0001130310 cnp:~~OGEMember~~NaturalGasExpensesMember cnp:EnableMidstreamPartnersMember 2019-01-01 ~~2019-06-30~~2019-09-30

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

__________________

FORM 10-Q



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

For the quarterly period ended ~~June~~September 30, 2019



☐	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
(Address of Principal Executive Offices)			(Zip Code)

(713) 207-1111

Registrant's telephone number, including area code

Commission file number 1-3187

CenterPoint Energy Houston Electric, LLC

(Exact name of registrant as specified in its charter)



Texas			22-3865106
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

1111 Louisiana	Houston	Texas	77002
(Address of Principal Executive Offices)			(Zip Code)

(713) 207-1111

Registrant's telephone number, including area code

Commission file number 1-13265

CenterPoint Energy Resources Corp.

(Exact name of registrant as specified in its charter)



Delaware			76-0511406
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

1111 Louisiana	Houston	Texas	77002
(Address of Principal Executive Offices)			(Zip Code)

(713) 207-1111

Registrant's telephone number, including area code



Securities registered pursuant to Section 12(b) of the Act:
Registrant	Title of each class	Trading Symbol(s)	Name of each exchange on which registered
CenterPoint Energy, Inc.	Common Stock, $0.01 par value	CNP	The New York Stock Exchange
			Chicago Stock Exchange, Inc.
CenterPoint Energy, Inc.	Depositary Shares for 1/20 of 7.00% Series B Mandatory Convertible Preferred Stock, $0.01 par value	CNP/PB	The New York Stock Exchange
CenterPoint Energy Houston Electric, LLC	9.15% First Mortgage Bonds due 2021	n/a	The New York Stock Exchange
CenterPoint Energy Houston Electric, LLC	6.95% General Mortgage Bonds due 2033	n/a	The New York Stock Exchange
CenterPoint Energy Resources Corp.	6.625% Senior Notes due 2037	n/a	The New York Stock Exchange

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.



CenterPoint Energy, Inc.	Yes	þ	No	o
CenterPoint Energy Houston Electric, LLC	Yes	þ	No	o
CenterPoint Energy Resources Corp.	Yes	þ	No	o

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files).



CenterPoint Energy, Inc.	Yes	þ	No	o
CenterPoint Energy Houston Electric, LLC	Yes	þ	No	o
CenterPoint Energy Resources Corp.	Yes	þ	No	o

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



	Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company	Emerging growth company
CenterPoint Energy, Inc.	þ	o	o	☐	☐
CenterPoint Energy Houston Electric, LLC	o	o	þ	☐	☐
CenterPoint Energy Resources Corp.	o	o	þ	☐	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).



CenterPoint Energy, Inc.	Yes	☐	No	þ
CenterPoint Energy Houston Electric, LLC	Yes	☐	No	þ
CenterPoint Energy Resources Corp.	Yes	☐	No	þ

Indicate the number of shares outstanding of each of the issuers’ classes of common stock as of ~~July 26,~~October 25, 2019:



CenterPoint Energy, Inc.	~~502,218,696~~502,241,723	shares of common stock outstanding, excluding 166 shares held as treasury stock
CenterPoint Energy Houston Electric, LLC	1,000	common shares outstanding, all held by Utility Holding, LLC, a wholly-owned subsidiary of CenterPoint Energy, Inc.
CenterPoint Energy Resources Corp.	1,000	shares of common stock outstanding, all held by Utility Holding, LLC, a wholly-owned subsidiary of CenterPoint Energy, Inc.

CenterPoint Energy Houston Electric, LLC and CenterPoint Energy Resources Corp. meet the conditions set forth in General Instructions H(1)(a) and (b) of Form 10-Q and are therefore filing this form with the reduced disclosure format specified in General Instruction H(2) of Form 10-Q.

TABLE OF CONTENTS



PART I.	FINANCIAL INFORMATION
Item 1.	Financial Statements	1
	CenterPoint Energy, Inc. Financial Statements (unaudited)	1
	CenterPoint Energy Houston Electric, LLC Financial Statements (unaudited)	7
	CenterPoint Energy Resources Corp. Financial Statements (unaudited)	13
	Combined Notes to Unaudited Condensed Consolidated Financial Statements (unaudited)	19
	(1) Background and Basis of Presentation	19
	(2) New Accounting Pronouncements	21
	(3) Mergers and Acquisitions	21
	(4) Revenue Recognition	24
	(5) Employee Benefit Plans	28
	(6) Regulatory Accounting	31
	(7) Derivative Instruments	32
	(8) Fair Value Measurements	3738
	(9) Unconsolidated Affiliates	4041
	(10) Goodwill and Other Intangibles	44
	(11) Indexed Debt Securities (ZENS) and Securities Related to ZENS	46
	(12) Short-term Borrowings and Long-term Debt	4647
	(13) Income Taxes	4950
	(14) Commitments and Contingencies	50
	(15) Earnings Per Share	5455
	(16) Reportable Segments	5455
	(17) Supplemental Disclosure of Cash Flow Information	5859
	(18) Related Party Transactions	5859
	(19) Leases	5960
	(20) Equity	6263
	(21) Subsequent Events	6465
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	6566
	Recent Events	6566
	Consolidated Results of Operations	6566
	Results of Operations by Reportable Segment	7071
	Certain Factors Affecting Future Earnings	8182
	Liquidity and Capital Resources	8182
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	9294
Item 4.	Controls and Procedures	9395

PART II.	OTHER INFORMATION
Item 1.	Legal Proceedings	9496
Item 1A.	Risk Factors	9496
Item 6.	Exhibits	9497
	Signatures	98101



GLOSSARY
ACE		Affordable Clean Energy
ALJ		Administrative Law Judge
AMA		Asset Management Agreement
AMS		Advanced Metering System
APSC		Arkansas Public Service Commission
ARO		Asset retirement obligation
ARP		Alternative revenue program
ASC		Accounting Standards Codification
ASU		Accounting Standards Update
AT&T Common		AT&T Inc. common stock
Bailey to Jones Creek Project		A transmission project in the greater Freeport, Texas area, which includes enhancements to two existing substations and the construction of a new 345 kV double-circuit line to be located in the counties of Brazoria, Matagorda and Wharton
Bcf		Billion cubic feet
Bond Companies		Bond Company II, Bond Company III, Bond Company IV and Restoration Bond Company, each a wholly-owned, bankruptcy remote entity formed solely for the purpose of purchasing and owning transition or system restoration property through the issuance of Securitization Bonds
Bond Company II		CenterPoint Energy Transition Bond Company II, LLC, a wholly-owned subsidiary of Houston Electric
Bond Company III		CenterPoint Energy Transition Bond Company III, LLC, a wholly-owned subsidiary of Houston Electric
Bond Company IV		CenterPoint Energy Transition Bond Company IV, LLC, a wholly-owned subsidiary of Houston Electric
Brazos Valley Connection		A portion of the Houston region transmission project between Houston Electric’s Zenith substation and the Gibbons Creek substation owned by the Texas Municipal Power Agency
CCR		Coal Combustion Residuals
CECA		Clean Energy Cost Adjustment
CECL		Current expected credit losses
CenterPoint Energy		CenterPoint Energy, Inc., and its subsidiaries
CERC		CERC Corp., together with its subsidiaries
CERC Corp.		CenterPoint Energy Resources Corp.
CES		CenterPoint Energy Services, Inc., a wholly-owned subsidiary of CERC Corp.
Charter Common		Charter Communications, Inc. common stock
CIP		Conservation Improvement Program
CME		Chicago Mercantile Exchange
CNP Midstream		CenterPoint Energy Midstream, Inc., a wholly-owned subsidiary of CenterPoint Energy
Common Stock		CenterPoint Energy, Inc. common stock, par value $0.01 per share
CPCN		Certificate of Public Convenience and Necessity
CPP		Clean Power Plan
CSIA		Compliance and System Improvement Adjustment
DCRF		Distribution Cost Recovery Factor
DRR		Distribution Replacement Rider
DSMA		Demand Side Management Adjustment
ECA		Environmental Cost Adjustment
EDIT		Excess deferred income taxes
EECR		Energy Efficiency Cost Recovery



GLOSSARY
EECRF		Energy Efficiency Cost Recovery Factor
EEFC		Energy Efficiency Funding Component
EEFR		Energy Efficiency Funding Rider



~~GLOSSARY~~
ELG		Effluent Limitation Guidelines
EMV		Evaluation, measurement and valuation
Enable		Enable Midstream Partners, LP
Enable GP		Enable GP, LLC, Enable’s general partner
Enable Series A Preferred Units		Enable’s 10% Series A Fixed-to-Floating Non-Cumulative Redeemable Perpetual Preferred Units, representing limited partner interests in Enable
EPA		Environmental Protection Agency
ERCOT		Electric Reliability Council of Texas
ESG		Energy Systems Group, LLC, a wholly-owned subsidiary of Vectren
FERC		Federal Energy Regulatory Commission
Fitch		Fitch, Inc.
Form 10-Q		Quarterly Report on Form 10-Q
FRP		Formula Rate Plan
Gas Daily		Platts gas daily indices
~~GenOn~~		~~GenOn Energy, Inc.~~
GHG		Greenhouse gases
GRIP		Gas Reliability Infrastructure Program
GWh		Gigawatt-hours
Houston Electric		CenterPoint Energy Houston Electric, LLC and its subsidiaries
IDEM		Indiana Department of Environmental Management
Indiana Electric		Operations of SIGECO’s electric transmission and distribution services, and includes its power generating and wholesale power operations
Indiana Gas		Indiana Gas Company, Inc., a wholly-owned subsidiary of Vectren
Indiana North		Gas operations of Indiana Gas
Indiana South		Gas operations of SIGECO
Indiana Utilities		The combination of Indiana Electric, Indiana North and Indiana South
Interim Condensed Financial Statements		Unaudited condensed consolidated interim financial statements and combined notes
Internal Spin		The series of internal transactions consummated on September 4, 2018 whereby CERC (i) contributed its equity investment in Enable consisting of Enable common units and its interests in Enable GP to CNP Midstream and (ii) transferred all of its interest in CNP Midstream to CenterPoint Energy
IRP		Integrated Resource Plan
IRS		Internal Revenue Service
IURC		Indiana Utility Regulatory Commission
kV		Kilovolt
LIBOR		London Interbank Offered Rate
MATS		Mercury and Air Toxics Standards
Merger		The merger of Merger Sub with and into Vectren on the terms and subject to the conditions set forth in the Merger Agreement, with Vectren continuing as the surviving corporation and as a wholly-owned subsidiary of CenterPoint Energy, Inc.
Merger Agreement		Agreement and Plan of Merger, dated as of April 21, 2018, among CenterPoint Energy, Vectren and Merger Sub
Merger Date		February 1, 2019
Merger Sub		Pacer Merger Sub, Inc., an Indiana corporation and wholly-owned subsidiary of CenterPoint Energy
MGP		Manufactured gas plant
~~MISO~~		~~Midcontinent Independent System Operator~~
~~MLP~~		~~Master Limited Partnership~~

iii



GLOSSARY
MISO		Midcontinent Independent System Operator
MLP		Master Limited Partnership
MMBtu		One million British thermal units
Moody’s		Moody’s Investors Service, Inc.
MPSC		Mississippi Public Service Commission
MPUC		Minnesota Public Utilities Commission
MRT		Enable Mississippi River Transmission, LLC
MW		Megawatts
NGD		Natural gas distribution business
NGLs		Natural gas liquids
NRG		NRG Energy, Inc.
NYMEX		New York Mercantile Exchange
NYSE		New York Stock Exchange
OCC		Oklahoma Corporation Commission
OGE		OGE Energy Corp.
PBRC		Performance Based Rate Change
PFD		Proposal for decision
PRPs		Potentially responsible parties
PUCO		Public Utilities Commission of Ohio
PUCT		Public Utility Commission of Texas
Railroad Commission		Railroad Commission of Texas
RCRA		Resource Conservation and Recovery Act of 1976
Registrants		CenterPoint Energy, Houston Electric and CERC, collectively
Reliant Energy		Reliant Energy, Incorporated
REP		Retail electric provider
Restoration Bond Company		CenterPoint Energy Restoration Bond Company, LLC, a wholly-owned subsidiary of Houston Electric
Revised Policy Statement		Revised Policy Statement on Treatment of Income Taxes
ROE		Return on equity
ROU		Right of use
RRA		Rate Regulation Adjustment
RRI		Reliant Resources, Inc.
RSP		Rate Stabilization Plan
SEC		Securities and Exchange Commission
Securitization Bonds		Transition and system restoration bonds
Series A Preferred Stock		CenterPoint Energy’s Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Stock, par value $0.01 per share, with a liquidation preference of $1,000 per share
Series B Preferred Stock		CenterPoint Energy’s 7.00% Series B Mandatory Convertible Preferred Stock, par value $0.01 per share, with a liquidation preference of $1,000 per share
SERP		Supplemental Executive Retirement Plan
SIGECO		Southern Indiana Gas and Electric Company, a wholly-owned subsidiary of Vectren
S&P		S&P Global Ratings
SRC		Sales Reconciliation Component
TBD		To be determined
TCEH Corp.		Formerly Texas Competitive Electric Holdings Company LLC, predecessor to Vistra Energy Corp. whose major subsidiaries include Luminant and TXU Energy



GLOSSARY
TCJA		Tax reform legislation informally called the Tax Cuts and Jobs Act of 2017
TCOS		Transmission Cost of Service



~~GLOSSARY~~
TDSIC		Transmission, Distribution and Storage System Improvement Charge
TDU		Transmission and distribution utility
Transition Agreements		Services Agreement, Employee Transition Agreement, Transitional Seconding Agreement and other agreements entered into in connection with the formation of Enable
TSCR		Tax Savings Credit Rider
Utility Holding		Utility Holding, LLC, a wholly-owned subsidiary of CenterPoint Energy
VCC		Vectren Capital Corp., a wholly-owned subsidiary of Vectren
Vectren		Vectren Corporation, a wholly-owned subsidiary of CenterPoint Energy as of the Merger Date
VEDO		Vectren Energy Delivery of Ohio, Inc., a wholly-owned subsidiary of Vectren
VIE		Variable interest entity
Vistra Energy Corp.		Texas-based energy company focused on the competitive energy and power generation markets
VRP		Voluntary Remediation Program
VUHI		Vectren Utility Holdings, Inc., a wholly-owned subsidiary of Vectren
ZENS		2.0% Zero-Premium Exchangeable Subordinated Notes due 2029
ZENS-Related Securities		As of both ~~June~~September 30, 2019 and December 31, 2018, consisted of AT&T Common and Charter Common
2018 Form 10-K		Annual Report on Form 10-K for the fiscal year ended December 31, 2018

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

From time to time the Registrants make statements concerning their 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 forward-looking statements by the words “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “goal,” “intend,” “may,” “objective,” “plan,” “potential,” “predict,” “projection,” “should,” “target,” “will” or other similar words.

The Registrants have based their forward-looking statements on management’s beliefs and assumptions based on information reasonably available to management at the time the statements are made. The Registrants caution you that assumptions, beliefs, expectations, intentions and projections about future events may and often do vary materially from actual results. Therefore, the Registrants cannot assure you that actual results will not differ materially from those expressed or implied by the Registrants’ forward-looking statements. In this Form 10-Q, unless context requires otherwise, the terms “our,” “we” and “us” are used as abbreviated references to CenterPoint Energy, Inc. together with its consolidated subsidiaries, including Houston Electric, CERC and Vectren.

The following are some of the factors that could cause actual results to differ from those expressed or implied by the Registrants’ forward-looking statements and apply to all Registrants unless otherwise indicated:

the performance of Enable, the amount of cash distributions CenterPoint Energy receives from Enable, Enable’s ability to redeem the Enable Series A Preferred Units in certain circumstances and the value of CenterPoint Energy’s interest in Enable, and factors that may have a material impact on such performance, cash distributions and value, including factors such as:


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

◦

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


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


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


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


◦	the timing of payments from Enable’s customers under existing contracts, including minimum volume commitment payments;


◦	changes in tax status; and


◦	access to debt and equity capital;

the expected benefits of the Merger and integration, including the outcome of shareholder litigation filed against Vectren that could reduce anticipated benefits of the Merger, as well as the ability to successfully integrate the Vectren businesses and to realize anticipated benefits and commercial opportunities;

industrial, commercial and residential growth in our service territories and changes in market demand, including the demand for our non-utility products and services and effects of energy efficiency measures and demographic patterns;

the outcome of the pending Houston Electric rate case;

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

future economic conditions in regional and national markets and their effect on sales, prices and costs;

weather variations and other natural phenomena, including the impact of severe weather events on operations and capital;

state and federal legislative and regulatory actions or developments affecting various aspects of our businesses (including the businesses of Enable), including, among others, energy deregulation or re-regulation, pipeline integrity and safety and changes in regulation and legislation pertaining to trade, health care, finance and actions regarding the rates charged by our regulated businesses;

tax legislation, including the effects of the TCJA (which includes any potential changes to interest deductibility) and uncertainties involving state commissions’ and local municipalities’ regulatory requirements and determinations regarding the treatment of EDIT and our rates;

CenterPoint Energy’s and CERC’s ability to mitigate weather impacts through normalization or rate mechanisms, and the effectiveness of such mechanisms;


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

the ability of CenterPoint Energy’s and CERC’s non-utility business operating in the Energy Services reportable segment to effectively optimize opportunities related to natural gas price volatility and storage activities, including weather-related impacts;

actions by credit rating agencies, including any potential downgrades to credit ratings;

changes in interest rates and their impact on costs of borrowing and the valuation of CenterPoint Energy’s pension benefit obligation;

problems with regulatory approval, legislative actions, construction, implementation of necessary technology or other issues with respect to major capital projects that result in delays or cancellation or in cost overruns that cannot be recouped in rates;

the availability and prices of raw materials and services and changes in labor for current and future construction projects;

local, state and federal legislative and regulatory actions or developments relating to the environment, including, among others, those related to global climate change, air emissions, carbon, waste water discharges and the handling and disposal of CCR that could impact the continued operation, and/or cost recovery of generation plant costs and related assets;

the impact of unplanned facility outages or other closures;

any direct or indirect effects on our or Enable’s facilities, operations and financial condition resulting from terrorism, cyber-attacks, data security breaches or other attempts to disrupt our businesses or the businesses of third parties, or other catastrophic events such as fires, ice, earthquakes, explosions, leaks, floods, droughts, hurricanes, tornadoes, pandemic health events or other occurrences;

our ability to invest planned capital and the timely recovery of our investments, including those related to Indiana Electric’s generation transition plan;

our ability to successfully construct and operate electric generating facilities, including complying with applicable environmental standards and the implementation of a well-balanced energy and resource mix, as appropriate;

our ability to control operation and maintenance costs;

the sufficiency of our insurance coverage, including availability, cost, coverage and terms and ability to recover claims;

the investment performance of CenterPoint Energy’s pension and postretirement benefit plans;

commercial bank and financial market conditions, our access to capital, the cost of such capital, and the results of our financing and refinancing efforts, including availability of funds in the debt capital markets;

changes in rates of inflation;

inability of various counterparties to meet their obligations to us;

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

the extent and effectiveness of our and Enable’s risk management and hedging activities, including, but not limited to financial and weather hedges and commodity risk management activities;

timely and appropriate regulatory actions, which include actions allowing securitization, for any future hurricanes or natural disasters or other recovery of costs, including costs associated with Hurricane Harvey;

CenterPoint Energy’s or Enable’s potential business strategies and strategic initiatives, including restructurings, joint ventures and acquisitions or dispositions of assets or businesses, which CenterPoint Energy and Enable cannot assure will be completed or will have the anticipated benefits to CenterPoint Energy or Enable;

the performance of projects undertaken by our non-utility businesses and the success of efforts to realize value from, invest in and develop new opportunities and other factors affecting those non-utility businesses, including, but not limited to, the level of success in bidding contracts, fluctuations in volume and mix of contracted work, mix of projects received under blanket contracts, failure to properly estimate cost to construct projects or unanticipated cost increases in completion

vii

of the contracted work, changes in energy prices that affect demand for construction services and projects and cancellation and/or reductions in the scope of projects by customers and obligations related to warranties and guarantees;

~~vii~~

acquisition and merger activities involving us or our competitors, including the ability to successfully complete merger, acquisition and divestiture plans;

our or Enable’s ability to recruit, effectively transition and retain management and key employees and maintain good labor relations;

the outcome of litigation;

the ability of REPs, including REP affiliates of NRG and Vistra Energy Corp., formerly known as TCEH Corp., to satisfy their obligations to CenterPoint Energy and Houston Electric;

changes in technology, particularly with respect to efficient battery storage or the emergence or growth of new, developing or alternative sources of generation;

the impact of alternate energy sources on the demand for natural gas;

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

the effective tax rates;

the transition to a replacement for the LIBOR benchmark interest rate;

the effect of changes in and application of accounting standards and pronouncements; and


•	other factors discussed in “Risk Factors” in Item 1A of Part I of the Registrants’ combined 2018 Form 10-K, which are incorporated herein by reference, in Item 1A of Part II of this Form 10-Q and other reports the Registrants file from time to time with the SEC.

You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement, and the Registrants undertake no obligation to update or revise any forward-looking statements. Investors should note that the Registrants announce material financial information in SEC filings, press releases and public conference calls. Based on guidance from the SEC, the Registrants may use the Investors section of CenterPoint Energy’s website (www.centerpointenergy.com) to communicate with investors about the Registrants. It is possible that the financial and other information posted there could be deemed to be material information. The information on CenterPoint Energy’s website is not part of this combined Form 10-Q.

viii

Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. FINANCIAL STATEMENTS

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(Unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
	(in millions, except per share amounts)												(in millions, except per share amounts)
Revenues:
Utility revenues	$	1,555		$	1,341		$	3,716		$	3,235		$	1,539		$	1,299		$	5,255		$	4,534
Non-utility revenues	1,243			845			2,613			2,106			1,203			913			3,816			3,019
Total	2,798			2,186			6,329			5,341			2,742			2,212			9,071			7,553
Expenses:
Utility natural gas, fuel and purchased power	264			188			999			825			179			134			1,178			959
Non-utility cost of revenues, including natural gas	910			790			2,161			2,063			852			864			3,013			2,927
Operation and maintenance	884			578			1,745			1,147			871			567			2,616			1,714
Depreciation and amortization	340			342			653			656			334			326			987			982
Taxes other than income taxes	113			101			239			212			114			95			353			307
Total	2,511			1,999			5,797			4,903			2,350			1,986			8,147			6,889
Operating Income	287			187			532			438			392			226			924			664
Other Income (Expense):
Gain on marketable securities	64			22			147			23			59			43			206			66
Loss on indexed debt securities	(68		)	(254		)	(154		)	(272		)	(62		)	(44		)	(216		)	(316		)
Interest and other finance charges	(134		)	(91		)	(255		)	(169		)	(134		)	(90		)	(389		)	(259		)
Interest on Securitization Bonds	(10		)	(14		)	(22		)	(30		)	(9		)	(16		)	(31		)	(46		)
Equity in earnings of unconsolidated affiliates, net	74			58			136			127			77			81			213			208
Other income, net	11			4			31			7			9			9			40			16
Total	(63		)	(275		)	(117		)	(314		)	(60		)	(17		)	(177		)	(331		)
Income (Loss) Before Income Taxes	224			(88		)	415			124
Income tax expense (benefit)	29			(13		)	51			34
Net Income (Loss)	195			(75		)	364			90
Income Before Income Taxes													332			209			747			333
Income tax expense													62			51			113			85
Net Income													270			158			634			248
Preferred stock dividend requirement	30			—			59			—			29			5			88			5
Income (Loss) Available to Common Shareholders	$	165		$	(75	)	$	305		$	90
Income Available to Common Shareholders													$	241		$	153		$	546		$	243

Basic Earnings (Loss) Per Common Share	$	0.33		$	(0.17	)	$	0.61		$	0.21
Diluted Earnings (Loss) Per Common Share	$	0.33		$	(0.17	)	$	0.61		$	0.21
Basic Earnings Per Common Share													$	0.48		$	0.35		$	1.09		$	0.56
Diluted Earnings Per Common Share													$	0.47		$	0.35		$	1.08		$	0.56
Weighted Average Common Shares Outstanding, Basic	502			432			502			431			502			432			502			431
Weighted Average Common Shares Outstanding, Diluted	505			432			504			434			505			435			505			435

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(Unaudited)

Three Months Ended Six Months Ended
June 30, June 30,
2019 2018 2019 2018
(in millions)
Net income (loss) $ 195
$ (75 ) $ 364
$ 90
Other comprehensive income (loss):
Adjustment to pension and other postretirement plans (net of tax of $1, $-0-, $2 and $1) 2
2
3
3
Net deferred gain (loss) from cash flow hedges (net of tax of $-0-, $-0-, $-0- and $1) —
(1 ) (1 ) 3
Reclassification of deferred loss from cash flow hedges realized in net income (net of tax of $-0-, $-0-, $-0- and $-0-) —
—
1
—
Total 2
1
3
6
Comprehensive income (loss) $ 197
$ (74 ) $ 367
$ 96



	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2019			2018		2019			2018
	(in millions)
Net income	$	270		$	158	$	634		$	248
Other comprehensive income (loss):
Adjustment to pension and other postretirement plans (net of tax of $-0-, $1, $2 and $2)	2			1		5			4
Net deferred gain (loss) from cash flow hedges (net of tax of $-0-, $1, $-0- and $2)	(2		)	3		(3		)	6
Reclassification of deferred loss from cash flow hedges realized in net income (net of tax of $-0-, $-0-, $-0- and $-0-)	—			—		1			—
Other comprehensive loss from unconsolidated affiliates (net of tax of $-0-, $-0-, $-0- and $-0-)	(2		)	—		(2		)	—
Total	(2		)	4		1			10
Comprehensive income	$	268		$	162	$	635		$	258

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

ASSETS


	June 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018
	(in millions)				(in millions)
Current Assets:
Cash and cash equivalents ($260 and $335 related to VIEs, respectively)	$	271	$	4,231
Cash and cash equivalents ($224 and $335 related to VIEs, respectively)					$	259	$	4,231
Investment in marketable securities	687		540		746		540
Accounts receivable ($77 and $56 related to VIEs, respectively), less bad debt reserve of $27 and $18, respectively	1,173		1,190
Accounts receivable ($48 and $56 related to VIEs, respectively), less bad debt reserve of $21 and $18, respectively					1,091		1,190
Accrued unbilled revenues	365		378		403		378
Natural gas inventory	212		194		299		194
Materials and supplies	267		200		273		200
Non-trading derivative assets	101		100		120		100
Taxes receivable	69		—		69		—
Prepaid expenses and other current assets ($33 and $34 related to VIEs, respectively)	181		192
Prepaid expenses and other current assets ($19 and $34 related to VIEs, respectively)					156		192
Total current assets	3,326		7,025		3,416		7,025
Property, Plant and Equipment:
Property, plant and equipment	29,552		20,267		30,066		20,267
Less: accumulated depreciation and amortization	9,620		6,223		9,738		6,223
Property, plant and equipment, net	19,932		14,044		20,328		14,044
Other Assets:
Goodwill	5,179		867		5,179		867
Regulatory assets ($895 and $1,059 related to VIEs, respectively)	2,228		1,967
Notes receivable – unconsolidated affiliate	4		—
Regulatory assets ($821 and $1,059 related to VIEs, respectively)					2,194		1,967
Non-trading derivative assets	44		38		64		38
Investment in unconsolidated affiliates	2,470		2,482		2,469		2,482
Preferred units – unconsolidated affiliate	363		363		363		363
Intangible assets, net	370		65		356		65
Other	273		158		273		158
Total other assets	10,931		5,940		10,898		5,940
Total Assets	$	34,189	$	27,009	$	34,642	$	27,009

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS – (continued)

(Unaudited)

LIABILITIES AND SHAREHOLDERS’ EQUITY


	June 30, 2019			December 31, 2018			September 30, 2019			December 31, 2018
	(in millions, except share amounts)						(in millions, except share amounts)
Current Liabilities:
Current portion of VIE Securitization Bonds long-term debt	$	349		$	458		$	229		$	458
Indexed debt, net	22			24			21			24
Current portion of other long-term debt	117			—			618			—
Indexed debt securities derivative	755			601			817			601
Accounts payable	936			1,240			888			1,240
Taxes accrued	158			204			193			204
Interest accrued	157			121			121			121
Dividends accrued	—			187			—			187
Customer deposits	126			86			122			86
Non-trading derivative liabilities	33			126			50			126
Other	343			255			375			255
Total current liabilities	2,996			3,302			3,434			3,302
Other Liabilities:
Deferred income taxes, net	3,805			3,239			3,851			3,239
Non-trading derivative liabilities	18			5			32			5
Benefit obligations	872			796			812			796
Regulatory liabilities	3,467			2,525			3,481			2,525
Other	653			402			672			402
Total other liabilities	8,815			6,967			8,848			6,967
Long-term Debt:
VIE Securitization Bonds, net	845			977			817			977
Other long-term debt, net	13,276			7,705			13,197			7,705
Total long-term debt, net	14,121			8,682			14,014			8,682
Commitments and Contingencies (Note 14)
Shareholders’ Equity:
Cumulative preferred stock, $0.01 par value, 20,000,000 shares authorized
Series A Preferred Stock, $0.01 par value, $800 aggregate liquidation preference, 800,000 shares outstanding	790			790			790			790
Series B Preferred Stock, $0.01 par value, $978 aggregate liquidation preference, 977,500 shares outstanding	950			950			950			950
Common stock, $0.01 par value, 1,000,000,000 shares authorized, 502,214,639 shares and 501,197,784 shares outstanding, respectively	5			5
Common stock, $0.01 par value, 1,000,000,000 shares authorized, 502,235,354 shares and 501,197,784 shares outstanding, respectively							5			5
Additional paid-in capital	6,065			6,072			6,072			6,072
Retained earnings	552			349			636			349
Accumulated other comprehensive loss	(105		)	(108		)	(107		)	(108		)
Total shareholders’ equity	8,257			8,058			8,346			8,058
Total Liabilities and Shareholders’ Equity	$	34,189		$	27,009		$	34,642		$	27,009

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)


	Six Months Ended June 30,						Nine Months Ended September 30,
	2019			2018			2019			2018
	(in millions)						(in millions)
Cash Flows from Operating Activities:
Net income	$	364		$	90		$	634		$	248
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	653			656			987			982
Amortization of deferred financing costs	14			18			22			34
Amortization of intangible assets in non-utility cost of revenues	12			—			19			—
Deferred income taxes	(21		)	(12		)	8			33
Unrealized gain on marketable securities	(147		)	(23		)	(206		)	(66		)
Loss on indexed debt securities	154			272			216			316
Write-down of natural gas inventory	3			1			5			2
Equity in earnings of unconsolidated affiliates, net of distributions	12			(9		)	13			(15		)
Pension contributions	(29		)	(64		)	(94		)	(67		)
Changes in other assets and liabilities, excluding acquisitions:
Accounts receivable and unbilled revenues, net	463			232			521			355
Inventory	10			52			(85		)	(10		)
Taxes receivable	(69		)	(39		)	(69		)	(38		)
Accounts payable	(594		)	(246		)	(646		)	(262		)
Fuel cost recovery	78			69			68			53
Non-trading derivatives, net	(71		)	64			(66		)	63
Margin deposits, net	(12		)	(9		)	(33		)	2
Interest and taxes accrued	(88		)	(64		)	(89		)	(53		)
Net regulatory assets and liabilities	(77		)	57			(101		)	44
Other current assets	20			(4		)	31			11
Other current liabilities	(156		)	(13		)	(118		)	16
Other assets	76			(3		)	81			(3		)
Other liabilities	(30		)	60			(22		)	24
Other operating activities, net	9			8			10			10
Net cash provided by operating activities	574			1,093			1,086			1,679
Cash Flows from Investing Activities:
Capital expenditures	(1,169		)	(697		)	(1,822		)	(1,121		)
Acquisitions, net of cash acquired	(5,987		)	—			(5,991		)	—
Increase in notes receivable – unconsolidated affiliate	(4		)	—
Distributions from unconsolidated affiliate in excess of cumulative earnings	—			30			—			30
Proceeds from sale of marketable securities	—			398			—			398
Other investing activities, net	11			2			38			19
Net cash used in investing activities	(7,149		)	(267		)	(7,775		)	(674		)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	—			(39		)	—			(39		)
Proceeds from (payments of) commercial paper, net	2,221			(1,188		)	1,584			(1,551		)
Proceeds from long-term debt, net	1,721			997			2,916			997
Payments of long-term debt	(1,077		)	(230		)	(1,225		)	(368		)
Long-term revolving credit facility	135			—
Debt issuance costs	(9		)	(35		)	(19		)	(36		)
Payment of dividends on Common Stock	(288		)	(240		)	(433		)	(360		)
Payment of dividends on Preferred Stock	(60		)	—			(101		)	—
Proceeds from issuance of Series A Preferred Stock, net							—			790
Distribution to ZENS note holders	—			(16		)	—			(398		)
Other financing activities, net	(14		)	(5		)	(14		)	(5		)
Net cash provided by (used in) financing activities	2,629			(756		)	2,708			(970		)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(3,946		)	70			(3,981		)	35
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	4,278			296			4,278			296
Cash, Cash Equivalents and Restricted Cash at End of Period	$	332		$	366		$	297		$	331

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CONSOLIDATED CHANGES IN EQUITY

(Unaudited)


	Three Months Ended June 30,								Six Months Ended June 30,								Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018				2019				2018				2019				2018
	Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount
	(in millions of dollars and shares, except per share amounts)																(in millions of dollars and shares, except per share amounts)
Cumulative Preferred Stock, $0.01 par value; authorized 20,000,000 shares
Balance, beginning of period	2	$	1,740		—	$	—		2	$	1,740		—	$	—		2	$	1,740		—	$	—		2	$	1,740		—	$	—
Issuances of Series A Preferred Stock																	—	—			1	790			—	—			1	790
Balance, end of period	2	1,740			—	—			2	1,740			—	—			2	1,740			1	790			2	1,740			1	790
Common Stock, $0.01 par value; authorized 1,000,000,000 shares
Balance, beginning of period	502	5			431	4			501	5			431	4			502	5			431	4			501	5			431	4
Issuances related to benefit and investment plans	—	—			—	—			1	—			—	—			—	—			—	—			1	—			—	—
Balance, end of period	502	5			431	4			502	5			431	4			502	5			431	4			502	5			431	4
Additional Paid-in-Capital
Balance, beginning of period		6,060				4,208				6,072				4,209				6,065				4,215				6,072				4,209
Issuances related to benefit and investment plans		5				7				(7		)		6				7				6				—				12
Balance, end of period		6,065				4,215				6,065				4,215				6,072				4,221				6,072				4,221
Retained Earnings
Balance, beginning of period		518				708				349				543				552				513				349				543
Net income		195				(75		)		364				90				270				158				634				248
Common Stock dividends declared ($0.2875, $0.2775, $0.2875 and $0.2775 per share, respectively)		(144		)		(120		)		(144		)		(120		)
Series B Preferred Stock dividends declared ($17.5000, $-0-, $17.5000, and $-0- per share, respectively)		(17		)		—				(17		)		—
Common Stock dividends declared ($0.2875, $0.2775, $0.5750 and $0.5550 per share, respectively)																		(145		)		(120		)		(289		)		(240		)
Series A Preferred Stock dividends declared ($30,625, $-0-, $30.625, and $-0- per share, respectively)																		(24		)		—				(24		)		—
Series B Preferred Stock dividends declared ($17.5000, $-0-, $35.0000, and $-0- per share, respectively)																		(17		)		—				(34		)		—
Balance, end of period		552				513				552				513				636				551				636				551
Accumulated Other Comprehensive Loss
Balance, beginning of period		(107		)		(63		)		(108		)		(68		)		(105		)		(62		)		(108		)		(68		)
Other comprehensive income		2				1				3				6				(2		)		4				1				10
Balance, end of period		(105		)		(62		)		(105		)		(62		)		(107		)		(58		)		(107		)		(58		)
Total Shareholders’ Equity		$	8,257			$	4,670			$	8,257			$	4,670			$	8,346			$	5,508			$	8,346			$	5,508

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(Unaudited)


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
	(in millions)												(in millions)
Revenues	$	765		$	854		$	1,451		$	1,609		$	859		$	897		$	2,310		$	2,506
Expenses:
Operation and maintenance	359			351			727			693			359			369			1,086			1,062
Depreciation and amortization	176			262			351			495			168			242			519			737
Taxes other than income taxes	61			60			123			121			63			59			186			180
Total	596			673			1,201			1,309			590			670			1,791			1,979
Operating Income	169			181			250			300			269			227			519			527
Other Income (Expense):
Interest and other finance charges	(42		)	(36		)	(82		)	(69		)	(41		)	(32		)	(123		)	(101		)
Interest on Securitization Bonds	(10		)	(14		)	(22		)	(30		)	(9		)	(16		)	(31		)	(46		)
Other income (expense), net	6			(3		)	10			(6		)	7			—			17			(6		)
Total	(46		)	(53		)	(94		)	(105		)	(43		)	(48		)	(137		)	(153		)
Income Before Income Taxes	123			128			156			195			226			179			382			374
Income tax expense	23			27			29			42			41			36			70			78
Net Income	$	100		$	101		$	127		$	153		$	185		$	143		$	312		$	296

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019			2018		2019		2018		2019			2018
	(in millions)									(in millions)
Net income	$	100	$	101	$	127		$	153	$	185	$	143	$	312		$	296
Other comprehensive income:
Net deferred gain (loss) from cash flow hedges (net of tax of $-0-, $-0-, $-0- and $1)	—		—		(1		)	4
Net deferred gain (loss) from cash flow hedges (net of tax of $-0-, $1, $-0- and $2)										—		3		(1		)	7
Total	—		—		(1		)	4		—		3		(1		)	7
Comprehensive income	$	100	$	101	$	126		$	157	$	185	$	146	$	311		$	303

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

ASSETS


	June 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018
	(in millions)				(in millions)
Current Assets:
Cash and cash equivalents ($260 and $335 related to VIEs, respectively)	$	260	$	335
Accounts and notes receivable ($77 and $56 related to VIEs, respectively), less bad debt reserve of $1 and $1, respectively	327		283
Cash and cash equivalents ($224 and $335 related to VIEs, respectively)					$	228	$	335
Accounts and notes receivable ($48 and $56 related to VIEs, respectively), less bad debt reserve of $1 and $1, respectively					341		283
Accounts and notes receivable–affiliated companies	831		20		787		20
Accrued unbilled revenues	122		110		136		110
Materials and supplies	142		135		144		135
Taxes receivable	13		5		—		5
Prepaid expenses and other current assets ($33 and $34 related to VIEs, respectively)	41		61
Prepaid expenses and other current assets ($19 and $34 related to VIEs, respectively)					30		61
Total current assets	1,736		949		1,666		949
Property, Plant and Equipment:
Property, plant and equipment	12,457		12,148		12,621		12,148
Less: accumulated depreciation and amortization	3,762		3,746		3,795		3,746
Property, plant and equipment, net	8,695		8,402		8,826		8,402
Other Assets:
Regulatory assets ($895 and $1,059 related to VIEs, respectively)	1,016		1,124
Regulatory assets ($821 and $1,059 related to VIEs, respectively)					951		1,124
Other	31		32		20		32
Total other assets	1,047		1,156		971		1,156
Total Assets	$	11,478	$	10,507	$	11,463	$	10,507

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

LIABILITIES AND MEMBER’S EQUITY


	June 30, 2019			December 31, 2018			September 30, 2019			December 31, 2018
	(in millions)						(in millions)
Current Liabilities:
Current portion of VIE Securitization Bonds long-term debt	$	349		$	458		$	229		$	458
Accounts payable	226			262			232			262
Accounts and notes payable–affiliated companies	59			78			65			78
Taxes accrued	63			115			107			115
Interest accrued	82			64			44			64
Non-trading derivative liabilities	—			24			—			24
Other	73			89			69			89
Total current liabilities	852			1,090			746			1,090
Other Liabilities:
Deferred income taxes, net	1,010			1,023			1,005			1,023
Benefit obligations	87			91			84			91
Regulatory liabilities	1,286			1,298			1,295			1,298
Other	69			65			61			65
Total other liabilities	2,452			2,477			2,445			2,477
Long-term Debt:
VIE Securitization Bonds, net	845			977			817			977
Other, net	3,971			3,281			3,972			3,281
Total long-term debt, net	4,816			4,258			4,789			4,258
Commitments and Contingencies (Note 14)
Member’s Equity:
Common stock	—			—			—			—
Additional paid-in capital	2,486			1,896			2,486			1,896
Retained earnings	887			800			1,012			800
Accumulated other comprehensive loss	(15		)	(14		)	(15		)	(14		)
Total member’s equity	3,358			2,682			3,483			2,682
Total Liabilities and Member’s Equity	$	11,478		$	10,507		$	11,463		$	10,507

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)


	Six Months Ended June 30,						Nine Months Ended September 30,
	2019			2018			2019			2018
	(in millions)						(in millions)
Cash Flows from Operating Activities:
Net income	$	127		$	153		$	312		$	296
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	351			495			519			737
Amortization of deferred financing costs	5			6			8			8
Deferred income taxes	(27		)	(38		)	(39		)	(24		)
Changes in other assets and liabilities:
Accounts and notes receivable, net	(56		)	(107		)	(84		)	(95		)
Accounts receivable/payable–affiliated companies	(35		)	78			(7		)	(12		)
Inventory	(7		)	(6		)	(9		)	(10		)
Accounts payable	2			(6		)	3			(6		)
Taxes receivable	(8		)	(23		)	5			(9		)
Interest and taxes accrued	(34		)	(45		)	(28		)	(50		)
Non-trading derivatives, net	(25		)	—			(25		)	—
Net regulatory assets and liabilities	(69		)	(59		)	(58		)	(66		)
Other current assets	18			4			15			13
Other current liabilities	(4		)	(11		)	(3		)	(9		)
Other assets	10			2			8			4
Other liabilities	(3		)	2			(13		)	16
Other operating activities, net	(5		)	(2		)	(9		)	(5		)
Net cash provided by operating activities	240			443			595			788
Cash Flows from Investing Activities:
Capital expenditures	(514		)	(441		)	(744		)	(678		)
Increase in notes receivable–affiliated companies	(794		)	(26		)	(772		)	—
Other investing activities, net	(3		)	(1		)	12			15
Net cash used in investing activities	(1,311		)	(468		)	(1,504		)	(663		)
Cash Flows from Financing Activities:
Proceeds from long-term debt, net	696			398			696			398
Payments of long-term debt	(242		)	(230		)	(390		)	(368		)
Decrease in notes payable–affiliated companies	(1		)	(60		)
Increase (decrease) in notes payable–affiliated companies							(1		)	15
Dividend to parent	(40		)	(63		)	(100		)	(123		)
Contribution from parent	590			—			590			—
Debt issuance costs	(8		)	(4		)	(8		)	(4		)
Other financing activities, net	(1		)	1			(1		)	—
Net cash provided by financing activities	994			42
Net cash provided by (used in) financing activities							786			(82		)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(77		)	17			(123		)	43
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	370			274			370			274
Cash, Cash Equivalents and Restricted Cash at End of Period	$	293		$	291		$	247		$	317

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED CHANGES IN EQUITY

(Unaudited)


	Three Months Ended June 30,								Six Months Ended June 30,								Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018				2019				2018				2019				2018
	Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount
	(in millions, except share amounts)																(in millions, except share amounts)
Common Stock
Balance, beginning of period	1,000	$	—		1,000	$	—		1,000	$	—		1,000	$	—		1,000	$	—		1,000	$	—		1,000	$	—		1,000	$	—
Balance, end of period	1,000	—			1,000	—			1,000	—			1,000	—			1,000	—			1,000	—			1,000	—			1,000	—
Additional Paid-in-Capital
Balance, beginning of period		2,486				1,697				1,896				1,696				2,486				1,697				1,896				1,696
Contribution from Parent		—				—				590				—				—				—				590				—
Other		—				—				—				1				—				(1		)		—				—
Balance, end of period		2,486				1,697				2,486				1,697				2,486				1,696				2,486				1,696
Retained Earnings
Balance, beginning of period		803				693				800				673				887				763				800				673
Net income		100				101				127				153				185				143				312				296
Dividend to parent		(16		)		(31		)		(40		)		(63		)		(60		)		(60		)		(100		)		(123		)
Balance, end of period		887				763				887				763				1,012				846				1,012				846
Accumulated Other Comprehensive Income (Loss)
Balance, beginning of period		(15		)		4				(14		)		—				(15		)		4				(14		)		—
Other comprehensive income (loss)		—				—				(1		)		4				—				3				(1		)		7
Balance, end of period		(15		)		4				(15		)		4				(15		)		7				(15		)		7
Total Member’s Equity		$	3,358			$	2,464			$	3,358			$	2,464			$	3,483			$	2,549			$	3,483			$	2,549

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(Unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
	(in millions)												(in millions)
Revenues:
Utility revenues	$	503		$	487		$	1,688		$	1,630		$	389		$	402		$	2,077		$	2,032
Non-utility revenues	839			841			2,022			2,098			737			910			2,759			3,008
Total	1,342			1,328			3,710			3,728			1,126			1,312			4,836			5,040
Expenses:
Utility natural gas	190			188			815			825			113			134			928			959
Non-utility cost of revenues, including natural gas	769			790			1,940			2,063			687			864			2,627			2,927
Operation and maintenance	211			217			461			455			195			211			656			666
Depreciation and amortization	76			72			153			145			75			77			228			222
Taxes other than income taxes	38			39			87			87			33			33			120			120
Total	1,284			1,306			3,456			3,575			1,103			1,319			4,559			4,894
Operating Income	58			22			254			153
Operating Income (Loss)													23			(7		)	277			146
Other Income (Expense):
Interest and other finance charges	(30		)	(33		)	(59		)	(62		)	(28		)	(30		)	(87		)	(92		)
Other expense, net	—			(1		)	(3		)	(5		)	(3		)	—			(6		)	(5		)
Total	(30		)	(34		)	(62		)	(67		)	(31		)	(30		)	(93		)	(97		)
Income (Loss) From Continuing Operations Before Income Taxes	28			(12		)	192			86			(8		)	(37		)	184			49
Income tax expense (benefit)	—			(4		)	26			16			(1		)	(2		)	25			14
Income (Loss) From Continuing Operations	28			(8		)	166			70			(7		)	(35		)	159			35
Income from discontinued operations (net of tax of $-0-, $14, $-0- and $31, respectively)	—			44			—			96
Net Income	$	28		$	36		$	166		$	166
Income from discontinued operations (net of tax of $-0-, $13, $-0- and $44, respectively)													—			44			—			140
Net Income (Loss)													$	(7	)	$	9		$	159		$	175

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(Unaudited)

Three Months Ended Six Months Ended
June 30, June 30,
2019 2018 2019 2018
(in millions)
Net income $ 28
$ 36
$ 166
$ 166
Comprehensive income $ 28
$ 36
$ 166
$ 166



	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2019			2018		2019		2018
	(in millions)
Net income (loss)	$	(7	)	$	9	$	159	$	175
Comprehensive income (loss)	$	(7	)	$	9	$	159	$	175

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

ASSETS


	June 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018
	(in millions)				(in millions)
Current Assets:
Cash and cash equivalents	$	1	$	14	$	2	$	14
Accounts receivable, less bad debt reserve of $21 and $17, respectively	506		894
Accounts receivable, less bad debt reserve of $16 and $17, respectively					428		894
Accrued unbilled revenues	90		268		83		268
Accounts and notes receivable–affiliated companies	192		120		100		120
Materials and supplies	71		65		73		65
Natural gas inventory	159		194		228		194
Non-trading derivative assets	101		100		120		100
Taxes receivable					4		—
Prepaid expenses and other current assets	39		115		36		115
Total current assets	1,159		1,770		1,074		1,770
Property, Plant and Equipment:
Property, plant and equipment	7,710		7,431		7,892		7,431
Less: accumulated depreciation and amortization	2,306		2,205		2,330		2,205
Property, plant and equipment, net	5,404		5,226		5,562		5,226
Other Assets:
Goodwill	867		867		867		867
Regulatory assets	187		181		189		181
Non-trading derivative assets	44		38		64		38
Other	154		132		173		132
Total other assets	1,252		1,218		1,293		1,218
Total Assets	$	7,815	$	8,214	$	7,929	$	8,214

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

LIABILITIES AND STOCKHOLDER’S EQUITY


	June 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018
	(in millions)				(in millions)
Current Liabilities:
Accounts payable	$	406	$	856	$	393	$	856
Accounts and notes payable–affiliated companies	45		50		48		50
Taxes accrued	51		82		66		82
Interest accrued	38		38		31		38
Customer deposits	74		75		74		75
Non-trading derivative liabilities	28		102		44		102
Other	132		137		143		137
Total current liabilities	774		1,340		799		1,340
Other Liabilities:
Deferred income taxes, net	446		406		455		406
Non-trading derivative liabilities	7		5		18		5
Benefit obligations	94		93		95		93
Regulatory liabilities	1,234		1,227		1,221		1,227
Other	357		329		381		329
Total other liabilities	2,138		2,060		2,170		2,060
Long-Term Debt	2,397		2,371		2,477		2,371
Commitments and Contingencies (Note 14)
Stockholder’s Equity:
Common stock	—		—		—		—
Additional paid-in capital	2,015		2,015		2,015		2,015
Retained earnings	486		423		463		423
Accumulated other comprehensive income	5		5		5		5
Total stockholder’s equity	2,506		2,443		2,483		2,443
Total Liabilities and Stockholder’s Equity	$	7,815	$	8,214	$	7,929	$	8,214

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)


	Six Months Ended June 30,						Nine Months Ended September 30,
	2019			2018			2019			2018
	(in millions)						(in millions)
Cash Flows from Operating Activities:
Net income	$	166		$	166		$	159		$	175
Less: Income from discontinued operations, net of tax	—			96			—			140
Income from continuing operations	166			70			159			35
Adjustments to reconcile income from continuing operations to net cash provided by operating activities:
Depreciation and amortization	153			145			228			222
Amortization of deferred financing costs	4			4			8			7
Deferred income taxes	20			9			26			6
Write-down of natural gas inventory	3			1			5			2
Changes in other assets and liabilities:
Accounts receivable and unbilled revenues, net	554			339			653			449
Accounts receivable/payable–affiliated companies	(11		)	(14		)	(9		)	—
Inventory	26			58			(47		)	1
Taxes receivable							(4		)	—
Accounts payable	(442		)	(248		)	(458		)	(261		)
Fuel cost recovery	78			69			68			53
Interest and taxes accrued	(31		)	(20		)	(23		)	(9		)
Non-trading derivatives, net	(62		)	61			(60		)	60
Margin deposits, net	(12		)	(9		)	(33		)	2
Net regulatory assets and liabilities	15			92			(1		)	73
Other current assets	7			7			11			7
Other current liabilities	(21		)	8			(9		)	24
Other assets	(2		)	4			(3		)	5
Other liabilities	3			52			2			(2		)
Other operating activities, net	1			—
Net cash provided by operating activities from continuing operations	449			628			513			674
Net cash provided by operating activities from discontinued operations	—			118			—			176
Net cash provided by operating activities	449			746			513			850
Cash Flows from Investing Activities:
Capital expenditures	(322		)	(230		)	(546		)	(411		)
Increase in notes receivable–affiliated companies	(66		)	—
Decrease in notes receivable–affiliated companies							27			—
Other investing activities, net	2			3			4			5
Net cash used in investing activities from continuing operations	(386		)	(227		)	(515		)	(406		)
Net cash provided by investing activities from discontinued operations	—			30			—			47
Net cash used in investing activities	(386		)	(197		)	(515		)	(359		)
Cash Flows from Financing Activities:
Decrease in short-term borrowings, net	—			(39		)	—			(39		)
Proceeds from (payments of) commercial paper, net	22			(333		)	100			(800		)
Proceeds from long-term debt	—			599			—			599
Dividends to parent	(103		)	(211		)	(119		)	(286		)
Debt issuance costs	—			(5		)	—			(5		)
Decrease in notes payable–affiliated companies	—			(570		)	—			(570		)
Contribution from parent							—			600
Other financing activities, net	(2		)	(1		)	(2		)	(1		)
Net cash used in financing activities from continuing operations	(83		)	(560		)	(21		)	(502		)
Net cash provided by financing activities from discontinued operations	—			—			—			—
Net cash used in financing activities	(83		)	(560		)	(21		)	(502		)
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(20		)	(11		)	(23		)	(11		)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	25			12			25			12
Cash, Cash Equivalents and Restricted Cash at End of Period	$	5		$	1		$	2		$	1

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

(AN INDIRECT, WHOLLY-OWNED SUBSIDIARY OF CENTERPOINT ENERGY, INC.)

CONDENSED STATEMENTS OF CONSOLIDATED CHANGES IN EQUITY

(Unaudited)


	Three Months Ended June 30,								Six Months Ended June 30,								Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018				2019				2018				2019				2018
	Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount			Shares	Amount
	(in millions, except share amounts)																(in millions, except share amounts)
Common Stock
Balance, beginning of period	1,000	$	—		1,000	$	—		1,000	$	—		1,000	$	—		1,000	$	—		1,000	$	—		1,000	$	—		1,000	$	—
Balance, end of period	1,000	—			1,000	—			1,000	—			1,000	—			1,000	—			1,000	—			1,000	—			1,000	—
Additional Paid-in-Capital
Balance, beginning of period		2,015				2,527				2,015				2,528				2,015				2,528				2,015				2,528
Other		—				1				—				—
Dividends related to CNP Midstream																		—				(1,460		)		—				(1,460		)
Contribution from parent																		—				600				—				600
Balance, end of period		2,015				2,528				2,015				2,528				2,015				1,668				2,015				1,668
Retained Earnings
Balance, beginning of period		541				618				423				574				486				529				423				574
Net income		28				36				166				166				(7		)		9				159				175
Dividend to parent		(83		)		(125		)		(103		)		(211		)		(16		)		(75		)		(119		)		(286		)
Balance, end of period		486				529				486				529				463				463				463				463
Accumulated Other Comprehensive Income
Balance, beginning of period		5				6				5				6				5				6				5				6
Balance, end of period		5				6				5				6				5				6				5				6
Total Stockholder’s Equity		$	2,506			$	3,063			$	2,506			$	3,063			$	2,483			$	2,137			$	2,483			$	2,137

See Combined Notes to Unaudited Condensed Consolidated Financial Statements

CENTERPOINT ENERGY, INC. AND SUBSIDIARIES

CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC AND SUBSIDIARIES

CENTERPOINT ENERGY RESOURCES CORP. AND SUBSIDIARIES

COMBINED NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(1) Background and Basis of Presentation

General. This combined Form 10-Q is filed separately by three registrants: CenterPoint Energy, Inc., CenterPoint Energy Houston Electric, LLC and CenterPoint Energy Resources Corp. Information contained herein relating to any individual registrant is filed by such registrant solely on its own behalf. Each registrant makes no representation as to information relating exclusively to the other Registrants or the subsidiaries of CenterPoint Energy other than itself or its subsidiaries.

Except as discussed in the last paragraph in Note 12 to the Registrants’ Condensed Consolidated Financial Statements, no registrant has an obligation in respect of any other Registrant’s debt securities, and holders of such debt securities should not consider the financial resources or results of operations of any Registrant other than the obligor in making a decision with respect to such securities.

Included in this combined Form 10-Q are the Interim Condensed Financial Statements of CenterPoint Energy, Houston Electric and CERC, which are referred to collectively as the Registrants. The Combined Notes to the Unaudited Condensed Consolidated Financial Statements apply to all Registrants and specific references to Houston Electric and CERC herein also pertain to CenterPoint Energy, unless otherwise indicated. The Interim Condensed Financial Statements are unaudited, omit certain financial statement disclosures and should be read with the Registrants’ combined 2018 Form 10-K.

Background. CenterPoint Energy, Inc. is a public utility holding company and owns interests in Enable as described below. On the Merger Date, pursuant to the Merger Agreement, CenterPoint Energy consummated the previously announced Merger and acquired Vectren for approximately $6 billion in cash. On the Merger Date, Vectren became a wholly-owned subsidiary of CenterPoint Energy.

As of ~~June~~September 30, 2019, CenterPoint Energy’s operating subsidiaries were as follows:

Houston Electric owns and operates electric transmission and distribution facilities in the Texas Gulf Coast area that includes the city of Houston; and

CERC (i) owns and operates natural gas distribution systems in ~~six~~6 states and (ii) obtains and offers competitive variable and fixed-price physical natural gas supplies and services primarily to commercial and industrial customers and electric and natural gas utilities in over 30 states through its wholly-owned subsidiary, CES.

Vectren holds three public utilities through its wholly-owned subsidiary, VUHI, a public utility holding company:

Indiana Gas provides energy delivery services to natural gas customers located in central and southern Indiana;

SIGECO provides energy delivery services to electric and natural gas customers located near Evansville in southwestern Indiana and owns and operates electric generation assets to serve its electric customers and optimizes those assets in the wholesale power market; and

VEDO provides energy delivery services to natural gas customers located near Dayton in west-central Ohio.

Vectren performs non-utility activities through:

Infrastructure Services, which provides underground pipeline construction and repair services through wholly-owned subsidiaries Miller Pipeline, LLC and Minnesota Limited, LLC and serves natural gas utilities across the United States, focusing on recurring integrity, station and maintenance work and opportunities for large transmission pipeline construction projects; and

ESG, which provides energy performance contracting and sustainable infrastructure services, such as renewables, distributed generation and combined heat and power projects.

As of ~~June~~September 30, 2019, CenterPoint Energy, indirectly through CNP Midstream, owned approximately ~~53.8%~~53.7% of the common units representing limited partner interests in Enable, 50% of the management rights and 40% of the incentive distribution rights in Enable GP and also directly owned an aggregate of 14,520,000 Enable Series A Preferred Units. Enable owns, operates and develops natural gas and crude oil infrastructure assets.

As of ~~June~~September 30, 2019, CenterPoint Energy and Houston Electric had VIEs consisting of the Bond Companies, which are consolidated. The consolidated VIEs are wholly-owned, bankruptcy-remote, special purpose entities that were formed solely for the purpose of securitizing transition and system restoration-related property. Creditors of CenterPoint Energy and Houston Electric have no recourse to any assets or revenues of the 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 or Houston Electric.

Basis of Presentation. The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

The 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 the 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. Certain prior year amounts have been reclassified to conform to the current year presentation. See Note 9 for further discussion.

Concurrent with the completion of the Merger, CenterPoint Energy added two new reportable segments, Indiana Electric Integrated and Infrastructure Services, to its five reportable segments disclosed in the Registrants’ combined 2018 Form 10-K. Additionally, CenterPoint Energy’s Natural Gas Distribution reportable segment now includes the gas operations of SIGECO (Indiana South), Indiana Gas and VEDO and CenterPoint Energy’s Corporate and Other reportable segment now includes ESG. Houston Electric’s and CERC’s reportable segments were not impacted by the Merger. For a description of the Registrants’ reportable segments, see Note 16.

Significant Accounting Policies. In addition to the significant accounting policies disclosed in the Registrants’ combined 2018 Form 10-K, CenterPoint Energy has adopted the following new or enhanced significant accounting policies subsequent to the consummation of the Merger:

Principles of Consolidation. Businesses within the Infrastructure Services reportable segment provide underground pipeline construction and repair services for customers that include NGD utilities. In accordance with consolidation guidance in ASC 980—Regulated Operations, costs incurred by NGD utilities for these pipeline construction and repair services are not eliminated in consolidation when capitalized and included in rate base by the NGD utility.

Guarantees. CenterPoint Energy recognizes guarantee obligations at fair value. CenterPoint Energy discloses parent company guarantees of a subsidiary’s obligation when that guarantee results in the exposure of a material obligation of the parent company even if the probability of fulfilling such obligation is considered remote. See Note 14(b).

Income Taxes. Investment tax credits are deferred and amortized to income over the approximate lives of the related property.

MISO Transactions. Indiana Electric is a member of MISO. MISO-related purchase and sale transactions are recorded using settlement information provided by the MISO. These purchase and sale transactions are accounted for on at least a net hourly position, meaning net purchases within that interval are recorded on CenterPoint Energy’s Condensed Statements of Consolidated Income in Utility natural gas, fuel and purchased power, and net sales within that interval are recorded on CenterPoint Energy’s Condensed Statements of Consolidated Income in Utility revenues. On occasion, prior period transactions are resettled outside the routine process due to a change in the MISO’s tariff or a material interpretation thereof. Expenses associated with resettlements are recorded once the resettlement is probable and the resettlement amount can be estimated. Revenues associated with resettlements are recognized when the amount is determinable and collectability is reasonably assured.

(2) New Accounting Pronouncements

The following table provides an overview of certain recently adopted or issued accounting pronouncements applicable to all the Registrants, unless otherwise noted.



Issued, Not Yet Effective Accounting Standards
ASU Number and Name	Description	Effective Date	Financial Statement Impact upon Adoption
ASU 2016-13- Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments	This standard, including standards amending this standard, requires a new model called CECL to estimate credit losses for (1) financial assets subject to credit losses and measured at amortized cost and (2) certain off-balance sheet credit exposures. Upon initial recognition of the exposure, the CECL model requires an entity to estimate the credit losses expected over the life of an exposure based on historical information, current information and reasonable and supportable forecasts, including estimates of prepayments. Transition method: modified retrospective	January 1, 2020 Early adoption is permitted	The adoption of this standard may result in an adjustment to the carrying value of the Registrants’ accounts receivable. The Registrants ~~are currently assessing~~do not anticipate the ~~impact that~~adoption of this standard will have a material impact on ~~their~~the Registrants’ financial position, results of operations or cash ~~flows and disclosures.~~flows.
ASU 2018-13- Fair Value Measurement (Topic 820): Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement	This standard eliminates, modifies and adds certain disclosure requirements for fair value measurements. Transition method: prospective for additions and one modification and retrospective for all other amendments	Adoption of eliminations and modifications as of September 30, 2018; Additions will be adopted January 1, 2020	The adoption of this standard did not impact the Registrants’ financial position, results of operations or cash flows. Note 8 reflects the disclosures modified upon adoption.
ASU 2018-15- Intangibles-Goodwill and Other- Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract	This standard aligns accounting for implementation costs incurred in a cloud computing arrangement that is accounted for as a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. The update also prescribes the balance sheet, income statement, and cash flow classification of the capitalized implementation costs and related amortization expense and requires additional quantitative and qualitative disclosures. Transition method: retrospective or prospective	January 1, 2020 Early adoption is permitted	The adoption of this standard will ~~allow~~require the Registrants to capitalize certain ~~implementation~~ costs ~~incurred in~~to implement cloud computing arrangements that are accounted for as service ~~contracts.~~contracts within Prepaid expenses and other current assets on the Registrants’ condensed consolidated balance sheets and record the amortization of such assets within Operation and maintenance expenses on the Registrants’ condensed statements of consolidated income. The Registrants ~~are currently assessing~~do not anticipate the ~~impact that~~ adoption of this standard will have a material impact on ~~their~~the Registrants’ financial position, results of operations, cash flows ~~and~~or disclosures.

Management believes that other recently adopted standards and recently issued standards that are not yet effective will not have a material impact on the Registrants’ financial position, results of operations or cash flows upon adoption.

(3) Mergers and Acquisitions (CenterPoint Energy)

Merger with Vectren. On the Merger Date, pursuant to the Merger Agreement, CenterPoint Energy consummated the previously announced Merger and acquired Vectren for approximately $6 billion in cash. Each share of Vectren common stock issued and outstanding immediately prior to the closing was canceled and converted into the right to receive $72.00 in cash per share, without interest. At the closing, each stock unit payable in Vectren common stock or whose value is determined with reference to the value of Vectren common stock, whether vested or unvested, was canceled with cash consideration paid in accordance with the terms of the Merger Agreement. These amounts did not include a stub period cash dividend of $0.41145 per share, which was declared, with CenterPoint Energy’s consent, by Vectren’s board of directors on January 16, 2019, and paid to Vectren stockholders as of the record date of February 1, 2019.

Pursuant to the Merger Agreement and immediately subsequent to the close of the Merger, CenterPoint Energy cash settled $78 million in outstanding share-based awards issued prior to the Merger Date by Vectren to its employees. As a result of the Merger, CenterPoint Energy assumed a liability for these share-based awards of $41 million and recorded an incremental cost of $37 million in Operation and maintenance expenses on its Condensed Statements of Consolidated Income during the ~~six~~nine months ended ~~June~~September 30, 2019 for the accelerated vesting of the awards in accordance with the Merger Agreement.

Subsequent to the close of the Merger, CenterPoint Energy recognized severance totaling $61 million to employees terminated immediately subsequent to the Merger close, inclusive of change of control severance payments to executives of Vectren under existing agreements, and which is included in Operation and maintenance expenses on its Condensed Statements of Consolidated Income during the ~~six~~nine months ended ~~June~~September 30, 2019.

In connection with the Merger, VUHI and VCC made offers to prepay certain outstanding guaranteed senior notes as required pursuant to certain note purchase agreements previously entered into by VUHI and VCC. See Note 12 for further details.

Following the closing, shares of Vectren common stock, which previously traded under the ticker symbol “VVC” on the NYSE, ceased trading on and were delisted from the NYSE.

The Merger is being accounted for in accordance with ASC 805, Business Combinations, with CenterPoint Energy as the accounting acquirer of Vectren. Identifiable assets acquired and liabilities assumed have been recorded at their estimated fair values on the Merger Date.

Vectren’s regulated operations, comprised of electric generation and electric and natural gas energy delivery services, are subject to the rate-setting authority of the FERC, the IURC and the PUCO, and are accounted for pursuant to U.S. generally accepted accounting principles for regulated operations. The rate-setting and cost-recovery provisions currently in place for Vectren’s regulated operations provide revenues derived from costs including a return on investment of assets and liabilities included in rate base. Thus, the fair values of Vectren’s tangible and intangible assets and liabilities subject to these rate-setting provisions approximate their carrying values. Accordingly, neither the assets and liabilities acquired, nor the unaudited pro forma financial information, reflect any adjustments related to these amounts. The fair value of regulatory assets not earning a return have been determined using the income approach and are considered Level 3 fair value measurements due to the use of significant judgmental and unobservable inputs.

The fair value of Vectren’s assets acquired and liabilities assumed that are not subject to the rate-setting provisions, including identifiable intangibles, have been determined using the income approach and the market approach. The valuation of Vectren’s long-term debt is primarily considered a Level 2 fair value measurement. All other valuations are considered Level 3 fair value measurements due to the use of significant judgmental and unobservable inputs, including projected timing and amount of future cash flows and discount rates reflecting risk inherent in the future market prices.

The following table presents the preliminary purchase price allocation as of ~~June~~September 30, 2019 (in millions):



Cash and cash equivalents	$	16
Other current assets	598
Property, plant and equipment, net	5,146
Identifiable intangibles	322
Regulatory assets	338
Other assets	151
Total assets acquired	6,571
Current liabilities	690
Regulatory liabilities	944
Other liabilities	860
Long-term debt	2,401
Total liabilities assumed	4,895
Net assets acquired	1,676
Goodwill	4,306
Total purchase price consideration	$	5,982

CenterPoint Energy has not completed a final valuation analysis necessary to determine the fair market values of all of Vectren’s assets and liabilities or the allocation of its purchase price. The preliminary amounts may change as CenterPoint Energy completes its analysis of key valuation assumptions and various tax matters. The preliminary amounts are subject to revision to the extent that additional information is obtained about the facts and circumstances that existed as of the Merger Date. The final allocation could differ materially from this preliminary purchase price allocation and, as such, no assurances can be provided regarding the preliminary purchase accounting. The final allocation may include changes in the fair value of (1) property, plant and equipment,

(2) intangible assets and goodwill, (3) deferred taxes ~~(4) regulatory assets~~ and ~~liabilities, (5) long-term debt and (6)~~(4) other assets and liabilities. Changes in the preliminary purchase price allocation since the initial estimates reported in the first quarter of 2019 primarily included additional information obtained related to intangible assets.

The excess of the purchase price over the estimated fair values of the assets acquired and liabilities assumed is recognized as goodwill, which is primarily attributable to significant potential strategic benefits to CenterPoint Energy, including growth opportunities for more rate-regulated investment, more customers for existing products and services and additional products and services for existing customers. Additionally, CenterPoint Energy believes the Merger will increase geographic and business diversity as well as scale in attractive jurisdictions and economies. CenterPoint Energy anticipates that the value assigned to goodwill will not be deductible for tax purposes.

The estimated fair value of the identifiable intangible assets and related useful lives as included in the preliminary purchase price allocation include:



	Weighted Average Useful Lives	Estimated Fair Value
	(in years)	(in millions)
Operation and maintenance agreements	24	$	12
Customer relationships	18	220
Construction backlog	1	28
Trade names	10	62
Total		$	322

Amortization expense related to the operation and maintenance agreements and construction backlog was $3$7 million and ~~$12~~$19 million ~~inclusive of a $4 million benefit related to a cumulative catch-up for remeasurement of the purchase price allocation,~~ for the three and ~~six~~nine months ended ~~June~~September 30, 2019, respectively, and is included in Non-utility cost of revenues, including natural gas on CenterPoint Energy’s Condensed Statements of Consolidated Income. Amortization expense related to customer relationships and trade names was $5 million and $8$13 million for the three and ~~six~~nine months ended ~~June~~September 30, 2019, respectively, and is included in Depreciation and amortization expense on CenterPoint Energy’s Condensed Statements of Consolidated Income.

The results of operations for Vectren included in CenterPoint Energy’s Interim Condensed Financial Statements from the Merger Date are as follows:


	Three Months Ended June 30, 2019		Six Months Ended June 30, 2019		Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019
	(in millions)				(in millions)
Operating revenues	$	688	$	1,161	$	756	$	1,917
Net income	38		19		67		86

The following unaudited pro forma financial information reflects the consolidated results of operations of CenterPoint Energy, assuming the Merger had taken place on January 1, 2018. The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved had the Merger taken place on the dates indicated or of the future consolidated results of operations of the combined company.


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,					Nine Months Ended September 30,
	2019		2018				2019			2018			2019		2018			2019			2018
	(in millions)												(in millions)
Operating revenues	$	2,798	$	2,830			$	6,575		$	6,644		$	2,742	$	2,877		$	9,317		$	9,521
Net income (loss)	199		(24		)	(1)	371		(2)	83		(3)
Net income													279		212		(1)	649		(2)	282		(3)


(1)	Pro forma net income was adjusted to exclude ~~$10~~$18 million ~~and $27 million, respectively,~~ of Vectren ~~and CenterPoint Energy~~ Merger-related transaction costs incurred in 2018 and reflected in the historical income statements.


(2)	Pro forma net income was adjusted to exclude $37 million of Vectren Merger-related transaction costs incurred in 2019.


(3)	Pro forma net income was adjusted to include ~~$46~~$38 million and $1 million, respectively, of Vectren and CenterPoint Energy Merger-related transaction costs incurred from ~~July~~October 1, 2018 to ~~June~~September 30, 2019.

CenterPoint Energy incurred integration costs in connection with the Merger of ~~$40~~$19 million and ~~$48~~$67 million for the three and ~~six~~nine months ended ~~June~~September 30, 2019, respectively, which were included in Operation and maintenance expenses in CenterPoint Energy’s Condensed Statements of Consolidated Income.

Acquisition of Utility Pipeline Construction Company. An acquisition was made during the ~~six~~nine months ended ~~June~~September 30, 2019 by CenterPoint Energy’s Infrastructure Services reportable segment, resulting in goodwill and intangible assets of approximately $6 million and $8 million, respectively. The intangible assets primarily relate to backlog and customer relationships. The ~~initial~~allocation of the $25 million purchase price ~~of $21 million is subject to change due to a working capital adjustment clause, and the purchase price allocation also~~ is preliminary and subject to change. The results of operations for the acquired company have been included in the consolidated financial statements from the date of acquisition and are not significant to the consolidated financial results of CenterPoint Energy. Pro forma results of operations have not been presented for the acquisition because the effects of the acquisition were not significant to CenterPoint Energy’s consolidated financial results for all periods presented.

(4) Revenue Recognition

In accordance with ASC 606, Revenue from Contracts with Customers, revenue is recognized when a customer obtains control of promised goods or services. The amount of revenue recognized reflects the consideration to which the Registrants expect to be entitled to receive in exchange for these goods or services.

The following tables disaggregate revenues by reportable segment and major source:

CenterPoint Energy


	Three Months Ended June 30, 2019																			Three Months Ended September 30, 2019
	Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)			Corporate and Other (2)		Total			Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)			Corporate and Other (2)		Total
	(in millions)																			(in millions)
Revenue from contracts	$	768		$	140	$	657		$	87		$	326		$	78	$	2,056		$	861		$	165	$	518		$	81		$	377		$	91	$	2,093
Derivatives income	—			—		—			768			—			—		768			—			—		—			664			—			—		664
Other (3)	(3		)	—		3			—			—			2		2			(2		)	—		6			—			—			2		6
Eliminations	—			—		(10		)	(17		)	(1		)	—		(28		)	—			—		(9		)	(11		)	(1		)	—		(21		)
Total revenues	$	765		$	140	$	650		$	838		$	325		$	80	$	2,798		$	859		$	165	$	515		$	734		$	376		$	93	$	2,742

	Six Months Ended June 30, 2019																			Nine Months Ended September 30, 2019
	Houston Electric T&D (1)			Indiana Electric Integrated (1) (4)		Natural Gas Distribution (1) (4)			Energy Services (2)			Infrastructure Services (2) (4)			Corporate and Other (2) (4)		Total			Houston Electric T&D (1)			Indiana Electric Integrated (1) (4)		Natural Gas Distribution (1) (4)			Energy Services (2)			Infrastructure Services (2) (4)			Corporate and Other (2) (4)		Total
	(in millions)																			(in millions)
Revenue from contracts	$	1,458		$	223	$	2,063		$	260		$	472		$	119	$	4,595		$	2,319		$	388	$	2,581		$	341		$	849		$	210	$	6,688
Derivatives income	3			—		—			1,841			—			—		1,844			3			—		—			2,505			—			—		2,508
Other (3)	(7		)	—		(4		)	—			—			3		(8		)	(9		)	—		2			—			—			5		(2		)
Eliminations	—			—		(20		)	(81		)	(1		)	—		(102		)	—			—		(29		)	(92		)	(2		)	—		(123		)
Total revenues	$	1,454		$	223	$	2,039		$	2,020		$	471		$	122	$	6,329		$	2,313		$	388	$	2,554		$	2,754		$	847		$	215	$	9,071


	Three Months Ended June 30, 2018																		Three Months Ended September 30, 2018
	Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)		Corporate and Other (2)		Total			Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)		Corporate and Other (2)		Total
	(in millions)																		(in millions)
Revenue from contracts	$	860		$	—	$	509		$	78		$	—	$	2	$	1,449		$	904		$	—	$	398		$	82		$	—	$	1	$	1,385
Derivatives income	—			—		—			782			—		—		782			—			—		—			838			—		—		838
Other (3)	(6		)	—		(14		)	—			—		2		(18		)	(7		)	—		12			—			—		2		7
Eliminations	—			—		(8		)	(19		)	—		—		(27		)	—			—		(8		)	(10		)	—		—		(18		)
Total revenues	$	854		$	—	$	487		$	841		$	—	$	4	$	2,186		$	897		$	—	$	402		$	910		$	—	$	3	$	2,212

	Six Months Ended June 30, 2018																		Nine Months Ended September 30, 2018
	Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)		Corporate and Other (2)		Total			Houston Electric T&D (1)			Indiana Electric Integrated (1)		Natural Gas Distribution (1)			Energy Services (2)			Infrastructure Services (2)		Corporate and Other (2)		Total
	(in millions)																		(in millions)
Revenue from contracts	$	1,621		$	—	$	1,695		$	256		$	—	$	3	$	3,575		$	2,525		$	—	$	2,093		$	338		$	—	$	4	$	4,960
Derivatives income	(4		)	—		—			1,889			—		—		1,885			(4		)	—		—			2,727			—		—		2,723
Other (3)	(12		)	—		(47		)	—			—		5		(54		)	(19		)	—		(35		)	—			—		7		(47		)
Eliminations	—			—		(18		)	(47		)	—		—		(65		)	—			—		(26		)	(57		)	—		—		(83		)
Total revenues	$	1,605		$	—	$	1,630		$	2,098		$	—	$	8	$	5,341		$	2,502		$	—	$	2,032		$	3,008		$	—	$	11	$	7,553


(1)	Reflected in Utility revenues in the Condensed Statements of Consolidated Income.


(2)	Reflected in Non-utility revenues in the Condensed Statements of Consolidated Income.

(3)

Primarily consists of income from ARPs and leases. ARPs are contracts between the utility and its regulators, not between the utility and a customer. The Registrants recognize ARP revenue as other revenues when the regulator-specified conditions for recognition have been met. Upon recovery of ARP revenue through incorporation in rates charged for utility service to customers, ARP revenue is reversed and recorded as revenue from contracts with customers. The recognition of ARP revenues and the reversal of ARP revenues upon recovery through rates charged for utility service may not occur in the same period.


(4)	Reflects revenues from Vectren subsidiaries for the period from February 1, 2019 to ~~June~~September 30, 2019.

Houston Electric


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
	(in millions)												(in millions)
Revenue from contracts	$	768		$	860		$	1,458		$	1,621		$	861		$	904		$	2,319		$	2,525
Other (1)	(3		)	(6		)	(7		)	(12		)	(2		)	(7		)	(9		)	(19		)
Total revenues	$	765		$	854		$	1,451		$	1,609		$	859		$	897		$	2,310		$	2,506

(1)

CERC


	Three Months Ended June 30,																						Three Months Ended September 30,
	2019											2018											2019											2018
	Natural Gas Distribution (1)			Energy Services (2)			Other Operations (2)		Total			Natural Gas Distribution (1)			Energy Services (2)			Other Operations (2)		Total			Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total			Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)																						(in millions)
Revenue from contracts	$	510		$	87		$	—	$	597		$	509		$	78		$	—	$	587		$	393		$	81		$	3	$	477		$	398		$	82		$	—	$	480
Derivatives income	—			768			—		768			—			782			—		782			—			664			—		664			—			838			—		838
Other (3)	3			—			—		3			(14		)	—			—		(14		)	5			—			—		5			12			—			—		12
Eliminations	(10		)	(16		)	—		(26		)	(8		)	(19		)	—		(27		)	(9		)	(11		)	—		(20		)	(8		)	(10		)	—		(18		)
Total revenues	$	503		$	839		$	—	$	1,342		$	487		$	841		$	—	$	1,328		$	389		$	734		$	3	$	1,126		$	402		$	910		$	—	$	1,312

	Six Months Ended June 30,																						Nine Months Ended September 30,
	2019											2018											2019											2018
	Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total			Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total			Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total			Natural Gas Distribution (1)			Energy Services (2)			Corporate and Other (2)		Total
	(in millions)																						(in millions)
Revenue from contracts	$	1,708		$	260		$	1	$	1,969		$	1,695		$	256		$	—	$	1,951		$	2,101		$	341		$	4	$	2,446		$	2,093		$	338		$	—	$	2,431
Derivatives income	—			1,841			—		1,841			—			1,889			—		1,889			—			2,505			—		2,505			—			2,727			—		2,727
Other (3)	—			—			—		—			(47		)	—			—		(47		)	5			—			—		5			(35		)	—			—		(35		)
Eliminations	(20		)	(80		)	—		(100		)	(18		)	(47		)	—		(65		)	(29		)	(91		)	—		(120		)	(26		)	(57		)	—		(83		)
Total revenues	$	1,688		$	2,021		$	1	$	3,710		$	1,630		$	2,098		$	—	$	3,728		$	2,077		$	2,755		$	4	$	4,836		$	2,032		$	3,008		$	—	$	5,040


(1)	Reflected in Utility revenues in the Condensed Statements of Consolidated Income.


(2)	Reflected in Non-utility revenues in the Condensed Statements of Consolidated Income.

(3)

Revenues from Contracts with Customers

Houston Electric T&D (CenterPoint Energy and Houston Electric). Houston Electric distributes electricity to customers over time and customers consume the electricity when delivered. Revenue, consisting of both volumetric and fixed tariff rates set by state regulators, is recognized as electricity is delivered and represents amounts both billed and unbilled. Discretionary services requested by customers are provided at a point in time with control transferring upon the completion of the service. Revenue for discretionary services is recognized upon completion of service based on the tariff rates set by state regulators. Payments for electricity distribution and discretionary services are aggregated and received on a monthly basis. Houston Electric performs transmission services over time as a stand-ready obligation to provide a reliable network of transmission systems. Revenue is recognized upon time elapsed, and the monthly tariff rate set by state regulators. Payments are received on a monthly basis.

Indiana Electric Integrated (CenterPoint Energy). Indiana Electric generates, distributes and transmits electricity to customers over time, and customers consume the electricity when delivered. Revenue, consisting of both volumetric and fixed tariff rates set by state regulators, is recognized as electricity is delivered and represents amounts both billed and unbilled. Customers are billed monthly and payment terms, set by the regulator, require payment within a month of billing.

Natural Gas Distribution (CenterPoint Energy and CERC). Natural gas is distributed and transported to customers over time, and customers consume the natural gas when delivered. Revenue, consisting of both volumetric and fixed tariff rates set by the state governing agency for that service area, is recognized as natural gas is delivered and represents amounts both billed and unbilled. Discretionary services requested by the customer are satisfied at a point in time and revenue is recognized upon completion of service and the tariff rates set by the applicable state regulator. Payments of natural gas distribution, transportation and discretionary services are aggregated and received on a monthly basis.

Energy Services (CenterPoint Energy and CERC). The majority of CES natural gas sales contracts are considered a derivative, as the contracts typically have a stated minimum or contractual volume of delivery.

For contracts in which CES delivers the full requirement of the natural gas needed by the customer and a volume is not stated, a contract as defined under ASC 606 is created upon the customer’s exercise of its option to take natural gas. CES supplies natural gas to retail customers over time as customers consume the natural gas when delivered. For wholesale customers, CES supplies natural gas at a point in time because the wholesale customer is presumed to have storage capabilities. Control is transferred to both types of customers upon delivery of natural gas. Revenue is recognized on a monthly basis based on the estimated volume of natural gas delivered and the price agreed upon with the customer. Payments are received on a monthly basis.

AMAs are natural gas sales contracts under which CES also assumes management of a customer’s physical storage and/or transportation capacity. AMAs have two distinct performance obligations, which consist of natural gas sales and natural gas delivery because delivery could occur separate from the sale of natural gas (e.g., from storage to customer premises). Most AMAs’ natural gas sales performance obligations are accounted for as embedded derivatives. The transaction price is allocated between the sale of natural gas and the delivery based on the stand-alone selling price as stated in the contract. CES performs natural gas delivery over time as customers take delivery of the natural gas and recognizes revenue on an aggregated monthly basis based on the volume of natural gas delivered and the fees stated within the contract. Payments are received on a monthly basis.

Infrastructure Services (CenterPoint Energy). Infrastructure Services provides underground pipeline construction and repair services. The contracts are generally less than one year in duration and consist of fixed price, unit, and time and material customer contracts. Under unit or time and material contracts, Infrastructure Services performs construction and repair services under specific work-orders at prices established by master service agreements. The performance obligation is defined at the work-order level. These services are billed to customers monthly or more frequently for work completed based on units completed or the costs of time and material incurred and generally require payment within 30 days of billing. Infrastructure Services has the right to consideration from customers in an amount that corresponds directly with the performance obligation satisfied, and therefore recognizes revenue at a point in time in the amount to which it has the right to invoice, which results in accrued unbilled revenues at the end of each accounting period.

Under fixed price contracts, Infrastructure Services performs larger scale construction and repair services. Each contract is typically accounted for as a single performance obligation. Services performed under fixed price contracts are typically billed per the terms of the contract, which can range from completion of specific milestones to scheduled billing intervals. Billings occur monthly or more frequently for work completed and generally require payment within 30 days of billing. Revenue for fixed price contracts is recognized over time as control is transferred using the input method, considering costs incurred relative to total expected cost. Total expected cost is therefore a significant judgment affecting the amount and timing of revenue recognition. Infrastructure Services’ revenues are not subject to significant returns, refunds or warranty obligations.

Contract Balances. When the timing of delivery of service is different from the timing of the payments made by customers and when the right to consideration is conditioned on something other than the passage of time, the Registrants recognize either a contract asset (performance precedes billing) or a contract liability (customer payment precedes performance). Those customers that prepay are represented by contract liabilities until the performance obligations are satisfied. The Registrants’ contract assets are included in Accrued unbilled revenues in their Condensed Consolidated Balance Sheets. On an aggregate basis as of ~~June~~September 30, 2019, the Registrants’ contract assets primarily relate to contracts in the Infrastructure Services segment where revenue is recognized using the input method. The Registrants’ contract liabilities are included in Accounts payable and Other current liabilities in their Condensed Consolidated Balance Sheets. On an aggregate basis as of ~~June~~September 30, 2019, the Registrants’ contract liabilities primarily relate to ESG contracts where revenue is recognized using the input method.

The opening and closing balances of accounts receivable, other accrued unbilled revenue, contract assets and contract liabilities from contracts with customers for the ~~six~~nine months ended ~~June~~September 30, 2019 are as follows:

CenterPoint Energy


	Accounts Receivable		Other Accrued Unbilled Revenues			Contract Assets		Contract Liabilities		Accounts Receivable		Other Accrued Unbilled Revenues			Contract Assets		Contract Liabilities
	(in millions)									(in millions)
Opening balance as of December 31, 2018 (1)	$	763	$	575		$	37	$	47	$	763	$	575		$	37	$	47
Closing balance as of June 30, 2019	831		362			56		54
Closing balance as of September 30, 2019										779		403			75		42
Increase (decrease)	$	68	$	(213	)	$	19	$	7	$	16	$	(172	)	$	38	$	(5	)


(1)	Opening balances related to Vectren are as of February 1, 2019.

The amount of revenue recognized in the ~~six-month~~nine-month period ended ~~June~~September 30, 2019 that was included in the opening contract liability was ~~$38~~$46 million. The difference between the opening and closing balances of the contract liabilities primarily results from the timing difference between CenterPoint Energy’s performance and the customer’s payment.

Houston Electric


	Accounts Receivable		Other Accrued Unbilled Revenues		Contract Liabilities		Accounts Receivable		Other Accrued Unbilled Revenues		Contract Liabilities
	(in millions)						(in millions)
Opening balance as of December 31, 2018	$	234	$	110	$	3	$	234	$	110	$	3
Closing balance as of June 30, 2019	305		122		5
Closing balance as of September 30, 2019							325		136		4
Increase	$	71	$	12	$	2	$	91	$	26	$	1

The amount of revenue recognized in the ~~six-month~~nine-month period ended ~~June~~September 30, 2019 that was included in the opening contract liability was $2$3 million. The difference between the opening and closing balances of the contract liabilities primarily results from the timing difference between Houston Electric’s performance and the customer’s payment.

CERC


	Accounts Receivable			Other Accrued Unbilled Revenues			Accounts Receivable			Other Accrued Unbilled Revenues
	(in millions)						(in millions)
Opening balance as of December 31, 2018	$	282		$	263		$	282		$	263
Closing balance as of June 30, 2019	191			87
Closing balance as of September 30, 2019							137			82
Decrease	$	(91	)	$	(176	)	$	(145	)	$	(181	)

CERC does not have any opening or closing contract asset or contract liability balances.

Remaining Performance Obligations (CenterPoint Energy). The table below discloses (1) the aggregate amount of the transaction price allocated to performance obligations that are unsatisfied (or partially unsatisfied) as of the end of the reporting period for contracts and (2) when CenterPoint Energy expects to recognize this revenue. Such contracts include fixed price contracts in the Infrastructure Services reportable segment.


	Rolling 12 Months		Thereafter		Total		Rolling 12 Months		Thereafter		Total
	(in millions)						(in millions)
Revenue expected to be recognized on contracts in place as of June 30, 2019:
Revenue expected to be recognized on contracts in place as of September 30, 2019:
Fixed price (bid)	$	317	$	—	$	317	$	365	$	—	$	365
	$	317	$	—	$	317	$	365	$	—	$	365

Practical Expedients and Exemption. Sales taxes and other similar taxes collected from customers are excluded from the transaction price. For contracts for which revenue from the satisfaction of the performance obligations is recognized in the amount invoiced, the practical expedient was elected and revenue expected to be recognized on these contracts has not been disclosed.

(5) Employee Benefit Plans

As a result of the Merger, CenterPoint Energy now maintains three additional qualified defined benefit pension plans which are closed to new participants, a non-qualified SERP and a postretirement benefit plan. The defined benefit pension plans cover eligible full-time regular employees and retirees of Vectren and are primarily non-contributory. The postretirement benefit plan provides health care and life insurance benefits, ~~to certain Vectren retirees,~~ which are a combination of self-insured and fully insured programs, to eligible Vectren retirees on both a contributory and non-contributory basis.

CenterPoint Energy, through its Infrastructure Services reportable segment, participates in several industry wide multi-employer pension plans for its collective bargaining employees which provide for monthly benefits based on length of service. The risks of participating in multi-employer pension plans are different from the risks of participating in single-employer pension plans in the following respects: (1) assets contributed to the multi-employer plan by one employer may be used to provide benefits

to employees of other participating employers, (2) if a participating employer stops contributing to the plan, the unfunded obligations

of the plan allocable to such withdrawing employer may be borne by the remaining participating employers and (3) if CenterPoint Energy stops participation in some of its multi-employer pension plans, CenterPoint Energy may be required to pay those plans an amount based on its allocable share of the underfunded status of the plan, referred to as a withdrawal liability.

CenterPoint Energy, through Vectren, also acquired additional defined contribution retirement savings plans qualified under sections 401(a) and 401(k) of the Internal Revenue Code.

The Registrants’ net periodic cost, before considering amounts subject to overhead allocations for capital expenditure projects or for amounts subject to deferral for regulatory purposes, includes the following components relating to pension and postretirement benefits:

Pension Benefits (CenterPoint Energy)


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
	(in millions)												(in millions)
Service cost (1)	$	10		$	9		$	20		$	18		$	10		$	10		$	30		$	28
Interest cost (2)	25			19			48			39			25			20			73			59
Expected return on plan assets (2)	(27		)	(26		)	(52		)	(53		)	(27		)	(27		)	(79		)	(80		)
Amortization of prior service cost (2)	2			2			4			4			2			3			6			7
Amortization of net loss (2)	13			11			26			22			13			10			39			32
Settlement cost (3)	1			—			1			—
Curtailment gain (4)	—			—			(1		)	—
Settlement cost (3) (2)													1			—			2			—
Curtailment gain (4) (2)													—			—			(1		)	—
Net periodic cost	$	24		$	15		$	46		$	30		$	24		$	16		$	70		$	46


(1)	Amounts presented in the table above are included in Operation and maintenance expense in each of the Registrants’ respective Condensed Statements of Consolidated Income, net of amounts capitalized and regulatory deferrals.


(2)	Amounts presented in the table above are included in Other income (expense), net in each of the Registrants’ respective Condensed Statements of Consolidated Income, net of regulatory deferrals.

(3)

A one-time, non-cash settlement cost is required when the total lump sum distributions or other settlements of plan benefit obligations during a plan year exceed the service cost and interest cost components of the net periodic cost for that year. ~~In June 2019,~~ CenterPoint Energy recognized a non-cash settlement cost of $1 million in June and September 2019, respectively, due to lump sum settlement ~~payments from Vectren pension plans.~~payments.


(4)	A curtailment gain or loss is required when the expected future services of a significant number of employees are reduced or eliminated for the accrual of benefits. In February 2019, CenterPoint Energy recognized a pension curtailment gain of $1 million related to Vectren employees whose employment was terminated after the Merger closed.

Postretirement Benefits


	Three Months Ended June 30,																		Three Months Ended September 30,
	2019									2018									2019									2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)																		(in millions)
Service cost (1)	$	—		$	—		$	1		$	1		$	—		$	—		$	2		$	—		$	—		$	—		$	—		$	1
Interest cost (2)	4			2			1			4			2			1			4			1			2			3			2			1
Expected return on plan assets (2)	(1		)	(1		)	(1		)	(2		)	(1		)	(1		)	(3		)	(1		)	—			(1		)	(1		)	—
Amortization of prior service cost (credit) (2)	(1		)	(2		)	—			(1		)	(2		)	1			(1		)	(1		)	—			(1		)	(1		)	—
Net periodic cost (income)	$	2		$	(1	)	$	1		$	2		$	(1	)	$	1		$	2		$	(1	)	$	2		$	1		$	—		$	2

	Six Months Ended June 30,																		Nine Months Ended September 30,
	2019									2018									2019									2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)																		(in millions)
Service cost (1)	$	1		$	—		$	1		$	1		$	—		$	—		$	3		$	—		$	1		$	1		$	—		$	1
Interest cost (2)	8			4			2			7			4			2			12			5			4			10			6			3
Expected return on plan assets (2)	(3		)	(2		)	(1		)	(3		)	(2		)	(1		)	(6		)	(3		)	(1		)	(4		)	(3		)	(1		)
Amortization of prior service cost (credit) (2)	(2		)	(3		)	—			(2		)	(3		)	1			(3		)	(4		)	—			(3		)	(4		)	1
Net periodic cost (income)	$	4		$	(1	)	$	2		$	3		$	(1	)	$	2		$	6		$	(2	)	$	4		$	4		$	(1	)	$	4


(1)	Amounts presented in the tables above are included in Operation and maintenance expense in each of the Registrants’ respective Condensed Statements of Consolidated Income, net of amounts capitalized and regulatory deferrals.


(2)	Amounts presented in the tables above are included in Other income (expense), net in each of the Registrants’ respective Condensed Statements of Consolidated Income, net of regulatory deferrals.

The table below reflects the expected contributions to be made to the pension and postretirement benefit plans during 2019:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
Expected minimum contribution to pension plans during 2019	$	94	$	—	$	—
Expected contribution to postretirement benefit plans in 2019	20		10		4

The table below reflects the contributions made to the pension and postretirement benefit plans during 2019:


	Three Months Ended June 30, 2019						Six Months Ended June 30, 2019						Three Months Ended September 30, 2019						Nine Months Ended September 30, 2019
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)												(in millions)
Pension plans	$	27	$	—	$	—	$	29	$	—	$	—	$	65	$	—	$	—	$	94	$	—	$	—
Postretirement benefit plans	3		2		1		8		5		2		4		3		1		12		8		3

(6) Regulatory ~~Accounting~~Matters

The following is a list of regulatory assets and liabilities reflected on the Registrants’ respective Condensed Consolidated Balance Sheets:


	June 30, 2019									December 31, 2018									September 30, 2019									December 31, 2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
Regulatory Assets:	(in millions)																		(in millions)
Current regulatory assets (1)	$	20		$	—		$	20		$	77		$	—		$	77		$	18		$	—		$	18		$	77		$	—		$	77
Non-current regulatory assets:
Securitized regulatory assets	895			895			—			1,059			1,059			—			821			821			—			1,059			1,059			—
Unrecognized equity return (2)	(189		)	(189		)	—			(213		)	(213		)	—			(175		)	(175		)	—			(213		)	(213		)	—
Unamortized loss on reacquired debt (3)	65			65			—			68			68			—			63			63			—			68			68			—
Pension and postretirement-related regulatory asset (3)	697			34			28			725			33			30			683			35			27			725			33			30
Hurricane Harvey restoration costs (3)	68			64			4			68			64			4			68			64			4			68			64			4
Regulatory assets related to TCJA (3) (4)	30			23			7			33			23			10			30			23			7			33			23			10
Asset retirement obligation (3)	140			25			90			109			24			85			139			25			92			109			24			85
Other regulatory assets-not earning a return (5)	133			74			28			81			55			26			154			65			46			81			55			26
Other regulatory assets	389			25			30			37			11			26			411			30			13			37			11			26
Total non-current regulatory assets	2,228			1,016			187			1,967			1,124			181			2,194			951			189			1,967			1,124			181
Total regulatory assets	2,248			1,016			207			2,044			1,124			258			2,212			951			207			2,044			1,124			258
Regulatory Liabilities:
Current regulatory liabilities (6)	55			5			43			38			17			21			31			—			28			38			17			21
Non-current regulatory liabilities:
Regulatory liabilities related to TCJA (4)	1,616			834			453			1,323			847			476			1,606			830			449			1,323			847			476
Estimated removal costs	1,415			271			629			886			269			617			1,430			259			634			886			269			617
Other regulatory liabilities	436			181			152			316			182			134			445			206			138			316			182			134
Total non-current regulatory liabilities	3,467			1,286			1,234			2,525			1,298			1,227			3,481			1,295			1,221			2,525			1,298			1,227
Total regulatory liabilities	3,522			1,291			1,277			2,563			1,315			1,248			3,512			1,295			1,249			2,563			1,315			1,248
Total regulatory assets and liabilities, net	$	(1,274	)	$	(275	)	$	(1,070	)	$	(519	)	$	(191	)	$	(990	)	$	(1,300	)	$	(344	)	$	(1,042	)	$	(519	)	$	(191	)	$	(990	)


(1)	Current regulatory assets are included in Prepaid expenses and other current assets in the Registrants’ respective Condensed Consolidated Balance Sheets.

(2)

The unrecognized equity return will be recognized as it is recovered in rates through 2024. The timing of CenterPoint Energy’s and Houston Electric’s recognition of the equity return will vary each period based on amounts actually collected during the period. The actual amounts recognized are adjusted at least annually to correct any over-collections or under-collections during the preceding 12 months.

Three Months Ended June 30, Six Months Ended June 30,
2019 2018 2019 2018
CenterPoint Energy Houston Electric CenterPoint Energy Houston Electric CenterPoint Energy Houston Electric CenterPoint Energy Houston Electric
(in millions)
Allowed equity return recognized $ 13
$ 13
$ 24
$ 24
$ 24
$ 24
$ 45
$ 45



	Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018
	CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)
Allowed equity return recognized	$	14	$	14	$	17	$	17	$	38	$	38	$	62	$	62


(3)	Substantially all of these regulatory assets are not earning a return.


(4)	The EDIT and deferred revenues will be recovered or refunded to customers as required by tax and regulatory authorities.


(5)	Regulatory assets acquired in the Merger and not earning a return were recorded at fair value as of the Merger Date. Such fair value adjustments are recognized over time until the regulatory asset is recovered.


(6)	Current regulatory liabilities are included in Other current liabilities in each of the Registrants’ respective Condensed Consolidated Balance Sheets.

Houston Electric Base Rate Case (CenterPoint Energy and Houston Electric)

The key proposals of the rate case include:

a rate base of $6.4 billion with a 50% debt, 50% equity capital structure and a 10.4% ROE;

a prudency determination on all capital investments made by Houston Electric since January 1, 2010;

the establishment of a rider to refund unprotected EDIT resulting from the TCJA; and

updated depreciation rates and approval to recover other costs.

On September 16, 2019, the ALJs issued a PFD recommending a revenue increase of approximately $2.6 million, which is lower than as filed primarily due to the recommended rate base and operation and maintenance expense disallowances, lower equity capital structure, and lower return on equity. If the PFD were approved in its entirety, it would result, among other things, in a one-time refund obligation of capital previously recovered through Houston Electric’s TCOS and DCRF mechanisms, and a pre-tax write-off of approximately $120 million for rate base disallowance of assets recorded in CenterPoint Energy’s and Houston Electric’s Condensed Consolidated Balance Sheets as of September 30, 2019. The amount of any refunds for previously recovered capital would be determined in a separate proceeding with the PUCT. Furthermore, the PFD recommends a separate proceeding with the PUCT to determine the amount, if any, of $158 million EDIT on Houston Electric’s securitized assets to be provided to customers.

The PUCT has not yet begun deliberating on the PFD, which is prepared by judges at a different state agency. A final order from the PUCT is currently expected in the fourth quarter of 2019, but motions for rehearing, if granted, could result in the order being issued in 2020. CenterPoint Energy and Houston Electric cannot predict the outcome of the proceeding.

CenterPoint Energy and Houston Electric record pre-tax expense for disallowed capital investments and customer refund obligations when the amounts are deemed both probable and estimable.

(7) Derivative Instruments

The Registrants are exposed to various market risks. These risks arise from transactions entered into in the normal course of business. The Registrants utilize derivative instruments such as physical forward contracts, swaps and options to mitigate the impact of changes in commodity prices, weather and interest rates on operating results and cash flows.


(a)	Non-Trading Activities

Commodity Derivative Instruments (CenterPoint Energy and CERC). CenterPoint Energy, through its Indiana Utilities, and CERC, through CES, enter into certain derivative instruments to mitigate the effects of commodity price movements. Certain financial instruments used to hedge portions of the natural gas inventory of the Energy Services reportable segment are designated as fair value hedges for accounting purposes. Outstanding derivative instruments designated as economic hedges at the ~~acquired~~ Indiana Utilities hedge long-term variable rate natural gas purchases. The Indiana Utilities have authority to refund and recover mark-to-market gains and losses associated with hedging natural gas purchases, and thus the gains and losses on derivatives are deferred in a regulatory liability or asset. All other financial instruments do not qualify or are not designated as cash flow or fair value hedges.

Interest Rate Risk Derivative Instruments. From time to time, the Registrants may enter into interest rate derivatives that are designated as economic or cash flow hedges. The objective of these hedges is to offset risk associated with interest rates borne by the Registrants in connection with an anticipated future fixed rate debt offering or other exposure to variable rate debt. The Indiana Utilities have authority to refund and recover mark-to-market gains and losses associated with hedging financing activity, and thus

the gains and losses on derivatives are deferred in a regulatory liability or asset. For the impacts of cash flow hedges to Accumulated other comprehensive income, see Note 20.

The table below summarizes the Registrants’ outstanding interest rate hedging activity:


	June 30, 2019				December 31, 2018				September 30, 2019				December 31, 2018
Hedging Classification	Notional Principal								Notional Principal
	CenterPoint Energy (1)		Houston Electric		CenterPoint Energy		Houston Electric		CenterPoint Energy (1)		Houston Electric		CenterPoint Energy		Houston Electric
	(in millions)								(in millions)
Economic hedge	$	84	$	—	$	—	$	—	$	84	$	—	$	—	$	—
Cash flow hedge	—		—		450		450		—		—		450		450


(1)	Relates to interest rate derivative instruments at SIGECO.

Weather Hedges (CenterPoint Energy and CERC). CenterPoint Energy and CERC have weather normalization or other rate mechanisms that largely mitigate the impact of weather on NGD in Arkansas, Indiana, Louisiana, Mississippi, Minnesota, Ohio and Oklahoma, as applicable. CenterPoint Energy’s and CERC’s NGD in Texas and CenterPoint Energy’s electric operations in Texas and Indiana do not have such mechanisms, although fixed customer charges are historically higher in Texas for NGD compared to its other jurisdictions. As a result, fluctuations from normal weather may have a positive or negative effect on CenterPoint Energy’s and CERC’s NGD’s results in Texas and on CenterPoint Energy’s electric operations’ results in its Texas and Indiana service territories.

CenterPoint Energy and CERC, as applicable, enter into winter season weather hedges from time to time for certain NGD jurisdictions and electric operations’ service territory to mitigate the effect of fluctuations from normal weather on results of operations and cash flows. These weather hedges are based on heating degree days at 10-year normal weather. Houston Electric and Indiana Electric do not enter into weather hedges.

The tables below summarize CenterPoint Energy’s and CERC’s current weather hedge gain (loss) activity:


	Three Months Ended June 30,														Three Months Ended September 30,
	2019							2018							2019							2018
Texas Operations	Winter Season	Bilateral Cap		CenterPoint Energy		CERC		Winter Season	Bilateral Cap		CenterPoint Energy		CERC		Winter Season	Bilateral Cap		CenterPoint Energy		CERC		Winter Season	Bilateral Cap		CenterPoint Energy		CERC
	(in millions)														(in millions)
NGD	2018 – 2019	$	9	$	—	$	—	2017 – 2018	$	8	$	—	$	—	2018 – 2019	$	9	$	—	$	—	2017 – 2018	$	8	$	—	$	—
Electric operations	2018 – 2019	8		—		—		2017 – 2018	9		—		—		2018 – 2019	8		—		—		2017 – 2018	9		—		—
Total (1)				$	—	$	—				$	—	$	—				$	—	$	—				$	—	$	—


	Six Months Ended June 30,															Nine Months Ended September 30,
	2019							2018								2019							2018
Texas Operations	Winter Season	Bilateral Cap		CenterPoint Energy		CERC		Winter Season	Bilateral Cap		CenterPoint Energy			CERC		Winter Season	Bilateral Cap		CenterPoint Energy		CERC		Winter Season	Bilateral Cap		CenterPoint Energy			CERC
	(in millions)															(in millions)
NGD	2018 – 2019	$	9	$	—	$	—	2017 – 2018	$	8	$	—		$	—	2018 – 2019	$	9	$	—	$	—	2017 – 2018	$	8	$	—		$	—
Electric operations	2018 – 2019	8		3		—		2017 – 2018	9		(4		)	—		2018 – 2019	8		3		—		2017 – 2018	9		(4		)	—
Total (1)				$	3	$	—				$	(4	)	$	—				$	3	$	—				$	(4	)	$	—


(1)	Weather hedge gains (losses) are recorded in Revenues in the Condensed Statements of Consolidated Income.


(b)	Derivative Fair Values and Income Statement Impacts

The following tables present information about derivative instruments and hedging activities. The first three tables provide a balance sheet overview of Derivative Assets and Liabilities, while the last two tables provide a breakdown of the related income statement impacts.

Fair Value of Derivative Instruments and Hedged Items

CenterPoint Energy


			June 30, 2019				December 31, 2018					September 30, 2019				December 31, 2018
		Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value		Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
			(in millions)									(in millions)
Derivatives designated as cash flow hedges:	Derivatives designated as cash flow hedges:										Derivatives designated as cash flow hedges:
Interest rate derivatives		Current Liabilities: Non-trading derivative liabilities	$	—	$	—	$	—	$	24	Current Liabilities: Non-trading derivative liabilities	$	—	$	—	$	—	$	24
Derivatives designated as fair value hedges:	Derivatives designated as fair value hedges:										Derivatives designated as fair value hedges:
Natural gas derivatives (1) (2) (3)		Current Liabilities: Non-trading derivative liabilities	11		—		1		7		Current Liabilities: Non-trading derivative liabilities	7		—		1		7
Derivatives not designated as hedging instruments:	Derivatives not designated as hedging instruments:										Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)		Current Assets: Non-trading derivative assets	103		2		103		3		Current Assets: Non-trading derivative assets	123		3		103		3
Natural gas derivatives (1) (2) (3)		Other Assets: Non-trading derivative assets	44		—		38		—		Other Assets: Non-trading derivative assets	65		—		38		—
Natural gas derivatives (1) (2) (3)		Current Liabilities: Non-trading derivative liabilities	74		148		62		173		Current Liabilities: Non-trading derivative liabilities	69		154		62		173
Natural gas derivatives (1) (2) (3)		Other Liabilities: Non-trading derivative liabilities	16		41		16		25		Other Liabilities: Non-trading derivative liabilities	13		68		16		25
Interest rate derivatives		Other Liabilities	—		8		—		—		Other Liabilities	—		15		—		—
Indexed debt securities derivative		Current Liabilities	—		755		—		601		Current Liabilities	—		817		—		601
Total CenterPoint Energy	Total CenterPoint Energy		$	248	$	954	$	220	$	833	Total CenterPoint Energy	$	277	$	1,057	$	220	$	833


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling ~~2,186~~2,252 Bcf or a net ~~355~~374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of ~~June~~September 30, 2019 and December 31, 2018, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.

(2)

Natural gas contracts are presented on a net basis in CenterPoint Energy’s Condensed Consolidated Balance Sheets as they are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within CenterPoint Energy’s Condensed Consolidated Balance Sheets. The net of total non-trading natural gas derivative assets and liabilities is detailed in the Offsetting of Natural Gas Derivative Assets and Liabilities table below.

Condensed Consolidated Balance Sheets. The net of total non-trading natural gas derivative assets and liabilities is detailed in the Offsetting of Natural Gas Derivative Assets and Liabilities table below.


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

Houston Electric


			June 30, 2019				December 31, 2018						September 30, 2019				December 31, 2018
		Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value			Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
			(in millions)										(in millions)
Derivatives designated as cash flow hedges:	Derivatives designated as cash flow hedges:										Derivatives designated as cash flow hedges:
Interest rate derivatives		Current Liabilities: Non-trading derivative liabilities	$	—	$	—	$	—	$	24		Current Liabilities: Non-trading derivative liabilities	$	—	$	—	$	—	$	24
Total Houston Electric	Total Houston Electric		$	—	$	—	$	—	$	24	Total Houston Electric		$	—	$	—	$	—	$	24

CERC


			June 30, 2019				December 31, 2018						September 30, 2019				December 31, 2018
		Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value			Balance Sheet Location	Derivative Assets Fair Value		Derivative Liabilities Fair Value		Derivative Assets Fair Value		Derivative Liabilities Fair Value
			(in millions)										(in millions)
Derivatives designated as fair value hedges:	Derivatives designated as fair value hedges:										Derivatives designated as fair value hedges:
Natural gas derivatives (1) (2) (3)		Current Liabilities: Non-trading derivative liabilities	$	11	$	—	$	1	$	7		Current Liabilities: Non-trading derivative liabilities	$	7	$	—	$	1	$	7
Derivatives not designated as hedging instruments:	Derivatives not designated as hedging instruments:										Derivatives not designated as hedging instruments:
Natural gas derivatives (1) (2) (3)		Current Assets: Non-trading derivative assets	103		2		103		3			Current Assets: Non-trading derivative assets	123		3		103		3
Natural gas derivatives (1) (2) (3)		Other Assets: Non-trading derivative assets	44		—		38		—			Other Assets: Non-trading derivative assets	65		—		38		—
Natural gas derivatives (1) (2) (3)		Current Liabilities: Non-trading derivative liabilities	74		142		62		173			Current Liabilities: Non-trading derivative liabilities	69		148		62		173
Natural gas derivatives (1) (2) (3)		Other Liabilities: Non-trading derivative liabilities	16		30		16		25			Other Liabilities: Non-trading derivative liabilities	13		54		16		25
Total CERC	Total CERC		$	248	$	174	$	220	$	208	Total CERC		$	277	$	205	$	220	$	208


(1)	The fair value shown for natural gas contracts is comprised of derivative gross volumes totaling ~~2,186~~2,252 Bcf or a net ~~355~~374 Bcf long position and 1,674 Bcf or a net 140 Bcf long position as of ~~June~~September 30, 2019 and December 31, 2018, respectively. Certain natural gas contracts hedge basis risk only and lack a fixed price exposure.

(2)

Natural gas contracts are presented on a net basis in CERC’s Condensed Consolidated Balance Sheets as they are subject to master netting arrangements. This netting applies to all undisputed amounts due or past due and causes derivative assets (liabilities) to be ultimately presented net in a liability (asset) account within CERC’s Condensed Consolidated Balance Sheets. The net of total non-trading natural gas derivative assets and liabilities is detailed in the Offsetting of Natural Gas Derivative Assets and Liabilities table below.


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

Cumulative Basis Adjustment for Fair Value Hedges (CenterPoint Energy and CERC)


			June 30, 2019											September 30, 2019
		Balance Sheet Location	Carrying Amount of Hedged Assets/(Liabilities)				Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item						Balance Sheet Location	Carrying Amount of Hedged Assets/(Liabilities)				Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item
			CenterPoint Energy		CERC		CenterPoint Energy			CERC				CenterPoint Energy		CERC		CenterPoint Energy			CERC
			(in millions)											(in millions)
Hedged items in fair value hedge relationship:	Hedged items in fair value hedge relationship:												Hedged items in fair value hedge relationship:
Natural gas inventory		Current Assets: Natural gas inventory	$	48	$	48	$	(9	)	$	(9	)	Current Assets: Natural gas inventory	$	42	$	42	$	(7	)	$	(7	)
Total	Total		$	48	$	48	$	(9	)	$	(9	)	Total	$	42	$	42	$	(7	)	$	(7	)



		December 31, 2018
	Balance Sheet Location	Carrying Amount of Hedged Assets/(Liabilities)				Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of Hedged Item
		CenterPoint Energy		CERC		CenterPoint Energy		CERC
		(in millions)
Hedged items in fair value hedge relationship:
Natural gas inventory	Current Assets: Natural gas inventory	$	57	$	57	$	1	$	1
Total		$	57	$	57	$	1	$	1

Offsetting of Natural Gas Derivative Assets and Liabilities (CenterPoint Energy and CERC)

CenterPoint Energy


	June 30, 2019									December 31, 2018									September 30, 2019									December 31, 2018
	Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)			Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)			Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)			Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)
	(in millions)																		(in millions)
Current Assets: Non-trading derivative assets	$	188		$	(87	)	$	101		$	166		$	(66	)	$	100		$	199		$	(79	)	$	120		$	166		$	(66	)	$	100
Other Assets: Non-trading derivative assets	60			(16		)	44			54			(16		)	38			78			(14		)	64			54			(16		)	38
Current Liabilities: Non-trading derivative liabilities	(149		)	116			(33		)	(183		)	81			(102		)	(157		)	107			(50		)	(183		)	81			(102		)
Other Liabilities: Non-trading derivative liabilities	(41		)	23			(18		)	(25		)	20			(5		)	(68		)	36			(32		)	(25		)	20			(5		)
Total CenterPoint Energy	$	58		$	36		$	94		$	12		$	19		$	31		$	52		$	50		$	102		$	12		$	19		$	31

CERC


	June 30, 2019									December 31, 2018									September 30, 2019									December 31, 2018
	Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)			Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)			Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)			Gross Amounts Recognized (1)			Gross Amounts Offset in the Consolidated Balance Sheets			Net Amount Presented in the Consolidated Balance Sheets (2)
	(in millions)																		(in millions)
Current Assets: Non-trading derivative assets	$	188		$	(87	)	$	101		$	166		$	(66	)	$	100		$	199		$	(79	)	$	120		$	166		$	(66	)	$	100
Other Assets: Non-trading derivative assets	60			(16		)	44			54			(16		)	38			78			(14		)	64			54			(16		)	38
Current Liabilities: Non-trading derivative liabilities	(144		)	116			(28		)	(183		)	81			(102		)	(151		)	107			(44		)	(183		)	81			(102		)
Other Liabilities: Non-trading derivative liabilities	(30		)	23			(7		)	(25		)	20			(5		)	(54		)	36			(18		)	(25		)	20			(5		)
Total CERC	$	74		$	36		$	110		$	12		$	19		$	31		$	72		$	50		$	122		$	12		$	19		$	31


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


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

Income Statement Impact of Hedge Accounting Activity (CenterPoint Energy and CERC)


	Three Months Ended June 30,												Three Months Ended September 30,
	2019						2018						2019						2018
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)												Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)
	Non-utility cost of revenues, including natural gas												Non-utility cost of revenues, including natural gas
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)												(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	910		$	769		$	790		$	790		$	852		$	687		$	864		$	864
Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	(4		)	(4		)	(12		)	(12		)	2			2			1			1
Derivatives designated as hedging instruments	4			4			12			12			(2		)	(2		)	(1		)	(1		)
Amounts excluded from effectiveness testing recognized in earnings immediately	(65		)	(65		)	69			69			(59		)	(59		)	6			6


	Six Months Ended June 30,												Nine Months Ended September 30,
	2019						2018						2019						2018
	Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)												Location and Amount of Gain (Loss) recognized in Income on Hedging Relationship (1)
	Non-utility cost of revenues, including natural gas												Non-utility cost of revenues, including natural gas
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)												(in millions)
Total amounts presented in the statements of income in which the effects of hedges are recorded	$	2,161		$	1,940		$	2,063		$	2,063		$	3,013		$	2,627		$	2,927		$	2,927
Gain (loss) on fair value hedging relationships:
Commodity contracts:
Hedged items - Natural gas inventory	(10		)	(10		)	(14		)	(14		)	(8		)	(8		)	(13		)	(13		)
Derivatives designated as hedging instruments	10			10			14			14			8			8			13			13
Amounts excluded from effectiveness testing recognized in earnings immediately	(79		)	(79		)	(2		)	(2		)	(138		)	(138		)	(73		)	(73		)


(1)	Income statement impact associated with cash flow hedge activity is related to gains and losses reclassified from Accumulated other comprehensive income into income. Amounts are immaterial for each Registrant in the three and ~~six~~nine months ended ~~June~~September 30, 2019 and 2018, respectively.

CenterPoint Energy


			Three Months Ended June 30,						Six Months Ended June 30,								Three Months Ended September 30,						Nine Months Ended September 30,
		Income Statement Location	2019			2018			2019			2018				Income Statement Location	2019			2018			2019			2018
			(in millions)														(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:	Effects of derivatives not designated as hedging instruments on the income statement:														Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts		Gains (losses) in Non-utility revenues	$	86		$	11		$	90		$	68			Gains (losses) in Non-utility revenues	$	69		$	2		$	159		$	70
Indexed debt securities derivative		Loss on indexed debt securities	(68		)	(254		)	(154		)	(272		)		Loss on indexed debt securities	(62		)	(44		)	(216		)	(316		)
Total CenterPoint Energy	Total CenterPoint Energy		$	18		$	(243	)	$	(64	)	$	(204	)	Total CenterPoint Energy		$	7		$	(42	)	$	(57	)	$	(246	)

CERC



		Three Months Ended September 30,				Nine Months Ended September 30,
	Income Statement Location	2019		2018		2019		2018
		(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts	Gains (losses) in Non-utility revenues	$	69	$	2	$	159	$	70
Total CERC		$	69	$	2	$	159	$	70

~~CERC~~

Three Months Ended June 30, Six Months Ended June 30,
Income Statement Location 2019 2018 2019 2018
(in millions)
Effects of derivatives not designated as hedging instruments on the income statement:
Commodity contracts Gains (losses) in Non-utility revenues $ 86
$ 11
$ 90
$ 68
Total CERC $ 86
$ 11
$ 90
$ 68


(c)	Credit Risk Contingent Features (CenterPoint Energy and CERC)

CenterPoint Energy and CERC enter into financial derivative contracts containing material adverse change provisions. These provisions could require CenterPoint Energy or CERC to post additional collateral if the S&P or Moody’s credit ratings of CenterPoint Energy, Inc. or its subsidiaries, including CERC Corp., are downgraded.


	June 30, 2019				December 31, 2018				September 30, 2019				December 31, 2018
	CenterPoint Energy		CERC		CenterPoint Energy		CERC		CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)								(in millions)
Aggregate fair value of derivatives containing material adverse change provisions in a net liability position	$	1	$	1	$	1	$	1	$	1	$	1	$	1	$	1
Fair value of collateral already posted	—		—		—		—		—		—		—		—
Additional collateral required to be posted if credit risk contingent features triggered	1		1		—		—		1		1		—		—

(8) Fair Value Measurements

Assets and liabilities that are recorded at fair value in the Registrants’ 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, as well as natural gas inventory that has been designated as the hedged item in a fair value hedge.

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, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means. 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 the Registrants’ Level 2 natural gas derivative assets or liabilities. CenterPoint Energy’s Level 2 indexed debt securities derivative is valued using an option model and a discounted cash flow model, which uses projected dividends on the ZENS-Related Securities and a discount rate as observable inputs.

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 the Registrants’ judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. The Registrants develop these inputs based on the best information available, including the Registrants’ own data. A market approach is utilized to value the Registrants’ Level 3 assets or liabilities. As of ~~June~~September 30, 2019, CenterPoint Energy’s and CERC’s Level 3 assets and liabilities are comprised of physical natural gas forward contracts and options. Level 3 physical natural gas forward contracts and options are valued using a discounted cash flow model which includes illiquid forward price curve locations (ranging from ~~$1.62~~$1.38 to ~~$5.64~~$6.09 per MMBtu for CenterPoint Energy and from ~~$1.62~~$1.38 to ~~$5.64~~$6.09 per MMBtu for CERC) as an unobservable input. CenterPoint Energy’s and CERC’s Level 3 physical natural gas forward contracts and options derivative assets and liabilities consist of both long and short positions (forwards and options). Forward price decreases (increases) as of ~~June~~September 30, 2019 would have resulted in lower (higher) values, respectively, for long forwards and options and higher (lower) values, respectively, for short forwards and options.

The Registrants determine the appropriate level for each financial asset and liability on a quarterly basis. The Registrants also recognize 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 the Registrants’ assets and liabilities (including derivatives that are presented net) measured at fair value on a recurring basis as of ~~June~~September 30, 2019 and December 31, 2018 and indicate the fair value hierarchy of the valuation techniques utilized by the Registrants to determine such fair value.

CenterPoint Energy


	June 30, 2019											December 31, 2018											September 30, 2019											December 31, 2018
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Assets	(in millions)																						(in millions)
Corporate equities	$	690	$	—	$	—	$	—		$	690	$	542	$	—	$	—	$	—		$	542	$	748	$	—	$	—	$	—		$	748	$	542	$	—	$	—	$	—		$	542
Investments, including money market funds (2)	63		—		—		—			63		66		—		—		—			66		50		—		—		—			50		66		—		—		—			66
Natural gas derivatives (3)(4)	—		215		33		(103		)	145		—		173		47		(82		)	138		—		234		43		(93		)	184		—		173		47		(82		)	138
Hedged portion of natural gas inventory	—		—		—		—			—		1		—		—		—			1		—		—		—		—			—		1		—		—		—			1
Total assets	$	753	$	215	$	33	$	(103	)	$	898	$	609	$	173	$	47	$	(82	)	$	747	$	798	$	234	$	43	$	(93	)	$	982	$	609	$	173	$	47	$	(82	)	$	747
Liabilities
Indexed debt securities derivative	$	—	$	755	$	—	$	—		$	755	$	—	$	601	$	—	$	—		$	601	$	—	$	817	$	—	$	—		$	817	$	—	$	601	$	—	$	—		$	601
Interest rate derivatives	—		8		—		—			8		24		—		—		—			24		—		15		—		—			15		24		—		—		—			24
Natural gas derivatives (3)(4)	—		177		13		(139		)	51		—		191		17		(101		)	107		—		203		22		(143		)	82		—		191		17		(101		)	107
Hedged portion of natural gas inventory	9		—		—		—			9		—		—		—		—			—		7		—		—		—			7		—		—		—		—			—
Total liabilities	$	9	$	940	$	13	$	(139	)	$	823	$	24	$	792	$	17	$	(101	)	$	732	$	7	$	1,035	$	22	$	(143	)	$	921	$	24	$	792	$	17	$	(101	)	$	732

Houston Electric


	June 30, 2019										December 31, 2018										September 30, 2019										December 31, 2018
	Level 1		Level 2		Level 3		Netting		Total		Level 1		Level 2		Level 3		Netting		Total		Level 1		Level 2		Level 3		Netting		Total		Level 1		Level 2		Level 3		Netting		Total
Assets	(in millions)																				(in millions)
Investments, including money market funds (2)	$	47	$	—	$	—	$	—	$	47	$	48	$	—	$	—	$	—	$	48	$	33	$	—	$	—	$	—	$	33	$	48	$	—	$	—	$	—	$	48
Total assets	$	47	$	—	$	—	$	—	$	47	$	48	$	—	$	—	$	—	$	48	$	33	$	—	$	—	$	—	$	33	$	48	$	—	$	—	$	—	$	48
Liabilities
Interest rate derivatives	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24
Total liabilities	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	—	$	—	$	24	$	—	$	—	$	—	$	24

CERC


	June 30, 2019											December 31, 2018											September 30, 2019											December 31, 2018
	Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total		Level 1		Level 2		Level 3		Netting (1)			Total
Assets	(in millions)																						(in millions)
Corporate equities	$	3	$	—	$	—	$	—		$	3	$	2	$	—	$	—	$	—		$	2	$	2	$	—	$	—	$	—		$	2	$	2	$	—	$	—	$	—		$	2
Investments, including money market funds (2)	11		—		—		—			11		11		—		—		—			11		11		—		—		—			11		11		—		—		—			11
Natural gas derivatives (3)(4)	—		215		33		(103		)	145		—		173		47		(82		)	138		—		234		43		(93		)	184		—		173		47		(82		)	138
Hedged portion of natural gas inventory	—		—		—		—			—		1		—		—		—			1		—		—		—		—			—		1		—		—		—			1
Total assets	$	14	$	215	$	33	$	(103	)	$	159	$	14	$	173	$	47	$	(82	)	$	152	$	13	$	234	$	43	$	(93	)	$	197	$	14	$	173	$	47	$	(82	)	$	152
Liabilities
Natural gas derivatives (3)(4)	$	—	$	161	$	13	$	(139	)	$	35	$	—	$	191	$	17	$	(101	)	$	107	$	—	$	183	$	22	$	(143	)	$	62	$	—	$	191	$	17	$	(101	)	$	107
Hedged portion of natural gas inventory	9		—		—		—			9		—		—		—		—			—		7		—		—		—			7		—		—		—		—			—
Total liabilities	$	9	$	161	$	13	$	(139	)	$	44	$	—	$	191	$	17	$	(101	)	$	107	$	7	$	183	$	22	$	(143	)	$	69	$	—	$	191	$	17	$	(101	)	$	107


(1)	Amounts represent the impact of legally enforceable master netting arrangements that allow CenterPoint Energy and CERC to settle positive and negative positions and also include cash collateral posted with the same counterparties as follows:

June 30, 2019 December 31, 2018
CenterPoint Energy CERC CenterPoint Energy CERC
(in millions)
Cash collateral posted with the same counterparties $ 36
$ 36
$ 19
$ 19



	September 30, 2019				December 31, 2018
	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)
Cash collateral posted with the same counterparties	$	50	$	50	$	19	$	19


(2)	Amounts are included in Prepaid expenses and other current assets in the Condensed Consolidated Balance Sheets.


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

(4)

Level 1 natural gas derivatives include exchange-traded derivatives cleared by the CME, which deems that financial instruments cleared by the CME are settled daily in connection with posted cash payments. As a result of this exchange rule, CME-related derivatives are considered to have no fair value at the balance sheet date for financial reporting purposes and are presented in Level 1 net of posted cash; however, the derivatives remain outstanding and subject to future commodity price fluctuations until they are settled in accordance with their contractual terms. Derivative transactions cleared on exchanges other than the CME (e.g., the Intercontinental Exchange or ICE) continue to be reported on a gross basis.

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


	Three Months Ended June 30,												Six Months Ended June 30,												Three Months Ended September 30,												Nine Months Ended September 30,
	2019						2018						2019						2018						2019						2018						2019						2018
	CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC			CenterPoint Energy			CERC
	(in millions)																								(in millions)
Beginning balance	$	13		$	13		$	(662	)	$	12		$	30		$	30		$	(622	)	$	46		$	20		$	20		$	(628	)	$	13		$	30		$	30		$	(622	)	$	46
Total gains (losses)	13			13			(11		)	1			12			12			(16		)	3
Total gains																									4			4			1			1			16			16			4			4
Total settlements	(2		)	(2		)	44			(1		)	(17		)	(17		)	11			(35		)	(1		)	(1		)	(1		)	(1		)	(18		)	(18		)	(36		)	(36		)
Transfers into Level 3	(2		)	(2		)	1			1			(1		)	(1		)	1			1			—			—			—			—			(1		)	(1		)	(2		)	(2		)
Transfers out of Level 3	(2		)	(2		)	—			—			(4		)	(4		)	(2		)	(2		)	(2		)	(2		)	650			9			(6		)	(6		)	678			10
Ending balance (1)	$	20		$	20		$	(628	)	$	13		$	20		$	20		$	(628	)	$	13		$	21		$	21		$	22		$	22		$	21		$	21		$	22		$	22

The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains or losses relating to assets still held at the reporting date:
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:																									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:
	$	9		$	9		$	(9	)	$	3		$	6		$	6		$	(23	)	$	(4	)	$	2		$	2		$	11		$	11		$	13		$	13		$	9		$	9


(1)	CenterPoint Energy and CERC did not have significant Level 3 sales or purchases during the three or ~~six~~nine months ended ~~June~~September 30, 2019 or 2018.

Estimated Fair Value of Financial Instruments

The fair values of cash and cash equivalents, investments in debt and equity securities classified as “trading” and short-term borrowings are estimated to be approximately equivalent to carrying amounts and have been excluded from the table below. The carrying amounts of non-trading derivative assets and liabilities, CenterPoint Energy’s ZENS indexed debt securities derivative and hedging instruments 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 a combination of historical trading prices and comparable issue data. These liabilities, which are not measured at fair value in the Registrants’ Condensed Consolidated Balance Sheets, but for which the fair value is disclosed, would be classified as Level 2 in the fair value hierarchy.


	June 30, 2019				December 31, 2018				September 30, 2019				December 31, 2018
	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)								(in millions)
CenterPoint Energy
Long-term debt, including current maturities (1)	$	14,587	$	15,438	$	9,140	$	9,308	$	14,861	$	15,994	$	9,140	$	9,308
Houston Electric
Long-term debt, including current maturities (1)	$	5,165	$	5,583	$	4,717	$	4,770	$	5,018	$	5,595	$	4,717	$	4,770
CERC
Long-term debt, including current maturities	$	2,397	$	2,641	$	2,371	$	2,488	$	2,477	$	2,783	$	2,371	$	2,488


(1)	Includes Securitization Bonds debt.

(9) Unconsolidated Affiliates (CenterPoint Energy and CERC)

CenterPoint Energy has the ability to significantly influence the operating and financial policies of Enable, a publicly traded MLP, and, accordingly, accounts for its investment in Enable’s common units using the equity method of accounting. Enable is considered to be a VIE because the power to direct the activities that most significantly impact Enable’s economic performance does not reside with the holders of equity investment at risk. However, CenterPoint Energy is not considered the primary beneficiary of Enable since it does not have the power to direct the activities of Enable that are considered most significant to the economic performance of Enable. As of ~~June~~September 30, 2019, CenterPoint Energy’s maximum exposure to loss related to Enable is limited to its investment in unconsolidated affiliate, its investment in Enable Series A Preferred Units and outstanding current accounts receivable from Enable.

Investment in Unconsolidated Affiliates (CenterPoint Energy):


	June 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018
	(in millions)				(in millions)
Enable	$	2,469	$	2,482	$	2,467	$	2,482
Other (1)	1		—		2		—
Total	$	2,470	$	2,482	$	2,469	$	2,482


(1)	Represents the equity investment in ProLiance Holdings, LLC related primarily to an investment in LA Storage, LLC, a joint venture in a development project for salt-cavern natural gas storage, which was acquired in the Merger. This presentation reflects preliminary fair value of the equity investment on the acquisition date and is subject to change. See Note 3.

CenterPoint Energy evaluates its equity method investments for impairment when factors indicate that a decrease in value of its investment has occurred and the carrying amount of its investment may not be recoverable. An impairment loss is recognized in earnings when an impairment is deemed to be other than temporary. As of September 30, 2019, CenterPoint Energy’s investment in Enable is $10.55 per unit and Enable’s common unit price closed at $12.03 per unit (approximately $347 million above carrying value). The lowest close price for Enable’s common units in October 2019 was $10.07, which was approximately $112 million below carrying value. CenterPoint Energy performed an analysis of its investment in Enable as of September 30, 2019 and determined it will recover the value of its investment of $2.5 billion.

Limited Partner Interest and Units Held in Enable (CenterPoint Energy):


	June 30, 2019				September 30, 2019
	Limited Partner Interest (1)		Common Units (2)	Enable Series A Preferred Units (3)	Limited Partner Interest (1)		Common Units (2)	Enable Series A Preferred Units (3)
CenterPoint Energy	53.8	%	233,856,623	14,520,000	53.7	%	233,856,623	14,520,000
OGE	25.5	%	110,982,805	—	25.5	%	110,982,805	—
Public unitholders	20.7	%	90,233,873	—	20.8	%	90,310,731	—
Total units outstanding	100.0	%	435,073,301	14,520,000	100.0	%	435,150,159	14,520,000


(1)	Excludes the Enable Series A Preferred Units owned by CenterPoint Energy.


(2)	Held indirectly through CNP Midstream by CenterPoint Energy.


(3)	The carrying amount of the Enable Series A Preferred Units, reflected as Preferred units - unconsolidated affiliate on CenterPoint Energy’s Condensed Consolidated Balance Sheets, was $363 million as of ~~June~~September 30, 2019 and $363 million as of December 31, 2018. No impairment charges or adjustment due to observable price changes were made during the current or prior reporting periods.

Generally, sales to any person or entity (including a series of sales to the same person or entity) of more than 5% of the aggregate of the common units CenterPoint Energy owns in Enable or sales to any person or entity (including a series of sales to the same person or entity) by OGE of more than 5% of the aggregate of the common units it owns in Enable are subject to mutual rights of first offer and first refusal set forth in Enable’s Agreement of Limited Partnership.

Interests Held in Enable GP (CenterPoint Energy):


	June 30, 2019				September 30, 2019
	Management Rights (1)		Incentive Distribution Rights (2)		Management Rights (1)		Incentive Distribution Rights (2)
CenterPoint Energy (3)	50	%	40	%	50	%	40	%
OGE	50	%	60	%	50	%	60	%


(1)	Enable is controlled jointly by CenterPoint Energy and OGE. Sale of CenterPoint Energy’s or OGE’s ownership interests in Enable GP to a third party is subject to mutual rights of first offer and first refusal, and CenterPoint Energy is not permitted to dispose of less than all of its interest in Enable GP.

(2)

Enable is expected to pay a minimum quarterly distribution of $0.2875 per common unit on its outstanding common units to the extent it has sufficient cash from operations after establishment of cash reserves and payment of fees and expenses, including payments to Enable GP and its affiliates, within 60 days after the end of each quarter. If cash distributions to Enable’s unitholders exceed $0.330625 per common unit in any quarter, Enable GP will receive increasing percentages or incentive distributions rights, up to 50%, of the cash Enable distributes in excess of that amount. In certain circumstances Enable GP will have the right to reset the minimum quarterly distribution and the target distribution levels at which the incentive distributions receive increasing percentages to higher levels based on Enable’s cash distributions at the time of the exercise of this reset election. To date, no incentive distributions have been made.


(3)	Held indirectly through CNP Midstream.

Distributions Received from Enable (CenterPoint Energy and CERC):

CenterPoint Energy


	Three Months Ended June 30,								Six Months Ended June 30,								Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018				2019				2018				2019				2018
	Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution		Per Unit		Cash Distribution
	(in millions, except per unit amounts)																(in millions, except per unit amounts)
Enable common units (1)	$	0.3180	$	75	$	0.3180	$	75	$	0.6360	$	149	$	0.6360	$	149	$	0.3305	$	77	$	0.3180	$	74	$	0.9665	$	226	$	0.9540	$	223
Enable Series A Preferred Units	0.6250		9		0.6250		9		1.2500		18		1.2500		18		0.6250		9		0.6250		9		1.8750		27		1.8750		27
Total CenterPoint Energy			$	84			$	84			$	167			$	167			$	86			$	83			$	253			$	250

CERC


									Three Months Ended September 30, 2018				Nine Months Ended September 30, 2018
	Three Months Ended June 30, 2018				Six Months Ended June 30, 2018				Per Unit		Cash Distribution		Per Unit		Cash Distribution
	Per Unit		Cash Distribution		Per Unit		Cash Distribution		(in millions, except per unit amounts)
Enable common units (1)	$	0.3180	$	75	$	0.6360	$	149	$	0.3180	$	74	$	0.9540	$	223
Total CERC			$	75			$	149			$	74			$	223


(1)	Prior to the Internal Spin in September 2018, distributions from Enable were received by CERC. After such date, distributions from Enable were received by CenterPoint Energy.

Transactions with Enable (CenterPoint Energy and CERC):


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018		2019		2018
	(in millions)								(in millions)
CenterPoint Energy
Natural gas expenses, including transportation and storage costs (1)	$	28	$	29	$	63	$	66	$	26	$	23	$	89	$	89
Reimbursement of support services (2)	1		1		3		3		—		1		3		4
CERC
Natural gas expenses, including transportation and storage costs (1)	28		29		63		66		26		23		89		89
Reimbursement of support services (2)	1		1		3		3		—		1		3		4


(1)	Included in Non-utility costs of revenues, including natural gas on CenterPoint Energy’s and CERC’s respective Condensed Statements of Consolidated Income.


(2)	Represents amounts billed for certain support services provided to Enable. Actual support services costs are recorded net of reimbursement.


	June 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018
	(in millions)				(in millions)
CenterPoint Energy
Accounts payable for natural gas purchases from Enable	$	9	$	11	$	9	$	11
Accounts receivable for amounts billed for services provided to Enable	3		2		3		2
CERC
Accounts payable for natural gas purchases from Enable	9		11		9		11
Accounts receivable for amounts billed for services provided to Enable	3		2		3		2

~~CERC’s continuing involvement with Enable subsequent to the Internal Spin described below is limited to its natural gas purchases from Enable.~~

Summarized unaudited consolidated income information for Enable is as follows:


	Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019			2018		2019		2018		2019			2018
	(in millions)									(in millions)
Operating revenues	$	735	$	805	$	1,530		$	1,553	$	699	$	928	$	2,229		$	2,481
Cost of sales, excluding depreciation and amortization	317		444		695			819		263		516		958			1,335
Depreciation and amortization	110		96		215			192		108		100		323			292
Operating income	167		126		332			265		175		171		507			436
Net income attributable to Enable common units	115		86		228			191		123		129		351			320
Reconciliation of Equity in Earnings (Losses), net:
CenterPoint Energy’s interest	$	62	$	46	$	123		$	103	$	66	$	70	$	189		$	173
Basis difference amortization (1)	12		12		24			24		11		11		35			35
Loss on dilution, net of proportional basis difference recognition	—		—		(11		)	—		—		—		(11		)	—
CenterPoint Energy’s equity in earnings, net	$	74	$	58	$	136		$	127	$	77	$	81	$	213		$	208


(1)	Equity in earnings of unconsolidated affiliate includes CenterPoint Energy’s share of Enable earnings adjusted for the amortization of the basis difference of CenterPoint Energy’s original investment in Enable and its underlying equity in net assets of Enable. The basis difference is being amortized through the year 2048.

Summarized unaudited consolidated balance sheet information for Enable is as follows:


	June 30, 2019			December 31, 2018			September 30, 2019			December 31, 2018
	(in millions)						(in millions)
Current assets	$	376		$	449		$	417		$	449
Non-current assets	12,033			11,995			12,018			11,995
Current liabilities	1,270			1,615			819			1,615
Non-current liabilities	3,580			3,211			4,076			3,211
Non-controlling interest	37			38			37			38
Preferred equity	362			362			362			362
Accumulated other comprehensive loss	(3		)	—			(4		)	—
Enable partners’ equity	7,163			7,218			7,145			7,218
Reconciliation of Investment in Enable:
CenterPoint Energy’s ownership interest in Enable partners’ equity	$	3,850		$	3,896		$	3,838		$	3,896
CenterPoint Energy’s basis difference	(1,381		)	(1,414		)	(1,371		)	(1,414		)
CenterPoint Energy’s equity method investment in Enable	$	2,469		$	2,482		$	2,467		$	2,482

Discontinued Operations (CERC):

On September 4, 2018, CERC completed the Internal Spin. CERC executed the Internal Spin to, among other things, enhance the access of CERC and CenterPoint Energy to low cost debt and equity through increased transparency and understandability of the financial statements, improve CERC’s credit quality by eliminating the exposure to Enable’s midstream business and provide clarity of internal reporting and performance metrics to enhance management’s decision making for CERC and CNP Midstream.

The Internal Spin represents a significant strategic shift that has a material effect on CERC’s operations and financial results and, as a result, CERC’s distribution of its equity investment in Enable met the criteria for discontinued operations classification. CERC has no continuing involvement ~~in the equity investment of~~with Enable other than its natural gas purchases from Enable. Therefore, CERC’s equity in earnings and related income taxes have been classified as Income from discontinued operations, net of tax, in CERC’s Condensed Statements of Consolidated Income for the periods presented. The following table presents amounts included in Income from discontinued operations, net of tax in CERC’s Condensed Statements of Consolidated Income.


	Three months ended June 30, 2018		Six months ended June 30, 2018			Three months ended September 30, 2018		Nine months ended September 30, 2018
	(in millions)				(in millions)
Equity in earnings of unconsolidated affiliate, net	$	58	$	127		$	57	$	184
Income tax expense	14		31			13		44
Income from discontinued operations, net of tax	$	44	$	96		$	44	$	140

(10) Goodwill and Other Intangibles (CenterPoint Energy and CERC)

CenterPoint Energy’s goodwill by reportable segment as of December 31, 2018 and changes in the carrying amount of goodwill as of ~~June~~September 30, 2019 is as follows:


	December 31, 2018		Additions (1)		June 30, 2019		December 31, 2018		Additions (1)		September 30, 2019
	(in millions)						(in millions)
Indiana Electric Integrated	$	—	$	1,008	$	1,008	$	—	$	1,008	$	1,008
Natural Gas Distribution	746		2,529		3,275		746		2,529		3,275
Energy Services (2)	110		—		110		110		—		110
Infrastructure Services	—		355		355		—		355		355
Corporate and Other	11		420		431		11		420		431
Total	$	867	$	4,312	$	5,179	$	867	$	4,312	$	5,179


(1)	~~CenterPoint Energy is currently assessing the~~The allocation of goodwill to reportable segments subsequent to the ~~Merger.~~Merger is preliminary and subject to change. See Note 3.


(2)	Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012.

CERC’s goodwill by reportable segment as of ~~June~~September 30, 2019 and December 31, 2018 is as follows:


	June 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018
	(in millions)				(in millions)
Natural Gas Distribution	$	746	$	746	$	746	$	746
Energy Services (1)	110		110		110		110
Corporate and Other	11		11		11		11
Total	$	867	$	867	$	867	$	867


(1)	Amount presented is net of the accumulated goodwill impairment charge of $252 million recorded in 2012.

CenterPoint Energy and CERC perform goodwill impairment tests at least annually and evaluate goodwill when events or changes in circumstances indicate that its carrying value may not be recoverable. The impairment evaluation for goodwill is performed by comparing the fair value of each reporting unit with the carrying amount of the reporting unit, including goodwill. The estimated fair value of the reporting unit is primarily determined based on an income approach or a weighted combination of income and market approaches. If the carrying amount is in excess of the estimated fair value of the reporting unit, then the excess amount is the impairment charge that should be recorded, not to exceed the carrying amount of goodwill. See Note 2.

CenterPoint Energy and CERC performed the annual goodwill impairment test in the third quarter of 2019 and determined that no goodwill impairment charge was required for any reporting unit. The reporting units approximate the reportable segments, with the exception of ESG, which is a separate reporting unit but included in CenterPoint Energy’s Corporate and Other reportable segment.

The tables below present information on CenterPoint Energy’s other intangible assets recorded in Intangible assets, net on CenterPoint Energy’s Condensed Consolidated Balance Sheets and the related amortization expense included in Depreciation and amortization on CenterPoint Energy’s Condensed Statements of Consolidated Income, unless otherwise indicated.


	June 30, 2019							December 31, 2018							September 30, 2019							December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in millions)														(in millions)
Customer relationships (1)	$	306	$	(36	)	$	270	$	86	$	(27	)	$	59	$	306	$	(40	)	$	266	$	86	$	(27	)	$	59
Covenants not to compete	4		(3		)	1		4		(3		)	1		4		(3		)	1		4		(3		)	1
Trade names (1)	62		(3		)	59		—		—			—		62		(4		)	58		—		—			—
Construction backlog (1) (2)	28		(11		)	17		—		—			—		28		(18		)	10		—		—			—
Operation and maintenance agreements (1) (2)	12		(1		)	11		—		—			—		12		(1		)	11		—		—			—
Other (1)	24		(12		)	12		16		(11		)	5		24		(14		)	10		16		(11		)	5
Total	$	436	$	(66	)	$	370	$	106	$	(41	)	$	65	$	436	$	(80	)	$	356	$	106	$	(41	)	$	65


(1)	The fair value of intangible assets acquired through acquisitions is preliminary and subject to change. See Note 3.


(2)	Amortization expense related to the operation and maintenance agreements and construction backlog is included in Non-utility cost of revenues, including natural gas on CenterPoint Energy’s Condensed Statements of Consolidated Income.


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018		2019		2018
	(in millions)								(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization (1)	$	7	$	2	$	13	$	5	$	7	$	2	$	20	$	7
Amortization expense of intangible assets recorded in Non-utility cost of revenues, including natural gas (2)	3		—		12		—		7		—		19		—


(1)	Includes $5 million and $8$13 million for the three and ~~six~~nine months ended ~~June~~September 30, 2019, respectively, of amortization expense related to intangibles acquired in the Merger. The fair value of intangible assets, and related amortization ~~assumptions, acquired through acquisitions during the six months ended June 30, 2019, is preliminary and subject to change. See Note 3.~~

assumptions, acquired through acquisitions during the nine months ended September 30, 2019, is preliminary and subject to change. See Note 3.

(2)

Includes a $4 million benefit related to a cumulative catch-up for remeasurement of the purchase price allocation for the three months ended June 30, 2019 related to the operation and maintenance agreements and construction backlog intangibles acquired in the Merger. The fair value of intangible assets, and related amortization assumptions, acquired through acquisitions during the ~~six~~nine months ended ~~June~~September 30, 2019, is preliminary and subject to change. See Note 3.

The tables below present information on CERC’s other intangible assets recorded in Other non-current assets on CERC’s Condensed Consolidated Balance Sheets and the related amortization expense included in Depreciation and amortization on CERC’s Condensed Statements of Consolidated Income.


	June 30, 2019							December 31, 2018							September 30, 2019							December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance		Gross Carrying Amount		Accumulated Amortization			Net Balance
	(in millions)														(in millions)
Customer relationships	$	86	$	(30	)	$	56	$	86	$	(27	)	$	59	$	86	$	(31	)	$	55	$	86	$	(27	)	$	59
Covenants not to compete	4		(3		)	1		4		(3		)	1		4		(3		)	1		4		(3		)	1
Other	16		(13		)	3		16		(11		)	5		16		(14		)	2		16		(11		)	5
Total	$	106	$	(46	)	$	60	$	106	$	(41	)	$	65	$	106	$	(48	)	$	58	$	106	$	(41	)	$	65

Three Months Ended June 30, Six Months Ended June 30,
2019 2018 2019 2018
(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization $ 2
$ 2
$ 5
$ 5



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Amortization expense of intangible assets recorded in Depreciation and amortization	$	2	$	2	$	7	$	7

CenterPoint Energy and CERC estimate that amortization expense of intangible assets with finite lives for the next five years will be as follows:


	Amortization Expense				Amortization Expense
	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)				(in millions)
Remaining six months of 2019	$	29	$	6
Remaining three months of 2019					$	15	$	4
2020	32		6		32		6
2021	31		6		31		6
2022	32		6		32		6
2023	31		5		31		5
2024	29		5		29		5

(11) Indexed Debt Securities (ZENS) and Securities Related to ZENS (CenterPoint Energy)

(a) Investment in Securities Related to ZENS

A subsidiary of CenterPoint Energy holds shares of certain securities detailed in the table below, which are classified as trading securities and are expected to be held to facilitate CenterPoint Energy’s ability to meet its obligation under the ZENS. Unrealized gains and losses resulting from changes in the market value of the ZENS-Related Securities are recorded in CenterPoint Energy’s Condensed Statements of Consolidated Income.


	Shares Held		Shares Held
	June 30, 2019	December 31, 2018	September 30, 2019	December 31, 2018
AT&T Common	10,212,945	10,212,945	10,212,945	10,212,945
Charter Common	872,503	872,912	872,503	872,912

(b) ZENS

In September 1999, CenterPoint Energy issued ZENS having an original principal amount of $1.0 billion of which $828 million remained outstanding as of ~~June~~September 30, 2019. Each ZENS is 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 attributable to such note. The number and identity of the reference shares attributable to each ZENS are adjusted for certain corporate events. CenterPoint Energy’s reference shares for each ZENS consisted of the following:


	June 30, 2019	December 31, 2018	September 30, 2019	December 31, 2018
	(in shares)		(in shares)
AT&T Common	0.7185	0.7185	0.7185	0.7185
Charter Common	0.061382	0.061382	0.061382	0.061382

CenterPoint Energy pays interest on the ZENS at an annual rate of 2% plus the amount of any quarterly cash dividends paid in respect of the ZENS-Related Securities. The principal amount of the ZENS is subject to increases or decreases to the extent that the annual yield from interest and cash dividends on the ZENS-Related Securities is less than or more than 2.309%. The adjusted principal amount is defined in the ZENS instrument as “contingent principal.” As of ~~June~~September 30, 2019, the ZENS, having an original principal amount of $828 million and a contingent principal amount of ~~$84~~$80 million, were outstanding and were exchangeable at the option of the holders for cash equal to 95% of the market value of the ZENS-Related Securities.

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


(a)	Short-term Borrowings (CenterPoint Energy and CERC)

Inventory Financing. NGD has AMAs associated with its utility distribution service in Arkansas, Louisiana, Mississippi, Oklahoma and Texas. The AMAs have varying terms, the longest of which expires in 2021. Pursuant to the provisions of the agreements, NGD sells natural gas and agrees to repurchase an equivalent amount of natural gas during the winter heating seasons at the same cost. These transactions are accounted for as an inventory financing. CenterPoint Energy and CERC had no outstanding obligations related to the AMAs as of both ~~June~~September 30, 2019 and December 31, 2018.


(b)	Long-term Debt

Debt Transactions. During the ~~six~~nine months ended ~~June~~September 30, 2019, the following debt instruments were issued or incurred:


	Issuance Date	Debt Instrument	Aggregate Principal Amount		Interest Rate as of June 30, 2019		Maturity Date	Issuance Date	Debt Instrument	Aggregate Principal Amount		Interest Rate as of September 30, 2019		Maturity Date
			(in millions)							(in millions)
Houston Electric	January 2019	General mortgage bonds	$	700	4.25	%	2049	January 2019	General mortgage bonds	$	700	4.25	%	2049
CenterPoint Energy (1)	February 2019	Variable rate term loan	25		3.14	%	2020	February 2019	Variable rate term loan	25		2.88	%	2020
CenterPoint Energy	May 2019	Variable rate term loan	1,000		3.17	%	2021	May 2019	Variable rate term loan	1,000		2.81	%	2021
CenterPoint Energy								August 2019	Unsecured senior notes	500		2.50	%	2024
CenterPoint Energy								August 2019	Unsecured senior notes	400		2.95	%	2030
CenterPoint Energy								August 2019	Unsecured senior notes	300		3.70	%	2049


(1)	Draw down by VCC on its variable rate term loan.

Proceeds from Houston Electric’s debt issuance were used for general limited liability company purposes, including capital expenditures. Proceeds from VCC’s draw down of its term loan were used for general corporate purposes. Proceeds from CenterPoint Energy’s ~~term loan~~debt issuances were used for general corporate purposes, including the repayment of commercial paper.

Acquired Debt (CenterPoint Energy). The table below summarizes the long-term external debt of Vectren and its subsidiaries that remained outstanding as of ~~June~~September 30, 2019:


	(in millions)		(in millions)
Long-term debt:
Senior notes due 2020 to 2045 (1)	$	637	$	637
Variable rate term loan due 2020 (2)	300		300
Variable rate term loan due 2020 (3)	200		200
First mortgage bonds due 2022 to 2055 (4)	293		293
Commercial paper (5)	297		278
Bank revolver (6)	135		—
Total Vectren debt	$	1,862	$	1,708

(1)

Consists of $532 million of senior notes issued by VUHI, $96 million of senior notes ~~issues~~issued by Indiana Gas, and $9 million of senior notes issued by VCC. The senior notes have stated interest rates that range from 3.33% to 7.08%. The senior notes issued by VUHI are guaranteed by SIGECO, Indiana Gas and VEDO. The senior notes issued by VCC are guaranteed by Vectren. In connection with the Merger, two of CenterPoint Energy’s acquired wholly-owned subsidiaries, VUHI and VCC, made offers to prepay certain outstanding guaranteed senior notes as required pursuant to certain note purchase agreements previously entered into by VUHI and VCC. In turn, VUHI and VCC borrowed $568 million and $191 million, respectively, from CenterPoint Energy to fund note redemptions effected pursuant to these prepayment offers. To fund these prepayments and payments of approximately $5 million of accrued interest, CenterPoint Energy issued approximately $764 million of commercial paper.


(2)	Issued by VUHI and guaranteed by SIGECO, Indiana Gas and VEDO. As of ~~June~~September 30, 2019, the term loan was fully drawn upon. The term loan’s interest rate is currently priced at one-month LIBOR, plus a credit spread ranging from 70 to 90 basis points depending on credit rating.


(3)	Issued by VCC and guaranteed by Vectren. As of ~~June~~September 30, 2019, the term loan was fully drawn upon, exclusive of any potential incremental term loans under the related facility’s accordion feature. The term loan’s interest rate is currently priced at one-month LIBOR, plus a credit spread of 70 basis points.


(4)	The first mortgage bonds issued by SIGECO subject SIGECO’s properties to a lien under the related mortgage indenture. The first mortgage bonds have stated interest rates that range from 2.375% to 6.72%.


(5)	Issued by VUHI with maturities up to 30 days.


(6)	Represents borrowings under the VCC credit facility, which is guaranteed by Vectren.

Maturities (CenterPoint Energy). As of ~~June~~September 30, 2019, maturities of CenterPoint Energy’s long-term debt were as follows:


	(in millions)		(in millions)
Remaining six months of 2019	$	216
Remaining three months of 2019			$	69
2020	831		831
2021	2,761		2,761
2022	3,769		2,998
2023	713		713
2024	684		1,184
2025 and thereafter	5,752		6,447

Credit Facilities. The Registrants had the following revolving credit facilities as of ~~June~~September 30, 2019:


Execution Date	Registrant	Size of Facility		Draw Rate of LIBOR plus (1)	Financial Covenant Limit on Debt for Borrowed Money to Capital Ratio		Debt for Borrowed Money to Capital Ratio as of June 30, 2019 (2)	Termination Date	Registrant	Size of Facility		Draw Rate of LIBOR plus (1)	Financial Covenant Limit on Debt for Borrowed Money to Capital Ratio		Debt for Borrowed Money to Capital Ratio as of September 30, 2019 (2)	Termination Date
		(in millions)								(in millions)
March 3, 2016	CenterPoint Energy	$	3,300	1.500%	65%	(3)	58.1%	March 3, 2022	CenterPoint Energy	$	3,300	1.500%	65%	(3)	58.6%	March 3, 2022
July 14, 2017	CenterPoint Energy (4)	400		1.125%	65%		52.0%	July 14, 2022	CenterPoint Energy (4)	400		1.125%	65%		52.9%	July 14, 2022
July 14, 2017	CenterPoint Energy (5)	200		1.250%	65%		58.0%	July 14, 2022	CenterPoint Energy (5)	200		1.250%	65%		57.1%	July 14, 2022
March 3, 2016	Houston Electric	300		1.125%	65%	(3)	49.4%	March 3, 2022	Houston Electric	300		1.125%	65%	(3)	48.7%	March 3, 2022
March 3, 2016	CERC	900		1.250%	65%		46.5%	March 3, 2022	CERC	900		1.250%	65%		47.5%	March 3, 2022
	Total	$	5,100						Total	$	5,100


(1)	Based on current credit ratings.


(2)	As defined in the revolving credit facility agreements, excluding Securitization Bonds.

(3)

For CenterPoint Energy and Houston Electric, the financial covenant limit will temporarily increase from 65% to 70% if Houston Electric experiences damage from a natural disaster in its service territory and CenterPoint Energy certifies to the administrative agent that Houston Electric has incurred system restoration costs reasonably likely to exceed $100 million in a consecutive 12-month period, all or part of which Houston Electric 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.


(4)	This credit facility was issued by VUHI, is guaranteed by SIGECO, Indiana Gas and VEDO and includes a $10 million swing line sublimit and a $20 million letter of credit sublimit. This credit facility backstops VUHI’s commercial paper program.


(5)	This credit facility was issued by VCC, is guaranteed by Vectren and includes a $40 million swing line sublimit and an $80 million letter of credit sublimit.

The Registrants, including the subsidiaries of CenterPoint Energy discussed above, were in compliance with all financial debt covenants as of ~~June~~September 30, 2019.

The table below reflects the utilization of the Registrants’ respective revolving credit facilities:


		June 30, 2019								December 31, 2018								September 30, 2019								December 31, 2018
Registrant		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate
	(in millions, except weighted average interest rates)																	(in millions, except weighted average interest rate)
CenterPoint Energy (1)		$	—	$	6	$	2,078	2.63	%	$	—	$	6	$	—	—	%	$	—	$	6	$	1,383	2.28	%	$	—	$	6	$	—	—	%
CenterPoint Energy (2)		—		—		297		2.58	%	—		—		—		—		—		—		278		2.30	%	—		—		—		—
CenterPoint Energy (3)		135		—		—		3.65	%	—		—		—		—		—		—		—		—	%	—		—		—		—
Houston Electric		—		4		—		—	%	—		4		—		—		—		—		—		—	%	—		4		—		—
CERC		—		1		232		2.59	%	—		1		210		2.93	%	—		1		310		2.28	%	—		1		210		2.93	%
Total		$	135	$	11	$	2,607			$	—	$	11	$	210			$	—	$	7	$	1,971			$	—	$	11	$	210

(1)

CenterPoint Energy’s outstanding commercial paper generally has maturities of 60 days or less. Approximately $1.7 billion was issued to refinance commercial paper used to fund a portion of the cash consideration for the Merger, pay related fees and expenses, pay Vectren’s stub period cash dividend and long-term incentive payments and repay indebtedness of Vectren subsidiaries redeemed at the option of the holder as a result of the closing of the Merger.


(2)	This credit facility was issued by VUHI and is guaranteed by SIGECO, Indiana Gas and VEDO.


(3)	This credit facility was issued by VCC and is guaranteed by Vectren.

Other. As of ~~June~~September 30, 2019, certain financial institutions agreed to issue, from time to time, up to $50 million of letters of credit on behalf of Vectren and certain of its subsidiaries in exchange for customary fees. These agreements to issue letters of credit expire on December 31, 2019. As of ~~June~~September 30, 2019, such financial institutions had issued $21 million of letters of credit on behalf of Vectren and certain of its subsidiaries.

Houston Electric had ~~issued~~ $68 million and $68 million of general mortgage bonds outstanding as of ~~June~~September 30, 2019 and December 31, 2018, respectively, as collateral for long-term debt of CenterPoint Energy that matures in 2028. These bonds are not reflected in Houston Electric’s consolidated financial statements because of the contingent nature of the obligations.

(13) Income Taxes

The Registrants reported the following effective tax rates:


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018		2019		2018
CenterPoint Energy (1)	13	%	15	%	12	%	27	%	19	%	24	%	15	%	26	%
Houston Electric (2)	19	%	21	%	19	%	22	%	18	%	20	%	18	%	21	%
CERC - Continuing operations (3)	—	%	33	%	14	%	19	%
CERC - Continuing operations (3) (4)									13	%	5	%	14	%	29	%
CERC - Discontinued operations ~~(4)~~(5)	n/a		24	%	n/a		24	%	n/a		23	%	n/a		24	%

(1)

CenterPoint Energy’s lower effective tax rate for the three and ~~six~~nine months ended ~~June~~September 30, 2019 compared to the same periods for 2018 was primarily due to the following: an increase in the amount of amortization of the net regulatory EDIT ~~liability as decreed by regulators in certain jurisdictions;~~liability; the ~~impact~~effect of state tax law changes that resulted in the remeasurement of state deferred taxes; and the ~~release~~impact of achanges in valuation ~~allowance~~allowances on certain state net operating ~~losses that are now expected to be utilized prior to expiration due to a current period law change.~~losses.


(2)	Houston Electric’s lower effective tax rate for the three and ~~six~~nine months ended ~~June~~September 30, 2019 compared to the same periods for 2018 was primarily due to an increase in the amount of amortization of the net regulatory EDIT ~~liability as decreed by regulators.~~liability.

(3)

CERC’s higher effective tax rate on loss from continuing operations for the three months ended September 30, 2019 compared to the same period for 2018 was primarily due to a decrease in the amount of amortization of the net regulatory EDIT liability, which was partially offset by the absence of a change in the valuation allowance on certain state net operating losses in the three months ended September 30, 2019, the effects of which are compounded by the book loss in the three months ended September 30, 2019.

(4)

CERC’s lower effective tax rate on income from continuing operations for the ~~three and six~~nine months ended ~~June~~September 30, 2019 compared to the same ~~periods~~period for 2018 was primarily due to ~~the following:~~ an increase in the amount of amortization of the net regulatory EDIT liability, ~~as decreed~~which was partially offset by ~~regulators in certain jurisdictions;~~ the impact of ~~state tax law~~ changes ~~that resulted~~ in the ~~remeasurement of state deferred taxes; and the release of a~~ valuation ~~allowance~~allowances on certain state net operating losses ~~that are now expected to be utilized prior to expiration due to a current period law change. The state law changes and valuation allowance release resulted~~ in ~~a lower than expected effective tax rate for the three months ended June 30, 2019 as compared to the three months ended June 30, 2018.~~2019.


~~(4)~~(5)	CERC’s effective tax rate on income from discontinued operations for the three and ~~six~~nine months ended ~~June~~September 30, 2018 was a result of the 21% federal income tax rate plus allocable state income taxes. There are no comparable periods in 2019 since the Internal Spin was completed in the third quarter of 2018.

The Registrants reported a net uncertain tax liability inclusive of interest and penalties of less than $1 million ~~for the three months ended June~~as of September 30, 2019, which reflects a release of approximately $1 million following the ~~anticipated~~ completion of Vectren’s 2016 IRS audit. No significant changes to the uncertain tax liability are expected over the next twelve months. For legacy CenterPoint Energy, tax years through 2016 have been audited and settled with the IRS; however, ~~during 2018,~~ CenterPoint Energy filed an amended returns for 2014 ~~tax return~~and 2015 to claim additional tax credits that isare currently under review by the IRS. For the 2017 –- 2019 tax years, CenterPoint Energy is a participant in the IRS’s Compliance Assurance Process.

(14) Commitments and Contingencies


(a)	Purchase Obligations (CenterPoint Energy and CERC)

Commitments include minimum purchase obligations related to CenterPoint Energy’s and CERC’s Natural Gas Distribution and Energy Services reportable segments and CenterPoint Energy’s Indiana Electric Integrated reportable segment. Contracts with minimum payment provisions have various quantity requirements and durations and are not classified as non-trading derivative

assets and liabilities in CenterPoint Energy’s and CERC’s Condensed Consolidated Balance Sheets as of ~~June~~September 30, 2019 and December 31, 2018. These contracts meet an exception as “normal purchases contracts” or do not meet the definition of a derivative. Natural gas and coal supply commitments also include transportation contracts that do not meet the definition of a derivative.

As of ~~June~~September 30, 2019, minimum purchase obligations are approximately:


	CenterPoint Energy		CERC		CenterPoint Energy		CERC
	(in millions)				(in millions)
Remaining six months of 2019	$	399	$	276
Remaining three months of 2019					$	217	$	160
2020	658		459		745		528
2021	488		308		614		429
2022	576		402		412		235
2023	350		197		330		177
2024	228		132		265		169
2025 and beyond	1,639		1,276		1,846		1,483

Indiana Electric Integrated also has other purchased power agreements that do not have minimum thresholds but do require payment when energy is generated by the provider. Costs arising from certain of these commitments are pass-through costs, generally collected dollar-for-dollar from retail customers through regulator-approved cost recovery mechanisms.


(b)	Guarantees and Product Warranties (CenterPoint Energy)

In the normal course of business, ESG enters into contracts requiring it to timely install infrastructure, operate facilities, pay vendors and subcontractors and support warranty obligations and, at times, issue payment and performance bonds and other forms of assurance in connection with these contracts.

Specific to ESG’s role as a general contractor in the performance contracting industry, as of ~~June~~September 30, 2019, there were 6863 open surety bonds supporting future performance with an aggregate face amount of approximately ~~$705~~$627 million. ESG’s exposure is less than the face amount of the surety bonds and is limited to the level of uncompleted work under the contracts. As of ~~June~~September 30, 2019, approximately ~~40%~~35% of the work was yet to be completed on projects with open surety bonds. Further, various subcontractors issue surety bonds to ESG. In addition to these performance obligations, ESG also warrants the functionality of certain installed infrastructure generally for one year and the associated energy savings over a specified number of years. Since ESG’s inception in 1994, CenterPoint Energy believes ESG has had a history of generally meeting its performance obligations and energy savings guarantees and its installed products operating effectively. CenterPoint Energy assessed the fair value of its obligation for such guarantees as of ~~June~~September 30, 2019 and no amounts were recorded on CenterPoint Energy’s Condensed Consolidated Balance Sheets. The Merger purchase price allocation, including the fair value of liabilities for guarantees on the Merger Date, remains preliminary. See Note 3.

CenterPoint Energy issues parent company level guarantees to certain vendors, customers and other commercial counterparties of ESG. These guarantees do not represent incremental consolidated obligations, but rather, represent guarantees of subsidiary obligations to allow those subsidiaries to conduct business without posting other forms of assurance. As of ~~June~~September 30, 2019, CenterPoint Energy, primarily through Vectren, has issued parent company level guarantees supporting ESG’s obligations. For those obligations where potential exposure can be estimated, management estimates the maximum exposure under these guarantees to be approximately ~~$489~~$498 million as of ~~June~~September 30, 2019. This exposure primarily relates to energy savings guarantees on federal energy savings performance contracts. Other parent company level guarantees, certain of which do not contain a cap on potential liability, have been issued in support of federal operations and maintenance projects for which a maximum exposure cannot be estimated based on the nature of the projects. While there can be no assurance that performance under any of these parent company guarantees will not be required in the future, CenterPoint Energy considers the likelihood of a material amount being incurred as remote.


(c)	Legal, Environmental and Other Matters

Legal Matters

Gas Market Manipulation Cases (CenterPoint Energy and CERC). CenterPoint Energy, its predecessor, Reliant Energy, and certain of their former subsidiaries were named as defendants in a large number of lawsuits filed against numerous gas market participants in a number of federal and western state courts in connection with the operation of the natural gas markets in 2000-2002. CenterPoint Energy and its affiliates were released or dismissed from all such cases, except for one case ~~pending~~ in federal court in Nevada

in which CES, a subsidiary of CERC, iswas a defendant. Plaintiffs in that case ~~allege~~alleged a conspiracy to inflate Wisconsin natural gas prices in 2000-2002. In May 2016, the district court granted CES’s motion for summary judgment, dismissing CES from the case. In August 2018, the Ninth Circuit Court of Appeals reversed that ruling, and CES requested further appellate review of that decision (which review has been stayed pending approval of the settlement agreement described below).

Under a master separation agreement between CenterPoint Energy and a former subsidiary, RRI, CenterPoint Energy and its subsidiaries are entitled to be indemnified by RRI and its successors for any losses, including certain attorneys’ fees and other costs, arising out of these lawsuits. Through a series of transactions, RRI became known as GenOn and a wholly-owned subsidiary of NRG. None of those transactions alters GenOn’s contractual obligations to indemnify CenterPoint Energy and its subsidiaries for certain liabilities, including their indemnification obligations regarding the gas market manipulation litigation. In June 2017, however, GenOn and various affiliates filed for protection under Chapter 11 of the U.S. Bankruptcy Code. In December 2018, GenOn completed its reorganization and emerged from Chapter 11. CenterPoint Energy, CERC, and CES submitted proofs of claim in the bankruptcy proceedings to protect their indemnity rights. In October 2018, CES ~~GenOn, and the plaintiffs~~ reached an agreement to settle all claims against CES and CES’s ~~indemnity~~ claims ~~against GenOn, subject to approvals by~~for indemnity. During the ~~bankruptcy court and the federal district court. In January 2019, the bankruptcy court approved the settlement between CES and GenOn, and in August~~third quarter of 2019, the federal district court issued final ~~approval. CES will now complete~~approval of the settlement ~~payments,~~ and dismissed the ~~matter should be concluded later this year.~~case, and CES completed the required settlement payments; the settlement agreement has now become final. This settlement did not have a material adverse effect on CenterPoint Energy’s or CERC’s financial condition, results of operations or cash flows.

Minnehaha Academy (CenterPoint Energy and CERC). On August 2, 2017, a natural gas explosion occurred at the Minnehaha Academy in Minneapolis, Minnesota, resulting in the deaths of two school employees, serious injuries to others and significant property damage to the school. CenterPoint Energy, certain of its subsidiaries, including CERC, and the contractor company working in the school have been named in litigation arising out of this incident. CenterPoint Energy and CERC have reached confidential settlement agreements with some claimants. Additionally, CenterPoint Energy and CERC are cooperating with the ongoing investigation conducted by the National Transportation Safety Board. Further, CenterPoint Energy and CERC contested and have since reached a settlement regarding approximately $200,000 in fines imposed by the Minnesota Office of Pipeline Safety. In early 2018, the Minnesota Occupational Safety and Health Administration concluded its investigation without any adverse findings against CenterPoint Energy or CERC. CenterPoint Energy’s and CERC’s general and excess liability insurance policies provide coverage for third party bodily injury and property damage claims.

Litigation Related to the Merger (CenterPoint Energy). With respect to the Merger, in July 2018, seven separate lawsuits were filed against Vectren and the individual directors of Vectren’s Board of Directors in the U.S. District Court for the Southern District of Indiana. These lawsuits ~~allege~~alleged violations of Sections 14(a) of the Exchange Act and SEC Rule 14a-9 on the grounds that the Vectren Proxy Statement filed on June 18, 2018 was materially incomplete because it omitted material information concerning the Merger. ~~The lawsuits also seek certification as class actions.~~ In August 2018, the seven lawsuits were consolidated, and the Court denied the plaintiffs’ request for a preliminary injunction. ~~The~~In October 2018, the plaintiffs filed their Consolidated Amended Class Action Complaint in October 2018, which the defendants have moved to dismiss and which motion remains pending. The plaintiffs filed their response in opposition to the motion to dismiss in January 2019, and Vectren filed its reply in support of the motion to dismiss in February 2019.Complaint. In December 2018, two plaintiffs voluntarily dismissed their ~~lawsuits, for~~lawsuits. In September 2019, the court granted the defendants’ motion to dismiss and dismissed the remaining plaintiffs’ claims with prejudice, which the ~~Court entered an order approving the voluntary dismissal and dismissed without prejudice~~plaintiffs appealed in ~~January~~October 2019. The defendants believe that the allegations asserted are without merit and intend to vigorously defend themselves against the claims raised. CenterPoint Energy does not expect the ultimate outcome of this matter to have a material adverse effect on its financial condition, results of operations or cash flows.

Environmental Matters

MGP Sites. CenterPoint Energy, CERC and their predecessors operated MGPs in the past. In addition, certain of CenterPoint Energy’s subsidiaries acquired through the Merger operated MGPs in the past. The costs CenterPoint Energy or CERC, as applicable, expect to incur to fulfill their respective obligations are estimated by management using assumptions based on actual costs incurred, the timing of expected future payments and inflation factors, among others. While CenterPoint Energy and CERC have recorded

all costs which they presently ~~expect~~are obligated to incur in connection with activities at these sites, it is possible that future events may require remedial activities which are not presently foreseen, and those costs may not be subject to PRP or insurance recovery.

(i)

Minnesota MGPs (CenterPoint Energy and CERC). With respect to certain Minnesota MGP sites, CenterPoint Energy and CERC have completed state-ordered remediation and continue state-ordered monitoring and water treatment. CenterPoint Energy and CERC recorded a liability as reflected in the table below for continued monitoring and any future remediation required by regulators in Minnesota. The estimated range of possible remediation costs for the sites for which CenterPoint Energy and CERC believe they may have responsibility was based on remediation continuing for the time frame given in the table below.

June 30, 2019
CenterPoint Energy CERC
(in millions, except years)
Amount accrued for remediation $ 7
$ 7
Minimum estimated remediation costs 4
4
Maximum estimated remediation costs 32
32
Minimum years of remediation 30
30
Maximum years of remediation 50
50

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 depend on the number of sites to be remediated, the participation of other PRPs, if any, and the remediation methods used.

(ii)

Indiana MGPs (CenterPoint Energy). In the Indiana Gas service territory, the existence, location and certain general characteristics of 26 gas manufacturing and storage sites have been identified for which CenterPoint Energy may have some remedial responsibility. A remedial investigation/feasibility study was completed at one of the sites under an agreed upon order between Indiana Gas and the IDEM, and a Record of Decision was issued by the IDEM in January 2000. The remaining sites have been submitted to the IDEM’s VRP. CenterPoint Energy has also identified its involvement in five manufactured gas plant sites in SIGECO’s service territory, all of which are currently enrolled in the IDEM’s VRP. CenterPoint Energy is currently conducting some level of remedial activities, including groundwater monitoring at certain sites.

As of June 30, 2019, approximately $2 million of accrued costs related to these sites are included in Other liabilities on CenterPoint Energy’s Condensed Consolidated Balance Sheets. Total costs that may be incurred in connection with addressing these sites cannot be determined at this time. The estimated accrued costs are limited to CenterPoint Energy’s share of the remediation efforts and are therefore net of exposures of other PRPs.


(iii)	Other MGPs (CenterPoint Energy and CERC). In addition to the Minnesota and Indiana sites, the EPA and other regulators have investigated MGP sites that were owned or operated by CenterPoint Energy or CERC or may have been owned by one of their former affiliates.

Total costs that may be incurred in connection with addressing these sites cannot be determined at this time. The estimated accrued costs are limited to CenterPoint Energy’s and CERC’s share of the remediation efforts and are therefore net of exposures of other PRPs. The estimated range of possible remediation costs for the sites for which CenterPoint Energy and CERC believe they may have responsibility was based on remediation continuing for the minimum time frame given in the table below.



	September 30, 2019
	CenterPoint Energy		CERC
	(in millions, except years)
Amount accrued for remediation	$	9	$	7
Minimum estimated remediation costs	7		4
Maximum estimated remediation costs	51		32
Minimum years of remediation	5		30
Maximum years of remediation	50		50

CenterPoint Energy and CERC do not expect the ultimate outcome of these matters to have a material adverse effect on the financial condition, results of operations or cash flows of either CenterPoint Energy or CERC.

Asbestos. Some facilities owned by the Registrants or their predecessors contain or have contained asbestos insulation and other asbestos-containing materials. The Registrants are from time to time named, along with numerous others, as defendants in lawsuits filed by a number of individuals who claim injury due to exposure to asbestos, and the Registrants anticipate that additional claims may be asserted in the future. Although their ultimate outcome cannot be predicted at this time, the Registrants do not expect these matters, either individually or in the aggregate, to have a material adverse effect on their financial condition, results of operations or cash flows.

CCR Rule (CenterPoint Energy). In April 2015, the EPA finalized its CCR Rule, which regulates ash as non-hazardous material under the RCRA. The final rule allows beneficial reuse of ash, and the majority of the ash generated by Indiana Electric’s generating plants will continue to be reused. In July 2018, the EPA released its final CCR Rule Phase I Reconsideration which extended the deadline to October 31, 2020 for ceasing placement of ash in ponds that exceed groundwater protections standards or that fail to meet location restrictions. While the EPA Phase I Reconsideration moves forward, the existing CCR compliance obligations remain in effect. In August 2019, the EPA proposed additional amendments to its CCR Rule with respect to beneficial reuse of ash and other materials. The proposed revisions would not restrict Indiana Electric’s current beneficial reuse of its fly ash.

Indiana Electric has three ash ponds, two at the F.B. Culley facility (Culley East and Culley West) and one at the A.B. Brown facility. Under the existing CCR Rule, Indiana Electric is required to perform integrity assessments, including ground water monitoring, at its F.B. Culley and A.B. Brown generating stations. The ground water studies are necessary to determine the remaining service life of the ponds and whether a pond must be retrofitted with liners or closed in place, with bottom ash handling conversions completed. Indiana Electric’s Warrick generating unit is not included in the scope of the CCR Rule as this unit has historically been part of a larger generating station that predominantly serves an adjacent industrial facility. In March 2018, Indiana Electric began posting ground water data monitoring reports annually to its public website in accordance with the requirements of the CCR Rule. This data preliminarily indicates potential groundwater impacts very close to Indiana Electric’s ash impoundments, and further analysis is ongoing. The CCR Rule required companies to complete location restriction determinations by October 18, 2018. Indiana Electric completed its evaluation and determined that one F.B. Culley pond (Culley East) and the A.B. Brown pond fail the aquifer placement location restriction. As a result of this failure, Indiana Electric is required to cease disposal of new ash in the ponds and commence closure of the ponds by October 31, 2020. CenterPoint Energy plans to seek extensions available under the CCR Rule that would allow Indiana Electric to continue to use the ponds through December 31, 2023. The inability to take these extensions may result in increased and potentially significant operational costs in connection with the accelerated implementation of an alternative ash disposal system or adversely impact Indiana Electric’s future operations. Failure to comply with these requirements could also result in an enforcement proceeding including the imposition of fines and penalties. On April 24, 2019, Indiana Electric received an order from the IURC approving recovery in rates of costs associated with the closure of ~~one of~~ the ~~ponds at F.B. Culley.~~Culley West pond, which has already commenced closure activities. CenterPoint Energy believes the language in the IURC order is favorable for future recovery of closure costs for Indiana Electric’s remaining ponds.

Indiana Electric continues to refine site specific estimates of closure costs. In March 2019, Indiana Electric entered into agreements with third parties for the excavation and beneficial reuse of the ash at the A.B. Brown ash pond. On August 14, 2019, Indiana Electric filed its petition with the IURC for recovery of costs associated with the closure of the A.B. Brown ash pond, which would include costs associated with the excavation and recycling of the ponded ash. In July 2018, Indiana Electric filed a Complaint for Damages and Declaratory Relief against its insurers seeking reimbursement of defense, investigation and pond closure costs incurred to comply with the CCR Rule, and has since reached a confidential settlement ~~agreement~~agreements with ~~one of the~~its insurers. Any

proceeds received will offset costs that have been and will be incurred to close the ponds. On November 4, 2019, the EPA released a pre-publication copy of proposed revisions to the CCR Rule. CenterPoint Energy will evaluate the proposals to determine potential impacts to current compliance plans for its A.B. Brown and F.B. Culley generating stations.

As of ~~June~~September 30, 2019, CenterPoint Energy has recorded an approximate ~~$90~~$75 million ARO, which represents the discounted value of future cash flow estimates to close the ponds at A.B. Brown and F.B. Culley. ~~The fair value of the ARO assumed on the Merger Date is preliminary.~~ This estimate is ~~also~~ subject to change ~~in the near term~~ due to the contractual arrangements; continued assessments of the ash, closure methods, and the timing of closure; implications of Indiana Electric’s generation transition plan; changing environmental regulations; and the anticipated outcome of the aforementioned insurance proceeding. In addition to these removal costs, Indiana Electric also anticipates equipment purchases of between $60 million and $80 million to complete the A.B. Brown closure project.

Other Environmental. From time to time, the Registrants identify the presence of environmental contaminants during operations or on property where their predecessors have conducted operations. Other such sites involving contaminants may be identified in the future. The Registrants have and expect to continue to remediate any identified sites consistent with state and federal legal obligations. From time to time, the Registrants have received notices, and may receive notices in the future, from regulatory authorities or others regarding status as a PRP in connection with sites found to require remediation due to the presence of environmental contaminants. In addition, the Registrants have been, or may be, named from time to time as defendants in litigation related to such sites. Although the ultimate outcome of such matters cannot be predicted at this time, the Registrants do not expect these matters, either individually or in the aggregate, to have a material adverse effect on their financial condition, results of operations or cash flows.

Other Proceedings

The Registrants are involved in other legal, environmental, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business. From time to time, the Registrants are also defendants in legal proceedings with respect to claims brought by various plaintiffs against broad groups of participants in the energy industry. Some of these proceedings involve substantial amounts. The Registrants regularly analyze current information and, as necessary, provide accruals for probable and reasonably estimable liabilities on the eventual disposition of these matters. The Registrants do not expect the disposition of these matters to have a material adverse effect on the Registrants’ financial condition, results of operations or cash flows.

(15) Earnings Per Share (CenterPoint Energy)

The following table reconciles numerators and denominators of CenterPoint Energy’s basic and diluted earnings per common share. Basic earnings per common share is determined by dividing Income available to common shareholders - basic by the Weighted average common shares outstanding - basic for the applicable period. Diluted earnings per common share is determined by the inclusion of potentially dilutive common stock equivalent shares that may occur if securities to issue Common Stock were exercised or converted into Common Stock.


	Three Months Ended June 30,					Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018			2019		2018		2019		2018		2019		2018
	(in millions, except share and per share amounts)									(in millions, except share and per share amounts)
Numerator:
Income (loss) available to common shareholders - basic	$	165	$	(75	)	$	305	$	90
Income available to common shareholders - basic										$	241	$	153	$	546	$	243
Add back: Series B Preferred Stock dividend	—		—			—		—		—		—		—		—
Income (loss) available to common shareholders - diluted	$	165	$	(75	)	$	305	$	90
Income available to common shareholders - diluted										$	241	$	153	$	546	$	243

Denominator:
Weighted average common shares outstanding - basic	502,200,000		431,523,000			501,862,000		431,378,000		502,228,000		431,554,000		501,986,000		431,437,000
Plus: Incremental shares from assumed conversions:
Restricted stock ~~(1)~~	2,631,000		—			2,631,000		3,029,000		2,852,000		3,337,000		2,852,000		3,337,000
Series B Preferred Stock ~~(2)~~(1)	—		—			—		—		—		—		—		—
Weighted average common shares outstanding - diluted	504,831,000		431,523,000			504,493,000		434,407,000		505,080,000		434,891,000		504,838,000		434,774,000

Earnings per common share:
Basic earnings (loss) per common share	$	0.33	$	(0.17	)	$	0.61	$	0.21
Diluted earnings (loss) per common share	$	0.33	$	(0.17	)	$	0.61	$	0.21
Basic earnings per common share										$	0.48	$	0.35	$	1.09	$	0.56
Diluted earnings per common share										$	0.47	$	0.35	$	1.08	$	0.56

(1)

The potentially dilutive impact from restricted stock awards applies the treasury stock method. Under this method, an increase in the average fair market value of Common Stock can result in a greater dilutive impact from these securities. 3,029,000 incremental shares from assumed conversions of restricted stock have not been included in the computation of diluted earnings (loss) per share for the three months ended June 30, 2018, as their inclusion would be anti-dilutive.

~~(2)~~

The potentially dilutive impact from Series B Preferred Stock applies the if-converted method in calculating diluted earnings per common share. Under this method, diluted earnings per common share is adjusted for the more dilutive effect of the Series B Preferred Stock as a result of either its accumulated dividend for the period in the numerator or the assumed-converted common share equivalent in the denominator. The computation of diluted earnings per common share outstanding for the three and ~~six~~nine months ended ~~June~~September 30, 2019 excludes ~~32,121,000~~Series B Preferred Stock dividends of $17 million and ~~32,121,000~~$51 million, respectively, and 33,537,000 and 33,537,000 potentially dilutive shares, respectively, because to include them would be anti-dilutive. However, these ~~shares~~ could be potentially dilutive in the future.

(16) Reportable Segments

The Registrants’ determination of reportable segments considers the strategic operating units under which the Registrants manage sales, allocate resources and assess performance of various products and services to wholesale or retail customers in differing regulatory environments. The Registrants use operating income as the measure of profit or loss for the reportable segments other than Midstream Investments, where equity in earnings is used.

As of ~~June~~September 30, 2019, reportable segments by Registrant were as follows:

Registrants

Houston Electric T&D

Indiana Electric Integrated

Natural Gas Distribution

Energy

Services

Infrastructure Services

Midstream Investments

Corporate and Other

CenterPoint Energy

Houston Electric

CERC

The Houston Electric T&D reportable segment consists of electric transmission and distribution services in the Texas Gulf Coast area.

The Indiana Electric Integrated reportable segment consists of electric transmission and distribution services primarily to southwestern Indiana and includes power generation and wholesale power operations.

CenterPoint Energy’s Natural Gas Distribution reportable segment consists of intrastate natural gas sales to, and natural gas transportation and distribution for residential, commercial, industrial and institutional customers in Arkansas, Indiana, Louisiana, Minnesota, Mississippi, Ohio, Oklahoma and Texas.

CERC’s Natural Gas Distribution reportable segment consists of intrastate natural gas sales to, and natural gas transportation and distribution for residential, commercial, industrial and institutional customers in Arkansas, Louisiana, Minnesota, Mississippi, Oklahoma and Texas.

•The Energy Services reportable segment consists of non-rate regulated natural gas sales and services operations.

•The Infrastructure Services reportable segment consists of underground pipeline construction and repair services.

The Midstream Investments reportable segment consists of the equity investment in Enable (excluding the Enable Series A Preferred Units).

CenterPoint Energy’s Corporate and Other reportable segment consists of energy performance contracting and sustainable infrastructure services through ESG and other corporate operations which support all of the business operations of CenterPoint Energy.

CERC’s Corporate and Other reportable segment consists primarily of corporate operations which support all of the business operations of CERC.

Financial data for reportable segments is as follows:

CenterPoint Energy


	Three Months Ended June 30,																		Three Months Ended September 30,
	2019									2018									2019								2018
	Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers			Net Intersegment Revenues			Operating Income			Revenues from External Customers			Net Intersegment Revenues			Operating Income		Revenues from External Customers			Net Intersegment Revenues			Operating Income
	(in millions)																		(in millions)
Houston Electric T&D	$	765	(1)	$	—		$	169		$	854	(1)	$	—		$	181		$	859	(1)	$	—		$	269	$	897	(1)	$	—		$	227
Indiana Electric Integrated	140			—			25			—			—			—			165			—			48		—			—			—
Natural Gas Distribution	650			10			47			487			8			7			515			9			27		402			8			3
Energy Services	838			17			29			841			19			15			734			11			2		910			10			(9		)
Infrastructure Services	325			1			24			—			—			—			376			1			42		—			—			—
Midstream Investments (2)	—			—			—			—			—			—			—			—			—		—			—			—
Corporate and Other	80			—			(7		)	4			—			(16		)	93			—			4		3			—			5
Eliminations	—			(28		)	—			—			(27		)	—			—			(21		)	—		—			(18		)	—
Consolidated	$	2,798		$	—		$	287		$	2,186		$	—		$	187		$	2,742		$	—		$	392	$	2,212		$	—		$	226


	Six Months Ended June 30,																		Nine Months Ended September 30,
	2019									2018									2019									2018
	Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers			Net Intersegment Revenues			Operating Income (Loss)
	(in millions)																		(in millions)
Houston Electric T&D	$	1,454	(1)	$	—		$	253		$	1,605	(1)	$	—		$	296		$	2,313	(1)	$	—		$	522		$	2,502	(1)	$	—		$	523
Indiana Electric Integrated	223			—			16			—			—			—			388			—			64			—			—			—
Natural Gas Distribution	2,039			20			214			1,630			18			163			2,554			29			241			2,032			26			166
Energy Services	2,020			81			62			2,098			47			(11		)	2,754			92			64			3,008			57			(20		)
Infrastructure Services	471			1			8			—			—			—			847			2			50			—			—			—
Midstream Investments (2)	—			—			—			—			—			—			—			—			—			—			—			—
Corporate and Other	122			—			(21		)	8			—			(10		)	215			—			(17		)	11			—			(5		)
Eliminations	—			(102		)	—			—			(65		)	—			—			(123		)	—			—			(83		)	—
Consolidated	$	6,329		$	—		$	532		$	5,341		$	—		$	438		$	9,071		$	—		$	924		$	7,553		$	—		$	664


(1)	Houston Electric T&D revenues from major external customers are as follows:


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018		2019		2018
	(in millions)								(in millions)
Affiliates of NRG	$	165	$	169	$	316	$	330	$	231	$	213	$	547	$	543
Affiliates of Vistra Energy Corp.	59		59		113		113		83		79		196		192


(2)	CenterPoint Energy’s Midstream Investments’ equity in earnings, net are as follows:

Three Months Ended June 30, Six Months Ended June 30,
2019 2018 2019 2018
(in millions)
Enable $ 74
$ 58
$ 136
$ 127



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Enable	$	77	$	81	$	213	$	208

Houston Electric

Houston Electric consists of a single reportable segment; therefore, a tabular reportable segment presentation has not been

included.


(1)	Houston Electric T&D revenues from major external customers are as follows:


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018		2019		2018
	(in millions)								(in millions)
Affiliates of NRG	$	165	$	169	$	316	$	330	$	231	$	213	$	547	$	543
Affiliates of Vistra Energy Corp.	59		59		113		113		83		79		196		192

CERC


	Three Months Ended June 30,														Three Months Ended September 30,
	2019							2018							2019							2018
	Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)		Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)		Revenues from External Customers		Net Intersegment Revenues			Operating Income		Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)
	(in millions)														(in millions)
Natural Gas Distribution	$	503	$	10		$	28	$	487	$	8		$	7	$	389	$	9		$	20	$	402	$	8		$	3
Energy Services	839		16			29		841		19			15		734		11			2		910		10			(9		)
Other Operations	—		—			1		—		—			—		3		—			1		—		—			(1		)
Eliminations	—		(26		)	—		—		(27		)	—		—		(20		)	—		—		(18		)	—
Consolidated	$	1,342	$	—		$	58	$	1,328	$	—		$	22	$	1,126	$	—		$	23	$	1,312	$	—		$	(7	)


	Six Months Ended June 30,															Nine Months Ended September 30,
	2019							2018								2019							2018
	Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)		Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)			Revenues from External Customers		Net Intersegment Revenues			Operating Income		Revenues from External Customers		Net Intersegment Revenues			Operating Income (Loss)
	(in millions)															(in millions)
Natural Gas Distribution	$	1,688	$	20		$	192	$	1,630	$	18		$	163		$	2,077	$	29		$	212	$	2,032	$	26		$	166
Energy Services	2,021		80			62		2,098		47			(11		)	2,755		91			64		3,008		57			(20		)
Corporate and Other	1		—			—		—		—			1			4		—			1		—		—			—
Eliminations	—		(100		)	—		—		(65		)	—			—		(120		)	—		—		(83		)	—
Consolidated	$	3,710	$	—		$	254	$	3,728	$	—		$	153		$	4,836	$	—		$	277	$	5,040	$	—		$	146

CenterPoint Energy and CERC


	Total Assets														Total Assets
	June 30, 2019							December 31, 2018							September 30, 2019								December 31, 2018
	CenterPoint Energy				CERC			CenterPoint Energy				CERC			CenterPoint Energy				CERC				CenterPoint Energy				CERC
	(in millions)														(in millions)
Houston Electric T&D	$	11,478			$	—		$	10,509			$	—		$	11,463			$	—			$	10,509			$	—
Indiana Electric Integrated (1)	2,989				—			—				—			3,009				—				—				—
Natural Gas Distribution (1)	12,946				6,843			6,956				6,956			13,235				7,018				6,956				6,956
Energy Services	1,262				1,262			1,558				1,558			1,264				1,264				1,558				1,558
Infrastructure Services (1)	1,303				—			—				—			1,284				—				—				—
Midstream Investments	2,915				—			2,482				—			2,529				—				2,482				—
Corporate and Other (1)	4,278			(2)	108			6,156			(2)	66			4,884			(2)	121				6,156			(2)	66
Eliminations	(2,982		)		(398		)	(652		)		(366		)	(3,026		)		(474		)		(652		)		(366		)
Consolidated	$	34,189			$	7,815		$	27,009			$	8,214		$	34,642			$	7,929		��	$	27,009			$	8,214


(1)	Total assets by reportable segment include assets acquired in the Merger, which are based on preliminary fair value estimates and allocations on the acquisition date and are subject to change. See Note 3.


(2)	Includes pension and other postemployment-related regulatory assets of ~~$639~~$625 million and $665 million, respectively, as of ~~June~~September 30, 2019 and December 31, 2018. Additionally, total assets as of December 31, 2018 included $3.9 billion of temporary investments included in Cash and cash equivalents on CenterPoint Energy’s Consolidated Balance Sheets.

(17) Supplemental Disclosure of Cash Flow Information

The table below provides supplemental disclosure of cash flow information:


	Six Months Ended June 30,												Nine Months Ended September 30,
	2019						2018						2019						2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)												(in millions)
Cash Payments/Receipts:
Interest, net of capitalized interest	$	231	$	113	$	55	$	167	$	90	$	50	$	364	$	203	$	88	$	301	$	173	$	85
Income taxes (refunds), net	142		73		3		88		120		3
Income taxes, net													174		93		3		89		122		3
Non-cash transactions:
Accounts payable related to capital expenditures	173		86		72		133		75		69		178		91		75		140		87		66
Capital distribution associated with the Internal Spin													—		—		—		—		—		1,460
ROU assets obtained in exchange for lease liabilities (1)	42		1		28		—		—		—		43		1		28		—		—		—


(1)	Includes the transition impact of adoption of ASU 2016-02 Leases.

The table below provides a reconciliation of cash, cash equivalents and restricted cash reported in the Condensed Consolidated Balance Sheets to the amount reported in the Condensed Statements of Consolidated Cash Flows:


	June 30, 2019						December 31, 2018						September 30, 2019						December 31, 2018
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)												(in millions)
Cash and cash equivalents	$	271	$	260	$	1	$	4,231	$	335	$	14	$	259	$	228	$	2	$	4,231	$	335	$	14
Restricted cash included in Prepaid expenses and other current assets	61		33		4		46		34		11		38		19		—		46		34		11
Restricted cash included in Other	—		—		—		1		1		—		—		—		—		1		1		—
Total cash, cash equivalents and restricted cash shown in Condensed Statements of Consolidated Cash Flows	$	332	$	293	$	5	$	4,278	$	370	$	25	$	297	$	247	$	2	$	4,278	$	370	$	25

(18) Related Party Transactions (Houston Electric and CERC)

Houston Electric and CERC participate in a money pool through which they can borrow or invest on a short-term basis. Funding needs are aggregated and external borrowing or investing is based on the net cash position. The net funding requirements of the money pool are expected to be met with borrowings under CenterPoint Energy’s revolving credit facility or the sale of CenterPoint Energy’s commercial paper.

The table below summarizes money pool activity:


	June 30, 2019						December 31, 2018						September 30, 2019						December 31, 2018
	Houston Electric			CERC			Houston Electric			CERC			Houston Electric			CERC			Houston Electric			CERC
	(in millions)												(in millions, except interest rates)
Money pool investments (borrowings) (1)	$	794		$	180		$	(1	)	$	114		$	772		$	87		$	(1	)	$	114
Weighted average interest rate	2.67		%	2.67		%	2.42		%	2.42		%	2.32		%	2.32		%	2.42		%	2.42		%


(1)	Included in Accounts and notes receivable (payable)–affiliated companies on Houston Electric’s and CERC’s respective Condensed Consolidated Balance Sheets.

Houston Electric and CERC affiliate related net interest income (expense) were as follows:

Three Months Ended June 30, Six Months Ended June 30,
2019 2018 2019 2018
Houston Electric CERC Houston Electric CERC Houston Electric CERC Houston Electric CERC
(in millions)
Interest income (expense) (1) $ 6
$ 1
$ —
$ —
$ 9
$ 2
$ —
$ (2 )



	Three Months Ended September 30,									Nine Months Ended September 30,
	2019				2018					2019				2018
	Houston Electric		CERC		Houston Electric		CERC			Houston Electric		CERC		Houston Electric		CERC
	(in millions)
Interest income (expense) (1)	$	5	$	1	$	1	$	(2	)	$	14	$	3	$	1	$	(4	)


(1)	Interest income is included in Other income (expense), net and interest expense is included in Interest and other finance charges on Houston Electric’s and CERC’s respective Condensed Statements of Consolidated Income.

CenterPoint Energy provides some corporate services to Houston Electric and CERC. The costs of services have been charged directly to Houston Electric and CERC using methods that management believes are reasonable. These methods include negotiated usage rates, dedicated asset assignment and proportionate corporate formulas based on operating expenses, assets, gross margin, employees and a composite of assets, gross margin and employees. Houston Electric provides certain services to CERC. These services are billed at actual cost, either directly or as an allocation and include fleet services, shop services, geographic services, surveying and right-of-way services, radio communications, data circuit management and field operations. Additionally, CERC provides certain services to Houston Electric. These services are billed at actual cost, either directly or as an allocation and include line locating and other miscellaneous services. These charges are not necessarily indicative of what would have been incurred had Houston Electric and CERC not been affiliates.

Amounts charged for these services were as follows and are included primarily in operation and maintenance expenses:


	Three Months Ended June 30,										Six Months Ended June 30,										Three Months Ended September 30,										Nine Months Ended September 30,
	2019					2018					2019					2018					2019					2018					2019					2018
	Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC		Houston Electric			CERC
	(in millions)																				(in millions)
Corporate service charges	$	42		$	32	$	47		$	35	$	94		$	75	$	91		$	69	$	38		$	31	$	47		$	36	$	132		$	106	$	138		$	105
Net affiliate service charges (billings)	(2		)	2		(3		)	3		(4		)	4		(5		)	5		(3		)	3		(3		)	3		(7		)	7		(8		)	8

Infrastructure Services provides pipeline construction and repair services to CERC. Amounts charged for operation and maintenance expenses by Infrastructure Services to CERC were not significant from February 1, 2019 to ~~June~~September 30, 2019. Additionally, CERC, through CES, sells natural gas to Indiana Electric for use in electric generation activities. Amounts charged by CERC to Indiana Electric were not significant from February 1, 2019 to ~~June~~September 30, 2019.

The table below presents transactions among Houston Electric, CERC and their parent, Utility Holding.


	Three Months Ended June 30,								Six Months Ended June 30,								Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018				2019				2018				2019				2018
	Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC		Houston Electric		CERC
	(in millions)																(in millions)
Cash dividends paid to parent	$	16	$	83	$	31	$	125	$	40	$	103	$	63	$	211	$	60	$	16	$	60	$	75	$	100	$	119	$	123	$	286
Cash contribution from parent	—		—		—		—		590		—		—		—		—		—		—		600		590		—		—		600
Capital distribution to parent associated with the Internal Spin																	—		—		—		1,460		—		—		—		1,460

(19) Leases

The Registrants adopted ASC 842, Leases, and all related amendments on January 1, 2019 using the modified retrospective transition method and elected not to recast comparative periods in the year of adoption as permitted by the standard. There was no adjustment to retained earnings as a result of transition. As a result, disclosures for periods prior to adoption will be presented in accordance with accounting standards in effect for those periods. The Registrants also elected the package of practical expedients permitted under the transition guidance within the new standard, which among other things, allowed them to carry forward the historical lease classification. Additionally, the Registrants elected the practical expedient related to land easements, which allows the carry forward of the accounting treatment for land easements on existing agreements. The total ROU assets obtained in exchange for new operating lease liabilities ~~at transition~~upon adoption were $30 million, $1 million and $27 million for CenterPoint Energy, Houston

Electric and CERC, respectively. The Merger was completed on February 1, 2019, and as such the amounts recorded upon adoption are exclusive of Vectren’s leases.

An arrangement is determined to be a lease at inception based on whether the Registrant has the right to control the use of an identified asset. ROU assets represent the Registrants’ right to use the underlying asset for the lease term and lease liabilities represent the Registrants’ obligation to make lease payments arising from the lease. ROU assets and liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term, including payments at commencement that depend on an index or rate. Most leases in which the Registrants are the lessee do not have a readily determinable implicit rate, so an incremental borrowing rate, based on the information available at the lease commencement date, is utilized to determine the present value of lease payments. When a secured borrowing rate is not readily available, unsecured borrowing rates are adjusted for the effects of collateral to determine the incremental borrowing rate. Each Registrant uses the implicit rate for agreements in which it is a lessor. Lease expense and lease income are recognized on a straight-line basis over the lease term for operating leases.

The Registrants have lease agreements with lease and non-lease components and have elected the practical expedient to combine lease and non-lease components for certain classes of leases, such as office buildings. For classes of leases in which lease and non-lease components are not combined, consideration is allocated between components based on the stand-alone prices. Variable payments are not significant to the Registrants.

The Registrants’ lease agreements do not contain any material residual value guarantees, material restrictions or material covenants. There are no material lease transactions with related parties. Agreements in which the Registrants are lessors do not include provisions for the lessee to purchase the assets. Because risk is minimal, the Registrants do not take any significant actions to manage risk associated with the residual value of their leased assets.

The Registrants’ lease agreements are primarily equipment and real property leases, including land and office facility leases. The Registrants’ lease terms may include options to extend or terminate a lease when it is reasonably certain that those options will be exercised. Operating lease payments exclude approximately $16 million of legally-binding undiscounted minimum lease payments for leases signed but not yet commenced. The Registrants have elected an accounting policy that exempts leases with terms of one year or less from the recognition requirements of ASU 842.

The components of lease cost, included in Operation and maintenance expense on the Registrants’ respective Condensed Statements of Consolidated Income, are as follows:


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019						2019						2019						2019
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)												(in millions)
Operating lease cost	$	7	$	—	$	2	$	11	$	—	$	3	$	8	$	—	$	1	$	19	$	—	$	4
Short-term lease cost	18		3		—		23		5		—		23		7		—		46		12		—
Variable lease cost													1		—		—		1		—		—
Total lease cost	$	25	$	3	$	2	$	34	$	5	$	3	$	32	$	7	$	1	$	66	$	12	$	4

Supplemental balance sheet information related to leases was as follows:


	June 30, 2019									September 30, 2019
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions, except lease term and discount rate)									(in millions, except lease term and discount rate)
Assets:
Operating ROU assets (1)	$	72		$	1		$	26		$	67		$	1		$	25
Total leased assets	$	72		$	1		$	26		$	67		$	1		$	25
Liabilities:
Current operating lease liability (2)	$	22		$	—		$	5		$	21		$	—		$	4
Non-current operating lease liability (3)	50			1			21			46			1			21
Total leased liabilities	$	72		$	1		$	26		$	67		$	1		$	25

Weighted-average remaining lease term (in years) - operating leases	5.2			5.5			8.1			5.2			5.4			7.9
Weighted-average discount rate - operating leases	3.41		%	3.51		%	3.67		%	3.41		%	3.51		%	3.66		%


(1)	Reported within Other assets in the Condensed Consolidated Balance Sheets.


(2)	Reported within Current other liabilities in the Condensed Consolidated Balance Sheets.


(3)	Reported within Other liabilities in the Condensed Consolidated Balance Sheets.

As of ~~June~~September 30, 2019, maturities of operating lease liabilities were as follows:


	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)						(in millions)
Remaining six months of 2019	$	14	$	—	$	3
Remaining three months of 2019							$	6	$	—	$	1
2020	21		1		5		22		1		5
2021	15		—		4		15		—		5
2022	8		—		4		9		—		4
2023	7		—		3		7		—		3
2024	3		—		2		3		—		2
2025 and beyond	12		—		9		12		—		9
Total lease payments	80		1		30		74		1		29
Less: Interest	8		—		4		7		—		4
Present value of lease liabilities	$	72	$	1	$	26	$	67	$	1	$	25

The following table sets forth information concerning the Registrants’ obligations under non-cancelable long-term operating leases as of December 31, 2018:



	CenterPoint Energy		Houston Electric		CERC
	(in millions)
2019	$	6	$	1	$	5
2020	6		—		5
2021	5		—		4
2022	4		—		4
2023	3		—		3
2024 and beyond	12		—		11
Total (1)	$	36	$	1	$	32


(1)	The Merger was completed on February 1, 2019. As such, these amounts are exclusive of Vectren’s leases.

As of ~~June~~September 30, 2019, maturities of undiscounted operating lease payments to be received are as follows:


	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)						(in millions)
Remaining six months of 2019	$	2	$	—	$	—
Remaining three months of 2019							$	1	$	—	$	—
2020	2		1		—		2		1		—
2021	2		—		—		2		—		—
2022	2		—		—		2		—		—
2023	2		—		—		2		—		—
2024	2		—		—		2		—		—
2025 and beyond	10		—		—		10		—		—
Total lease payments to be received	$	22	$	1	$	—	$	21	$	1	$	—

Other information related to leases is as follows:

Three Months Ended June 30, Six Months Ended June 30,
2019 2019
CenterPoint Energy Houston Electric CERC CenterPoint Energy Houston Electric CERC
(in millions)
Operating cash flows from operating leases included in the measurement of lease liabilities $ 7
$ —
$ 1
$ 12
$ 1
$ 2



	Three Months Ended September 30,						Nine Months Ended September 30,
	2019						2019
	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)
Operating cash flows from operating leases included in the measurement of lease liabilities	$	6	$	—	$	2	$	18	$	1	$	4

(20) Equity

Dividends Declared and Paid (CenterPoint Energy)

CenterPoint Energy paid dividends on its Common Stock during the ~~six~~nine months ended ~~June~~September 30, 2019 and 2018 as presented in the table below:


Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)		Record Date	Payment Date	Per Share		Total (in millions)
December 12, 2018	February 21, 2019	March 14, 2019	$	0.2875	$	144	February 21, 2019	March 14, 2019	$	0.2875	$	144
April 25, 2019	May 16, 2019	June 13, 2019	0.2875		144		May 16, 2019	June 13, 2019	0.2875		144
July 31, 2019							August 15, 2019	September 12, 2019	0.2875		145
Total 2019			$	0.5750	$	288			$	0.8625	$	433

December 13, 2017	February 15, 2018	March 8, 2018	$	0.2775	$	120	February 15, 2018	March 8, 2018	$	0.2775	$	120
April 26, 2018	May 17, 2018	June 14, 2018	0.2775		120		May 17, 2018	June 14, 2018	0.2775		120
July 26, 2018							August 16, 2018	September 13, 2018	0.2775		120
Total 2018			$	0.5550	$	240			$	0.8325	$	360

CenterPoint Energy declared no dividends on its Series A Preferred Stock or Series B Preferred Stock during the three or ~~six~~nine months ended ~~June~~September 30, 2018.

CenterPoint Energy paid dividends on its Series A Preferred Stock during the ~~six~~nine months ended ~~June~~September 30, 2019 as presented in the table below:


Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)		Record Date	Payment Date	Per Share		Total (in millions)
December 12, 2018	February 15, 2019	March 1, 2019	$	32.1563	$	26	February 15, 2019	March 1, 2019	$	32.1563	$	26
July 31, 2019							August 15, 2019	September 3, 2019	30.6250		24
Total 2019			$	32.1563	$	26			$	62.7813	$	50

CenterPoint Energy paid dividends on its Series B Preferred Stock during the ~~six~~nine months ended ~~June~~September 30, 2019 as presented in the table below:


Declaration Date	Record Date	Payment Date	Per Share		Total (in millions)		Record Date	Payment Date	Per Share		Total (in millions)
December 12, 2018	February 15, 2019	March 1, 2019	$	17.5000	$	17	February 15, 2019	March 1, 2019	$	17.5000	$	17
April 25, 2019	May 15, 2019	June 3, 2019	17.5000		17		May 15, 2019	June 3, 2019	17.5000		17
July 31, 2019							August 15, 2019	September 3, 2019	17.5000		17
Total 2019			$	35.0000	$	34			$	52.5000	$	51

Dividend Requirement on Preferred Stock (CenterPoint Energy)


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018		2019		2018
	(in millions)								(in millions)
Series A Preferred Stock	$	13	$	—	$	25	$	—	$	12	$	5	$	37	$	5
Series B Preferred Stock	17		—		34		—		17		—		51		—
Total preferred stock dividend requirement	$	30	$	—	$	59	$	—	$	29	$	5	$	88	$	5

Accumulated Other Comprehensive Income (Loss)

Changes in accumulated comprehensive income (loss) are as follows:


	Three Months Ended June 30,																Three Months Ended September 30,
	2019								2018								2019								2018
	CenterPoint Energy			Houston Electric			CERC		CenterPoint Energy			Houston Electric			CERC		CenterPoint Energy			Houston Electric			CERC		CenterPoint Energy			Houston Electric		CERC
	(in millions)																(in millions)
Beginning Balance	$	(107	)	$	(15	)	$	5	$	(63	)	$	4		$	6	$	(105	)	$	(15	)	$	5	$	(62	)	$	4	$	6
Other comprehensive income (loss) before reclassifications:
Deferred gain (loss) from interest rate derivatives (1)	—			—			—		(1		)	—			—		(2		)	—			—		4			3		—
Other comprehensive loss from unconsolidated affiliates																	(2		)	—			—		—			—		—
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (2)	1			—			—		1			—			—
Actuarial losses (2)	2			—			—		1			—			—		2			—			—		2			—		—
Tax expense	(1		)	—			—		—			—			—		—			—			—		(2		)	—		—
Net current period other comprehensive income	2			—			—		1			—			—		(2		)	—			—		4			3		—
Ending Balance	$	(105	)	$	(15	)	$	5	$	(62	)	$	4		$	6	$	(107	)	$	(15	)	$	5	$	(58	)	$	7	$	6

	Six Months Ended June 30,
	2019								2018
	CenterPoint Energy			Houston Electric			CERC		CenterPoint Energy			Houston Electric			CERC
	(in millions)
Beginning Balance	$	(108	)	$	(14	)	$	5	$	(68	)	$	—		$	6
Other comprehensive income (loss) before reclassifications:
Deferred gain (loss) from interest rate derivatives (1)	(1		)	(1		)	—		4			5			—
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (2)	1			—			—		1			—			—
Actuarial losses (2)	4			—			—		3			—			—
Reclassification of deferred loss from cash flow hedges realized in net income	1			—			—		—			—			—
Tax expense	(2		)	—			—		(2		)	(1		)	—
Net current period other comprehensive income (loss)	3			(1		)	—		6			4			—
Ending Balance	$	(105	)	$	(15	)	$	5	$	(62	)	$	4		$	6



	Nine Months Ended September 30,
	2019								2018
	CenterPoint Energy			Houston Electric			CERC		CenterPoint Energy			Houston Electric			CERC
	(in millions)
Beginning Balance	$	(108	)	$	(14	)	$	5	$	(68	)	$	—		$	6
Other comprehensive income (loss) before reclassifications:
Deferred gain (loss) from interest rate derivatives (1)	(3		)	(1		)	—		8			8			—
Other comprehensive loss from unconsolidated affiliates	(2		)	—			—		—			—			—
Amounts reclassified from accumulated other comprehensive loss:
Prior service cost (2)	1			—			—		1			—			—
Actuarial losses (2)	6						—		5			—			—
Reclassification of deferred loss from cash flow hedges realized in net income	1			—			—		—			—			—
Tax expense	(2		)	—			—		(4		)	(1		)	—
Net current period other comprehensive income (loss)	1			(1		)	—		10			7			—
Ending Balance	$	(107	)	$	(15	)	$	5	$	(58	)	$	7		$	6

(1)

Gains and losses are reclassified from Accumulated other comprehensive income into income when the hedged transactions affect earnings. The reclassification amounts are included in Interest and other finance charges in each of the Registrants’ respective Statements of Consolidated Income. Over the next twelve months estimated amortization from Accumulated Comprehensive Income into income is expected to be immaterial.


(2)	Amounts are included in the computation of net periodic cost and are reflected in Other income (expense), net in each of the Registrants’ respective Statements of Consolidated Income.

(21) Subsequent Events (CenterPoint Energy)

CenterPoint Energy Dividend Declarations

Equity Instrument

Declaration Date

Record Date

Payment Date

Per Share

Declaration Date

Record Date

Payment Date

Per Share

Common Stock

July 31, 2019

August 15, 2019

September 12, 2019

0.2875

October 17, 2019

November 21, 2019

December 12, 2019

0.2875

Series A Preferred Stock

July 31, 2019

August 15, 2019

September 3, 2019

30.6250

Series B Preferred Stock

July 31, 2019

August 15, 2019

September 3, 2019

17.5000

October 17, 2019

November 15, 2019

December 2, 2019

17.5000

Enable Distributions Declarations (CenterPoint Energy)

Equity Instrument

Declaration Date

Record Date

Payment Date

Per Unit Distribution

Expected Cash Distribution

(in millions)

Declaration Date

Record Date

Payment Date

Per Unit Distribution

Expected Cash Distribution

(in millions)

Enable common units

August 2, 2019

August 20, 2019

August 27, 2019

0.3305

November 5, 2019

November 19, 2019

November 26, 2019

0.3305

Enable Series A Preferred Units

August 2, 2019

August 14, 2019

0.6250

November 5, 2019

November 14, 2019

0.6250


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

No Registrant makes any representations as to the information related solely to CenterPoint Energy or the subsidiaries of CenterPoint Energy other than itself.

The following combined discussion and analysis should be read in combination with the Interim Condensed Financial Statements contained in this Form 10-Q and the Registrants’ combined 2018 Form 10-K. When discussing CenterPoint Energy’s consolidated financial information, it includes the results of Houston Electric and CERC, which, along with CenterPoint Energy, are collectively referred to as the Registrants. Where appropriate, information relating to a specific Registrant has been segregated and labeled as such. In this Form 10-Q, the terms “our,” “we” and “us” are used as abbreviated references to CenterPoint Energy, Inc. together with its consolidated subsidiaries.

RECENT EVENTS

Merger with Vectren. On February 1, 2019, pursuant to the Merger Agreement, CenterPoint Energy consummated the previously announced Merger and acquired Vectren for approximately $6 billion in cash. For more information about the Merger, see Notes 1 and 3 to the Interim Condensed Financial Statements. Concurrent with the completion of the Merger, CenterPoint Energy added two new reportable segments, Indiana Electric Integrated and Infrastructure Services, to its five reportable segments disclosed in CenterPoint Energy’s 2018 Form 10-K. For a description of the Registrants’ reportable segments, see Note 16 to the Interim Condensed Financial Statements.

Debt Transactions. In January 2019, Houston Electric issued $700 million aggregate principal amount of general mortgage bonds, ~~and~~ in May 2019, CenterPoint Energy entered into a $1.0 billion variable rate term ~~loan.~~loan and in August 2019, CenterPoint Energy issued $1.2 billion aggregate principal amount of senior notes. For more information about the 2019 debt transactions, see Note 12 to the Interim Condensed Financial Statements.

Regulatory Proceedings. On April 5, 2019, and subsequently adjusted in errata filings in May and June 2019, Houston Electric filed its base rate application with the PUCT and the cities in its service area to change its rates. For details related to our pending and completed regulatory proceedings and orders related to the TCJA to date in 2019, see “—Liquidity and Capital Resources —Regulatory Matters” below.

CENTERPOINT ENERGY CONSOLIDATED RESULTS OF OPERATIONS

For information regarding factors that may affect the future results of our consolidated operations, please read “Risk Factors” in Item 1A of Part I of the Registrants’ combined 2018 Form ~~10-K.~~10-K and in Item 1A of Part II of this Form 10-Q.


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
	(in millions, except per share amounts)												(in millions, except per share amounts)
Revenues	$	2,798		$	2,186		$	6,329		$	5,341		$	2,742		$	2,212		$	9,071		$	7,553
Expenses	2,511			1,999			5,797			4,903			2,350			1,986			8,147			6,889
Operating Income	287			187			532			438			392			226			924			664
Interest and Other Finance Charges	(134		)	(91		)	(255		)	(169		)	(134		)	(90		)	(389		)	(259		)
Interest on Securitization Bonds	(10		)	(14		)	(22		)	(30		)	(9		)	(16		)	(31		)	(46		)
Equity in Earnings of Unconsolidated Affiliate, net	74			58			136			127			77			81			213			208
Other Income (Expense), net	7			(228		)	24			(242		)	6			8			30			(234		)
Income (Loss) Before Income Taxes	224			(88		)	415			124
Income Tax Expense (Benefit)	29			(13		)	51			34
Net Income (Loss)	195			(75		)	364			90
Income Before Income Taxes													332			209			747			333
Income Tax Expense													62			51			113			85
Net Income													270			158			634			248
Preferred Stock Dividend Requirement	30			—			59			—			29			5			88			5
Income (Loss) Available to Common Shareholders	$	165		$	(75	)	$	305		$	90
Basic Earnings (Loss) Per Common Share	$	0.33		$	(0.17	)	$	0.61		$	0.21
Diluted Earnings (Loss) Per Common Share	$	0.33		$	(0.17	)	$	0.61		$	0.21
Income Available to Common Shareholders													$	241		$	153		$	546		$	243
Basic Earnings Per Common Share													$	0.48		$	0.35		$	1.09		$	0.56
Diluted Earnings Per Common Share													$	0.47		$	0.35		$	1.08		$	0.56

Three months ended ~~June~~September 30, 2019 compared to three months ended ~~June~~September 30, 2018

CenterPoint Energy reported income available to common shareholders of ~~$165~~$241 million ($~~0.33~~0.47 per diluted common share) for the three months ended ~~June~~September 30, 2019 compared to ~~a net loss of $75~~$153 million ($~~(0.17)~~0.35 per diluted common share) for the three months ended ~~June~~September 30, 2018.

The increase in income available to common shareholders of ~~$240~~$88 million was primarily due to the following key factors:

a $186 million decrease in losses on the underlying value of the indexed debt securities related to the ZENS, included in Other Income (Expense), net shown above (losses recorded from AT&T Inc.’s acquisition of Time Warner Inc. in June 2018);

~~a $100~~$166 million increase in operating income discussed below in Results of Operations by Reportable Segment;

a ~~$42~~$16 million increase in gain on marketable securities, included in Other Income (Expense), net shown above;

~~a $16 million increase in equity earnings from the investment in Enable, discussed further in Note 9 to the Interim Condensed Financial Statements;~~ and

a $7 ~~million increase in miscellaneous other non-operating income, included in Other Income (Expense), net shown above; and~~

~~a $4~~ million decrease in interest expense related to lower outstanding balances of the Securitization Bonds.

These increases were partially offset by the following:

a ~~$43~~$44 million increase in interest expense, primarily as a result of higher outstanding ~~other~~ long-term debt used to finance the Merger and additional long-term debt acquired through the Merger, discussed further in Notes 3 and 12 to the Interim Condensed Financial Statements;

a ~~$42~~$24 million increase in preferred stock dividend requirements primarily as a result of the Merger;

an $18 million increase in losses on the underlying value of the indexed debt securities related to the ZENS, included in Other Income (Expense), net shown above;

a $11 million increase in income tax expense due to higher income before income taxes that was partially offset by the lower effective tax rate as explained below; and

a ~~$30~~$4 million ~~increase~~decrease to equity in ~~preferred stock dividend requirements.~~earnings from the investment in Enable, discussed further in Note 9 to the Interim Condensed Financial Statements.

~~Six~~Nine months ended ~~June~~September 30, 2019 compared to ~~six~~nine months ended ~~June~~September 30, 2018

CenterPoint Energy reported income available to common shareholders of ~~$305~~$546 million ($~~0.61~~1.08 per diluted common share) for the ~~six~~nine months ended ~~June~~September 30, 2019 compared to ~~$90~~$243 million ($~~0.21~~0.56 per diluted common share) for the ~~six~~nine months ended ~~June~~September 30, 2018.

The increase of ~~$215~~$303 million in income available to common shareholders was primarily due to the following key factors:

a ~~$124~~$260 million increase in operating income discussed below in Results of Operations by Reportable Segment;

a $140 million increase in gain on marketable securities, included in Other Income (Expense), net shown above;

a ~~$118~~$100 million decrease in losses on the underlying value of indexed debt securities related to the ZENS, included in Other Income (Expense), net shown above (losses recorded from Meredith Corporation’s acquisition of Time Inc. in March 2018 and AT&T Inc.’s acquisition of Time Warner Inc. in June 2018);

a ~~$94 million increase in operating income discussed below in Results of Operations by Reportable Segment;~~

a $24 million increase in other miscellaneous non-operating income included in Other Income (Expense), net shown above that included ~~$14~~$16 million in higher interest income, a $5 million increase in dividend income and $5$3 million in additional income from miscellaneous items;

a $9$15 million decrease in interest expense related to lower outstanding balances of the Securitization Bonds; and

a $5 million increase to equity in ~~equity~~ earnings from the investment in Enable, discussed further in Note 9 to the Interim Condensed Financial ~~Statements; and~~

~~an $8 million decrease in interest expense related to lower outstanding balances of the Securitization Bonds.~~Statements.

These increases were partially offset by the following:

a ~~$86~~$130 million increase in interest expense, primarily as a result of higher outstanding ~~other~~ long-term debt used to finance the Merger and additional long-term debt acquired through the Merger, discussed further in Notes 3 and 12 to the Interim Condensed Financial Statements;

a ~~$59~~$83 million increase in preferred stock dividend ~~requirements;~~requirements primarily as a result of the Merger; and

a ~~$17~~$28 million increase in income tax expense due to higher income before income taxes that was partially offset by the lower effective tax rate as explained below.

Income Tax Expense

CenterPoint Energy’s effective tax rate reported for the three months ended ~~June~~September 30, 2019 was ~~13%~~19% compared to ~~15%~~24% for the three months ended ~~June~~September 30, 2018. CenterPoint Energy’s effective tax rate reported for the ~~six~~nine months ended ~~June~~September 30, 2019 was ~~12%~~15% compared to ~~27%~~26% for the ~~six~~nine months ended ~~June~~September 30, 2018. The lower effective tax rate for the three and ~~six~~nine months ended ~~June~~September 30, 2019 was primarily due to the following: an increase in the amount of amortization of the net regulatory EDIT ~~liability as decreed by regulators in certain jurisdictions;~~liability; the ~~impact~~effect of state tax law changes that resulted in the remeasurement of state deferred taxes; and the ~~release~~impact of changes in valuation allowances on certain state net operating ~~losses that are now expected to be utilized prior to expiration due to a current period law change.~~losses.

HOUSTON ELECTRIC’S MANAGEMENT’S NARRATIVE ANALYSIS

OF CONSOLIDATED RESULTS OF OPERATIONS

Houston Electric’s results of operations are affected by seasonal fluctuations in the demand for electricity. Houston Electric’s results of operations are also affected by, among other things, the actions of various governmental authorities having jurisdiction over rates Houston Electric charges, debt service costs, income tax expense, Houston Electric’s ability to collect receivables from REPs and Houston Electric’s ability to recover its regulatory assets. For more information regarding factors that may affect the future results of operations of Houston Electric’s business, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Electric Generation, Transmission and Distribution Businesses” and “— Other Risk Factors Affecting Our Businesses or CenterPoint Energy’s Interests in Enable Midstream Partners, LP” in Item 1A of Part I of the Registrants’ combined 2018 Form ~~10-K.~~10-K and in Item 1A of Part II of this Form 10-Q.


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
	(in millions)												(in millions)
Revenues (1)	$	765		$	854		$	1,451		$	1,609		$	859		$	897		$	2,310		$	2,506
Expenses	596			673			1,201			1,309			590			670			1,791			1,979
Operating income	169			181			250			300			269			227			519			527
Interest and other finance charges	(42		)	(36		)	(82		)	(69		)	(41		)	(32		)	(123		)	(101		)
Interest on Securitization Bonds	(10		)	(14		)	(22		)	(30		)	(9		)	(16		)	(31		)	(46		)
Other income (expense), net	6			(3		)	10			(6		)	7			—			17			(6		)
Income before income taxes	123			128			156			195			226			179			382			374
Income tax expense	23			27			29			42			41			36			70			78
Net income	$	100		$	101		$	127		$	153		$	185		$	143		$	312		$	296

(1)

Excludes weather hedge gain (loss) of $-0- and ~~$3 million~~$-0- for the three ~~and six~~ months ended ~~June~~September 30, 2019 and 2018, respectively, and ~~$-0-~~$3 million and $(4) million for the ~~three and six~~nine months ended ~~June~~September 30, 2019 and 2018, respectively, recorded in Utility revenues on CenterPoint Energy’s Condensed Statements of Consolidated Income. See Note 7(a) to the Interim Condensed Financial Statements for more information on the weather hedge.

Three months ended ~~June~~September 30, 2019 compared to three months ended ~~June~~September 30, 2018

Houston Electric reported net income of ~~$100~~$185 million for the three months ended ~~June~~September 30, 2019 compared to net income of ~~$101~~$143 million for the three months ended ~~June~~September 30, 2018.

The ~~decrease~~increase of $1$42 million in net income was primarily due to the following key factors:

a $7$47 million ~~decrease~~increase in TDU operating income discussed below in Results of Operations by Reportable Segment;

a $6$7 million decrease in interest expense related to lower outstanding balances of the Securitization Bonds; and

a $7 million increase in Other income (expense), net due to increased interest income primarily from investments in the CenterPoint Energy money pool.

These increases were partially offset by the following:

a $9 million increase in interest expense due to higher outstanding other long-term debt;

a $5 million decrease in operating income from the Bond Companies; and

a $5 million increase of income tax expense due to higher income before income taxes that was partially offset by the lower effective tax rate as explained below.

Nine months ended September 30, 2019 compared to nine months ended September 30, 2018

Houston Electric reported net income of $312 million for the nine months ended September 30, 2019 compared to net income of $296 million for the nine months ended September 30, 2018.

The increase of $16 million in net income was primarily due to the following key factors:

a $23 million increase in Other income (expense), net due to increased interest income of $19 million primarily from investments in the CenterPoint Energy money pool and $4 million from miscellaneous other non-operating income;

a $15 million decrease in interest expense related to lower outstanding balances of the Securitization Bonds;

an $8 million increase in TDU operating income discussed below in Results of Operations by Reportable Segment, exclusive of a $3 million gain in the nine months ended September 30, 2019 and a $4 million loss in the nine months ended September 30, 2018 from weather hedges recorded at CenterPoint Energy; and

an $8 million decrease in income tax expense primarily due to the lower effective tax rate as explained below that was partially offset by higher income before income taxes.

These increases were partially offset by the following:

a $22 million increase in interest expense due to higher outstanding other long-term debt; and

a $5$16 million decrease in operating income from the Bond Companies.

~~These decreases were partially offset by the following:~~

~~a $9 million increase in Other income (expense), net that included $6 million of interest income on money pool investments and $3 million in miscellaneous other non-operating income;~~

~~a $4 million decrease in interest expense related to the Securitization Bonds; and~~

~~a $4 million reduction of income tax expense due to the lower effective tax rate as explained below.~~

~~Six months ended June 30, 2019 compared to six months ended June 30, 2018~~

~~Houston Electric reported net income of $127 million for the six months ended June 30, 2019 compared to net income of $153 million for the six months ended June 30, 2018.~~

~~The decrease of $26 million in net income was primarily due to the following key factors:~~

~~a $39 million decrease in TDU operating income discussed below in Results of Operations by Reportable Segment, exclusive of a $7 million gain from the weather hedge recorded at CenterPoint Energy;~~

~~a $13 million increase in interest expense due to higher outstanding other long-term debt; and~~

~~an $11 million decrease in operating income from the Bond Companies.~~

~~These decreases were partially offset by the following:~~

a $16 million increase in Other income (expense), net that included $9 million of interest income on money pool investments, $3 million in interest income related to the Securitization Bonds and $4 million in miscellaneous other non-operating income;

~~a $13 million decrease in income tax expense primarily due to lower income and the lower effective tax rate as explained below; and~~

~~an $8 million decrease in interest expense related to the Securitization Bonds.~~

Income Tax Expense

Houston Electric’s effective tax rate reported for the three months ended ~~June~~September 30, 2019 was ~~19%~~18% compared to ~~21%~~20% for the three months ended ~~June~~September 30, 2018. Houston Electric’s effective tax rate reported for the ~~six~~nine months ended ~~June~~September 30, 2019 was ~~19%~~18% compared to ~~22%~~21% for the ~~six~~nine months ended ~~June~~September 30, 2018. The lower effective tax rate for both the three and ~~six~~nine months ended ~~June~~September 30, 2019 was primarily due to an increase in the amount of amortization of the net regulatory EDIT ~~liability as decreed by regulators.~~liability.

CERC’S MANAGEMENT’S NARRATIVE ANALYSIS OF CONSOLIDATED RESULTS OF OPERATIONS

CERC’s results of operations are affected by seasonal fluctuations in the demand for natural gas and price movements of energy commodities as well as the optimization of margins through natural gas basis differentials. CERC’s results of operations are also affected by, among other things, the actions of various federal, state and local governmental authorities having jurisdiction over rates CERC charges, competition in CERC’s various business operations, the effectiveness of CERC’s risk management activities, debt service costs and income tax expense. For more information regarding factors that may affect the future results of operations for CERC’s business, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Natural Gas Distribution and Competitive Energy Services Businesses” and “— Other Risk Factors Affecting Our Businesses or CenterPoint Energy’s Interests in Enable Midstream Partners, LP” in Item 1A of Part I of the Registrants’ combined 2018 Form ~~10-K.~~10-K and in Item 1A of Part II of this Form 10-Q.


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018			2019			2018			2019			2018
	(in millions)												(in millions)
Revenues	$	1,342		$	1,328		$	3,710		$	3,728		$	1,126		$	1,312		$	4,836		$	5,040
Expenses	1,284			1,306			3,456			3,575			1,103			1,319			4,559			4,894
Operating Income (Loss)	58			22			254			153			23			(7		)	277			146
Interest and other finance charges	(30		)	(33		)	(59		)	(62		)	(28		)	(30		)	(87		)	(92		)
Other expense, net	—			(1		)	(3		)	(5		)	(3		)	—			(6		)	(5		)
Income (loss) from continuing operations before income taxes	28			(12		)	192			86			(8		)	(37		)	184			49
Income tax expense (benefit)	—			(4		)	26			16			(1		)	(2		)	25			14
Income (loss) from continuing operations	28			(8		)	166			70			(7		)	(35		)	159			35
Income from discontinued operations, net of tax	—			44			—			96			—			44			—			140
Net Income	$	28		$	36		$	166		$	166
Net Income (Loss)													$	(7	)	$	9		$	159		$	175

Three months ended ~~June~~September 30, 2019 compared to three months ended ~~June~~September 30, 2018

CERC reported a net ~~income~~loss of ~~$28~~$7 million for the three months ended ~~June~~September 30, 2019 compared to net income of ~~$36~~$9 million for the three months ended ~~June~~September 30, 2018.

The decrease of $8$16 million in net income was primarily due to the following key factors:

a $44 million decrease in income from discontinued operations, net of tax, discussed further in Notes 9 and 13 to the Interim Condensed Financial Statements; and

a $4$3 million increase in Other expense, net primarily due to higher pension accruals.

These decreases were partially offset by the following:

a $30 million increase in operating income discussed below in Results of Operations by Reportable Segment; and

a $2 million decrease in interest and other finance charges.

Nine months ended September 30, 2019 compared to nine months ended September 30, 2018

CERC reported net income of $159 million for the nine months ended September 30, 2019 compared to net income of $175 million for the nine months ended September 30, 2018.

The decrease of $16 million in net income was primarily due to the the following key factors:

a $140 million decrease in income from discontinued operations, net of tax, discussed further in Notes 9 and 13 to the Interim Condensed Financial Statements; and

an $11 million increase in income tax expense due to higher income from continuing operations, partially offset by the lower effective tax rate as explained below.

These decreases were partially offset by the following:

a ~~$36~~$131 million increase in operating income discussed below in Results of Operations by Reportable Segment; and

a $3$5 million decrease in interest and other finance charges.

~~Six months ended June 30, 2019 compared to six months ended June 30, 2018~~

~~CERC reported net income of $166 million for the six months ended June 30, 2019 compared to net income of $166 million for the six months ended June 30, 2018.~~

~~Net income was primarily impacted by the following key factors:~~

~~a $101 million increase in operating income discussed below in Results of Operations by Reportable Segment;~~

~~a $96 million decrease in income from discontinued operations, net of tax, discussed further in Notes 9 and 13 to the Interim Condensed Financial Statements;~~

~~a $10 million increase in income tax expense due to higher income from continuing operations, partially offset by the lower effective tax rate as explained below; and~~

~~a $3 million decrease in interest and other finance charges.~~

Income Tax Expense - Continuing Operations

CERC’s effective tax rate on income from continuing operations for the three months ended ~~June~~September 30, 2019 was 0%13% compared to ~~33%~~5% for the three months ended ~~June~~September 30, 2018. CERC’s effective tax rate on income from continuing operations for the ~~six~~nine months ended ~~June~~September 30, 2019 was 14% compared to ~~19%~~29% for the ~~six~~nine months ended ~~June~~September 30, 2018. ~~The~~CERC’s higher effective tax rate on loss from continuing operations for the three months ended September 30, 2019 compared to the three months ended September 30, 2018 was primarily due to a decrease in the amount of amortization of the net regulatory EDIT liability, which was partially offset by the absence of a change in the valuation allowance on certain state net operating losses in 2019, the effects of which are compounded by the book loss in the three months ended September 30, 2019. CERC’s lower effective tax rate for ~~both~~ the ~~three and six~~nine months ended ~~June~~September 30, 2019 compared to the nine months ended September 30, 2018 was primarily due to ~~the following:~~ an increase in the amount of amortization of the net regulatory EDIT liability, ~~as decreed~~which was partially offset by ~~regulators in certain jurisdictions;~~ the impact of ~~state tax law~~ changes ~~that resulted~~ in ~~the remeasurement of state deferred taxes; and the release of a~~ valuation ~~allowance~~allowances on certain state net operating losses ~~that are now expected to be utilized prior to expiration due to a current period law change. The state law changes and valuation allowance release resulted~~ in ~~a lower than expected effective tax rate for the three months ended June 30,~~ 2019.

RESULTS OF OPERATIONS BY REPORTABLE SEGMENT

As of ~~June~~September 30, 2019, reportable segments by Registrant were as follows:

Registrants

Houston Electric T&D

Indiana Electric Integrated

Natural Gas Distribution

Energy

Services

Infrastructure Services

Midstream Investments

Corporate and Other

CenterPoint Energy

Houston Electric

CERC

The Midstream Investments reportable segment consists of CenterPoint Energy’s equity investment in Enable and is therefore not included in the operating income table below. Included in revenues are intersegment sales, which are accounted for as if the sales were to third parties at current market prices. See Note 16 to the Interim Condensed Financial Statements for details of reportable segments by Registrant.

The following table presents operating income (loss) for each reportable segment:

Three Months Ended June 30, Six Months Ended June 30,
2019 2018 2019 2018
(in millions)
CenterPoint Energy
Houston Electric T&D $ 169
$ 181
$ 253
$ 296
Indiana Electric Integrated 25
—
16
—
Natural Gas Distribution 47
7
214
163
Energy Services 29
15
62
(11 )
Infrastructure Services 24
—
8
—
Corporate and Other (7 ) (16 ) (21 ) (10 )
Total CenterPoint Energy Consolidated Operating Income $ 287
$ 187
$ 532
$ 438
Houston Electric
Houston Electric T&D $ 169
$ 181
$ 250
$ 300
CERC
Natural Gas Distribution $ 28
$ 7
$ 192
$ 163
Energy Services 29
15
62
(11 )
Other Operations 1
—
—
1
Total CERC Consolidated Operating Income $ 58
$ 22
$ 254
$ 153



	Three Months Ended September 30,					Nine Months Ended September 30,
	2019		2018			2019			2018
	(in millions)
CenterPoint Energy
Houston Electric T&D	$	269	$	227		$	522		$	523
Indiana Electric Integrated	48		—			64			—
Natural Gas Distribution	27		3			241			166
Energy Services	2		(9		)	64			(20		)
Infrastructure Services	42		—			50			—
Corporate and Other	4		5			(17		)	(5		)
Total CenterPoint Energy Consolidated Operating Income	$	392	$	226		$	924		$	664
Houston Electric
Houston Electric T&D	$	269	$	227		$	519		$	527
CERC
Natural Gas Distribution	$	20	$	3		$	212		$	166
Energy Services	2		(9		)	64			(20		)
Other Operations	1		(1		)	1			—
Total CERC Consolidated Operating Income (Loss)	$	23	$	(7	)	$	277		$	146

Houston Electric T&D (CenterPoint Energy and Houston Electric)

For information regarding factors that may affect the future results of operations of the Houston Electric T&D reportable segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Electric Generation, Transmission and Distribution Businesses” and “— Other Risk Factors Affecting Our Businesses or CenterPoint Energy’s Interests in Enable Midstream Partners, LP” in Item 1A of Part I of the Registrants’ combined 2018 Form ~~10-K.~~10-K and in Item 1A of Part II of this Form 10-Q.

The following table provides summary data of the Houston Electric T&D reportable segment:


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018		2019		2018
	(in millions, except throughput and customer data)								(in millions, except throughput and customer data)
Revenues:
TDU	$	672	$	676	$	1,267	$	1,274	$	776	$	735	$	2,043	$	2,009
Bond Companies	93		178		187		331		83		162		270		493
Total revenues	765		854		1,454		1,605		859		897		2,313		2,502
Expenses:
Operation and maintenance, excluding Bond Companies	357		349		723		689		357		367		1,080		1,056
Depreciation and amortization, excluding Bond Companies	94		100		187		198		95		95		282		293
Taxes other than income taxes	61		60		123		121		63		59		186		180
Bond Companies	84		164		168		301		75		149		243		450
Total expenses	596		673		1,201		1,309		590		670		1,791		1,979
Operating Income	$	169	$	181	$	253	$	296	$	269	$	227	$	522	$	523
Operating Income:
TDU	$	160	$	167	$	234	$	266	$	261	$	214	$	495	$	480
Bond Companies (1)	9		14		19		30		8		13		27		43
Total segment operating income	$	169	$	181	$	253	$	296	$	269	$	227	$	522	$	523
Throughput (in GWh):
Residential	7,985		8,327		13,168		13,932		11,224		10,555		24,392		24,486
Total	24,018		23,688		43,037		43,332		28,379		27,015		71,417		70,347
Number of metered customers at end of period:
Residential	2,217,326		2,179,048		2,217,326		2,179,048		2,232,740		2,188,211		2,232,740		2,188,211
Total	2,506,124		2,463,500		2,506,124		2,463,500		2,523,450		2,475,018		2,523,450		2,475,018


(1)	Operating income from the Bond Companies, together with $1 million and $3$4 million of interest income for the three and ~~six~~nine months ended ~~June~~September 30, 2019, respectively, and $1$3 million of interest income for both the three and ~~six~~nine months ended ~~June~~September 30, 2018, are necessary to pay interest on the Securitization Bonds.

Three months ended ~~June~~September 30, 2019 compared to three months ended ~~June~~September 30, 2018

The Houston Electric T&D reportable segment reported operating income of ~~$169~~$269 million for the three months ended ~~June~~September 30, 2019, consisting of ~~$160~~$261 million from the TDU and $9$8 million related to the Bond Companies. For the three months ended ~~June~~September 30, 2018, operating income totaled ~~$181~~$227 million, consisting of ~~$167~~$214 million from the TDU and ~~$14~~$13 million related to the Bond Companies.

TDU operating income ~~decreased $7~~increased $47 million, primarily due to the following key factors:

~~lower usage~~decreased operation and maintenance expenses of ~~$13~~$29 million primarily due to ~~a return~~the following:


◦	decreased support services costs of $12 million;


◦	other miscellaneous operation and maintenance expense decreases of $9 million; and


◦	decreased labor and benefits costs of $6 million.

higher usage of $12 million primarily due to ~~more~~warmer than normal weather;

customer growth of $9 million from the addition of over 48,000 customers;

rate increases of $7 million related to distribution capital investments, exclusive of the TCJA mentioned below; and

higher transmission-related revenues of $18 million, exclusive of the TCJA mentioned below, partially offset by higher transmission costs billed by transmission providers of $16 million.

These increases to operating income were partially offset by the following:

higher depreciation and amortization expense, primarily because of ongoing additions to plant in service, and other taxes of $9 million;

lower equity return of ~~$11~~$3 million, primarily related to the annual true-up of transition charges correcting for over-collections that occurred during the preceding 12 months;

~~higher depreciation and amortization expense, primarily because of ongoing additions to plant in service, and other taxes of $6 million;~~ and

lower revenue of $6$3 million related to the impact of the TCJA.

~~These decreases~~Lower depreciation and amortization expenses related to AMS of $5 million were offset by a corresponding decrease in related revenues.

Nine months ended September 30, 2019 compared to nine months ended September 30, 2018

The Houston Electric T&D reportable segment reported operating income ~~were partially offset by~~of $522 million for the ~~following:~~nine months ended September 30, 2019, consisting of $495 million from the TDU and $27 million related to the Bond Companies. For the nine months ended September 30, 2018, operating income totaled $523 million, consisting of $480 million from the TDU and $43 million related to the Bond Companies.

TDU operating income increased $15 million, primarily due to the following key factors:

customer growth of $22 million from the addition of over 48,000 customers;

rate increases of $20 million related to distribution capital investments, exclusive of the TCJA mentioned above;

higher transmission-related revenues of ~~$22~~$56 million, exclusive of the TCJA mentioned above, partially offset by higher transmission costs billed by transmission providers of ~~$13~~$38 million;

~~rate increases of $8 million related to distribution capital investments, exclusive of the TCJA mentioned above;~~

•~~customer growth of $7 million from the addition of almost 43,000 customers; and~~

decreased operation and maintenance expenses of ~~$3 million.~~$17 million, net of $10 million of Merger-related severance costs, primarily due to lower labor and benefits costs and lower support services costs; and

~~Lower depreciation and amortization expenses~~higher miscellaneous revenues of $13 million primarily related to ~~AMS of $11 million were offset by a corresponding decrease in related~~right-of-way revenues.

~~Six months ended June 30, 2019 compared~~These increases to ~~six months ended June 30, 2018~~

~~The Houston Electric T&D reportable segment reported~~ operating income ~~of $253 million for~~were partially offset by the six months ended June 30, 2019, consisting of $234 million from the TDU and $19 million related to the Bond Companies. For the six months ended June 30, 2018, operating income totaled $296 million, consisting of $266 million from the TDU and $30 million related to the Bond Companies.

~~TDU operating income decreased $32 million, primarily due to the following key factors:~~

~~lower usage of $28 million primarily due to a return to more normal weather;~~following:

lower equity return of ~~$21~~$24 million, primarily related to the annual true-up of transition charges ~~correcting for~~to correct over-collections that occurred during the preceding 12 months;

higher depreciation and amortization expense, primarily because of ongoing additions to plant in service, and other taxes of ~~$13~~$22 million;

~~increased operation and maintenance expenses~~lower usage of ~~$13 million, including $10 million of Merger-related severance costs;~~$16 million; and

•lower revenue of ~~$12~~$15 million related to the impact of the TCJA.

~~These decreases to operating income were partially offset by the following:~~

~~higher transmission-related revenues of $38 million, exclusive of the TCJA mentioned above, partially offset by higher transmission costs billed by transmission providers of $22 million;~~

•~~customer growth of $13 million from the addition of almost 43,000 customers;~~

~~rate increases of $13 million related to distribution capital investments, exclusive of the TCJA mentioned above; and~~

~~higher miscellaneous revenues of $10 million primarily related to right-of-way revenues.~~

Lower depreciation and amortization expenses related to AMS of ~~$22~~$27 million were offset by a corresponding decrease in related revenues.

Indiana Electric Integrated (CenterPoint Energy)

For information regarding factors that may affect the future results of operations of the Indiana Electric Integrated reportable segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Electric Generation, Transmission and Distribution Businesses” and “— Other Risk Factors Affecting Our Businesses or CenterPoint Energy’s Interests in Enable Midstream Partners, LP” in Item 1A of Part I of the Registrants’ combined 2018 Form ~~10-K.~~10-K and in Item 1A of Part II of this Form 10-Q.

The following table provides summary data of CenterPoint Energy’s Indiana Electric Integrated reportable segment:


	Three Months Ended June 30, 2019		Six Months Ended June 30, 2019 (1)		Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019 (1)
	(in millions, except throughput and customer data)				(in millions, except throughput and customer data)
Revenues	$	140	$	223	$	165	$	388
Expenses:
Utility natural gas, fuel and purchased power	40		66		46		112
Operation and maintenance	46		94		42		136
Depreciation and amortization	25		41		25		66
Taxes other than income taxes	4		6		4		10
Total expenses	115		207		117		324
Operating Income	$	25	$	16	$	48	$	64
Throughput (in GWh):
Retail	1,157		1,861		1,416		3,277
Wholesale	94		152		139		291
Total	1,251		2,013		1,555		3,568
Number of metered customers at end of period:
Residential	128,167		128,167		128,381		128,381
Total	147,076		147,076		147,337		147,337


(1)	Represents February 1, 2019 through ~~June~~September 30, 2019 results only due to the Merger.

Three months ended ~~June~~September 30, 2019

The Indiana Electric Integrated reportable segment reported operating income of ~~$25~~$48 million for the three months ended ~~June~~September 30, 2019. These results are not comparable to the prior year as this reportable segment was acquired in the Merger as discussed in Note 3 to the Interim Condensed Financial Statements.

~~Six~~Nine months ended ~~June~~September 30, 2019

The Indiana Electric Integrated reportable segment reported operating income of ~~$16~~$64 million for the period ended ~~June~~September 30, 2019, which includes operation and maintenance expenses of $20 million for Merger-related severance and incentive compensation costs. These results are not comparable to the prior year as this reportable segment was acquired in the Merger as discussed in Note 3 to the Interim Condensed Financial Statements.

Natural Gas Distribution (CenterPoint Energy)

For information regarding factors that may affect the future results of operations of CenterPoint Energy’s Natural Gas Distribution reportable segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Natural Gas Distribution and Competitive Energy Services Businesses” and “— Other Risk Factors Affecting Our Businesses or CenterPoint Energy’s Interests in Enable Midstream Partners, LP” in Item 1A of Part I of the Registrants’ combined 2018 Form ~~10-K.~~10-K and in Item 1A of Part II of this Form 10-Q.

The following table provides summary data of CenterPoint Energy’s Natural Gas Distribution reportable segment:


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018		2019		2018
	(in millions, except throughput and customer data)								(in millions, except throughput and customer data)
Revenues	$	660	$	495	$	2,059	$	1,648	$	524	$	410	$	2,583	$	2,058
Expenses:
Utility natural gas, fuel and purchased power	222		185		993		852		125		120		1,118		972
Operation and maintenance	239		196		546		409		221		183		767		592
Depreciation and amortization	105		69		200		137		108		73		308		210
Taxes other than income taxes	47		38		106		87		43		31		149		118
Total expenses	613		488		1,845		1,485		497		407		2,342		1,892
Operating Income	$	47	$	7	$	214	$	163	$	27	$	3	$	241	$	166
Throughput (in Bcf):
Residential	30		23		144		110		16		13		160		123
Commercial and industrial	102		61		238		155		88		53		326		208
Total Throughput	132		84		382		265		104		66		486		331
Number of customers at end of period:
Residential	4,195,222		3,204,897		4,195,222		3,204,897		4,194,232		3,205,916		4,194,232		3,205,916
Commercial and industrial	347,092		255,115		347,092		255,115		344,858		255,244		344,858		255,244
Total	4,542,314		3,460,012		4,542,314		3,460,012		4,539,090		3,461,160		4,539,090		3,461,160

Three months ended ~~June~~September 30, 2019 compared to three months ended ~~June~~September 30, 2018

CenterPoint Energy’s Natural Gas Distribution reportable segment reported operating income of ~~$47~~$27 million for the three months ended ~~June~~September 30, 2019 compared to $7$3 million for the three months ended ~~June~~September 30, 2018.

Operating income increased ~~$40~~$24 million primarily as a result of the following key factors:

lower operation and maintenance expenses of $12 million primarily driven by lower support services costs and lower labor and benefits costs in CERC’s NGD service territories;

rate increases of $9 million, exclusive of the TCJA impact discussed below, from rate filings in CERC’s NGD service territories;

a ~~$19~~$7 million increase in operating income associated with the natural gas businesses acquired in the Merger, which includes the addition of over 1 million customers in Indiana and Ohio; and

ana $3 million increase in revenues associated with customer growth from the addition of over 47,000 new customers in CERC’s NGD service territories.

These increases were partially offset by the following:

a $8 million decrease in revenues, primarily driven by the timing of a decoupling mechanism (a revenue stabilization mechanism used to adjust revenues impacted by changes in natural gas consumption, including usage and weather) in Minnesota in CERC’s NGD service territory;

~~rate increases of $7 million, exclusive of the TCJA impact discussed below, primarily from rate filings in Texas, Arkansas, Oklahoma, Louisiana and Mississippi in CERC’s NGD service territories;~~

~~a $3 million increase in revenues associated with customer growth from the addition of over 48,000 new customers in CERC’s NGD service territories;~~ and

~~lower operation and maintenance expenses of $6 million primarily driven by lower support services cost and lower bad debt costs in CERC’s NGD service territories.~~

~~These increases were partially offset by the following:~~

~~increased depreciation and amortization expense of $4 million, primarily due to ongoing additions to plant-in-service, in CERC’s NGD service territories; and~~

lower revenue of $2 million related to the impact of the TCJA in CERC’s NGD service territories.

Increased operation and maintenance expenses related to increased gross receipts taxes of $1 million were offset by corresponding increases in the related revenues in CERC’s service territories. Decreased operation and maintenance expenses related to energy efficiency programs of $3$2 million were offset by corresponding decreases in the related revenues in CERC’s NGD service territories.

~~Six~~Nine months ended ~~June~~September 30, 2019 compared to ~~six~~nine months ended ~~June~~September 30, 2018

CenterPoint Energy’s Natural Gas Distribution reportable segment reported operating income of ~~$214~~$241 million for the ~~six~~nine months ended ~~June~~September 30, 2019 compared to ~~$163~~$166 million for the ~~six~~nine months ended ~~June~~September 30, 2018.

Operating income increased ~~$51~~$75 million primarily as a result of the following key factors:

~~an increase~~rate increases of ~~$28~~$30 million, ~~primarily driven by~~exclusive of the ~~timing of a decoupling mechanism explained above in Minnesota~~TCJA impact discussed below, from rate filings in CERC’s NGD ~~territory;~~service territories;

a ~~$22~~$29 million increase in operating income associated with the natural gas businesses acquired in the Merger for the period from February 1, 2019 through ~~June~~September 30, 2019, which includes operation and maintenance expenses of ~~$43~~$44 million for Merger-related severance and incentive compensation costs, as well as the addition of over 1 million customers in Indiana and Ohio;

~~rate increases of~~a $22 million ~~exclusive~~increase in revenues for usage, partially driven by the timing of ~~the TCJA impact~~a decoupling mechanism discussed ~~below, primarily from rate filings~~above in ~~the~~Minnesota in CERC’s NGD service ~~territories;~~territory; and

an $8$11 million increase in revenues associated with customer growth from the addition of over ~~48,000~~47,000 new customers in CERC’s NGD service ~~territories; and~~

•~~lower other taxes of $2 million, primarily due to the Minnesota property tax tracking mechanism.~~territories.

These increases were partially offset by the following:

lower revenue of ~~$14~~$16 million related to the impact of the TCJA in CERC’s NGD service territories;

~~higher operation and maintenance expenses of $12 million in CERC’s NGD service territories, primarily due to Merger-related severance costs;~~ and

increased depreciation and amortization expense of $9$7 million, primarily due to ongoing additions to plant-in-service, in CERC’s NGD service territories.

Increased operation and maintenance expenses related to increased gross receipts taxes of $2 million were offset by corresponding increases in the related revenues in CERC’s NGD service territories. Decreased operation and maintenance expenses related to energy efficiency programs of ~~$11~~$13 million and rate case amortization of $1 million were offset by corresponding decreases in the related revenues in CERC’s NGD service territories.

Natural Gas Distribution (CERC)

For information regarding factors that may affect the future results of operations of CERC’s Natural Gas Distribution reportable segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Natural Gas Distribution and Competitive Energy Services Businesses” and “— Other Risk Factors Affecting Our Businesses or CenterPoint Energy’s Interests in Enable Midstream Partners, LP” in Item 1A of Part I of the Registrants’ combined 2018 Form ~~10-K.~~10-K and in Item 1A of Part II of this Form 10-Q.

The following table provides summary data of CERC’s Natural Gas Distribution reportable segment:


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018		2019		2018		2019		2018
	(in millions, except throughput and customer data)								(in millions, except throughput and customer data)
Revenues	$	513	$	495	$	1,708	$	1,648	$	398	$	410	$	2,106	$	2,058
Expenses:											—
Utility natural gas	187		185		875		852		105		120		980		972
Operation and maintenance	187		196		410		409		169		183		579		592
Depreciation and amortization	73		69		145		137		71		73		216		210
Taxes other than income taxes	38		38		86		87		33		31		119		118
Total expenses	485		488		1,516		1,485		378		407		1,894		1,892
Operating Income	$	28	$	7	$	192	$	163	$	20	$	3	$	212	$	166
Throughput (in Bcf):
Residential	22		23		113		110		12		13		125		123
Commercial and industrial	63		61		161		155		53		53		214		208
Total Throughput	85		84		274		265		65		66		339		331
Number of customers at end of period:
Residential	3,248,679		3,204,897		3,248,679		3,204,897		3,250,810		3,205,916		3,250,810		3,205,916
Commercial and industrial	259,504		255,115		259,504		255,115		257,655		255,244		257,655		255,244
Total	3,508,183		3,460,012		3,508,183		3,460,012		3,508,465		3,461,160		3,508,465		3,461,160

Three months ended ~~June~~September 30, 2019 compared to three months ended ~~June~~September 30, 2018

CERC’s Natural Gas Distribution reportable segment reported operating income of ~~$28~~$20 million for the three months ended ~~June~~September 30, 2019 compared to $7$3 million for the three months ended ~~June~~September 30, 2018.

Operating income increased ~~$21~~$17 million primarily as a result of the following key factors:

anlower operation and maintenance expenses of $12 million primarily driven by lower support services costs and lower labor and benefits costs;

rate increases of $9 million, exclusive of the TCJA impact discussed below; and

a $3 million increase in revenues associated with customer growth from the addition of over 47,000 new customers.

These increases were partially offset by the following:

a $8 million ~~partially~~decrease in revenues, primarily driven by the timing of a decoupling mechanism (a revenue stabilization mechanism used to adjust revenues impacted by changes in natural gas consumption, including usage and weather) in Minnesota;

~~rate increases of $7 million, exclusive of the TCJA impact discussed below, primarily from rate filings in Texas, Arkansas, Oklahoma, Louisiana and Mississippi;~~

~~lower operation and maintenance expenses of $6 million primarily driven by lower support services and lower bad debt costs;~~ and

~~a $3 million increase in revenues associated with customer growth from the addition of over 48,000 new customers.~~

~~These increases were partially offset by the following:~~

~~increased depreciation and amortization expense of $4 million, primarily due to ongoing additions to plant-in-service; and~~

lower revenue of $2 million related to the impact of the TCJA.

Increased operation and maintenance expenses related to increased gross receipts taxes of $1 million were offset by corresponding increases in the related revenues. Decreased operation and maintenance expenses related to energy efficiency programs of $3$2 million were offset by corresponding decreases in the related revenues.

~~Six~~Nine months ended ~~June~~September 30, 2019 compared to ~~six~~nine months ended ~~June~~September 30, 2018

CERC’s Natural Gas Distribution reportable segment reported operating income of ~~$192~~$212 million for the ~~six~~nine months ended ~~June~~September 30, 2019 compared to ~~$163~~$166 million for the ~~six~~nine months ended ~~June~~September 30, 2018.

Operating income increased ~~$29~~$46 million primarily as a result of the following key factors:

~~an increase of $28 million primarily driven by the timing of a decoupling mechanism explained above in Minnesota;~~

rate increases of ~~$22~~$30 million, exclusive of the TCJA impact discussed below;

a $22 million increase in revenues for usage, partially driven by the timing of a decoupling mechanism in Minnesota discussed above; and

an $8$11 million increase in revenues associated with customer growth from the addition of over ~~48,000~~47,000 new ~~customers; and~~

~~lower other taxes of $2 million, primarily due to the Minnesota property tax tracking mechanism.~~customers.

These increases were partially offset by the following:

lower revenue of ~~$14~~$16 million related to the impact of the TCJA;

~~higher operation and maintenance expenses of $12 million, primarily due to Merger-related severance costs;~~ and

increased depreciation and amortization expense of $9$7 million, primarily due to ongoing additions to plant-in-service.

Increased operation and maintenance expenses related to increased gross receipts taxes of $2 million were offset by corresponding increases in the related revenues. Decreased operation and maintenance expenses related to energy efficiency programs of ~~$11~~$13 million and rate case amortization of $1 million were offset by corresponding decreases in the related revenues.

Energy Services (CenterPoint Energy and CERC)

For information regarding factors that may affect the future results of operations of the Energy Services reportable segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Natural Gas Distribution and Competitive Energy Services Businesses” and “— Other Risk Factors Affecting Our Businesses or CenterPoint Energy’s Interests in Enable Midstream Partners, LP” in Item 1A of Part I of the Registrants’ combined 2018 Form ~~10-K.~~10-K and in Item 1A of Part II of this Form 10-Q.

The following table provides summary data of the Energy Services reportable segment:


	Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,						Nine Months Ended September 30,
	2019		2018		2019		2018			2019			2018			2019		2018
	(in millions, except throughput and customer data)									(in millions, except throughput and customer data)
Revenues	$	855	$	860	$	2,101	$	2,145		$	745		$	920		$	2,846	$	3,065
Expenses:
Non-utility cost of revenues, including natural gas	798		820		1,980		2,101			716			897			2,696		2,998
Operation and maintenance	25		21		50		46			23			28			73		74
Depreciation and amortization	3		3		8		8			4			4			12		12
Taxes other than income taxes	—		1		1		1			—			—			1		1
Total expenses	826		845		2,039		2,156			743			929			2,782		3,085
Operating Income (Loss)	$	29	$	15	$	62	$	(11	)	$	2		$	(9	)	$	64	$	(20	)

Timing impacts related to mark-to-market gain (loss)	$	30	$	8	$	49	$	(72	)	$	(2	)	$	1		$	47	$	(71	)
Throughput (in Bcf)	298		311		677		686			283			307			960		993
Approximate number of customers at end of period (1)	31,000		30,000		31,000		30,000			31,000			30,000			31,000		30,000


(1)	Does not include approximately ~~68,000~~66,000 and ~~71,000~~67,000 natural gas customers as of ~~June~~September 30, 2019 and 2018, respectively, that are under residential and small commercial choice programs invoiced by their host utility.

Three months ended ~~June~~September 30, 2019 compared to three months ended ~~June~~September 30, 2018

The Energy Services reportable segment reported operating income of ~~$29~~$2 million for the three months ended ~~June~~September 30, 2019 compared to an operating ~~income~~loss of ~~$15~~$9 million for the three months ended ~~June~~September 30, 2018.

Operating income increased ~~$14~~$11 million primarily as a result of the following key factors:


•	a $10 million increase in margin due to fewer opportunities to optimize natural gas supply costs in the third quarter of 2018; and

a $4 million decrease in operation and maintenance expenses, primarily due to lower support services expenses.

These increases were partially offset by a $3 million decrease from mark-to-market accounting for derivatives associated with certain natural gas purchases and sales used to lock in economic margins.

Nine months ended September 30, 2019 compared to nine months ended September 30, 2018

The Energy Services reportable segment reported operating income of $64 million for the nine months ended September 30, 2019 compared to an operating loss of $20 million for the nine months ended September 30, 2018.

Operating income increased $84 million primarily as a result of a ~~$22~~$118 million increase from mark-to-market accounting for derivatives associated with certain natural gas purchases and sales used to lock in economic margins. This increase was partially offset ~~by:~~

by a ~~$5 million decrease in margin, primarily due to the impact of less price volatility on natural gas storage activity; and~~

a $3 million increase in operation and maintenance expenses, primarily due to higher employee benefit expenses, higher contract and services expenses related to pipeline integrity testing and higher facilities expenses.

~~Six months ended June 30, 2019 compared to six months ended June 30, 2018~~

~~The Energy Services reportable segment reported operating income of $62 million for the~~ ~~six~~ ~~months ended June 30, 2019 compared to an operating loss of $11 million for the six months ended June 30, 2018.~~

Operating income increased $73 million primarily as a result of a $121 million increase from mark-to-market accounting for derivatives associated with certain natural gas purchases and sales used to lock in economic margins. This increase was partially offset by:

~~a $44~~$34 million decrease in margin due to fewer opportunities to optimize natural gas costs relative to last year, primarily in the first quarter of 2019. Specifically, weather-facilitated market impacts in various regions of the continental United

States during the three months ended March 31, 2018 allowed Energy Services to increase its margins in the first quarter of ~~2018; and~~

a $4 million increase in operation and maintenance expenses, primarily due to higher benefits expenses, higher contract and services expenses related to pipeline integrity testing and higher facilities expenses.2018.

Infrastructure Services (CenterPoint Energy)

For information regarding factors that may affect the future results of operations of the Infrastructure Services reportable segment, please read “Risk Factors — Risk Factors Associated with Our Consolidated Financial Condition,” “— Risk Factors Affecting Natural Gas Distribution and Competitive Energy Services Businesses” and “— Other Risk Factors Affecting Our Businesses or CenterPoint Energy’s Interests in Enable Midstream Partners, LP” in Item 1A of Part I of the Registrants’ combined 2018 Form ~~10-K.~~10-K and in Item 1A of Part II of this Form 10-Q.

The following table provides summary data of the Infrastructure Services reportable segment:


	Three Months Ended June 30, 2019		Six Months Ended June 30, 2019 (1)		Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019 (1)
	(in millions)				(in millions)
Revenues	$	326	$	472	$	377	$	849
Expenses:
Non-utility cost of revenues, including natural gas	89		132		96		228
Operation and maintenance	197		307		223		530
Depreciation and amortization	15		24		15		39
Taxes other than income taxes	1		1		1		2
Total expenses	302		464		335		799
Operating Income	$	24	$	8	$	42	$	50
Backlog at period end (2):
Blanket contracts (3)	$	616	$	616	$	637	$	637
Bid contracts (4)	317		317		301		301
Total	$	933	$	933	$	938	$	938


(1)	Represents February 1, 2019 through ~~June~~September 30, 2019 results only due to the Merger.


(2)	Backlog represents the amount of revenue Infrastructure Services expects to realize from work to be performed on uncompleted contracts in the next twelve months, including new contractual agreements on which work has not begun. Infrastructure Services operates primarily under two types of contracts, blanket contracts and bid contracts.

(3)

Using blanket contracts, customers are not contractually committed to specific volumes of services; however, Infrastructure Services expects to be chosen to perform work needed by a customer in a given time frame. These contracts are typically awarded on an annual or multi-year basis. For blanket work, backlog represents an estimate of the amount of revenue that Infrastructure Services expects to realize from work to be performed in the next twelve months on existing contracts or contracts management expects to be renewed or awarded.


(4)	Using bid contracts, customers are contractually committed to a specific service to be performed for a specific price, whether in total for a project or on a per unit basis.

Three months ended ~~June~~September 30, 2019

The Infrastructure Services reportable segment reported operating income of ~~$24~~$42 million for the three months ended ~~June~~September 30, 2019, which includes $7$6 million of Merger-related amortization of intangibles for construction backlog recorded in non-utility cost of revenues, including natural gas, and $5$3 million of Merger-related intangibles amortization recorded in depreciation and amortization. These results are not comparable to the prior year as this reportable segment was acquired in the Merger as discussed in Note 3 to the Interim Condensed Financial Statements.

~~Six~~Nine months ended ~~June~~September 30, 2019

The Infrastructure Services reportable segment reported operating income of $8$50 million for the ~~six~~nine months ended ~~June~~September 30, 2019, which includes $13 million for Merger-related severance and incentive compensation costs, $9$15 million of Merger-related amortization of intangibles for construction backlog recorded in non-utility cost of revenues, including natural gas, and $7$10 million of Merger-related intangibles amortization recorded in depreciation and amortization. These results are not comparable to the prior year as this reportable segment was acquired in the Merger as discussed in Note 3 to the Interim Condensed Financial Statements.

Midstream Investments (CenterPoint Energy)

For information regarding factors that may affect the future results of operations of the Midstream Investments reportable segment, please read “Risk Factors — Risk Factors Affecting CenterPoint Energy’s Interests in Enable Midstream Partners, LP” and “— Other Risk Factors Affecting Our Businesses or CenterPoint Energy’s Interests in Enable Midstream Partners, LP” in Item 1A of Part I of the Registrants’ combined 2018 Form ~~10-K.~~10-K and in Item 1A of Part II of this Form 10-Q.

The following table provides pre-tax equity income of the Midstream Investments reportable segment:

Three Months Ended June 30, Six Months Ended June 30,
2019 2018 2019 2018
(in millions)
Equity earnings from Enable, net $ 74
$ 58
$ 136
$ 127



	Three Months Ended September 30,				Nine Months Ended September 30,
	2019		2018		2019		2018
	(in millions)
Equity in earnings from Enable, net	$	77	$	81	$	213	$	208

Corporate and Other (CenterPoint Energy)

The following table shows the operating ~~loss~~income (loss) of CenterPoint Energy’s Corporate and Other reportable segment:


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,					Nine Months Ended September 30,
	2019			2018			2019			2018			2019		2018			2019			2018
	(in millions)												(in millions)
Revenues	$	80		$	4		$	122		$	8		$	93	$	3		$	215		$	11
Expenses:
Non-utility cost of revenues, including natural gas	53			—			90			—			68		—			158			—
Operation and maintenance	19			11			23			(1		)	2		(13		)	25			(14		)
Depreciation and amortization	15			7			28			15			16		9			44			24
Taxes other than income taxes	—			2			2			4			3		2			5			6
Total	87			20			143			18			89		(2		)	232			16
Operating Loss	$	(7	)	$	(16	)	$	(21	)	$	(10	)
Operating Income (Loss)													$	4	$	5		$	(17	)	$	(5	)

Three months ended ~~June~~September 30, 2019 compared to three months ended ~~June~~September 30, 2018

CenterPoint Energy’s Corporate and Other reportable segment reported an operating ~~loss~~income of $7$4 million for the three months ended ~~June~~September 30, 2019 compared to an operating ~~loss~~income of ~~$16~~$5 million for the three months ended ~~June~~September 30, 2018.

The operating ~~loss~~income decreased $9$1 million ~~primarily~~ due to ~~the following factors:~~

a ~~$13~~$9 million increase in ~~operating income,~~operation and maintenance expenses primarily ~~from $9~~for Merger-related transaction and integration costs, which was offset by $8 million in operating income associated with ESG, which was acquired in the Merger, ~~inclusive of a $5 million benefit related to a cumulative catch-up for remeasurement of the purchase price allocation related to~~including Merger-related amortization of intangibles for operation and maintenance agreements and construction backlog recorded in non-utility cost of revenues, including natural gas ~~and $1 million~~ of ~~Merger-related intangibles amortization recorded in depreciation and amortization; and~~$2 million.

•~~a $3 million property tax refund.~~

~~These decreases in the operating loss were partially offset by a $5 million increase in operation and maintenance expenses primarily for Merger-related transaction and integration costs.~~

~~Six~~Nine months ended ~~June~~September 30, 2019 compared to ~~six~~nine months ended ~~June~~September 30, 2018

CenterPoint Energy’s Corporate and Other reportable segment reported an operating loss of ~~$21~~$17 million for the ~~six~~nine months ended ~~June~~September 30, 2019 compared to an operating loss of ~~$10~~$5 million for the ~~six~~nine months ended ~~June~~September 30, 2018.

The operating loss increased ~~$11~~$12 million ~~primarily~~ due to ~~the following factors:~~

a ~~$13~~$20 million increase in operation and maintenance expenses primarily for Merger-related transaction and integration ~~costs; and~~costs, which was partially offset by:

a $3$5 million operating ~~loss~~income associated with ESG, which was acquired in the Merger, for the period February 1, 2019 through ~~June~~September 30, 2019, including operation and maintenance expenses of $2 million for Merger-related severance and incentive compensation costs, Merger-related amortization of intangibles for operation and maintenance agreements and construction backlog recorded in non-utility cost of revenues, including natural gas of $2$4 million and Merger-related intangibles amortization recorded in depreciation and amortization of $1 ~~million.~~million; and

~~These increases in the operating loss were partially offset by~~ a $3 million property tax refund.

Corporate and Other (CERC)

The following table shows the operating income (loss) of CERC’s Corporate and Other reportable segment:


	Three Months Ended June 30,					Six Months Ended June 30,					Three Months Ended September 30,					Nine Months Ended September 30,
	2019			2018		2019		2018			2019		2018			2019		2018
	(in millions)										(in millions)
Revenues	$	—		$	—	$	1	$	—		$	3	$	—		$	4	$	—
Expenses	(1		)	—		1		(1		)	2		1			3		—
Operating Income (Loss)	$	1		$	—	$	—	$	1		$	1	$	(1	)	$	1	$	—

CERTAIN FACTORS AFFECTING FUTURE EARNINGS

For information on other developments, factors and trends that may have an impact on the Registrants’ 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 and “Risk Factors” in Item 1A of Part I of the Registrants’ combined 2018 Form 10-K, in Item 1A of Part II of this Form 10-Q 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:


	Six Months Ended June 30,																		Nine Months Ended September 30,
	2019									2018									2019									2018
	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)																		(in millions)
Cash provided by (used in):
Operating activities	$	574		$	240		$	449		$	1,093		$	443		$	746		$	1,086		$	595		$	513		$	1,679		$	788		$	850
Investing activities	(7,149		)	(1,311		)	(386		)	(267		)	(468		)	(197		)	(7,775		)	(1,504		)	(515		)	(674		)	(663		)	(359		)
Financing activities	2,629			994			(83		)	(756		)	42			(560		)	2,708			786			(21		)	(970		)	(82		)	(502		)

Operating Activities. The following items contributed to increased (decreased) net cash provided by operating activities for the ~~six~~nine months ended ~~June~~September 30, 2019 compared to the same period of 2018:


	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)									(in millions)
Changes in net income after adjusting for non-cash items	$	30		$	(160	)	$	117		$	136		$	(217	)	$	154
Changes in working capital	(595		)	(43		)	(242		)	(768		)	53			(311		)
Change in equity in earnings from Enable, net of distributions (1)	21			—			—			28			—			—
Changes related to discontinued operations	—			—			(118		)	—			—			(176		)
Lower pension contribution	35			—			—			(27		)	—			—
Other	(10		)	—			(54		)	38			(29		)	(4		)
	$	(519	)	$	(203	)	$	(297	)	$	(593	)	$	(193	)	$	(337	)


(1)	This change is partially offset by the change in distributions from Enable in excess of cumulative earnings in investing activities noted in the table below.

Investing Activities. The following items contributed to (increased) decreased net cash used in investing activities for the ~~six~~nine months ended ~~June~~September 30, 2019 compared to the same period of 2018:


	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)									(in millions)
Proceeds from the sale of marketable securities in 2018	$	(398	)	$	—		$	—		$	(398	)	$	—		$	—
2019 mergers and acquisitions, net of cash acquired (See Note 3 to the Interim Condensed Financial Statements)	(5,987		)	—			—			(5,991		)	—			—
Higher capital expenditures	(472		)	(73		)	(92		)	(701		)	(66		)	(135		)
Net change in notes receivable from affiliated companies	(4		)	(768		)	(66		)	—			(772		)	27
Change in distributions from Enable in excess of cumulative earnings	(30		)	—			—			(30		)	—			—
Changes related to discontinued operations	—			—			(30		)	—			—			(47		)
Other	9			(2		)	(1		)	19			(3		)	(1		)
	$	(6,882	)	$	(843	)	$	(189	)	$	(7,101	)	$	(841	)	$	(156	)

Financing Activities. The following items contributed to (increased) decreased net cash used in financing activities for the ~~six~~nine months ended ~~June~~September 30, 2019 compared to the same period of 2018:


	CenterPoint Energy			Houston Electric			CERC			CenterPoint Energy			Houston Electric			CERC
	(in millions)									(in millions)
Net changes in commercial paper outstanding	$	3,409		$	—		$	355		$	3,135		$	—		$	900
Decreased proceeds from issuances of preferred stock										(790		)	—			—
Net changes in long-term debt outstanding, excluding commercial paper	(123		)	286			(599		)	1,062			276			(599		)
Net changes in long-term revolving credit facilities	135			—			—
Net changes in debt issuance costs	26			(4		)	5			17			(4		)	5
Net changes in short-term borrowings	39			—			39			39			—			39
Distributions to ZENS note holders in 2018	16			—			—			398			—			—
Increased payment of Common Stock dividends	(48		)	—			—			(73		)	—			—
Increased payment of preferred stock dividends	(60		)	—			—			(101		)	—			—
Net change in notes payable from affiliated companies	—			59			570			—			(16		)	570
Contribution from parent	—			590			—			—			590			(600		)
Dividend to parent	—			23			108			—			23			167
Other	(9		)	(2		)	(1		)	(9		)	(1		)	(1		)
	$	3,385		$	952		$	477		$	3,678		$	868		$	481

Future Sources and Uses of Cash

The liquidity and capital requirements of the Registrants are affected primarily by results of operations, capital expenditures, debt service requirements, tax payments, working capital needs and various regulatory actions. Capital expenditures are expected to be used for investment in infrastructure. These capital expenditures are anticipated to maintain reliability and safety, increase resiliency and expand our systems through value-added projects. In addition to dividend payments on CenterPoint Energy’s Series ~~A Preferred Stock, Series~~ B Preferred Stock and Common Stock, and in addition to interest payments on debt, the Registrants’ principal anticipated cash requirements for the remaining ~~six~~three months of 2019 include the following:


	CenterPoint Energy		Houston Electric		CERC		CenterPoint Energy		Houston Electric		CERC
	(in millions)						(in millions)
Estimated capital expenditures	$	1,370	$	546	$	449	$	704	$	307	$	221
Scheduled principal payments on Securitization Bonds	216		216		—		69		69		—

For an update on CenterPoint Energy’s contractual obligations following the Merger, see Notes 12, 14 and 19 to the Interim Condensed Financial Statements.

The Registrants expect that anticipated cash needs for the remaining ~~six~~three months of 2019 will be met with borrowings under their credit facilities, bank loans, proceeds from the issuance of long-term debt, anticipated cash flows from operations, with respect to CenterPoint Energy and CERC, proceeds from commercial paper and with respect to CenterPoint Energy, distributions from Enable. Discretionary financing or refinancing may result in the issuance of equity securities of CenterPoint Energy or debt securities of the Registrants in the capital markets or the arrangement of additional credit facilities or term bank loans. 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 on acceptable terms.

Off-Balance Sheet Arrangements

Other than Houston Electric’s general mortgage bonds issued as collateral for tax-exempt long-term debt of CenterPoint Energy as discussed in Note 12, guarantees as discussed in Note 14(b) to the Interim Condensed Financial Statements and operating leases, we have no off-balance sheet arrangements.

Regulatory Matters

Houston Electric Base Rate Case (CenterPoint Energy and Houston Electric)

On April 5, 2019, and subsequently adjusted in errata filings in May and June 2019, Houston Electric filed its base rate application with the PUCT and the cities in its service area to change its rates, seeking approval for revenue increases of approximately $194 million, excluding a rider to refund approximately $40 million annually over three years discussed below. This rate filing is based on a rate base of $6.4 billion, a 50% debt, 50% equity capital structure, and a 10.4% ROE. Houston Electric last filed for a base rate increase on June 30, 2010, with a test year ending December 31, 2009. Houston Electric also requested a prudency determination on all capital investments made since January 1, 2010, the establishment of a rider to refund over three years to its customers approximately $119 million of unprotected EDIT resulting from the TCJA, updated depreciation rates and approval to clarify and update various non-rate tariff provisions. Recovery of all reasonable and necessary rate case expenses for this case and certain prior rate case proceedings were severed into a separate proceeding. A hearing was held June 24–28, 2019.

On September 16, 2019, the ALJs issued a PFD recommending a revenue increase of approximately $2.6 million based on a 55% debt, 45% equity capital structure, a 9.42% ROE, rate base reductions of approximately $350 million, operation and maintenance expense disallowances and certain “ring-fencing” measures. If the PFD were approved in its entirety, it would result, among other things, in a one-time refund obligation of capital previously recovered through Houston Electric’s TCOS and DCRF mechanisms, and a pre-tax write-off of approximately $120 million for rate base disallowance of assets recorded in CenterPoint Energy’s and Houston Electric’s Condensed Consolidated Balance Sheets as of September 30, 2019. The amount of any refunds for previously recovered capital would be determined in a separate proceeding with the PUCT. Furthermore, the PFD recommends a separate proceeding with the PUCT to determine the amount, if any, of $158 million EDIT on Houston Electric’s securitized assets to be provided to customers. Parties filed exceptions and replies to exceptions in October 2019.

A summary of the PFD impacts are as follows, assuming the issues identified in the PFD as noted in Houston Electric’s exceptions to the PFD filing with the PUCT are adjusted:



	(in millions)
Operating income impact from Houston Electric's request	$	111
PFD proposed reductions:
ROE and equity ratio	(62		)
Rate base disallowances	(25		)
Operations and maintenance expenses	(39		)
Weather normalization	(12		)
Operating income impact from PFD	$	(27	)

Total operating income change from request to PFD	$	(138	)

CenterPoint Energy and Houston Electric records pre-tax expense for disallowed capital investments and customer refund obligations when the amounts are deemed both probable and estimable.

Brazos Valley Connection Project (CenterPoint Energy and Houston Electric)

Houston Electric completed construction on and energized the Brazos Valley Connection in March 2018, ahead of the original June 1, 2018 energization date. The final capital costs of the project reported to the PUCT in December 2018 were $281 million, which was within the estimated range of approximately $270-$310 million in the PUCT’s original order. Houston Electric applied for interim recovery of project costs incurred through July 31, 2018, which were not already included in rates in a filing with the PUCT in September 2018 and received approval for interim recovery in November 2018. Final approval by the PUCT of the project costs is expected to occur in Houston Electric’s pending base rate case ~~which was filed in April 2019. A final order is expected in the fourth quarter of 2019.~~discussed above.

Bailey to Jones Creek Project (CenterPoint Energy and Houston Electric)

In April 2017, Houston Electric submitted a proposal to ERCOT requesting its endorsement of ~~a transmission project in~~ the ~~greater Freeport, Texas area, which includes enhancements~~Bailey to ~~two existing substations and the construction of a new 345 kV double-circuit line to be located in the counties of Brazoria, Matagorda and Wharton.~~Jones Creek

Project. On December 12, 2017, Houston Electric received approval from ERCOT. In September 2018, Houston Electric filed a certificate of convenience and necessity application with the PUCT that included capital cost estimates for the project that ranged from approximately $482-$695 million, which were higher than the initial cost estimates. The revised project cost estimates include additional costs associated with the routing of the line to mitigate environmental and other land use impacts and structure design to address soil and coastal wind conditions. The actual capital costs of the project will depend on those factors as well as other factors, including land acquisition costs, construction costs and the ultimate route approved by the PUCT. On the request of the PUCT, ERCOT intervened in the proceeding and performed a re-evaluation of the cost-effectiveness of the proposed project. Based on that re-evaluation, ERCOT reaffirmed the recommended transmission option for the project. An unopposed settlement agreement was filed on August 15, 2019, under which Houston Electric would construct the project at an estimated cost of approximately $483 million. Houston Electric anticipates that the PUCT will issue a final decision on the certificate of convenience and necessity application in the ~~second half~~fourth quarter of 2019.

Indiana Electric Generation Project (CenterPoint Energy)

Indiana Electric must make substantial investments in its generation resources in the near term to comply with environmental regulations. On February 20, 2018, Indiana Electric filed a petition seeking authorization from the IURC to construct a new 700-850 MW natural gas combined cycle generating facility to replace the baseload capacity of its existing generation fleet at an approximate cost of $900 million, which includes the cost of a new natural gas pipeline to serve the plant.

As a part of this same proceeding, Indiana Electric also sought recovery under Indiana Senate Bill 251 of costs to be incurred for environmental investments to be made at its F.B. Culley generating plant to comply with ELG and CCR rules. The F.B. Culley investments, estimated to be approximately $95 million, ~~will begin~~began in 2019 and will allow the F.B. Culley Unit 3 generating facility to comply with environmental requirements and continue to provide generating capacity to Indiana Electric’s customers. Under Indiana Senate Bill 251, Indiana Electric sought authority to recover 80% of the approved costs, including a return, using a tracking mechanism, with the remaining 20% of the costs deferred for recovery in Indiana Electric’s next base rate proceeding.

On April 24, 2019, the IURC issued an order approving the environmental investments proposed for the F.B. Culley generating facility, along with recovery of prior pollution control investments made in 2014. The order denied the proposed gas combined cycle generating facility. Indiana Electric will conduct a new IRP, expected to be completed in mid-2020, to identify an appropriate investment of capital in its generation fleet to satisfy the needs of its customers and comply with environmental regulations.

Indiana Electric Solar Project (CenterPoint Energy)

On February 20, 2018, Indiana Electric announced it was finalizing details to install an additional 50 MW of universal solar energy, consistent with its IRP, with a petition seeking authority to recover costs associated with the project pursuant to Indiana Senate Bill 29. Indiana Electric filed a settlement agreement with the intervening parties whereby the energy produced by the solar farm would be set at a fixed market rate over the life of the investment and recovered within Indiana Electric’s CECA mechanism. On March 20, 2019, the IURC approved the settlement. Indiana Electric reached an agreement with the other settling parties to amend the settlement agreement to ensure the project would not cause negative tax consequences. The ~~project~~amendment must be approved by the IURC. Indiana Electric has filed the amended settlement agreement with the IURC and a hearing is ~~expected~~scheduled to be ~~completed by~~held in January ~~2021.~~2020.

Rate Change Applications

The Registrants are routinely involved in rate change applications before state regulatory authorities. Those applications include general rate cases, where the entire cost of service of the utility is assessed and reset. In addition, Houston Electric is periodically involved in proceedings to adjust its capital tracking mechanisms (TCOS and DCRF) and annually files to adjust its EECRF. CERC is periodically involved in proceedings to adjust its capital tracking mechanisms in Texas (GRIP), its cost of service adjustments in Arkansas, Louisiana, Mississippi and Oklahoma (FRP, RSP, RRA and PBRC, respectively), its decoupling mechanism in Minnesota, and its energy efficiency cost trackers in Arkansas, Minnesota, Mississippi and Oklahoma (EECR, CIP, EECR and EECR, respectively). CenterPoint Energy is periodically involved in proceedings to adjust its capital tracking mechanisms in Indiana (CSIA for gas and TDSIC for Electric) and Ohio (DRR), its decoupling mechanism in Indiana (SRC for gas), and its energy efficiency cost trackers in Indiana (EEFC for gas and DSMA for electric) and Ohio (EEFR).

The table below reflects significant applications pending or completed since the Registrants’ combined 2018 Form 10-K was filed with the SEC.



Mechanism	Annual Increase (Decrease) (1) (in millions)	Filing Date	Effective Date	Approval Date	Additional Information
CenterPoint Energy and Houston Electric (PUCT)
Rate Case (1)	$155	April 2019	TBD	TBD	~~On April 5, 2019, and subsequently adjusted in errata filings in May and June 2019,~~ See discussion above under Houston Electric filed its base rate application with the PUCT and the cities in its service area to change its rates, seeking approval for base rate increases of approximately $149 million, including a rider of $(40) million discussed below, for service to retail customers and approximately $5 million for wholesale transmission service based on a test year ending December 31, 2018. This rate filing is based on a rate base of $6.4 billion and a 10.4% ROE. Houston Electric last filed for a base rate increase on June 30, 2010, with a test year ending December 31, 2009. Houston Electric also requested a prudency determination on all capital investments made since January 1, 2010, the establishment of a rider to refund over three years to its customers approximately $119 million of unprotected EDIT resulting from the TCJA, updated depreciation rates and approval to clarify and update various non-rate tariff provisions. Recovery of all reasonable and necessary rate case expenses for this case and certain prior rate case proceedings were severed into a separate proceeding. A hearing was held June 24–28, 2019, and a final order is expected in the fourth quarter of 2019.



~~Mechanism~~	~~Annual Increase (Decrease)~~ Base Rate Case~~(1)~~. ~~(in millions)~~	~~Filing~~ ~~Date~~	~~Effective Date~~	~~Approval Date~~	~~Additional Information~~
EECRF	397	May 2019	March 2020	~~TBD~~October 2019	The ~~requested amount, as amended~~PUCT issued a final order in ~~an errata filing in July~~October 2019 ~~is comprised primarily of the following: 2020 Program costs of $38 million, 2018 over~~approving recovery of ~~($6)~~2020 EECRF of $35 million, ~~and 2018 Earned bonus of~~including a $7 ~~million.~~million performance bonus.
CenterPoint Energy and CERC - Beaumont/East Texas, South Texas, Houston and Texas Coast (Railroad Commission)
GRIP	20	March 2019	July 2019	June 2019	Based on net change in invested capital of $123 million.
CenterPoint Energy and CERC - Houston and Texas Coast (Railroad Commission)
Administrative 104.111	n/a	August 2019	TBD	TBD	On August 1, 2019, and subsequent supplemental filings in August and October 2019, Houston and Texas Coast proposed a rider to refund over three years to its Houston and Texas Coast customers combined, approximately $18 million of unprotected EDIT related to the TCJA.
CenterPoint Energy and CERC - Arkansas (APSC)
FRP~~(1)~~	147	April 2019	October 2019	~~TBD~~August 2019	Based on ROE of 9.5% approved in the last rate case. On ~~July 31,~~August 23, 2019, the APSC approved a unanimous comprehensive settlement ~~was filed~~ that ~~if approved, would result~~results in an FRP revenue increase of $7 million and includes additional non-monetary items.
CenterPoint Energy and CERC - Louisiana (LPSC)
RSP(1)	3	September 2019	December 2019	TBD	Based on ROE of 9.95%.
CenterPoint Energy and CERC - Minnesota (MPUC)
CIP Financial Incentive	11	May 2019	~~TBD~~October 2019	~~TBD~~September 2019	CIP Financial Incentive based on 2018 activity.
Decoupling	n/a	September 2019	September 2019	TBD	Represents over-recovery of $21 million recorded for and during the period July 1, 2018 through June 30, 2019, partially offset by over-refund of $2 million related to the period July 1, 2017 through June 30, 2018.
Rate Case (1)	62	October 2019	TBD	TBD	Reflects a proposed 10.15% ROE on a 51.39% equity ratio. Interim rates reflecting an annual increase of $53 million requested to be effective January 1, 2020.
CenterPoint Energy and CERC - Mississippi (MPSC)
RRA (1)	2	May 2019	TBD	TBD	Based on ROE of 9.26%.
CenterPoint Energy and CERC - Oklahoma (OCC)
PBRC~~(1)~~	2	March 2019	~~TBD~~September 2019	~~TBD~~August 2019	Based on ROE of 10%. On July ~~27,~~26, 2019, the ALJ recommended that the OCC approve an increase of $2 million. ~~The~~On August 29, 2019, the OCC ~~is anticipated to issue a final order on~~approved the ~~PBRC docket in the third quarter~~ALJ-recommended revenue increase of ~~2019.~~$2 million.
CenterPoint Energy - Indiana South - Gas (IURC)
CSIA	3	October 2018	January 2019	January 2019	Requested an increase of $16 million to rate base, which reflects a $3 million annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until next rate case. The mechanism also includes refunds associated with the TCJA, resulting in a change of ~~$(2)~~$(1) million, and a change in the total (over)/under-recovery variance of ~~$(4)~~$(3) million annually.
CSIA	5	April 2019	July 2019	July 2019	Requested an increase of $22 million to rate base, which reflects a $5 million annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until the next rate case. The mechanism also includes refunds associated with the TCJA, resulting in ano change ~~of $1 million,~~to the previous credit provided, and a change in the total (over)/under-recovery variance of $3 million annually.
CSIA (1)	3	October 2019	January 2020	TBD	Requested an increase of $18 million to rate base, which reflects a $3 million annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until the next rate case. The mechanism also includes refunds associated with the TCJA, resulting in no change to the previous credit provided, and a change in the total (over)/under-recovery variance of $(0.2) million annually.



Mechanism	Annual Increase (Decrease) (1) (in millions)	Filing Date	Effective Date	Approval Date	Additional Information
CenterPoint Energy - Indiana North - Gas (IURC)
CSIA	3	October 2018	January 2019	January 2019	Requested an increase of $54 million to rate base, which reflects a $3 million annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until next rate case. The mechanism also includes refunds associated with the TCJA, resulting in a change of ~~$(10)~~$(11) million, and a change in the total (over)/under-recovery variance of ~~$(17)~~$(19) million annually.
CSIA	1312	April 2019	July 2019	July 2019	Requested an increase of $58 million to rate base, which reflects a ~~$13~~$12 million annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until next rate case. The mechanism also includes refunds associated with the TCJA, resulting in ano change ~~of $(2) million,~~to the previous credit provided, and a change in the total (over)/under-recovery variance of ~~$12~~$14 million annually.
CSIA (1)	4	October 2019	January 2020	TBD	Requested an increase of $29 million to rate base, which reflects a $4 million annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until next rate case. The mechanism also includes refunds associated with the TCJA, resulting in no change to the previous credit provided, and a change in the total (over)/under-recovery variance of $(7) million annually.
CenterPoint Energy - Ohio (PUCO)
DRR~~(1)~~	11	May 2019	September 2019	~~TBD~~August 2019	Requested an increase of $78 million to rate base for investments made in 2018, which reflects a $11 million annual increase in current revenues. A change in (over)/under-recovery variance of $(3) million annually is also included in rates. All pre-2018 investments are included in rate case request.
Rate Case~~(1)~~	23	March 2018	~~TBD~~September 2019	~~TBD~~August 2019	Settlement agreement ~~awaiting approval~~approved by PUCO Order that provides for a $23 million annual increase in current revenues. ~~Settlement agreement also includes~~Order based upon $622 million of total rate base, a 7.48% overall rate of return, and extension of conservation and DRR programs. ~~A final order is expected in the third quarter of 2019.~~
TSCR (1)	(18)	January 2019	TBD	TBD	Application to flow back to customers certain benefits from the TCJA. Initial impact reflects credits for 2018 of $(10) million and 2019 of $(8) million, with mechanism to begin ~~in conjunction with~~subsequent to new base rates.



~~Mechanism~~	~~Annual Increase (Decrease)~~ ~~(1)~~ ( Order is expected in ~~millions)~~	~~Filing~~ ~~Date~~	~~Effective Date~~	~~Approval Date~~	~~Additional Information~~the fourth quarter of 2019 or early 2020.
CenterPoint Energy - Indiana Electric (IURC)
TDSIC	3	February 2019	May 2019	May 2019	Requested an increase of $24 million to rate base, which reflects a $3 million annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until next rate case. The mechanism also includes refunds associated with the TCJA, resulting in a change of $5 million, and a change in the total (over)/under-recovery variance of $5 million annually.
TDSIC (1)	4	August 2019	November 2019	TBD	Requested an increase of $35 million to rate base, which reflects a $4 million annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until next rate case. The mechanism also includes a change in (over)/under-recovery variance of $4 million annually.
ECA - MATS	13	February 2018	January 2019	April 2019	Requested an increase of $58 million to rate base, which reflects a $13 million annual increase in current revenues. 80% of revenue requirement is included in requested rate increase and 20% is deferred until next rate case. The mechanism includes recovery of prior accounting deferrals associated with investments (depreciation, carrying costs, operating expenses).
CECA	2	February 2019	June 2019	May 2019	Requested an increase of $13 million to rate base related to solar pilot investments, which reflects a $2 million annual increase in current revenues. Additional solar investment to supply 50 MW of solar capacity is approved and will be included for recovery once completed in 2021.


(1)	Represents proposed increases (decreases) when effective date and/or approval date is not yet determined. Approved rates could differ materially from proposed rates.

Tax Reform

TCJA-related 2018 tax expense refunds are currently included in the Registrants’ existing rates and are therefore reducing the Registrants’ current annual revenue. The TCJA-related 2018 tax expense refunds for Houston Electric ~~are expected to be~~were completed in September 2019. However, in Houston Electric’s rate case filed in April 2019, and subsequently adjusted in errata filings in May and June 2019, Houston Electric is proposing to continue returning other benefits of the TCJA through a separate rider that will return approximately $119 million to customers over the next three years. The TCJA is also expected to continue to return benefits to customers through Houston Electric’s base rates by approximately $73 million per year.

CenterPoint Energy’s electric and natural gas utilities in Indiana and Ohio, which were acquired during the Merger, currently recover corporate income tax expense in approved rates charged to customers. The IURC and the PUCO both issued orders which

initiated proceedings to investigate the impact of the TCJA on utility companies and customers within Indiana and Ohio, respectively. In addition, the IURC and PUCO have ordered each utility to establish regulatory liabilities to record all estimated impacts of tax reform starting January 1, 2018 until the date when rates are adjusted to capture these impacts. In Indiana, in response to Vectren’s pre-Merger filing for proposed changes to its rates and charges to consider the impact of the lower federal income tax rates, the IURC approved an initial reduction to current rates and charges, effective June 1, 2018, to capture the immediate impact of the lower corporate federal income tax rate. The refund of ~~excess deferred taxes~~EDIT and regulatory liabilities commenced in November 2018 for Indiana electric customers and in January 2019 for Indiana gas customers. In Ohio, the initial rate reduction to current rates and charges ~~will be~~became effective upon conclusion of its pending base rate case ~~filed~~ on ~~March 30, 2018.~~August 28, 2019. In January 2019, an application was filed with PUCO in compliance with its October 2018 order requiring utilities to file for a request to adjust rates to reflect the impact of the TCJA, requesting authority to implement a rider to flow back to customers the tax benefits realized under the TCJA, including the refund of ~~excess deferred taxes~~EDIT and regulatory liabilities. CenterPoint Energy expects this proceeding to be approved in ~~conjunction with~~ the ~~pending base rate case.~~fourth quarter of 2019 or early 2020.

ELG (CenterPoint Energy)

Under the Clean Water Act, the EPA sets technology-based guidelines for water discharges from new and existing electric generation facilities. In September 2015, the EPA finalized revisions to the existing steam electric ELG setting stringent technology-based water discharge limits for the electric power industry. The EPA focused this rulemaking on wastewater generated primarily by pollution control equipment necessitated by the comprehensive air regulations, specifically setting strict water discharge limits for arsenic, mercury and selenium for scrubber waste waters. The ELG will be implemented when existing water discharge permits for the plants are renewed. In the case of Indiana Electric’s water discharge permits, in 2017 the IDEM issued final renewals for the F.B. Culley and A.B. Brown power plants. IDEM agreed that units identified for retirement by December 2023 would not be required to install new treatment technology to meet ELG, and approved a 2020 compliance date for dry bottom ash and a 2023 compliance date for flue gas desulfurization wastewater treatment standards for the remaining coal-fired unit at F.B. Culley.

On April 13, 2017, as part of the U.S. President’s Administration’s regulatory reform initiative, which is focused on the number and nature of regulations, the EPA granted petitions to reconsider the ELG rule, and indicated it would stay the current implementation deadlines in the rule during the pendency of the reconsideration. On September 13, 2017, the EPA finalized a rule postponing certain interim compliance dates by two years, but did not postpone the final compliance deadline of December 31, 2023. In April 2018, the EPA published an effluent guidelines program plan that anticipated a December 2019 rule revising the effluent limitations and pre-treatment standards for existing sources in the 2015 rule. On April 12, 2019, the U.S. Court of Appeals for the Fifth Circuit vacated and remanded portions of the ELG rule that selected impoundment as the best available technology for legacy wastewater and leachate. It is not clear what revisions to the ELG rule the EPA will implement, or what effect those revisions may have. As Indiana Electric does not currently have short-term ELG implementation deadlines in its recently renewed wastewater discharge permits, it does not anticipate immediate impacts from the EPA’s two-year extension of preliminary implementation deadlines due to the longer compliance time frames granted by IDEM and will continue to work with IDEM to evaluate further implementation plans. On November 4, 2019, the EPA released a pre-publication copy of proposed revisions to the CCR and ELG rules. CenterPoint Energy will evaluate the proposals to determine potential impacts to current compliance plans for its A.B. Brown and F.B. Culley generating stations.

CPP and ACE Rule (CenterPoint Energy)

On August 3, 2015, the EPA released its CPP Rule, which required a 32% reduction in carbon emissions from 2005 levels. The final rule was published in the Federal Register on October 23, 2015, and that action was immediately followed by litigation ultimately resulting in the U.S. Supreme Court staying implementation of the rule. On August 31, 2018, the EPA published its proposed CPP replacement rule, the ACE Rule, which was finalized on July 8, 2019 and requires states to implement a program of energy efficiency improvement targets for individual coal-fired electric generating units. States have three years to develop state plans to implement the ACE rule, and CenterPoint Energy does not expect a state ACE rule to be finalized and approved by the EPA until 2024. CenterPoint Energy is currently unable to predict the effect of a state plan to implement the ACE rule but does not anticipate that such a plan would have a material effect.

Impact of Legislative Actions & Other Initiatives (CenterPoint Energy)

At this time, compliance costs and other effects associated with reductions in GHG emissions or obtaining renewable energy sources remain uncertain. While the requirements of a state ACE rule remain uncertain, Indiana Electric will continue to monitor regulatory activity regarding GHG emission standards that may affect its electric generating units.

FERC Revised Policy Statement (CenterPoint Energy and CERC)

The regulation of midstream energy infrastructure assets has a significant impact on Enable’s business. For example, Enable’s interstate natural gas transportation and storage assets are subject to regulation by the FERC under the Natural Gas Act. In March 2018, the FERC announced a Revised Policy Statement stating that it would no longer allow pipelines organized as a master limited partnership to recover an income tax allowance in their cost-of-service rates. In July 2018, the FERC issued new regulations which required all FERC-regulated natural gas pipelines to make a one-time Form No. 501-G filing providing certain financial information. In October 2018, Enable Gas Transmission, LLC filed its Form No. 501-G and filed a statement that it intended to take no other action. On March 8, 2019, the FERC terminated the 501-G proceeding and required no other action. MRT did not file a FERC Form No. 501-G because it had filed a general rate case in June 2018. In July 2018, the FERC issued an order accepting MRT’s proposed rate increases subject to refund upon a final determination of MRT’s rates and ordering MRT to refile its rate case to reflect the elimination of an income tax allowance in its cost-of-service rates. On August 30, 2018, MRT submitted a supplemental filing to comply with the FERC’s order. MRT has appealed the FERC’s order to eliminate the income tax allowance in its cost-of-service rates. The FERC set MRT’s ~~refiled~~re-filed rate case for ~~hearing~~hearing. The procedural schedule has been suspended to ~~begin in January 2020.~~afford MRT time to file a settlement. If a settlement is not filed or all of the participants do not agree to a settlement, then the proceeding may advance to hearing.

Other Matters

Credit Facilities

The Registrants may draw on their respective revolving credit facilities from time to time to provide funds used for general corporate and limited liability company purposes, including to backstop CenterPoint Energy’s and CERC’s commercial paper programs. The facilities may also be utilized to obtain letters of credit. For further details related to the Registrants’ revolving credit facilities, please see Note 12 to the Interim Condensed Financial Statements.

Based on the consolidated debt to capitalization covenant in the Registrants’ revolving credit facilities, the Registrants would have been permitted to utilize the full capacity of such revolving credit facilities, which aggregated approximately $5.1 billion as of ~~June~~September 30, 2019. As of ~~July 26,~~October 25, 2019, the Registrants had the following revolving credit facilities and utilization of such facilities:


			Amount Utilized as of July 26, 2019										Amount Utilized as of October 25, 2019
Registrant	Size of Facility		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate	Termination Date	Size of Facility		Loans		Letters of Credit		Commercial Paper		Weighted Average Interest Rate	Termination Date
	(in millions)										(in millions)
CenterPoint Energy ~~(1)~~	$	3,300	$	—	$	6	$	2,101	2.57%	March 3, 2022	$	3,300	$	—	$	6	$	1,412	2.14%	March 3, 2022
CenterPoint Energy ~~(2)~~(1)	400		—		—		314		2.54%	July 14, 2022	400		—		—		282		2.08%	July 14, 2022
CenterPoint Energy ~~(3)~~(2)	200		135		—		—		3.51%	July 14, 2022	200		—		—		—		—%	July 14, 2022
Houston Electric	300		—		4		—		—%	March 3, 2022	300		—		—		—		—%	March 3, 2022
CERC	900		—		1		285		2.54%	March 3, 2022	900		—		1		320		2.08%	March 3, 2022
Total	$	5,100	$	135	$	11	$	2,700			$	5,100	$	—	$	7	$	2,014

(1)

Approximately $1.7 billion of outstanding commercial paper was issued to refinance commercial paper used to fund a portion of the cash consideration for the Merger, pay related fees and expenses, pay Vectren’s stub period cash dividend and long-term incentive payments and repay indebtedness of Vectren subsidiaries redeemed at the option of the holder as a result of the closing of the Merger. CenterPoint Energy expects to refinance or otherwise fund the repayment of maturing commercial paper through its sources of cash described in “—Liquidity and Capital Resources—Future Sources and Uses of Cash.”


~~(2)~~	The credit facility was issued by VUHI and is guaranteed by SIGECO, Indiana Gas and VEDO.


~~(3)~~(2)	The credit facility was issued by VCC and is guaranteed by Vectren.

Borrowings under each of the revolving credit facilities are subject to customary terms and conditions. However, there is no requirement that the borrower makes representations prior to borrowing 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 revolving credit facilities are subject to acceleration upon the occurrence of events of default that we consider customary. The revolving credit 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 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 their respective revolving credit facilities.

Long-term Debt

For detailed information about the Registrants’ debt transactions in 2019, see Note 12 to the Interim Condensed Financial Statements.

Securities Registered with the SEC

On January 31, 2017, the Registrants filed a joint shelf registration statement with the SEC, as amended on September 24, 2018, registering indeterminate principal amounts of Houston Electric’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 shares of Common Stock, shares of preferred stock, depositary shares, as well as stock purchase contracts and equity units. The joint shelf registration statement will expire on January 31, 2020. For information related to the Registrants’ debt securities issuances to date in 2019, see Note 12 to the Interim Condensed Financial Statements.

Temporary Investments

As of ~~July 26,~~October 25, 2019, the Registrants had no temporary investments.

Money ~~Pool~~Pools

The Registrants participate in a money ~~pool~~pools through which they and certain of their 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 CenterPoint Energy money pool are expected to be met with borrowings under CenterPoint Energy’s revolving credit facility or the sale of CenterPoint Energy’s commercial paper. The net funding requirements of the CERC money pool are expected to be met with borrowings under CERC’s revolving credit facility or the sale of CERC’s commercial paper. The money pools may not provide sufficient funds to meet the Registrants’ cash needs.

The table below summarizes CenterPoint Energy money pool activity by Registrant as of ~~July 26,~~October 25, 2019:

Weighted Average Interest Rate Houston Electric CERC
(in millions)
Money pool investments 2.60% $ 778
$ 180



	Weighted Average Interest Rate	Houston Electric		CERC
		(in millions)
Money pool investments	2.17%	$	789	$	—

Impact on Liquidity of a Downgrade in Credit Ratings

The interest on borrowings under the credit facilities is based on each respective borrower’s credit ratings. On October 25, 2019, Moody’s downgraded VUHI’s and Indiana Gas’ senior unsecured debt rating to A3 from A2 and SIGECO’s senior secured debt rating to A1 from Aa3. The outlooks of VUHI, Indiana Gas and SIGECO were revised to stable from negative. As of ~~July 26,~~October 25, 2019, Moody’s, S&P and Fitch had assigned the following credit ratings to the borrowers:

Moody’s

S&P

Fitch

Registrant

Borrower/Instrument

Rating

Outlook (1)

Rating

Outlook (2)

Rating

Outlook (3)

CenterPoint Energy

CenterPoint Energy Senior Unsecured Debt

Baa2

Stable

BBB

Stable

BBB

Stable

CenterPoint Energy

Vectren Corp. Issuer Rating

n/a

BBB+

Stable

n/a

CenterPoint Energy

VUHI Senior Unsecured Debt

A2A3

~~Negative~~Stable

BBB+

Stable

n/a

CenterPoint Energy

Indiana Gas Senior Unsecured Debt

A2A3

~~Negative~~Stable

BBB+

Stable

n/a

CenterPoint Energy

SIGECO Senior Secured Debt

~~Aa3~~A1

~~Negative~~Stable

Stable

n/a

Houston Electric

Houston Electric Senior Secured Debt

Negative

Stable

A+

Stable

CERC

CERC Corp. Senior Unsecured Debt

Baa1

Positive

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 outlook assesses the potential direction of a long-term credit rating over the intermediate to longer term.


(3)	A Fitch rating outlook indicates the direction a rating is likely to move over a one- to two-year period.

The Registrants cannot assure that the ratings set forth above will remain in effect for any given period of time or that one or more of these ratings will not be lowered or withdrawn entirely by a rating agency. The Registrants note that these credit ratings are included for informational purposes and are not recommendations to buy, sell or hold the Registrants’ 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 the Registrants’ credit ratings could have a material adverse impact on the Registrants’ ability to obtain short- and long-term financing, the cost of such financings and the execution of the Registrants’ commercial strategies.

A decline in credit ratings could increase borrowing costs under the Registrants’ revolving credit facilities. If the Registrants’ credit ratings had been downgraded one notch by ~~each of the three principal credit rating agencies~~S&P and Moody’s from the ratings that existed as of ~~June~~September 30, 2019, the impact on the borrowing costs under the five revolving 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 the Registrants’ ability to complete capital market transactions and to access the commercial paper market. Additionally, a decline in credit ratings could increase cash collateral requirements and reduce earnings of CenterPoint Energy’s and CERC’s Natural Gas Distribution and Energy Services reportable segments.

CES, operating in the Energy Services reportable segment, provides natural gas sales and services primarily to commercial and industrial customers and electric and natural gas utilities throughout the United States. To economically hedge its exposure to natural gas prices, CES uses derivatives with provisions standard for the industry, including those pertaining to 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. Similarly, mark-to-market exposure offsetting and exceeding the credit threshold may cause the counterparty to provide collateral to CES. As of ~~June~~September 30, 2019, the amount posted by CES as collateral aggregated approximately ~~$49~~$69 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. CenterPoint Energy and CERC estimate that as of ~~June~~September 30, 2019, unsecured credit limits extended to CES by counterparties aggregated ~~$367~~$467 million, and ~~less than $1 million~~none 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 might need to provide cash or other collateral of as much as ~~$192~~$165 million as of ~~June~~September 30, 2019. The amount of collateral will depend on seasonal variations in transportation levels.

ZENS and Securities Related to ZENS (CenterPoint Energy)

If CenterPoint Energy’s creditworthiness were to drop such that ZENS holders thought its liquidity was adversely affected or the market for the ZENS were to become illiquid, some ZENS holders might decide to exchange their ZENS for cash. Funds for the payment of cash upon exchange could be obtained from the sale of the shares of ZENS-Related Securities that CenterPoint Energy owns or from other sources. CenterPoint Energy owns shares of ZENS-Related Securities equal to approximately 100% of the reference shares used to calculate its obligation to the holders of the ZENS. ZENS exchanges result in a cash outflow because tax deferrals related to the ZENS and shares of ZENS-Related Securities would typically cease when ZENS are exchanged or otherwise retired and shares of ZENS-Related Securities are sold. The ultimate tax liability related to the ZENS 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 or exchange of the ZENS. If all ZENS had been exchanged for cash on ~~June~~September 30, 2019, deferred taxes of approximately $432 million would have been payable in 2019. If all the ZENS-Related Securities had been sold on ~~June~~September 30, 2019, capital gains taxes of approximately ~~$121~~$133 million would have been payable in 2019 based on 2019 tax rates in effect. For additional information about ZENS, see Note 11 to the Interim Condensed Financial Statements.

Cross Defaults

Under each of CenterPoint Energy’s, Houston Electric’s and CERC’s respective revolving credit facilities, as well as under CenterPoint Energy’s term loan agreement, a payment default on, or a non-payment default that permits acceleration of, any indebtedness for borrowed money and certain other specified types of obligations (including guarantees) exceeding $125 million by the borrower or any of their respective significant subsidiaries will cause a default under such borrower’s respective credit

facility or term loan agreement. A default by CenterPoint Energy would not trigger a default under its subsidiaries’ debt instruments or revolving credit facilities.

Under each of VUHI’s and VCC’s respective revolving credit facilities and term loan agreements, a payment default on, or a non-payment default that permits acceleration of, any indebtedness for borrowed money and certain other specified types of obligations (including guarantees) exceeding $50 million by the borrower, any of their respective subsidiaries or any of the respective guarantors of a credit facility or term loan agreement will cause a default under such borrower’s respective credit facility or term loan agreement.

Possible Acquisitions, Divestitures and Joint Ventures

From time to time, the Registrants consider the acquisition or the disposition of assets or businesses or possible joint ventures, strategic initiatives 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. The Registrants 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 the Registrants 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.

CenterPoint Energy previously disclosed that it may reduce its ownership in Enable over time through sales in the public equity markets, or otherwise, of the Enable common units it holds, subject to market conditions. CenterPoint Energy has no intention to reduce its ownership of Enable common units and currently plans to hold such Enable common units and to utilize any cash

distributions received on such Enable common units to finance a portion of CenterPoint Energy’s capital expenditure program. CenterPoint Energy may consider or alter its plans or proposals in respect of any such plans in the future.

Enable Midstream Partners ~~(CenterPoint~~(CenterPoint Energy and CERC)

In September 2018, CERC completed the Internal Spin, after which CERC’s equity investment in Enable met the criteria for discontinued operations classification. As a result, the operations have been classified as Income from discontinued operations, net of tax, in CERC’s Condensed Statements of Consolidated Income for the periods presented. For further information, see Note 9 to the Interim Condensed Financial Statements.

CenterPoint Energy receives quarterly cash distributions from Enable on its common units and Enable Series A Preferred Units. A reduction in the cash distributions CenterPoint Energy receives from Enable could significantly impact CenterPoint Energy’s liquidity. For additional information about cash distributions from Enable, see Notes 9 and 21 to the Interim Condensed Financial Statements.

Hedging of Interest Expense

From time to time, the Registrants may enter into interest rate agreements to hedge, in part, volatility in the U.S. treasury rates by reducing variability in cash flows related to interest payments. For further information, see Note 7(a) to the Interim Condensed Financial Statements.

Weather Hedge (CenterPoint Energy and CERC)

CenterPoint Energy and CERC have historically entered into partial weather hedges for certain NGD jurisdictions and electric operations’ Texas service territory to mitigate the impact of fluctuations from normal weather. CenterPoint Energy and CERC remain exposed to some weather risk as a result of the partial hedges. For more information about weather hedges, see Note 7(a) to the Interim Condensed Financial Statements.

Collection of Receivables from REPs (CenterPoint Energy and Houston Electric)

Houston Electric’s receivables from the distribution of electricity are collected from REPs that supply the electricity Houston Electric distributes to their customers. Before conducting business, a REP must register with the PUCT and must meet certain financial qualifications. Nevertheless, adverse economic conditions, structural problems in the market served by ERCOT or financial difficulties of one or more REPs could impair the ability of these REPs to pay for Houston Electric’s services or could cause them to delay such payments. Houston Electric depends on these REPs to remit payments on a timely basis, and any delay or default in payment by REPs could adversely affect Houston Electric’s cash flows. In the event of a REP’s default, Houston Electric’s tariff provides a number of remedies, including the option for Houston Electric to request that the PUCT suspend or revoke the certification of the REP. Applicable regulatory provisions require that customers be shifted to another REP or a provider

of last resort if a REP cannot make timely payments. However, Houston Electric remains at risk for payments related to services provided prior to the shift to the replacement REP or the provider of last resort. If a REP were unable to meet its obligations, it could consider, among various options, restructuring under the bankruptcy laws, in which event such REP might seek to avoid honoring its obligations and claims might be made against Houston Electric involving payments it had received from such REP. If a REP were to file for bankruptcy, Houston Electric may not be successful in recovering accrued receivables owed by such REP that are unpaid as of the date the REP filed for bankruptcy. However, PUCT regulations authorize utilities, such as Houston Electric, to defer bad debts resulting from defaults by REPs for recovery in future rate cases, subject to a review of reasonableness and necessity.

Other Factors that Could Affect Cash Requirements

In addition to the above factors, the Registrants’ liquidity and capital resources could be affected by:

cash collateral requirements that could exist in connection with certain contracts, including weather hedging arrangements, and natural gas purchases, natural gas price and natural gas storage activities of CenterPoint Energy’s and CERC’s Natural Gas Distribution and Energy Services reportable segments;

acceleration of payment dates on certain gas supply contracts, under certain circumstances, as a result of increased natural gas prices and concentration of natural gas suppliers (CenterPoint Energy and CERC);

increased costs related to the acquisition of natural gas (CenterPoint Energy and CERC);

increases in interest expense in connection with debt refinancings and borrowings under credit facilities or term loans;

various legislative or regulatory actions;

incremental collateral, if any, that may be required due to regulation of derivatives (CenterPoint Energy and CERC);

the ability of REPs, including REP affiliates of NRG and Vistra Energy Corp., formerly known as TCEH Corp., to satisfy their obligations to CenterPoint Energy and Houston Electric;

slower customer payments and increased write-offs of receivables due to higher natural gas prices or changing economic conditions (CenterPoint Energy and CERC);

the satisfaction of any obligations pursuant to guarantees;

the outcome of litigation;

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 the Registrants’ combined 2018 Form 10-K. and in Item 1A of Part II of this Form 10-Q.

Certain Contractual Limits on Our Ability to Issue Securities and Borrow Money

Houston Electric has contractually agreed that it will not issue additional first mortgage bonds, subject to certain exceptions. For information about the total debt to capitalization financial covenants in the Registrants’ and certain of CenterPoint Energy’s subsidiaries’ revolving credit facilities, see Note 12 to the Interim Condensed Financial Statements.

CRITICAL ACCOUNTING POLICIES

Impairment of Goodwill

CenterPoint Energy and CERC perform the annual goodwill impairment test in the third quarter of each year and additional tests are performed if events or circumstances indicate that a potential goodwill impairment may exist. A reporting unit is an operating segment or one level below an operating segment (a component) and is the level at which goodwill is tested for impairment. CenterPoint Energy’s reporting units approximate its applicable reportable segments with the exception of ESG, which is a separate

reporting unit, but is included in CenterPoint Energy’s Corporate and Other reportable segment for segment reporting purposes. CERC’s reporting units approximate its reportable segments.

Fair value is the amount at which the asset could be bought or sold in a current transaction between willing parties and may be estimated using a number of techniques, including quoted market prices or valuations by third parties, present value techniques based on estimates of cash flows, or multiples of earnings or revenue performance measures. The fair value of the asset could be different using different estimates and assumptions in these valuation techniques.

The determination of fair value requires significant assumptions by management which are subjective and forward-looking in nature. To assist in deriving these assumptions, CenterPoint Energy and CERC utilized a third-party valuation specialist in both determining and testing key assumptions used in the valuation of each of its reporting units. CenterPoint Energy and CERC based their assumptions on projected financial information that they believe are reasonable; however, actual results may differ materially from those projections. These projected cash flows factor into planned growth initiatives, and for certain reporting units, the regulatory environment.

CenterPoint Energy and CERC completed their 2019 annual goodwill impairment test as of July 1, 2019 and determined, based on an income approach or a weighted combination of income and market approaches, that no goodwill impairment charge was required for any reporting unit. The fair values of each reporting unit significantly exceeded the carrying value of the reporting unit with the exception of CenterPoint Energy’s Infrastructure Services and ESG reporting units. Infrastructure Services’ fair value exceeded its carrying values by 6% and it had total goodwill of $355 million. ESG’s fair value exceeded its carrying value by 8% and had total goodwill of $127 million. These reporting units are comprised entirely of recent acquired businesses, where assets and liabilities were adjusted to fair value and as a result, carrying values approximate fair value. These reporting units have a greater risk of future impairment if their operations were to experience a decline or if market rates were to increase.

Additionally, CenterPoint Energy’s measurement period for the acquisition of Vectren remains open as of September 30, 2019 and is expected to conclude by December 31, 2019. The goodwill assigned to these reporting units as of the testing date is preliminary and subject to change. See Note 3 to the Registrants Interim Condensed Financial Statements for a discussion of CenterPoint Energy’s valuation analysis of Vectren post-Merger.

NEW ACCOUNTING PRONOUNCEMENTS

See Note 2 to the Interim Condensed Financial Statements, incorporated herein by reference, for a discussion of new accounting pronouncements that affect the Registrants.


Item 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Houston Electric and CERC meet the conditions specified in General Instruction H(1)(a) and (b) to Form 10-Q and are therefore permitted to use the reduced disclosure format for wholly-owned subsidiaries of reporting companies. Accordingly, Houston Electric and CERC have omitted from this report the information called for by Item 3 (Quantitative and Qualitative Disclosures About Market Risk) of Part I of the Form 10-Q.

Interest Rate Risk (CenterPoint Energy)

As of ~~June~~September 30, 2019, CenterPoint Energy had outstanding long-term debt, lease obligations and obligations under its ZENS that subject it to the risk of loss associated with movements in market interest rates.

CenterPoint Energy’s floating rate obligations aggregated ~~$4.4~~$3.6 billion and $210 million as of ~~June~~September 30, 2019 and December 31, 2018, respectively. If the floating interest rates were to increase by 10% from ~~June~~September 30, 2019 rates, CenterPoint Energy’s combined interest expense would increase by approximately ~~$13~~$9 million annually.

As of ~~June~~September 30, 2019 and December 31, 2018, CenterPoint Energy had outstanding fixed-rate debt (excluding indexed debt securities) aggregating ~~$10.2~~$11.3 billion and $9.0 billion, respectively, in principal amount and having a fair value of $~~11.1~~12.4 billion and $9.2 billion, respectively. Because these instruments are fixed-rate, they do not expose CenterPoint Energy 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 ~~$328~~$346 million if interest rates were to decline by 10% from levels at ~~June~~September 30, 2019. In general, such an increase in fair value would impact earnings and cash flows only if CenterPoint Energy 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 $2221 million as of ~~June~~September 30, 2019 was a fixed-rate obligation and, therefore, did not expose CenterPoint Energy to the risk of loss in ~~earnings~~

earnings due to changes in market interest rates. However, the fair value of the debt component would increase by approximately $3 million if interest rates were to decline by 10% from levels at ~~June~~September 30, 2019. Changes in the fair value of the derivative component, a ~~$755~~$817 million recorded liability at ~~June~~September 30, 2019, are recorded in CenterPoint Energy’s Condensed Statements of Consolidated Income and, therefore, it is 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 ~~June~~September 30, 2019 levels, the fair value of the derivative component liability would decrease by approximately $1 million, which would be recorded as an unrealized gain in CenterPoint Energy’s Condensed Statements of Consolidated Income.

Equity Market Value Risk (CenterPoint Energy)

CenterPoint Energy is exposed to equity market value risk through its ownership of 10.2 million shares of AT&T Common and 0.9 million shares of Charter Common, which CenterPoint Energy holds to facilitate its ability to meet its obligations under the ZENS. See Note 11 to the condensed consolidated financial statements for a discussion of CenterPoint Energy’s ZENS obligation. Changes in the fair value of the ZENS-Related Securities held by CenterPoint Energy are expected to substantially offset changes in the fair value of the derivative component of the ZENS. A decrease of 10% from the ~~June~~September 30, 2019 aggregate market value of these shares would result in a net loss of less than $1 million, which would be recorded as an unrealized loss in CenterPoint Energy’s Condensed Statements of Consolidated Income.

Commodity Price Risk From Non-Trading Activities (CenterPoint Energy)

CenterPoint Energy uses derivative instruments as economic hedges to offset the commodity price exposure inherent in its Energy Services business. The commodity risk created by these instruments, including the offsetting impact on the market value of natural gas inventory, is described below. CenterPoint Energy measures this commodity risk using a sensitivity analysis. For purposes of this analysis, CenterPoint Energy estimates commodity price risk by applying a $0.50 change in the forward NYMEX price to its net open fixed price position (including forward fixed price physical contracts, natural gas inventory and fixed price financial contracts) at the end of each period. As of ~~June~~September 30, 2019, the recorded fair value of CenterPoint Energy’s non-trading energy derivatives was a net asset of ~~$74~~$72 million (before collateral), all of which is related to the Energy Services reportable segment. A $0.50 change in the forward NYMEX price would have had a combined impact of $13 million on CenterPoint Energy’s non-trading energy derivatives net asset and the market value of natural gas inventory.

Commodity price risk is not limited to changes in forward NYMEX prices. Variation of commodity pricing between the different indices used to mark to market portions of Energy Services’ natural gas inventory (Gas Daily) and the related fair value hedge (NYMEX) can result in volatility to CenterPoint Energy’s net income. Over time, any gains or losses on the sale of storage gas inventory would be offset by gains or losses on the fair value hedges.

CenterPoint Energy’s regulated operations in Indiana have limited exposure to commodity price risk for transactions involving purchases and sales of natural gas, coal and purchased power for the benefit of retail customers due to current state regulations, which, subject to compliance with those regulations, allow for recovery of the cost of such purchases through natural gas and fuel cost adjustment mechanisms. CenterPoint Energy’s utility natural gas operations in Indiana have regulatory authority to lock in pricing for up to 50% of annual natural gas purchases using arrangements with an original term of up to 10 years. This authority has been utilized to secure fixed price natural gas using both physical purchases and financial derivatives. As of ~~June~~September 30, 2019, the recorded fair value of non-trading energy derivative liabilities was ~~$17~~$20 million for CenterPoint Energy’s utility natural gas operations in Indiana, which is offset by a regulatory asset.

Although CenterPoint Energy’s regulated operations are exposed to limited commodity price risk, natural gas and coal prices have other effects on working capital requirements, interest costs, and some level of price-sensitivity in volumes sold or delivered. Constructive regulatory orders, such as those authorizing lost margin recovery, other innovative rate designs and recovery of unaccounted for natural gas and other natural gas-related expenses, also mitigate the effect natural gas costs may have on CenterPoint Energy’s financial condition. In 2008, the PUCO approved an exit of the merchant function in CenterPoint Energy’s Ohio natural gas service territory, allowing Ohio customers to purchase substantially all natural gas directly from retail marketers rather than from CenterPoint Energy.


Item 4.	CONTROLS AND PROCEDURES

In accordance with Exchange Act Rules 13a-15 and 15d-15, the Registrants carried out separate evaluations, under the supervision and with the participation of each company’s management, including the principal executive officer and principal financial officer, of the effectiveness of the disclosure controls and procedures as of the end of the period covered by this report. Based on those evaluations, the principal executive officer and principal financial officer, in each case, concluded that the disclosure controls and procedures were effective as of ~~June~~September 30, 2019 to provide assurance that information required to be disclosed in the reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods ~~specified~~

specified in the SEC’s rules and forms and such information is accumulated and communicated to management, including the principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding disclosure.

On the Merger Date, CenterPoint Energy completed the acquisition of Vectren. CenterPoint Energy is currently in the process of evaluating the control environment and implementing CenterPoint Energy’s internal control structure over the acquired operations. This effort is expected to continue through 2019. With the exception of the implementation of the Vectren acquisition into CenterPoint Energy’s control structure, there has been no change in the Registrants’ internal controls over financial reporting that occurred during the three months ended ~~June~~September 30, 2019 that has materially affected, or is reasonably likely to materially affect, the Registrants’ internal controls over financial reporting.

PART II. OTHER INFORMATION


Item 1.	LEGAL PROCEEDINGS

For a description of certain legal and regulatory proceedings, please read Note 14(c) to the 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” and “— 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 the Registrants’ combined 2018 Form 10-K.


Item 1A.	RISK FACTORS

~~There~~Other than with respect to the risk factor set forth below, which pertains to CenterPoint Energy and Houston Electric, there have been no material changes from the risk factors disclosed in ~~the Registrants’~~our combined 2018 Form 10-K.

The outcome of the pending Houston Electric rate case, including the imposition of any “ring-fencing” measures, could adversely affect CenterPoint Energy’s and Houston Electric’s reputation, cash flows, credit quality, financial condition and results of operations and may result in a delay or denial of the ability to earn an expected return on invested capital and fully recover costs as well as the degradation in credit metrics resulting in downgrades at one or more credit rating agencies

In Houston Electric’s pending rate case, the ALJs at the Texas State Office of Administrative Hearings have recommended in their PFD, among other items, various rate base disallowances, a reduction in allowed return on equity, reductions to operation and maintenance expenses and a change to Houston Electric’s proposed capital structure. If the PFD were to be approved and adopted in its entirety, the PFD would result in an operating income reduction of $155 million, or, assuming certain issues identified in the PFD (as noted in Houston Electric’s exceptions to the PFD filing with the PUCT) are adjusted, $138 million, from Houston Electric’s request. This equates to a $27 million operating income reduction to CenterPoint Energy’s and Houston Electric’s current rates in place. Additionally, CenterPoint Energy and Houston Electric would expect to incur a pre-tax write-off of approximately $120 million and a one-time refund obligation of capital recovered from TCOS and DCRF mechanisms. The PFD recommends a separate proceeding with the PUCT to determine the amount, if any, of $158 million EDIT on securitized assets to be provided to customers. Furthermore, the PFD recommendations, if approved and adopted by the PUCT, would result in significant reduction in CenterPoint Energy’s and Houston Electric’s funds from operations, or FFO, as calculated by rating agencies, and potentially degrade CenterPoint Energy’s and Houston Electric’s credit metrics. The resulting decrease in cash flows from these recommendations and proposals, if approved and adopted by the PUCT, would potentially result in the degradation of CenterPoint Energy’s and Houston Electric’s credit quality, which may lead to downgrades at one or more credit rating agencies. Such downgrades, in turn, could increase the cost of capital for CenterPoint Energy and Houston Electric, among other potential effects.

If the PUCT were to adopt all these recommendations, the negative implications to CenterPoint Energy’s and Houston Electric’s cash flows, credit quality and cost of capital could affect their ability to recover capital investments, meet PUCT reliability thresholds, and maintain their current high level of operational and customer service performance. Additionally, the recommendations in the PFD include certain “ring-fencing” measures to increase Houston Electric’s financial separateness from CenterPoint Energy and to purportedly mitigate the risk that Houston Electric would be harmed in the event of a bankruptcy or other adverse financial development affecting CenterPoint Energy. These recommendations included ordering Houston Electric to:

limit its payment of dividends to an amount not to exceed its net income (as determined in accordance with GAAP);

work to ensure that its credit ratings at all three major ratings agencies (S&P, Moody’s, and Fitch) remain at or above Houston Electric’s current credit ratings and, if Houston Electric’s credit rating at any one of the three major ratings agencies were to fall below BBB+ (or its equivalent) for Houston Electric’s senior secured debt, be required to suspend

payment of dividends or other distributions, except for contractual tax payments, until otherwise allowed by the PUCT; and

ensure that its debt to equity ratio is at or below the debt-to-equity ratio established from time to time by the PUCT for ratemaking purposes in Houston Electric rate proceedings.

These recommended ring-fencing measures, if ordered by the PUCT, could, among other things, cause Houston Electric to:

exceed its authorized equity levels in its authorized capital structure by limiting or prohibiting Houston Electric’s ability to true-up its capital structure through distributions to CenterPoint Energy;

be prohibited from participating in the CenterPoint Energy money pool, thereby increasing Houston Electric’s cost of capital and reducing Houston Electric’s return on short term investments;

realize increased administrative expenses due to increased separateness requirements and less ability to use shared services; and

in conjunction with the ALJs’ other recommendations in their PFD, suffer downgrades at one or more credit rating agencies, thereby increasing Houston Electric’s cost of capital.

The recommendations in the PFD described above (including the ring-fencing measures), if ordered by the PUCT, could adversely affect CenterPoint Energy’s and Houston Electric’s reputation, cash flows, credit quality, financial condition and results of operations.


Item 6.	EXHIBITS

Exhibits filed herewith are designated by a cross (+); all exhibits not so designated are incorporated by reference to a prior filing as indicated. 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 the Registrants, any other persons, any state of affairs or other matters.

Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, the Registrants have 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 the Registrants and its subsidiaries on a consolidated basis. The Registrants hereby agree 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

CenterPoint Energy

Houston Electric

CERC

2.1*

Agreement and Plan of Merger, dated as of April 21, 2018, by and among Vectren Corporation, CenterPoint Energy, Inc. and Pacer Merger Sub, Inc.

CenterPoint Energy’s Form 8-K dated April 21, 2018

1-31447

2.1

3.1

Restated Articles of Incorporation of CenterPoint Energy

CenterPoint Energy’s Form 8-K dated July 24, 2008

1-31447

3.2

Restated Certificate of Formation of Houston Electric

Houston Electric’s Form 10-Q for the quarter ended June 30, 2011

1-3187

3.1

3.3

Certificate of Incorporation of RERC Corp.

CERC Form 10-K for the year ended December 31, 1997

1-13265

3(a)(1)

3.4

Certificate of Merger merging former NorAm Energy Corp. with and into HI Merger, Inc. dated August 6, 1997

CERC Form 10-K for the year ended December 31, 1997

1-13265

3(a)(2)

3.5

Certificate of Amendment changing the name to Reliant Energy Resources Corp.

CERC Form 10-K for the year ended December 31, 1998

1-13265

3(a)(3)

3.6

Certificate of Amendment changing the name to CenterPoint Energy Resources Corp.

CERC Form 10-Q for the quarter ended June 30, 2003

1-13265

3(a)(4)



Exhibit Number	Description	Report or Registration Statement	SEC File or Registration Number	Exhibit Reference	CenterPoint Energy	Houston Electric	CERC
3.7	Third Amended and Restated Bylaws of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated February 21, 2017	1-31447	3.1	x
3.8	Amended and Restated Limited Liability Company Agreement of Houston Electric	Houston Electric’s Form 10-Q for the quarter ended June 30, 2011	1-3187	3.2		x
3.9	Bylaws of RERC Corp.	CERC Form 10-K for the year ended December 31, 1997	1-13265	3(b)			x
3.10	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)	x
3.11	Statement of Resolution Establishing Series of Shares Designated Series A Fixed-to-Floating Rate Cumulative Redeemable Preferred Stock of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated August 22, 2018	1-31447	3.1	x
3.12	Statement of Resolution Establishing Series of Shares designated 7.00% Series B Mandatory Convertible Preferred Stock of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated September 25, 2018	1-31447	3.1	x
4.1	Form of CenterPoint Energy Stock Certificate	CenterPoint Energy’s Registration Statement on Form S-4	3-69502	4.1	x
4.2	Form of Certificate representing the Series A Fixed-to-Floating Rate Cumulative Redeemable Preferred Stock of CenterPoint Energy	CenterPoint Energy’s Form 8-K dated August 22, 2018	1-31447	4.1	x
4.3	Form of Certificate representing the 7.00% Series B Mandatory Convertible Preferred Stock of CenterPoint Energy (included as Exhibit A to Exhibit 3.12)	CenterPoint Energy’s Form 8-K dated September 25, 2018	1-31447	4.1	x
4.4	Deposit Agreement, dated as of October 1, 2018, among CenterPoint Energy and Broadridge Corporate Issuer Solutions, Inc., as Depositary, and the holders from time to time of the Depositary Receipts described therein	CenterPoint Energy’s Form 8-K dated September 25, 2018	1-31447	4.2	x
4.5	Form of Depositary Receipt for the Depositary Shares (included as Exhibit A to Exhibit 4.4)	CenterPoint Energy’s Form 8-K dated September 25, 2018	1-31447	4.3	x
4.6	$1,600,000,000 Credit Agreement, dated as of March 3, 2016, among CenterPoint Energy, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated March 3, 2016	1-31447	4.1	x
4.7	$300,000,000 Credit Agreement, dated as of March 3, 2016, among Houston Electric, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated March 3, 2016	1-31447	4.2	x	x
4.8	$600,000,000 Credit Agreement, dated as of March 3, 2016, among CERC Corp., as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated March 3, 2016	1-31447	4.3	x		x
4.9	First Amendment to Amended and Restated Credit Agreement, dated as of June 16, 2017, by and among CenterPoint Energy, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated June 16, 2017	1-31447	4.1	x
4.10	Second Amendment to Amended and Restated Credit Agreement, dated as of May 25, 2018, by and among CenterPoint Energy, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated May 25, 2018	1-31447	4.1	x
4.11	First Amendment to Credit Agreement, dated as of June 16, 2017, among Houston Electric, as Borrower, and the banks named therein	CenterPoint Energy’s Form 8-K dated June 16, 2017	1-31447	4.2	x	x

Exhibit

Number

Description

Report or Registration

Statement

SEC File or

Registration

Number

Exhibit

Reference

CenterPoint Energy

Houston Electric

CERC

Description

Report or Registration

Statement

SEC File or

Registration

Number

Exhibit

Reference

CenterPoint Energy

Houston Electric

CERC

4.12

First Amendment to Credit Agreement, dated as of June 16, 2017, among CERC Corp., as Borrower, and the banks named therein

CenterPoint Energy’s Form 8-K dated June 16, 2017

1-31447

4.3

First Amendment to Credit Agreement, dated as of June 16, 2017, among CERC Corp., as Borrower, and the banks named therein

CenterPoint Energy’s Form 8-K dated June 16, 2017

1-31447

4.3

4.13

$400,000,000 Credit Agreement, dated as of July 14, 2017, among VUHI, as Borrower, certain Subsidiaries of VUHI, as Guarantors, and the banks named therein

Vectren’s Form 8-K dated July 17, 2017

1-15467

10.1

$400,000,000 Credit Agreement, dated as of July 14, 2017, among VUHI, as Borrower, certain Subsidiaries of VUHI, as Guarantors, and the banks named therein

Vectren’s Form 8-K dated July 17, 2017

1-15467

10.1

4.14

$200,000,000 Credit Agreement, dated as of July 14, 2017, among VCC, as Borrower, Vectren Corporation, as Guarantor, and the banks named therein

Vectren’s Form 8-K dated July 17, 2017

1-15467

10.2

$200,000,000 Credit Agreement, dated as of July 14, 2017, among VCC, as Borrower, Vectren Corporation, as Guarantor, and the banks named therein

Vectren’s Form 8-K dated July 17, 2017

1-15467

10.2

4.15

Term Loan Agreement dated as of July 30, 2018, among VUHI, as Borrower, the Subsidiaries of Borrower identified herein as Guarantors and the banks named therein

Vectren’s Form 8-K dated July 30, 2018

1-15467

10.1

Term Loan Agreement dated as of July 30, 2018, among VUHI, as Borrower, the Subsidiaries of Borrower identified herein as Guarantors and the banks named therein

Vectren’s Form 8-K dated July 30, 2018

1-15467

10.1

4.16

Term Loan Agreement dated as of September 14, 2018, among VCC, as Borrower, Vectren as Guarantor, and the banks named therein

Vectren’s Form 8-K dated September 18, 2018

1-15467

10.1

Term Loan Agreement dated as of September 14, 2018, among VCC, as Borrower, Vectren as Guarantor, and the banks named therein

Vectren’s Form 8-K dated September 18, 2018

1-15467

10.1

+4.17

First Amendment to Term Loan Agreement, dated as of June 25, 2019, among VCC, as Borrower, Vectren as Guarantor and the banks named therein

4.17

First Amendment to Term Loan Agreement, dated as of June 25, 2019, among VCC, as Borrower, Vectren as Guarantor and the banks named therein

CenterPoint Energy’s Form 10-Q for the quarter ended June 30, 2019

1-31447

4.17

4.18

$1,000,000,000 Term Loan Agreement, dated as of May 15, 2019, among CenterPoint Energy, as Borrower, Mizuho Bank, Ltd., as Administrative Agent and Lead Arranger, and the banks named therein

CenterPoint Energy’s Form 8-K dated May 15, 2019

1-31447

4.1

$1,000,000,000 Term Loan Agreement, dated as of May 15, 2019, among CenterPoint Energy, as Borrower, Mizuho Bank, Ltd., as Administrative Agent and Lead Arranger, and the banks named therein

CenterPoint Energy’s Form 8-K dated May 15, 2019

1-31447

4.1

+10.1

Letter Agreement, dated April 9, 2019, between CenterPoint Energy and Xia Liu

4.19

Indenture, dated as of May 19, 2003, between CenterPoint Energy and JPMorgan Chase Bank, as Trustee

CenterPoint Energy’s Form 8-K dated May 19, 2003

1-31447

4.1

+4.20

Supplemental Indenture No. 11 to Exhibit 4.19, dated as of August 14, 2019, providing for the issuance of CenterPoint Energy’s 2.50% Senior Notes due 2024, 2.95% Senior Notes due 2030 and 3.70% Senior Notes due 2049

+31.1.1

Rule 13a-14(a)/15d-14(a) Certification of Scott M. Prochazka

+31.1.2

Rule 13a-14(a)/15d-14(a) Certification of Scott M. Prochazka

+31.1.3

Rule 13a-14(a)/15d-14(a) Certification of Scott M. Prochazka

+31.2.1

Rule 13a-14(a)/15d-14(a) Certification of Xia Liu

+31.2.2

Rule 13a-14(a)/15d-14(a) Certification of Xia Liu

+31.2.3

Rule 13a-14(a)/15d-14(a) Certification of Xia Liu

+32.1.1

Section 1350 Certification of Scott M. Prochazka

+32.1.2

Section 1350 Certification of Scott M. Prochazka

+32.1.3

Section 1350 Certification of Scott M. Prochazka

+32.2.1

Section 1350 Certification of Xia Liu

+32.2.2

Section 1350 Certification of Xia Liu

+32.2.3

Section 1350 Certification of Xia Liu

+101.INS

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+101.SCH

Inline XBRL Taxonomy Extension Schema Document

+101.CAL

Inline XBRL Taxonomy Extension Calculation Linkbase Document

+101.DEF

Inline XBRL Taxonomy Extension Definition Linkbase Document

Exhibit

Number

Description

Report or Registration

Statement

SEC File or

Registration

Number

Exhibit

Reference

CenterPoint Energy

Houston Electric

CERC

+101.SCH

Inline XBRL Taxonomy Extension Schema Document

+101.CAL

Inline XBRL Taxonomy Extension Calculation Linkbase Document

+101.DEF

Inline XBRL Taxonomy Extension Definition Linkbase Document

+101.LAB

Inline XBRL Taxonomy Extension Labels Linkbase Document

+101.PRE

Inline XBRL Taxonomy Extension Presentation Linkbase Document

+104

Cover Page Interactive Data File ~~- the cover page interactive data file does not appear in the Interactive Data File because its XBRL tags are embedded within the~~(formatted as Inline XBRL ~~document~~and contained in Exhibit 101)



*	Schedules to this agreement have been omitted pursuant to Item 601(b)(2) of Regulation S-K. A copy of any omitted schedules will be furnished supplementally to the SEC upon request; provided, however, that the parties may request confidential treatment pursuant to Rule 24b-2 of the Exchange Act for any document so furnished.

SIGNATURES

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



	CENTERPOINT ENERGY, INC.
	CENTERPOINT ENERGY HOUSTON ELECTRIC, LLC
	CENTERPOINT ENERGY RESOURCES CORP.


By:	/s/ Kristie L. Colvin
	Kristie L. Colvin
	Senior Vice President and Chief Accounting Officer

Date: ~~August~~November 7, 2019

98101

Recently Adopted Accounting Standards

ASU Number and Name

Description

Date of Adoption

Financial Statement Impact
upon Adoption

ASU 2016-02- Leases (Topic 842) and related amendments

ASU 2016-02 provides a comprehensive new lease model that requires lessees to recognize assets and liabilities for most leases and would change certain aspects of lessor accounting.
Transition method: modified retrospective

January 1, 2019

The Registrants adopted the standard and recognized a right-of-use asset and lease liability on their statement of financial position with no material impact on their results of operations and cash flows. See Note 19 for more information.