily due to a $26 million decrease in operating income (discussed by segment below) and a $10 million increase in the loss on our indexed debt securities, which were partially offset by a $15 million decrease in income tax expense and a $14 million increase in the gain on our marketable securities.

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Income Tax Expense

We reported an effective tax rate of 33% for the three months ended March 31, 2012 compared to 37% for the same period in 2011. The decrease in the effective tax rate of 4% is primarily due to a $10 million reduction to the uncertain tax liability related to a settlement with the Internal Revenue Service of our consolidated federal income tax returns for tax years 2006 and 2007.

RESULTS OF OPERATIONS BY BUSINESS SEGMENT

The following table presents operating income (loss) (in millions) for each of our business segments for the three months ended March 31, 2011 and 2012. Included in revenues are intersegment sales. We account for intersegment sales as if the sales were to third parties, that is, at current market prices.



	Three Months Ended March 31,
	2011			2012
Electric Transmission & Distribution	$	101		$	107
Natural Gas Distribution	142			121
Competitive Natural Gas Sales and Services	10			1
Interstate Pipelines	76			60
Field Services	36			47
Other Operations	(1		)	2
Total Consolidated Operating Income	$	364		$	338

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Electric Transmission & Distribution

For information regarding factors that may affect the future results of operations of our Electric Transmission & Distribution business segment, please read “Risk Factors ─ Risk Factors Affecting Our Electric Transmission & Distribution Business,” “─ Risk Factors Associated with Our Consolidated Financial Condition” and “─ Risks Common to Our Businesses and Other Risks” in Item 1A of Part I of our 2011 Form 10-K.

The following tables provide summary data of our Electric Transmission & Distribution business segment for the three months ended March 31, 2011 and 2012 (in millions, except throughput and customer data):



	Three Months Ended March 31,
	2011		2012
Revenues:
Electric transmission and distribution utility	$	400	$	415
Transition and system restoration bond companies	89		116
Total revenues	489		531
Expenses:
Operation and maintenance, excluding transition and system restoration bond companies	208		220
Depreciation and amortization, excluding transition and system restoration bond companies	71		73
Taxes other than income taxes	53		52
Transition and system restoration bond companies	56		79
Total expenses	388		424
Operating Income	$	101	$	107

Operating Income:
Electric transmission and distribution utility	$	68	$	70
Transition and system restoration bond companies (1)	33		37
Total segment operating income	$	101	$	107

Throughput (in gigawatt-hours (GWh)):
Residential	4,871		4,525
Total	16,768		16,544

Number of metered customers at end of period:
Residential	1,879,796		1,914,906
Total	2,124,809		2,167,052

________________


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

Three months ended March 31, 2012 compared to three months ended March 31, 2011

Our Electric Transmission & Distribution business segment reported operating income of $107 million for the three months ended March 31, 2012, consisting of $70 million from the regulated electric transmission and distribution utility (TDU) and $37 million related to transition and system restoration bond companies (Bond Companies). For the three months ended March 31, 2011, operating income totaled $101 million, consisting of $68 million from the TDU and $33 million related to Bond Companies. TDU operating income increased $2 million due to increased miscellaneous revenues ($11 million), primarily from right-of-way access and land grants, customer growth ($5 million) from the addition of over 42,000 new customers and higher equity return ($4 million) primarily due to the recovery of true-up proceeds, partially offset by the impact of the 2010 rate case implemented in September 2011 ($11 million) and decreased usage ($8 million), primarily due to milder winter weather.

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Natural Gas Distribution

For information regarding factors that may affect the future results of operations of our Natural Gas Distribution business segment, please read “Risk Factors ─ Risk Factors Affecting Our Natural Gas Distribution, Competitive Natural Gas Sales and Services, Interstate Pipelines and Field Services Businesses,” “─ Risk Factors Associated with Our Consolidated Financial Condition” and “─ Risks Common to Our Businesses and Other Risks” in Item 1A of Part I of our 2011 Form 10-K.

The following table provides summary data of our Natural Gas Distribution business segment for the three months ended March 31, 2011 and 2012 (in millions, except throughput and customer data):



	Three Months Ended March 31,
	2011		2012
Revenues	$	1,212	$	854
Expenses:
Natural gas	818		493
Operation and maintenance	168		163
Depreciation and amortization	42		43
Taxes other than income taxes	42		34
Total expenses	1,070		733
Operating Income	$	142	$	121

Throughput (in billion cubic feet (Bcf)):
Residential	90		62
Commercial and industrial	88		74
Total Throughput	178		136

Number of customers at end of period:
Residential	3,029,079		3,042,617
Commercial and industrial	246,987		246,852
Total	3,276,066		3,289,469

Three months ended March 31, 2012 compared to three months ended March 31, 2011

Our Natural Gas Distribution business segment reported operating income of $121 million for the three months ended March 31, 2012 compared to $142 million for the three months ended March 31, 2011. Operating income decreased $21 million primarily as a result of decreased throughput primarily due to the impacts of warmer winter weather partially mitigated by weather hedges and weather normalization adjustments ($24 million) and increased other expenses ($3 million). Adverse impacts were partially offset by the addition of over 13,000 customers ($1 million), lower bad debt expense ($5 million) and rate increases ($4 million). Increased expense related to energy efficiency programs ($3 million) and decreased expense related to lower gross receipt taxes ($9 million) were offset by the related revenues.

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Competitive Natural Gas Sales and Services

For information regarding factors that may affect the future results of operations of our Competitive Natural Gas Sales and Services business segment, please read “Risk Factors ─ Risk Factors Affecting Our Natural Gas Distribution, Competitive Natural Gas Sales and Services, Interstate Pipelines and Field Services Businesses,” “─ Risk Factors Associated with Our Consolidated Financial Condition” and “─ Risks Common to Our Businesses and Other Risks” in Item 1A of Part I of our 2011 Form 10-K.

The following table provides summary data of our Competitive Natural Gas Sales and Services business segment for the three months ended March 31, 2011 and 2012 (in millions, except throughput and customer data):



	Three Months Ended March 31,
	2011		2012
Revenues	$	706	$	525
Expenses:
Natural gas	685		511
Operation and maintenance	10		12
Depreciation and amortization	1		1
Taxes other than income taxes	—		—
Total expenses	696		524
Operating Income	$	10	$	1

Throughput (in Bcf)	155		161

Number of customers at end of period	11,942		14,495

Three months ended March 31, 2012 compared to three months ended March 31, 2011

Our Competitive Natural Gas Sales and Services business segment reported operating income of $1 million for the three months ended March 31, 2012 compared to $10 million for the three months ended March 31, 2011. The decrease in operating income of $9 million is attributable to milder winter weather and compressed margins of $4 million, higher operation and maintenance expenses of $2 million and a $4 million write-down of natural gas inventory to the lower of cost or market. The first quarter of 2012 also included charges of $1 million resulting from mark-to-market accounting for derivatives associated with certain forward natural gas purchases and sales used to lock in economic margins compared to charges of $2 million for the same period of 2011. Throughput volumes and the number of customers increased in the first quarter of 2012 compared to the first quarter of 2011 as a result of continued growth in this segment's commercial retail business.

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Interstate Pipelines

For information regarding factors that may affect the future results of operations of our Interstate Pipelines business segment, please read “Risk Factors ─ Risk Factors Affecting Our Natural Gas Distribution, Competitive Natural Gas Sales and Services, Interstate Pipelines and Field Services Businesses,” “─ Risk Factors Associated with Our Consolidated Financial Condition” and “─ Risks Common to Our Businesses and Other Risks” in Item 1A of Part I of our 2011 Form 10-K.

The following table provides summary data of our Interstate Pipelines business segment for the three months ended March 31, 2011 and 2012 (in millions, except throughput data):



	Three Months Ended March 31,
	2011		2012
Revenues	$	147	$	127
Expenses:
Natural gas	18		7
Operation and maintenance	31		38
Depreciation and amortization	13		14
Taxes other than income taxes	9		8
Total expenses	71		67
Operating Income	$	76	$	60

Equity in earnings of unconsolidated affiliates	$	4	$	6

Transportation throughput (in Bcf)	455		378

Three months ended March 31, 2012 compared to three months ended March 31, 2011

Our Interstate Pipeline business segment reported operating income of $60 million for the three months ended March 31, 2012 compared to $76 million for the three months ended March 31, 2011. Margins (revenues less natural gas costs) decreased $9 million primarily due to lower revenues on the Carthage to Perryville pipeline as a result of an expired backhaul contract ($10 million) and from reduced gains on retained fuel and other revenues ($3 million) as well as lower off-system revenues ($3 million), which were partially offset by increased revenues from the effects of the restructured 10-year agreement with our natural gas distribution affiliate ($4 million) and ancillary services ($3 million). Operation and maintenance expenses increased $7 million primarily due to a 2011 insurance settlement ($4 million) and timing of expenses ($3 million). Depreciation and amortization expenses increased primarily due to prior year expenditures for maintenance capital ($1 million) which were offset by a decrease in taxes other than income ($1 million).

Equity Earnings. In addition, this business segment recorded equity income of $4 million and $6 million for the three months ended March 31, 2011 and 2012, respectively, from its 50% interest in the Southeast Supply Header, a jointly-owned pipeline. These amounts are included in Equity in Earnings of Unconsolidated Affiliates under the Other Income (Expense) caption.

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Field Services

For information regarding factors that may affect the future results of operations of our Field Services business segment, please read “Risk Factors ─ Risk Factors Affecting Our Natural Gas Distribution, Competitive Natural Gas Sales and Services, Interstate Pipelines and Field Services Businesses,” “─ Risk Factors Associated with Our Consolidated Financial Condition” and “─ Risks Common to Our Businesses and Other Risks” in Item 1A of Part I of our 2011 Form 10-K.

The following table provides summary data of our Field Services business segment for the three months ended March 31, 2011 and 2012 (in millions, except throughput data):



	Three Months Ended March 31,
	2011		2012
Revenues	$	90	$	105
Expenses:
Natural gas	15		18
Operation and maintenance	29		27
Depreciation and amortization	9		11
Taxes other than income taxes	1		2
Total expenses	54		58
Operating Income	$	36	$	47

Equity in earnings of unconsolidated affiliates	$	2	$	3

Gathering throughput (in Bcf)	183		237

Three months ended March 31, 2012 compared to three months ended March 31, 2011

Our Field Services business segment reported operating income of $47 million for the three months ended March 31, 2012 compared to $36 million for the three months ended March 31, 2011. Margins (revenues less natural gas costs) increased $12 million primarily due to to higher throughput from gathering projects in the Haynesville and Fayetteville shales and growth in core gathering services, including revenues from annual contracted volume commitments ($18 million), partially offset by lower commodity prices ($6 million) from sales of retained natural gas. Higher depreciation expense ($2 million) related to new assets placed in service and an increase in taxes other than income ($1 million) were partially offset by lower operation and maintenance expenses ($2 million).

Equity Earnings. In addition, this business segment recorded equity income of $2 million and $3 million in the three months ended March 31, 2011 and 2012, respectively, from its 50% general partnership interest in Waskom Gas Processing Company. These amounts are included in Equity in Earnings of Unconsolidated Affiliates under the Other Income (Expense) caption.

Other Operations

The following table shows the operating income (loss) of our Other Operations business segment for the three months ended March 31, 2011 and 2012 (in millions):



	Three Months Ended March 31,
	2011			2012
Revenues	$	3		$	3
Expenses	4			1
Operating Income (Loss)	$	(1	)	$	2

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CERTAIN FACTORS AFFECTING FUTURE EARNINGS

For information on other developments, factors and trends that may have an impact on our future earnings, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations ─ Certain Factors Affecting Future Earnings” in Item 7 of Part II of our 2011 Form 10-K, “Risk Factors” in Item 1A of Part I of our 2011 Form 10-K, and “Cautionary Statement Regarding Forward-Looking Information” in this Form 10-Q.

LIQUIDITY AND CAPITAL RESOURCES

Historical Cash Flows

The following table summarizes the net cash provided by (used in) operating, investing and financing activities for the three months ended March 31, 2011 and 2012:



	Three Months Ended March 31,
	2011			2012
	(in millions)
Cash provided by (used in):
Operating activities	$	627		$	424
Investing activities	(308		)	(292		)
Financing activities	(423		)	744

Cash Provided by Operating Activities

Net cash provided by operating activities in the first three months of 2012 decreased $203 million compared to the same period in 2011 due primarily to decreased tax refunds ($152 million), decreased cash provided by fuel cost recovery ($56 million), decreased cash related to gas storage ($67 million) and increased net margin deposits ($22 million), which were partially offset by increased cash provided by net accounts receivable/payable ($141 million).

Cash Used in Investing Activities

Net cash used in investing activities in the first three months of 2012 decreased $16 million compared to the same period in 2011 due to decreased capital expenditures ($69 million), which was partially offset by decreased cash received from a grant from the U.S. Department of Energy ($32 million) and increased restricted cash of Bond Companies ($15 million).

Cash Provided by (Used in) Financing Activities

Net cash provided by financing activities in the first three months of 2012 increased $1,167 million compared to the same period in 2011 due to increased proceeds from long-term debt ($1,145 million), decreased payments of long-term debt ($240 million) and decreased cash paid for debt exchange ($58 million), which were partially offset by decreased proceeds from commercial paper ($280 million).

Future Sources and Uses of Cash

Our liquidity and capital requirements are affected primarily by our results of operations, capital expenditures, debt service requirements, tax payments and working capital needs. Substantially all of our capital expenditures are expected to be used for investment in infrastructure for our electric transmission and distribution operations, and our natural gas transmission, distribution and gathering operations. These capital expenditures relate to reliability and safety and system expansions. Our principal cash requirements for the remaining nine months of 2012 include the following:


•	capital expenditures of approximately $1.0 billion;


•	scheduled principal payments on transition and system restoration bonds of $219 million;


•	pension contributions of approximately $122 million;


•	the retirement of long-term debt aggregating $46 million that matured in April 2012; and

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

We expect that cash on hand and anticipated cash flows from operations will be sufficient to meet our anticipated cash needs for the remaining nine months of 2012.

Longer term cash requirements or discretionary financing or refinancing may result in the issuance of equity or debt securities in the capital markets, borrowing under existing credit facilities, the issuance of commercial paper or the arrangement of additional credit facilities. Issuances of equity or debt in the capital markets, funds raised in the commercial paper markets and additional credit facilities may not, however, be available to us on acceptable terms.

Off-Balance Sheet Arrangements. Other than the guaranties described below and operating leases, we have no off-balance sheet arrangements.

Prior to the distribution of our ownership in RRI Energy, Inc. (RRI) to our shareholders, CenterPoint Energy Resources Corp. (CERC Corp. and, together with its subsidiaries, CERC) had guaranteed certain contractual obligations of what became RRI’s trading subsidiary. When the companies separated, RRI agreed to secure CERC against obligations under the guaranties RRI had been unable to extinguish by the time of separation. Pursuant to such agreement, as amended in December 2007, RRI (now GenOn Energy, Inc. (GenOn)) agreed to provide to CERC cash or letters of credit as security against CERC’s obligations under its remaining guaranties for demand charges under certain gas transportation agreements if and to the extent changes in market conditions expose CERC to a risk of loss on those guaranties based on an annual calculation, with any required collateral to be posted each December. The undiscounted maximum potential payout of the demand charges under these transportation contracts, which will be in effect until 2018, was approximately $86 million as of March 31, 2012. Market conditions in the fourth quarters of 2010 and 2011 required posting of security under the agreement, and GenOn has posted approximately $28 million of collateral as of March 31, 2012. If GenOn should fail to perform the contractual obligations, CERC could have to honor its guarantee and, in such event, collateral provided as security may be insufficient to satisfy CERC’s obligations.

Regulatory Matters. Regulatory developments that have occurred since our 2011 Form 10-K was filed with the Securities and Exchange Commission (SEC) are discussed below.

CenterPoint Houston

June 2010 Rate Case. The order on rehearing issued by the Public Utility Commission of Texas (Texas Utility Commission)in connection with CenterPoint Houston’s 2010 rate case was appealed to the Texas courts by various parties and we currently expect a trial will be scheduled for either the fourth quarter of 2012 or the first quarter of 2013.

Other. In May 2012, CenterPoint Houston filed an application with the Texas Utility Commission requesting approval to recover a total of approximately $48.6 million in 2013 consisting of: (1) estimated 2013 energy efficiency program costs of $42.9 million; (2) a credit of $1.8 million related to the over-recovery of 2011 program costs; (3) a performance incentive for 2011 program achievements of $6.3 million; (4) $1.1 million for anticipated 2013 evaluation measurement and verification expenses; and (5) certain rate case expenses. The proposed adjustments are expected to take effect with the commencement of CenterPoint Houston's January 2013 billing month.

Gas Operations

Minnesota Conservation Improvement Program (CIP). In May 2012, the natural gas distribution business of CERC (Gas Operations) filed a request with the Minnesota Public Utilities Commission for a $4.6 million CIP incentive.

Oklahoma Performance Based Rate Change (PBRC). In March 2012, Gas Operations filed a PBRC with the Oklahoma Corporation Commission showing that it had earnings for 2011 above the prescribed threshold and would refund approximately $1.86 million to customers beginning in July 2012. An expedited procedural schedule is being discussed with a hearing scheduled in May 2012.

Houston and South Texas Gas Reliability Infrastructure Programs (GRIP). Gas Operations’ Houston and South Texas Divisions each submitted annual GRIP filings on March 30, 2012. For the Houston division, this filing is to recover costs related to $51.2 million in incremental capital expenditures that were incurred in 2011. The increase in revenue requirements for this filing period is $9.4 million annually based on an authorized rate of return of 8.65%. For the South Texas division, this filing is to recover costs related to $14.5 million in incremental capital expenditures that were incurred since the last rate case. The increase in revenue requirements for this filing period is $2.4 million annually based on an authorized rate of return of 8.75%. For both GRIP filings,

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rates are expected to go into effect in July 2012.

Debt Financing Transactions. In January 2012, Bond Company IV issued $1.695 billion of transition bonds in three tranches with interest rates ranging from 0.9012% to 3.0282% and final maturity dates ranging from April 15, 2018 to October 15, 2025. Through the issuance of these transition bonds, CenterPoint Houston recovered the Recoverable True-Up Balance, less approximately $10.4 million of offering expenses. The transition bonds will be repaid over time through a charge imposed on customers in CenterPoint Houston’s service territory.

In February 2012, we purchased $275 million aggregate principal amount of pollution control bonds issued on our behalf at 100% of their principal amount plus accrued interest pursuant to the mandatory tender provisions of the bonds. The purchased pollution control bonds will remain outstanding and may be remarketed. Prior to the purchase, the pollution control bonds had fixed interest rates ranging from 5.15% to 5.95%. The purchases reduced temporary investments and leverage while providing us with the flexibility to finance future capital needs in the tax-exempt market through the remarketing of these bonds. Additionally, in March 2012, we redeemed $100 million aggregate principal amount of pollution control bonds issued on our behalf at 100% of their principal amount plus accrued interest pursuant to the optional redemption provisions of the bonds. The redeemed pollution control bonds had a fixed interest rate of 5.25%.

Credit Facilities. As of April 16, 2012, we had the following revolving credit facilities (in millions):

Date Executed

Company

Size of

Facility

Amount

Utilized at

April 16, 2012 ⁽¹⁾

Termination Date

September 9, 2011

CenterPoint Energy

1,200

⁽²⁾

September 9, 2016

September 9, 2011

CenterPoint Houston

300

⁽²⁾

September 9, 2016

September 9, 2011

CERC Corp.

950

—

September 9, 2016

________________


(1)	Based on the debt (excluding transition and system restoration bonds) to earnings before interest, taxes, depreciation and amortization (EBITDA) covenant in our $1.2 billion credit facility, we would have been permitted to utilize the full capacity of our revolving credit facilities aggregating $2.5 billion at March 31, 2012.


(2)	Represents outstanding letters of credit.

Our $1.2 billion credit facility can be drawn at the London Interbank Offered Rate (LIBOR) plus 175 basis points based on our current credit ratings. The facility contains a debt (excluding transition and system restoration bonds) to EBITDA covenant (as those terms are defined in the facility). The facility allows for a temporary increase of the permitted ratio in the financial covenant from 5 times to 5.5 times if CenterPoint Houston experiences damage from a natural disaster in its service territory and we certify to the administrative agent that CenterPoint Houston has incurred system restoration costs reasonably likely to exceed $100 million in a consecutive twelve-month period, all or part of which CenterPoint Houston intends to seek to recover through securitization financing. Such temporary increase in the financial covenant would be in effect from the date we deliver our certification until the earliest to occur of (i) the completion of the securitization financing, (ii) the first anniversary of our certification or (iii) the revocation of such certification.

CenterPoint Houston’s $300 million credit facility can be drawn at LIBOR plus 150 basis points based on CenterPoint Houston’s current credit ratings. The facility contains a debt (excluding transition and system restoration bonds) to total capitalization covenant which limits debt to 65% of CenterPoint Houston’s total capitalization.

CERC Corp.’s $950 million credit facility can be drawn at LIBOR plus 150 basis points based on CERC Corp.’s current credit ratings. The facility contains a debt to total capitalization covenant which limits debt to 65% of CERC’s total capitalization.

Borrowings under each of the facilities are subject to customary terms and conditions. However, there is no requirement that the borrower 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 each of the credit facilities are subject to acceleration upon the occurrence of events of default that we consider customary. The facilities also provide for customary fees, including commitment fees, administrative agent fees, fees in respect of letters of credit and other fees. In each of the three revolving credit facilities, the spread to LIBOR and the commitment fees fluctuate based on the borrower’s credit rating. The borrowers are currently in compliance with the various business and financial covenants in the three revolving credit facilities.

Our $1.2 billion credit facility backstops our $1.0 billion commercial paper program. The $950 million CERC Corp. credit facility backstops a $915 million commercial paper program. As of March 31, 2012, we and CERC Corp. had no outstanding

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commercial paper.

Securities Registered with the SEC. CenterPoint Energy, CenterPoint Houston and CERC Corp. have filed a joint shelf registration statement with the SEC registering indeterminate principal amounts of CenterPoint Houston’s general mortgage bonds, CERC Corp.’s senior debt securities and CenterPoint Energy’s senior debt securities and junior subordinated debt securities and an indeterminate number of CenterPoint Energy’s shares of common stock, shares of preferred stock, as well as stock purchase contracts and equity units.

Temporary Investments. As of April 16, 2012, we had external temporary investments of $1.0 billion.

Money Pool. We have a money pool through which the holding company and participating subsidiaries 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 our revolving credit facility or the sale of our commercial paper.

Impact on Liquidity of a Downgrade in Credit Ratings. The interest on borrowings under our credit facilities is based on our credit rating. As of April 16, 2012, 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 senior debt of CenterPoint Energy and certain subsidiaries:

Moody’s

S&P

Fitch

Company/Instrument

Rating

Outlook(1)

Rating

Outlook (2)

Rating

Outlook (3)

CenterPoint Energy Senior

Unsecured Debt

Baa3

Stable

BBB

Stable

BBB-

Positive

CenterPoint Houston Senior

Secured Debt

Stable

A-

Stable

A-

Positive

CERC Corp. Senior Unsecured

Debt

Baa2

Stable

BBB+

Stable

BBB

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 encompasses a one- to two-year horizon as to the likely ratings direction.

We cannot assure you 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.

A decline in credit ratings could increase borrowing costs under our $1.2 billion credit facility, CenterPoint Houston’s $300 million credit facility and CERC Corp.’s $950 million credit facility. If our credit ratings or those of CenterPoint Houston or CERC Corp. had been downgraded one notch by each of the three principal credit rating agencies from the ratings that existed at March 31, 2012, the impact on the borrowing costs under our bank credit facilities 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 and to access the commercial paper market.

CERC Corp. and its subsidiaries purchase natural gas from one of their suppliers under supply agreements that contain an aggregate credit threshold of $120 million based on CERC Corp.’s S&P senior unsecured long-term debt rating of BBB+. Under these agreements, CERC may need to provide collateral if the aggregate threshold is exceeded. Upgrades and downgrades from this BBB+ rating will increase and decrease the aggregate credit threshold accordingly.

CenterPoint Energy Services, Inc. (CES), a wholly owned subsidiary of CERC Corp. operating in our Competitive Natural Gas Sales and Services business segment, provides comprehensive natural gas sales and services primarily to commercial and industrial customers and electric and gas utilities throughout the central and eastern United States. In order to economically hedge its exposure to natural gas prices, CES uses derivatives with provisions standard for the industry, including those pertaining to

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credit thresholds. Typically, the credit threshold negotiated with each counterparty defines the amount of unsecured credit that such counterparty will extend to CES. To the extent that the credit exposure that a counterparty has to CES at a particular time does not exceed that credit threshold, CES is not obligated to provide collateral. Mark-to-market exposure in excess of the credit threshold is routinely collateralized by CES. As of March 31, 2012, the amount posted as collateral aggregated approximately $59 million. Should the credit ratings of CERC Corp. (as the credit support provider for CES) fall below certain levels, CES would be required to provide additional collateral up to the amount of its previously unsecured credit limit. We estimate that as of March 31, 2012, unsecured credit limits extended to CES by counterparties aggregate $371 million and $15 million of such amount was utilized.

Pipeline tariffs and contracts typically provide that if the credit ratings of a shipper or the shipper’s guarantor drop below a threshold level, which is generally investment grade ratings from both Moody’s and S&P, cash or other collateral may be demanded from the shipper in an amount equal to the sum of three months’ charges for pipeline services plus the unrecouped cost of any lateral built for such shipper. If the credit ratings of CERC Corp. decline below the applicable threshold levels, CERC Corp. might need to provide cash or other collateral of as much as $172 million as of March 31, 2012. The amount of collateral will depend on seasonal variations in transportation levels.

In September 1999, we issued Zero-Premium Exchangeable Subordinated Notes due 2029 (ZENS) having an original principal amount of $1.0 billion of which $840 million remains outstanding at March 31, 2012. Each ZENS note was originally exchangeable at the holder’s option at any time for an amount of cash equal to 95% of the market value of the reference shares of Time Warner Inc. common stock (TW Common) attributable to such note. The number and identity of the reference shares attributable to each ZENS note are adjusted for certain corporate events. As of March 31, 2012, the reference shares for each ZENS note consisted of 0.5 share of TW Common, 0.125505 share of Time Warner Cable Inc. common stock (TWC Common) and 0.045455 share of AOL Inc. common stock (AOL Common). If our creditworthiness were to drop such that ZENS note holders thought our liquidity was adversely affected or the market for the ZENS notes were to become illiquid, some ZENS note holders might decide to exchange their ZENS notes for cash. Funds for the payment of cash upon exchange could be obtained from the sale of the shares of TW Common, TWC Common and AOL Common that we own or from other sources. We own shares of TW Common, TWC Common and AOL Common equal to approximately 100% of the reference shares used to calculate our obligation to the holders of the ZENS notes. ZENS note exchanges result in a cash outflow because tax deferrals related to the ZENS notes and TW Common, TWC Common and AOL Common shares would typically cease when ZENS notes are exchanged or otherwise retired and TW Common, TWC Common and AOL Common shares are sold. The ultimate tax liability related to the ZENS notes continues to increase by the amount of the tax benefit realized each year, and there could be a significant cash outflow when the taxes are paid as a result of the retirement of the ZENS notes. If all ZENS notes had been exchanged for cash on March 31, 2012, deferred taxes of approximately $411 million would have been payable in 2012.

Cross Defaults. Under our revolving credit facility, a payment default on, or a non-payment default that permits acceleration of, any indebtedness exceeding $75 million by us or any of our significant subsidiaries will cause a default. In addition, three outstanding series of our senior notes, aggregating $750 million in principal amount as of March 31, 2012, provide that a payment default by us, CERC Corp. or CenterPoint Houston in respect of, or an acceleration of, borrowed money and certain other specified types of obligations, in the aggregate principal amount of $50 million, will cause a default. A default by CenterPoint Energy would not trigger a default under our subsidiaries’ debt instruments or bank credit facilities.

Possible Acquisitions, Divestitures and Joint Ventures. From time to time, we consider the acquisition or the disposition of assets or businesses or possible joint ventures or other joint ownership arrangements with respect to 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 and/or equity issuances. Debt or equity 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.

Other Factors that Could Affect Cash Requirements. In addition to the above factors, our liquidity and capital resources could be affected by:


•	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 Competitive Natural Gas Sales and 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;

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•	increased costs related to the acquisition of natural gas;


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


•	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;


•	the ability of retail electric providers (REPs), including REP affiliates of NRG Energy, Inc. and REP affiliates of Energy Future Holdings Corp., which are CenterPoint Houston’s two largest customers, 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 our 2011 Form 10-K.

Certain Contractual Limits on Our Ability to Issue Securities and Borrow Money. CenterPoint Houston’s credit facilities limit CenterPoint Houston’s debt (excluding transition and system restoration bonds) as a percentage of its total capitalization to 65%. CERC Corp.’s bank facility limits CERC’s debt as a percentage of its total capitalization to 65%. Our $1.2 billion credit facility contains a debt, excluding transition and system restoration bonds, to EBITDA covenant which will temporarily increase if CenterPoint Houston experiences damage from a natural disaster in its service territory that meets certain criteria. Additionally, CenterPoint Houston has contractually agreed that it will not issue additional first mortgage bonds, subject to certain exceptions.

NEW ACCOUNTING PRONOUNCEMENTS

See Note 2 to our Interim Condensed Consolidated Financial Statements for a discussion of new accounting pronouncements that affect us.


Item 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Price Risk From Non-Trading Activities

We use derivative instruments as economic hedges to offset the commodity price exposure inherent in our businesses. The stand-alone commodity risk created by these instruments, without regard to the offsetting effect of the underlying exposure these instruments are intended to hedge, is described below. We measure the commodity risk of our non-trading energy derivatives using a sensitivity analysis. The sensitivity analysis performed on our non-trading energy derivatives measures the potential loss in fair value based on a hypothetical 10% movement in energy prices. At March 31, 2012, the recorded fair value of our non-trading energy derivatives was a net asset of $37 million (before collateral), all of which is related to our Competitive Natural Gas Sales and Services business segment. A decrease of 10% in the market prices of energy commodities from their March 31, 2012 levels would have decreased the fair value of our non-trading energy derivatives net asset by $1 million.

The above analysis of the non-trading energy derivatives utilized for commodity price risk management purposes does not include the favorable impact that the same hypothetical price movement would have on our non-derivative physical purchases and sales of natural gas to which the hedges relate. Furthermore, the non-trading energy derivative portfolio is managed to complement the physical transaction portfolio, reducing overall risks within limits. Therefore, the adverse impact to the fair value of the portfolio of non-trading energy derivatives held for hedging purposes associated with the hypothetical changes in commodity prices referenced above is expected to be substantially offset by a favorable impact on the underlying hedged physical transactions.

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Interest Rate Risk

As of March 31, 2012, we had outstanding long-term debt, bank loans, lease obligations and obligations under our ZENS (indexed debt securities) that subject us to the risk of loss associated with movements in market interest rates.

We have no material floating-rate obligations.

At December 31, 2011 and March 31, 2012, we had outstanding fixed-rate debt (excluding indexed debt securities) aggregating $8.7 billion and $9.9 billion, respectively, in carrying amount and having a fair value of $9.8 billion and $10.9 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. However, the fair value of these instruments would increase by approximately $245 million if interest rates were to decline by 10% from their levels at March 31, 2012. 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.

The ZENS obligation is bifurcated into a debt component and a derivative component. The debt component of $133 million at March 31, 2012 was a fixed-rate obligation and, therefore, did not expose us to the risk of loss in earnings due to changes in market interest rates. However, the fair value of the debt component would increase by approximately $22 million if interest rates were to decline by 10% from levels at March 31, 2012. Changes in the fair value of the derivative component, a $230 million recorded liability at March 31, 2012, are recorded in our Condensed Statements of Consolidated Income and, therefore, we are exposed to changes in the fair value of the derivative component as a result of changes in the underlying risk-free interest rate. If the risk-free interest rate were to increase by 10% from March 31, 2012 levels, the fair value of the derivative component liability would increase by approximately $5 million, which would be recorded as an unrealized loss in our Condensed Statements of Consolidated Income.

Equity Market Value Risk

We are exposed to equity market value risk through our ownership of 7.2 million shares of TW Common, 1.8 million shares of TWC Common and 0.7 million shares of AOL Common, which we hold to facilitate our ability to meet our obligations under the ZENS. A decrease of 10% from the March 31, 2012 aggregate market value of these shares would result in a net loss of approximately $11 million, which would be recorded as an unrealized loss in our Condensed Statements of Consolidated Income.


Item 4.	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 March 31, 2012 to provide assurance that information required to be disclosed in our reports filed or submitted under the Securities Exchange Act of 1934, as amended, 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 March 31, 2012 that has materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.

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PART II. OTHER INFORMATION


Item 1.	LEGAL PROCEEDINGS

For a description of certain legal and regulatory proceedings affecting CenterPoint Energy, please read Note 12(c) to our Interim Condensed Financial Statements and “Management’s Discussion and Analysis of Financial Condition and Results of Operations ─ Liquidity and Capital Resources ─ Future Sources and Uses of Cash ─ Regulatory Matters”, each of which is incorporated herein by reference. See also “Business ─ Regulation” and “─ Environmental Matters” in Item 1 and “Legal Proceedings” in Item 3 of our 2011 Form 10-K.


Item 1A.	RISK FACTORS

There have been no material changes from the risk factors disclosed in our 2011 Form 10-K.


Item 5.	OTHER INFORMATION

The ratio of earnings to fixed charges for the three months ended March 31, 2011 and 2012 was 2.48 and 2.47, respectively. We do not believe that the ratios for these three-month periods are necessarily indicative of the ratios for the twelve-month periods due to the seasonal nature of our business. The ratios were calculated pursuant to applicable rules of the Securities and Exchange Commission.

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Item 6.	EXHIBITS

The following exhibits are filed herewith:

Exhibits not incorporated by reference to a prior filing are designated by a cross (+); all exhibits not so designated are incorporated by reference to a prior filing of CenterPoint Energy, Inc.

Agreements included as exhibits are included only to provide information to investors regarding their terms. Agreements listed below may contain representations, warranties and other provisions that were made, among other things, to provide the parties thereto with specified rights and obligations and to allocate risk among them, and no such agreement should be relied upon as constituting or providing any factual disclosures about CenterPoint Energy, Inc., any other persons, any state of affairs or other matters.

Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, CenterPoint Energy has not filed as exhibits to this Form 10-Q 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 Energy and its subsidiaries on a consolidated basis. CenterPoint Energy 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
3.1	Restated Articles of Incorporation of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated July 24, 2008	1-31447	3.2
3.2	Amended and Restated Bylaws of CenterPoint Energy	CenterPoint Energy’s Form 10-K for the year ended December 31, 2010	1-31447	3(b)
3.3	Statement of Resolutions Deleting Shares Designated Series A Preferred Stock of CenterPoint Energy	CenterPoint Energy’s Form 10-K for the year ended December 31, 2011	1-31447	3(c)
4.1	Form of CenterPoint Energy Stock Certificate	CenterPoint Energy’s Registration Statement on Form S-4	3-69502	4.1
4.2	$1,200,000,000 Credit Agreement, dated as of September 9, 2011, among CenterPoint Energy, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated September 9, 2011	1-31447	4.1
4.3	$300,000,000 Credit Agreement, dated as of September 9, 2011, among CenterPoint Houston, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated September 9, 2011	1-31447	4.2
4.4	$950,000,000 Credit Agreement, dated as of September 9, 2011, among CERC Corp., as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated September 9, 2011	1-31447	4.3
+12	Computation of Ratios of Earnings to Fixed Charges
+31.1	Rule 13a-14(a)/15d-14(a) Certification of David M. McClanahan
+31.2	Rule 13a-14(a)/15d-14(a) Certification of Gary L. Whitlock
+32.1	Section 1350 Certification of David M. McClanahan
+32.2	Section 1350 Certification of Gary L. Whitlock
+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

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SIGNATURES

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



	CENTERPOINT ENERGY, INC.


By:	/s/ Walter L. Fitzgerald
	Walter L. Fitzgerald
	Senior Vice President and Chief Accounting Officer

Date: May 3, 2012

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Index to Exhibits

The following exhibits are filed herewith:

Exhibits not incorporated by reference to a prior filing are designated by a cross (+); all exhibits not so designated are incorporated by reference to a prior filing as indicated.



Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	Exhibit Reference
3.1	Restated Articles of Incorporation of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated July 24, 2008	1-31447	3.2
3.2	Amended and Restated Bylaws of CenterPoint Energy	CenterPoint Energy’s Form 10-K for the year ended December 31, 2010	1-31447	3(b)
3.3	Statement of Resolutions Deleting Shares Designated Series A Preferred Stock of CenterPoint Energy	CenterPoint Energy’s Form 10-K for the year ended December 31, 2011	1-31447	3(c)
4.1	Form of CenterPoint Energy Stock Certificate	CenterPoint Energy’s Registration Statement on Form S-4	3-69502	4.1
4.2	$1,200,000,000 Credit Agreement, dated as of September 9, 2011, among CenterPoint Energy, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated September 9, 2011	1-31447	4.1
4.3	$300,000,000 Credit Agreement, dated as of September 9, 2011, among CenterPoint Houston, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated September 9, 2011	1-31447	4.2
4.4	$950,000,000 Credit Agreement, dated as of September 9, 2011, among CERC Corp., as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated September 9, 2011	1-31447	4.3
+12	Computation of Ratios of Earnings to Fixed Charges
+31.1	Rule 13a-14(a)/15d-14(a) Certification of David M. McClanahan
+31.2	Rule 13a-14(a)/15d-14(a) Certification of Gary L. Whitlock
+32.1	Section 1350 Certification of David M. McClanahan
+32.2	Section 1350 Certification of Gary L. Whitlock
+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