FERC Form

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose
FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
Who Must Submit
Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).
Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
1. one million megawatt hours of total annual sales,
2. 100 megawatt hours of annual sales for resale,
3. 500 megawatt hours of annual power exchanges delivered, or
4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).

What and Where to Submit

Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
Secretary
Federal Energy Regulatory Commission 888 First Street, NE
Washington, DC 20426

For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

The CPA Certification Statement should:

Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and

Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

Schedules	Pages
Comparative Balance Sheet	110-113
Statement of Income	114-117
Statement of Retained Earnings	118-119
Statement of Cash Flows	120-121
Notes to Financial Statements	122-123

The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.
“In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.
Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.

When to Submit
FERC Forms 1 and 3-Q must be filed by the following schedule:
1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
Where to Send Comments on Public Reporting Burden.
The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.
Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.

Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS

Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
'Person' means an individual or a corporation;
'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;

'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......

"project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered

'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.

Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10

"Sec. 309.

The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).

FERC FORM NO.

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER

IDENTIFICATION

01 Exact Legal Name of Respondent

CenterPoint Energy Houston Electric, LLC

02 Year/ Period of Report

End of:

2022

03 Previous Name and Date of Change (If name changed during year)

04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

1111 Louisiana Street, Houston, TX 77002

05 Name of Contact Person

Kara G. Ryan

06 Title of Contact Person

VP and Chief Accounting Officer

07 Address of Contact Person (Street, City, State, Zip Code)

1111 Louisiana Street, Houston, TX 77002

08 Telephone of Contact Person, Including Area Code

(713) 207-6786

09 This Report is An Original / A Resubmission

(1)

☑ An Original

(2)

☐ A Resubmission

10 Date of Report (Mo, Da, Yr)

04/18/2023

Annual Corporate Officer Certification

The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Kara G. Ryan

02 Title

VP and Chief Accounting Officer

03 Signature

Kara G. Ryan

04 Date Signed (Mo, Da, Yr)

04/18/2023

Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

LIST OF SCHEDULES (Electric Utility)
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".
Line No.	Title of Schedule (a)	Reference Page No. (b)	Remarks (c)
	ScheduleIdentificationAbstract Identification	1
	ScheduleListOfSchedulesAbstract List of Schedules	2
1	ScheduleGeneralInformationAbstract General Information	101
2	ScheduleControlOverRespondentAbstract Control Over Respondent	102
3	ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent	103
4	ScheduleOfficersAbstract Officers	104
5	ScheduleDirectorsAbstract Directors	105
6	ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates	106	None
7	ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year	108
8	ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet	110
9	ScheduleStatementOfIncomeAbstract Statement of Income for the Year	114
10	ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year	118
12	ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows	120
12	ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements	122
13	ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities	122a
14	ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep	200
15	ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials	202	None
16	ScheduleElectricPlantInServiceAbstract Electric Plant in Service	204
17	ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others	213	None
18	ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use	214
19	ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric	216
20	ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant	219
21	ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies	224
22	ScheduleMaterialsAndSuppliesAbstract Materials and Supplies	227
23	ScheduleAllowanceInventoryAbstract Allowances	228	None
24	ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses	230a	None
25	ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs	230b	None
26	ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs	231
27	ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets	232
28	ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits	233
29	ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes	234
30	ScheduleCapitalStockAbstract Capital Stock	250
31	ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital	253
32	ScheduleCapitalStockExpenseAbstract Capital Stock Expense	254b	None
33	ScheduleLongTermDebtAbstract Long-Term Debt	256
34	ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax	261
35	ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year	262
36	ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits	266	None
37	ScheduleOtherDeferredCreditsAbstract Other Deferred Credits	269
38	ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property	272	None
39	ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property	274
40	ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other	276
41	ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities	278
42	ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues	300
43	ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1)	302	None
44	ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules	304
45	ScheduleSalesForResaleAbstract Sales for Resale	310	None
46	ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses	320
47	SchedulePurchasedPowerAbstract Purchased Power	326	None
48	ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others	328
49	ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs	331	None
50	ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others	332
51	ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric	335
52	ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405)	336
53	ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses	350
54	ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities	352
55	ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages	354
56	ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses	356	None
57	ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements	397	None
58	SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services	398	None
59	ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load	400	None
60	ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load	400a	None
61	ScheduleElectricEnergyAccountAbstract Electric Energy Account	401a	None
62	ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output	401b	None
63	ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics	402	None
64	ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics	406	None
65	SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics	408	None
66	ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages	410	None
0	ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants)	414	None
67	ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages	422
68	ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year	424
69	ScheduleSubstationsAbstract Substations	426
70	ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies	429
71	FootnoteDataAbstract Footnote Data	450
	StockholdersReportsAbstract Stockholders' Reports (check appropriate box)
	Stockholders' Reports Check appropriate box: ☐ Two copies will be submitted ☑ No annual report to stockholders is prepared

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept. Kara G. Ryan VP and Chief Accounting Officer (a) 1111 Louisiana, Houston, TX 770021
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized. State of Incorporation: TX Date of Incorporation: 2002-08-31 Incorporated Under Special Law:
3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased. (a) Name of Receiver or Trustee Holding Property of the Respondent: (b) Date Receiver took Possession of Respondent Property: (c) Authority by which the Receivership or Trusteeship was created: (d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated. Electric Service - Texas
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements? (1) ☐ Yes (2) ☑ No

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: AddressWhereCorporateBooksAreKept

CenterPoint Energy Houston Electric, LLC (CenterPoint Houston) rates, charges, services, contracts, rules and regulations for the transmission and distribution of electric energy are subject to regulation by the State of Texas and the governing bodies of the cities and towns in which CenterPoint Houston operates and said authorities claim or may, hereafter, claim jurisdiction over some or all of the matters above mentioned and those that this report relates. Furthermore, the foregoing affords an effective measure of regulation of the accounting procedures and fiscal operations of CenterPoint Houston.

CenterPoint Houston is not a "public utility" under the Federal Power Act and, therefore, is not generally regulated by the Federal Energy Regulatory Commission (FERC), although certain of its transactions are subjected to limited FERC jurisdiction. The FERC has certain responsibilities with respect to ensuring the reliability of electric transmission service, including transmission facilities owned by CenterPoint Houston and other utilities within Electric Reliability Council of Texas (ERCOT). The FERC has designated the North American Electric Reliability Corporation (NERC) as the Electric Reliability Organization (ERO) to promulgate standards, under FERC oversight, for all owners, operators and users of the bulk power system (Electric Entities). The ERO and the FERC have authority to (a) impose fines and other sanctions on Electric Entities that fail to comply with approved standards and (b) audit compliance with approved standards. The FERC has approved the delegation by the NERC of authority for reliability in ERCOT to the Texas Reliability Entity, Inc. (TRE). CenterPoint Houston does not anticipate that the reliability standards proposed by the NERC and approved by the FERC will have a material adverse impact on its operations. To the extent that CenterPoint Houston is required to make additional expenditures to comply with these standards, it is anticipated that CenterPoint Houston will seek to recover those costs through the transmission charges that are imposed on all distribution service providers within ERCOT for electric transmission provided.

CenterPoint Houston, therefore, files this report with the Federal Energy Regulatory Commission as a completely voluntary act. However, CenterPoint Energy Houston Electric, LLC does file this report with the Public Utility Commission of Texas, as required by PUCT Substantive Rule §25.73 (a) (1).

CenterPoint Houston is an indirect wholly owned subsidiary of CenterPoint Energy, Inc., a public utility holding company.

The financial and statistical information presented within this FERC Form 1 contains only information applicable to the Transmission & Distribution Utility (TDU) a division of CenterPoint Energy Houston Electric, LLC. The TDU's business includes 1) Distribution - which function is to distribute electricity for retail electric providers in its certificated service area by carrying power from the substation to the retail electric customer; 2) Transmission which function is to transport electricity from power plants to substations and from one substation to another in locations in the control area managed by ERCOT.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.

CenterPoint Energy Houston Electric, LLC is an indirect wholly owned subsidiary of CenterPoint Energy, Inc. and is not controlled by any other corporation, business or similar organization.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

CORPORATIONS CONTROLLED BY RESPONDENT
Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests. Definitions See the Uniform System of Accounts for a definition of control. Direct control is that which is exercised without interposition of an intermediary. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.	NameOfCompanyControlledByRespondent Name of Company Controlled (a)	CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b)	VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c)	FootnoteReferences Footnote Ref. (d)
1	CenterPoint Energy Energy Restoration Bond Company, LLC	Bond Service	(a) 0
2	CenterPoint Energy Transition Bond Company IV, LLC	Bond Service	(b) 0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: VotingStockOwnedByRespondentPercentage

CenterPo i nt Energy Restoration Bond Company, LLC is a Delaware limited liability company which is 100% owned by Cente r Po i nt Ene r gy Houston Electric, LLC (CEHE) . Per its l imited liability company agreement , its ownership is described as a "common interest" wh i ch is held 1 00% by CEHE .

(b) Concept: VotingStockOwnedByRespondentPercentage

CenterPo i nt Energy Transition Bond Company IV, LLC is a Delaware limited liability company which is 100% owned by Cente r Po i nt Ene r gy Houston Electric, LLC (CEHE) . Per its l imited liability company agreement , its ownership is described as a "common interest" wh i ch is held 1 00% by CEHE .

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

OFFICERS
Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.	OfficerTitle Title (a)	OfficerName Name of Officer (b)	OfficerSalary Salary for Year (c)	DateOfficerIncumbencyStarted Date Started in Period (d)	DateOfficerIncumbencyEnded Date Ended in Period (e)
1	(a) See attached page for additional information. Officers listed on the attached pages are officers for CenterPoint Energy, Inc. per the proxy filed.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: OfficerTitle

EXECUTIVE COMPENSATION TABLES

The following tables show compensation information for: (i) our Chief Executive Officer, our President, Chief Operating Officer and Chief Financial Officer, our Former Executive Vice President, Utility Operations and our Former Executive Vice President, Customer Transformation and Business Services for the periods ended December 31, 2022, 2021 and 2020; and (ii) our Executive Vice President and General Counsel for the periods ended December 31, 2022 and 2021.

Summary Compensation Table for Fiscal Year 2022


Name and Principal Position	Year	Salary ($)	Bonus (1) ($)	Stock Awards (2) ($)	Option Awards (3) ($)	Non-Equity Incentive Plan Compensation (4) ($)	Change in Pension Value and Nonqualified Deferred Compensation Earnings (5) ($)	All Other Compensation (6) ($)	Total ($)
David J. Lesar President and Chief Executive Officer	2022	1,423,241	—	8,481,240	—	3,407,250	—	556,144	13,867,875
	2021	1,425,000	—	33,359,999	—	2,116,125	—	908,686	37,809,810
	2020	675,000	—	8,169,996	—	2,463,750	—	637,549	11,946,295
Jason P. Wells President, Chief Operating Officer and Chief Financial Officer	2022	667,463	—	1,737,497	—	860,063	—	193,847	3,458,870
	2021	665,000	—	1,675,003	—	548,625	—	362,752	3,251,380
	2020	169,886	—	2,625,007	—	711,800	—	136,813	3,643,507
Scott E. Doyle	2022	563,504	—	1,500,005	—	—	(119,284)	90,477	2,034,702
Former Executive Vice President, Utility Operations Utility Operations	2021	518,750	—	997,503	—	399,437	34,944	100,381	2,051,015
	2020	487,500	—	849,989	—	462,600	113,597	61,067	1,974,753
Monica Karuturi Executive Vice President and General Counsel	2022	552,462	100,000	1,102,006	—	669,900	9,454	71,527	2,505,350
	2021	527,500	80,000	971,997	—	377,163	30,437	65,754	2,052,851


Gregory E. Knight Former Executive Vice President, Customer Transformation and Business Services	2022	506,396	—	1,006,977	—	612,150	(15,660)	95,624	2,205,487
	2021	496,249	—	949,979	—	382,112	(1,831)	74,775	1,866,547
	2020	181,875	400,000	1,076,010	—	172,600	(982)	180,392	2,009,894

(1) For 2021, amounts for Ms. Karuturi include a retention cash bonus of $80,000. For 2022, amounts for Ms. Karuturi include a cash bonus of $100,000. For 2020, amounts for Mr. Knight include a sign-on bonus of $400,000 approved by the Compensation Committee in connection with Mr. Knight’s appointment as the Company’s Executive Vice President, Customer Transformation and Business Services effective August 17, 2020.

(2) Reported amounts for our named executive officers represent the aggregate grant date fair value of awards computed in accordance with FASB ASC Topic 718 based on the probable achievement level of the underlying performance conditions as of the grant date. For 2021, amounts for Mr. Lesar include the retention awards under Mr. Lesar’s Retention Incentive Agreement, pursuant to which Mr. Lesar received RSUs for a total of 1 million shares of Common stock that were granted through multiple annual awards in 2021, 2022, and 2023. The retention awards were valued at $25,240,000 as of the date of Retention Incentive Agreement (July 20,2021). Assumptions, where applicable, are the same assumptions disclosed in “Stock-Based Incentive Compensation Plans and Employee Benefit Plans” in Note 8 to our consolidated financial statements included in our annual report on Form 10-K for the year ended December 31, 2022. For purposes of the tables above and below, the effects of estimated forfeitures are excluded. Please also refer to the Grants of Plan-Based Awards for Fiscal Year 2022 table and the accompanying footnotes..

The maximum value at the grant date of stock awards for each of our named executive officers assuming the highest level of performance conditions is achieved is as follows:


Name	Year	Maximum Value of Stock Awards ($)
Lesar	2022	14,842,187
	2021	38,232,004
	2020	12,934,005
Wells	2022	3,040,614
	2021	2,680,005
	2020	3,762,517
Doyle	2022	2,625,002
	2021	1,596,011
	2020	1,444,981
Kauturi	2022	1,928,524
	2021	1,555,190
Knight	2022	1,762,209
	2021	1,519,972
	2020	1,619,208

(3) CenterPoint Energy has not granted stock options since 2004.

(4) Non-Equity Incentive Plan Compensation represents short-term incentive awards earned with respect to performance in the designated year and paid in the following year. For more information on the 2022 short-term incentive awards, refer to the Grants of Plan-Based Awards for Fiscal Year 2022 table and the accompanying footnotes. Under the terms of our short-term incentive plan, an individual age 55 or older with at least five years of

service satisfies certain vesting provisions under the plan. If the individual terminates employment during the plan year, he or she is eligible for a pro rata payment at the target level of achievement.

(5) The two components of the 2021 Change in Pension Value and Nonqualified Deferred Compensation Earnings are as follows:


Name	Change in Pension Value(a) ($)	Above Market Earnings on Nonqualified Deferred Compensation(b) ($)	Total ($)
Lesar	—	—	—
Wells	—	—	—
Doyle	(141,946)	22,662	(119,284)
Karuturi	9,454	—	9,454
Knight	(15,660)	—	(15,660)

(a) The Change in Pension Value is the increase or decrease in the present value of accumulated benefits under our retirement plan and the related benefit restoration plans from December 31, 2021 to December 31, 2022. Benefits are assumed to commence as of the earliest age that an individual could retire without a reduction in benefits. The present value as of December 31, 2022 assumed a discount rate of 5.15% and lump sum conversion interest rate of 5.15% for benefits paid in all future years. The present value as of December 31, 2021 assumed a discount rate of 2.8% and lump sum conversion interest rate of 2.8% for benefits paid in all future years. Refer to the narrative accompanying the Pension Benefits table for a more detailed discussion of the present value calculation.

(b) Above Market Earnings consist of the amounts that exceed 120% of the applicable federal long-term rate at the time the interest rate was set.

(6) The following table sets forth the elements of All Other Compensation for 2022:


Name	Perquisites and Other Personal Benefits (a) ($)	Tax Reimbursements (b) ($)	Contributions to Vested and Unvested Defined Contribution Plans (qualified) (c) ($)	Contributions to Vested and Unvested Defined Contribution Plans (nonqualified) (d) ($)	Insurance Premiums (e) ($)	Other (f) ($)	Director Fees Earned or Paid in Cash (g) ($)	Total All Other Compensation ($)
Lesar	187,601	—	27,450	291,093	—	—	50,000	556,144
Wells	59,399	—	27,450	81,998	—	—	25,000	193,847
Doyle	17,279	—	18,300	34,898	—	—	20,000	90,477
Karuturi	—	—	18,300	43,477	—	—	9,750	71,527
Knight	15,658	—	27,450	52,516	—	—	—	95,624

(a) For Mr. Lesar, this amount includes the incremental cost to the Company attributable to security-related services provided to Mr. Lesar, including the use of a car and security personnel, such as a security driver, to mitigate risk to the Company by supporting Mr. Lesar’s safety, health and well-being. The Company considers costs for security-related services, which were put into place in accordance with the recommendations of an independent security consultant based on a security risk assessment, to be business expenses rather than personal benefits to Mr. Lesar; however, disclosure regulations require certain security expenses to be reported as personal benefits. The incremental cost for the use of the car is based on the annualized cost of the car over its useful life, including annual depreciation, as well as maintenance, insurance and fuel expense. The incremental cost of providing security personnel, including a security driver, includes the actual incremental cost of expenses incurred by such security personnel, but does not include the fixed costs associated with such personnel.

For Mr. Lesar, due, in part, for efficiency and personal safety as well as security risk considerations identified in the aforementioned security assessment related to Mr. Lesar, this amount includes the incremental cost to the Company for personal travel on aircraft owned by the Company or provided by a third-party aircraft charter company. The incremental cost for personal travel on aircraft owned by the Company includes variable operating

costs such as landing, parking, hanger and dead-head costs, crew travel expenses, supplies and catering, fuelcosts, and passenger ground transportation, and does not include an allocable share of fixed costs associated with the Company’s ownership of the aircraft. No amounts were included where spouses or family members accompanied the executives on Company aircraft flights because there was no incremental cost to the Company. The incremental cost to the Company for personal travel on aircraft provided by a third-party aircraft charter company includes the amount invoiced to CenterPoint Energy for the hourly rate and operating costs of flights for Messrs. Lesar and Wells, $12,993 and $42,050, respectively. Amounts include incremental costs to the Company for spouses or family members accompanying executives provided by a third-party charter company.

Additionally, for Messrs. Lesar, Wells, Doyle and Knight, the amount includes financial planning services of $15,000, $15,830, $15,830 and $15,658, respectively. None of the other named executive officers received perquisites valued in excess of $10,000 during 2022.

(b) These amounts represent CenterPoint Energy’s contributions to the savings plan, which is described under “Savings Plan and Savings Restoration Plans.”

(c) These amounts represent benefits accrued under the savings restoration plan, which is described under “Savings Plan and Savings Restoration Plans.”

(d) These amounts represent CenterPoint Energy Foundation, Inc.’s charitable contribution to non-profit organizations to match personal qualified contributions on a dollar-for-dollar basis up to an annual maximum match of $25,000 ($50,000 for Mr. Lesar).

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

DIRECTORS
Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.	NameAndTitleOfDirector Name (and Title) of Director (a)	PrincipalBusinessAddress Principal Business Address (b)	MemberOfTheExecutiveCommittee Member of the Executive Committee (c)	ChairmanOfTheExecutiveCommittee Chairman of the Executive Committee (d)
1	CenterPoint Energy Houston Electric, LLC. is a Texas limited liability company created effective August 31, 2002 when Reliant Energy, Incorporated, of which Reliant Energy HL&P was an unincorporated division, was converted from a corporation to a limited liability company. The conversion was accomplished in connection with the restructuring of Reliant Energy, Incorporated and the formation of CenterPoint Energy, Inc. as a new holding company. CenterPoint Energy Houston Electric, LLC does not have an executive committee.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

INFORMATION ON FORMULA RATES
Does the respondent have formula rates?		☐ Yes ☐ No
Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
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Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?			☐ Yes ☑ No (Checked by default - Not explicitly defined)
If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.	AccessionNumber Accession No. (a)	DocumentDate Document Date / Filed Date (b)	DocketNumber Docket No. (c)	DescriptionOfFiling Description (d)	RateScheduleTariffNumber Formula Rate FERC Rate Schedule Number or Tariff Number (e)
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Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

INFORMATION ON FORMULA RATES - Formula Rate Variances
If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.	PageNumberOfFormulaRateVariances Page No(s). (a)	ScheduleOfFormulaRateVariances Schedule (b)	ColumnOfFormulaRateVariances Column (c)	LineNumberOfFormulaRateVariances Line No. (d)
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Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

IMPORTANT CHANGES DURING THE QUARTER/YEAR
Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments. State the estimated annual effect and nature of any important wage scale changes during the year. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest. (Reserved.) If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.

1. None
2. None
3. None
4. None
5. Space City Solar Transmission Interconnection Project (CenterPoint Houston): On December 17, 2020, Houston Electric filed a certificate of convenience and necessity application with the PUCT for approval to build a 345 kV transmission line in Wharton County, Texas connecting the Hillje substation on Houston Electric’s transmission system to the planned 610 MW Space City Solar Generation facility being developed by third-party developer EDF Renewables. The actual capital costs of the project will depend on actual land acquisition costs, construction costs, and other factors. In November 2021, the PUCT approved a route that was estimated to cost $25 million and issued a final order on January 12, 2022. There have been project delays due to supply chain constraints in the developer acquiring solar panels. Houston Electric expects to complete construction and energization of the transmission line by the end of 2023.
6. In March 2022, CEHE issued $300 million of general mortgage bonds due 2032 and $500 million of general mortgage bonds due 2052. In September 2022, CEHE issued $500 million general mortgage bonds due 2032 and $300 mortgage bonds due 2052. On December 6, 2022, CEHE replaced its existing $300 million revolving credit facility with a new 5-year $300 million revolving credit facility maturing on December 6, 2027. From time to time, CEHE may borrow money from the CenterPoint Energy money pool.
7. None
8. None
9. None
10. None
12. None
13. Changes effective 2022: Kristie L. Colvin has served as Senior Vice President, Regulatory Planning, Reporting & Electric Services of CNP since March, 2022. Stacey Peterson and Kenneth Mercado left the company in 2022. • Stacey Peterson resigned as SVP & Chief Accounting Officer on August 15, 2022. • Kenneth Mercado retired as President & CEO of CEHE December 31, 2021. Scott E. Doyle has served as President of CEHE since January, 2022. Kara Gostenhofer Ryan has served as VP & Chief Accounting Officer since August 15, 2022.
14. None

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlant Utility Plant (101-106, 114)	200	16,055,493,258	14,426,746,540
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	1,071,752,129	685,810,110
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		17,127,245,387	15,112,556,650
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	4,411,071,383	4,299,680,845
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		12,716,174,004	10,812,875,805
7	NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)	202	0	0
8	NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2)		0	0
9	NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3)		0	0
10	SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4)		0	0
11	NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6)		0	0
12	AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)	202	0	0
13	NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12)		0	0
14	UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13)		12,716,174,004	10,812,875,805
15	OtherElectricPlantAdjustments Utility Plant Adjustments (116)		0	0
16	GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117)		0	0
17	OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS
18	NonutilityProperty Nonutility Property (121)		116,195	116,195
19	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)		0	0
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)		0	0
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224	8,478,000	11,803,295
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228	0	0
24	OtherInvestments Other Investments (124)		0	0
25	SinkingFunds Sinking Funds (125)		0	0
26	DepreciationFund Depreciation Fund (126)		0	0
27	AmortizationFundFederal Amortization Fund - Federal (127)		0	0
28	OtherSpecialFunds Other Special Funds (128)		0	0
29	SpecialFunds Special Funds (Non Major Only) (129)		0	0
30	DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175)		0	0
31	DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176)		0	0
32	OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31)		8,594,195	11,919,490
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)		0	0
35	Cash Cash (131)		222,156	126,464,748
36	SpecialDeposits Special Deposits (132-134)		0	0
37	WorkingFunds Working Fund (135)		1,162,563	684,822
38	TemporaryCashInvestments Temporary Cash Investments (136)		0	0
39	NotesReceivable Notes Receivable (141)		0	0
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		255,033,043	214,084,519
41	OtherAccountsReceivable Other Accounts Receivable (143)		35,320,256	21,275,187
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)		1,137,616	1,137,616
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)		0	0
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		21,561,296	11,471,744
45	FuelStock Fuel Stock (151)	227	0	0
46	FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152)	227	0	0
47	Residuals Residuals (Elec) and Extracted Products (153)	227	0	0
48	PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154)	227	433,536,326	257,880,852
49	Merchandise Merchandise (155)	227	0	0
50	OtherMaterialsAndSupplies Other Materials and Supplies (156)	227	0	0
51	NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157)	202/227	0	0
52	AllowanceInventoryAndWithheld Allowances (158.1 and 158.2)	228	0	0
53	NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances	228	0	0
54	StoresExpenseUndistributed Stores Expense Undistributed (163)	227	738	1,431,584
55	GasStoredCurrent Gas Stored Underground - Current (164.1)		0	0
56	LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)		0	0
57	Prepayments Prepayments (165)		44,835,220	32,797,957
58	AdvancesForGas Advances for Gas (166-167)		0	0
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)		0	0
60	RentsReceivable Rents Receivable (172)		0	0
61	AccruedUtilityRevenues Accrued Utility Revenues (173)		141,605,253	127,251,384
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)		0	0
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)		0	0
64	DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175)		0	0
65	DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176)		0	0
66	DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)		0	0
67	CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66)		932,137,759	792,205,181
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		51,177,310	37,838,819
70	ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1)	230a	0	0
71	UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2)	230b	0	0
72	OtherRegulatoryAssets Other Regulatory Assets (182.3)	232	1,089,602,734	552,723,719
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)		0	0
74	PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1)		0	0
75	OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2)		0	0
76	ClearingAccounts Clearing Accounts (184)		35,579	46,329
77	TemporaryFacilities Temporary Facilities (185)		0	0
78	MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186)	233	118,018,567	54,364,888
79	DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187)		0	0
80	ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188)	352	0	0
81	UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189)		46,757,247	49,251,383
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	270,197,483	236,573,283
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)		0	0
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		1,575,788,920	930,798,421
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		15,232,694,878	12,547,798,897

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	ProprietaryCapitalAbstract PROPRIETARY CAPITAL
2	CommonStockIssued Common Stock Issued (201)	250	1,000	1,000
3	PreferredStockIssued Preferred Stock Issued (204)	250	0	0
4	CapitalStockSubscribed Capital Stock Subscribed (202, 205)		0	0
5	StockLiabilityForConversion Stock Liability for Conversion (203, 206)		0	0
6	PremiumOnCapitalStock Premium on Capital Stock (207)		0	0
7	OtherPaidInCapital Other Paid-In Capital (208-211)	253	3,727,187,337	2,669,598,394
8	InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212)	252	0	0
9	DiscountOnCapitalStock (Less) Discount on Capital Stock (213)	254	0	0
10	CapitalStockExpense (Less) Capital Stock Expense (214)	254b	0	0
11	RetainedEarnings Retained Earnings (215, 215.1, 216)	118	1,160,903,818	953,448,202
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118	0	0
13	ReacquiredCapitalStock (Less) Reaquired Capital Stock (217)	250	0	0
14	NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218)		0	0
15	AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219)	122(a)(b)	9,636	17,055
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		4,888,082,519	3,623,064,651
17	LongTermDebtAbstract LONG-TERM DEBT
18	Bonds Bonds (221)	256	(a) 6,112,275,000	5,012,275,000
19	ReacquiredBonds (Less) Reaquired Bonds (222)	256	0	0
20	AdvancesFromAssociatedCompanies Advances from Associated Companies (223)	256	0	0
21	OtherLongTermDebt Other Long-Term Debt (224)	256	0	0
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)		0	0
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)		27,612,109	17,747,880
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		6,084,662,891	4,994,527,120
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		1,009,706	342,544
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)		0	0
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)		30,622,855	31,168,154
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)		37,175,124	53,960,692
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)		0	0
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)		0	0
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities		0	0
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges		0	0
34	AssetRetirementObligations Asset Retirement Obligations (230)		35,990,153	41,711,440
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		104,797,838	127,182,830
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)		0	0
38	AccountsPayable Accounts Payable (232)		376,711,997	481,260,524
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)		641,971,745	511,862,023
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		113,097,372	56,669,808
41	CustomerDeposits Customer Deposits (235)		343,681	1,002,242
42	TaxesAccrued Taxes Accrued (236)	262	288,026,002	166,005,664
43	InterestAccrued Interest Accrued (237)		76,749,627	65,326,571
44	DividendsDeclared Dividends Declared (238)		0	0
45	MaturedLongTermDebt Matured Long-Term Debt (239)		0	0
46	MaturedInterest Matured Interest (240)		0	0
47	TaxCollectionsPayable Tax Collections Payable (241)		2,602	5,875
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		80,500,331	56,186,670
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		0	0
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)		0	0
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities		0	0
52	DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245)		0	0
53	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges		0	0
54	CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53)		1,577,403,357	1,338,319,377
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)		4,507,607	22,006,386
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266	0	0
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)		0	0
59	OtherDeferredCredits Other Deferred Credits (253)	269	92,213,598	111,541,108
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	990,699,193	942,879,065
61	UnamortizedGainOnReacquiredDebt Unamortized Gain on Reaquired Debt (257)		0	0
62	AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281)	272	0	0
63	AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282)		1,330,424,870	1,215,264,089
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		159,903,005	173,014,271
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		2,577,748,273	2,464,704,919
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		15,232,694,878	12,547,798,897

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: Bonds

Long-term debt previously recorded in FERC Accounts 221 and 224, are now currently being recorded in FERC Account 221.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

STATEMENT OF INCOME
Quarterly Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter. If additional columns are needed, place them in a footnote. Annual or Quarterly if applicable Do not report fourth quarter data in columns (e) and (f) Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. Use page 122 for important notes regarding the statement of income for any account thereof. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.	Title of Account (a)	(Ref.) Page No. (b)	Total Current Year to Date Balance for Quarter/Year (c)	Total Prior Year to Date Balance for Quarter/Year (d)	Current 3 Months Ended - Quarterly Only - No 4th Quarter (e)	Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f)	Electric Utility Current Year to Date (in dollars) (g)	Electric Utility Previous Year to Date (in dollars) (h)	Gas Utiity Current Year to Date (in dollars) (i)	Gas Utility Previous Year to Date (in dollars) (j)	Other Utility Current Year to Date (in dollars) (k)	Other Utility Previous Year to Date (in dollars) (l)
1	UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME
2	OperatingRevenues Operating Revenues (400)	300	3,205,486,058	2,894,086,916			3,205,486,058	2,894,086,916
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	1,491,812,845	1,439,865,876			1,491,812,845	1,439,865,876
5	MaintenanceExpense Maintenance Expenses (402)	320	139,603,597	149,303,769			139,603,597	149,303,769
6	DepreciationExpense Depreciation Expense (403)	336	421,579,159	379,135,422			421,579,159	379,135,422
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	43,868,146	36,276,707			43,868,146	36,276,707
9	AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406)	336
10	AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11	AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2)
12	RegulatoryDebits Regulatory Debits (407.3)		14,603,134	14,603,134			14,603,134	14,603,134
13	RegulatoryCredits (Less) Regulatory Credits (407.4)		12,934,600	12,934,600			12,934,600	12,934,600
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	292,320,914	285,417,305			292,320,914	285,417,305
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	65,690,812	6,345,373			65,690,812	6,345,373
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	95,576	7,363			95,576	7,363
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	205,365,728	370,159,090			205,365,728	370,159,090
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	157,218,252	306,857,984			157,218,252	306,857,984
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)
22	GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8)
23	LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9)
24	AccretionExpense Accretion Expense (411.10)
25	UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)		2,504,787,059	2,348,615,983			2,504,787,059	2,374,485,183
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		700,698,999	545,470,933			700,698,999	519,601,733
28	OtherIncomeAndDeductionsAbstract Other Income and Deductions
29	OtherIncomeAbstract Other Income
30	NonutilityOperatingIncomeAbstract Nonutilty Operating Income
31	RevenuesFromMerchandisingJobbingAndContractWork Revenues From Merchandising, Jobbing and Contract Work (415)
32	CostsAndExpensesOfMerchandisingJobbingAndContractWork (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
33	RevenuesFromNonutilityOperations Revenues From Nonutility Operations (417)
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)			7
35	NonoperatingRentalIncome Nonoperating Rental Income (418)
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119
37	InterestAndDividendIncome Interest and Dividend Income (419)		2,545,499	473,291
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		23,994,834	20,143,639
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		2,634,978	6,322,035
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		29,175,311	26,938,972
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		375,678	272,304
46	LifeInsurance Life Insurance (426.2)		5,590,351	6,033,953
47	Penalties Penalties (426.3)		1,531,960	22,500
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		3,082,536	3,627,867
49	OtherDeductions Other Deductions (426.5)		534,366	475,958
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		8,050,971	10,432,582
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	1,673,198	1,808,839
54	IncomeTaxesOther Income Taxes-Other (409.2)	262
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272
56	ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2)	234, 272
57	InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5)
58	InvestmentTaxCredits (Less) Investment Tax Credits (420)
59	TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)		1,673,198	1,808,839
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		22,797,538	18,315,229
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)		215,967,836	185,092,376
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		4,751,056	4,016,587
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)		4,980,475	6,091,757
65	AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429)
66	AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67	InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430)		1,929,380	494,249
68	OtherInterestExpense Other Interest Expense (431)		13,149,958	140,787
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		14,437,868	13,057,845
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		200,040,921	182,496,337
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		523,455,616	381,289,825
72	ExtraordinaryItemsAbstract Extraordinary Items
73	ExtraordinaryIncome Extraordinary Income (434)
74	ExtraordinaryDeductions (Less) Extraordinary Deductions (435)
75	NetExtraordinaryItems Net Extraordinary Items (Total of line 73 less line 74)
76	IncomeTaxesExtraordinaryItems Income Taxes-Federal and Other (409.3)	262
77	ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76)
78	NetIncomeLoss Net Income (Total of line 71 and 77)		523,455,616	381,289,825

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

STATEMENT OF RETAINED EARNINGS
Do not report Lines 49-53 on the quarterly report. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b). State the purpose and amount for each reservation or appropriation of retained earnings. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order. Show dividends for each class and series of capital stock. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.	Item (a)	Contra Primary Account Affected (b)	Current Quarter/Year Year to Date Balance (c)	Previous Quarter/Year Year to Date Balance (d)
	UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1	UnappropriatedRetainedEarnings Balance-Beginning of Period		953,448,202	572,158,377
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)
10	AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit
15	AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439)
16	BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1)		523,455,616	381,289,825
17	AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436)
22	AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436)
23	DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437)
29	DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30	DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438)
30.1	DividendsDeclaredCommonStock Dividends Declared-Common Stock		316,000,000
36	DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438)		316,000,000
37	TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
38	UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37)		1,160,903,818	953,448,202
39	AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215)
45	AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215)
	AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46	AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47	AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48	RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)		1,160,903,818	953,448,202
	UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49	UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit)		0
50	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1)
51	DividendsReceived (Less) Dividends Received (Debit)
52	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53	UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52)		0	0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

STATEMENT OF CASH FLOWS
Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.	Description (See Instructions No.1 for explanation of codes) (a)	Current Year to Date Quarter/Year (b)	Previous Year to Date Quarter/Year (c)
1	NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities
2	NetIncomeLoss Net Income (Line 78(c) on page 117)	523,455,616	381,289,825
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	421,579,159	379,135,422
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of Utility Plant	43,868,146	36,276,707
5.2	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization Other	24,340,507	24,361,457
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	48,147,476	63,301,107
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	23,009,448	48,775,718
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	174,223,152	85,837,332
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	137,988,174	205,602,677
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	580,983,389	273,740,492
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities	26,569,811	127,232,396
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	23,994,834	20,143,639
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other (provide details in footnote):
18.2	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other Assets	(a) 83,642,269	(f) 31,124,144
18.3	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other Liabilities	(b) 32,541,519	(g) 73,538,336
18.4	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other, net	(c) 13,268,470	(h) 9,112,576
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	385,905,786	585,764,386
24	CashFlowsFromInvestmentActivitiesAbstract Cash Flows from Investment Activities:
25	ConstructionAndAcquisitionOfPlantIncludingLandAbstract Construction and Acquisition of Plant (including land):
26	GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities Gross Additions to Utility Plant (less nuclear fuel)	2,476,751,558	1,798,465,424
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	23,994,834	20,143,639
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
31.1	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Other (provide details in footnote):
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	2,452,756,724	1,778,321,785
36	AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d)
37	ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d)	36,422,071	2,672,702
39	InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Investments in and Advances to Assoc. and Subsidiary Companies
40	ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies Contributions and Advances from Assoc. and Subsidiary Companies
41	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract Disposition of Investments in (and Advances to)
42	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44	PurchaseOfInvestmentSecurities Purchase of Investment Securities (a)
45	ProceedsFromSalesOfInvestmentSecurities Proceeds from Sales of Investment Securities (a)
46	LoansMadeOrPurchased Loans Made or Purchased
47	CollectionsOnLoans Collections on Loans
49	NetIncreaseDecreaseInReceivablesInvestingActivities Net (Increase) Decrease in Receivables
50	NetIncreaseDecreaseInInventoryInvestingActivities Net (Increase) Decrease in Inventory
51	NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities Net (Increase) Decrease in Allowances Held for Speculation
52	NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities Net Increase (Decrease) in Payables and Accrued Expenses
53	OtherAdjustmentsToCashFlowsFromInvestmentActivities Other (provide details in footnote):
53.1	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Other (provide details in footnote):
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	2,416,334,653	1,775,649,083
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)	1,588,667,339	1,095,513,000
62	ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock
63	ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock
64	OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote):
64.1	OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription Other (provide details in footnote):	(d) 17,688,195	(i) 12,519,225
64.2	OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription Net Increase in Short-Term from Associated Companies	130,109,721	504,290,632
66	NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c)
67	OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
67.1	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
70	CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69)	1,701,088,865	1,587,284,407
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)	500,000,000	402,442,000
74	PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock
75	PaymentsForRetirementOfCommonStockFinancingActivities Common Stock
76	OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.1	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):	(e) 1,019,575,151	(j) 130,100,000
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)
80	DividendsOnPreferredStock Dividends on Preferred Stock
81	DividendsOnCommonStock Dividends on Common Stock	316,000,000
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	1,904,664,016	1,314,942,407
85	NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents
86	NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)	125,764,851	125,057,710
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period	127,149,570	2,091,860
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period	1,384,719	127,149,570

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities


Investment in Associated Companies	$	3,325,295
Prepayments	$	(12,037,263)
Unamortized Debt Issuance Costs	(12,817,300)
General Liability Insurance Receivable	6,068,462
Insurance Proceeds	(4,717,763)
Other Deferred Debits	(63,463,700)
	$	(83,642,269)

(b) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities


Accumulated Deferred Income Tax	$	41,528,158
Benefit Obligation	(16,632,640)
ASC 715 Year Ene Reclass and ASC 842 Adoption	(6,068,462)
CEHE Non Cash Reclass
Equity Interest	18,103,821
Injuries and Damages	(545,299)
Customer Advances for Construction	(17,498,779)
ASC 158 Reclass	14,024,841
Other	(370,121)
	$	32,541,519


Unamortized Debt Issuance Costs	$	13,119,378
Value of Shares Withheld for Taxes	507,311
Other Operating	(331,529)
Accrued Other Comprehensive Income	(26,690)
	$	13,268,470

(d) Concept: OtherAdjustmentsToCashFlowsFromFinancingActivities


Debt Issuance Cost	$	(17,180,885)
Other Financing, Net	(507,311)
ASC 718	1
	$	(17,688,195)

(e) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities


Contribution from Parent	$	1,057,588,942
CEHE Non Cash Reclass	(38,013,791)
	$	1,019,575,151

(f) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities


Investment in Associated Companies	$	—
Prepayments	(886,362)
Unamortized Debt Issuance Costs	(9,193,665)
General Liability Insurance Receivable	(3,400,000)
Insurance Proceeds	2,063,909
Other Deferred Debits	(19,708,026)
	$	(31,124,144)

(g) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities


Accumulated Deferred Income Tax	$	98,616,114
Benefit Obligation	(19,638,010)
CEHE Non Cash Reclass	2,010,680
Equity Interest	(37,225,352)
Injuries and Damages	3,873,933
Customer Advances for Construction	6,119,852
ASC 158 Reclass	19,120,174
Other	660,945
	$	73,538,336

(h) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities


Unamortized Debt Issuance Costs	$	8,653,229
Value of Shares Withheld for Taxes	394,808
Accrued Other Comprehensive Income	64,539
	$	9,112,576

(i) Concept: OtherAdjustmentsToCashFlowsFromFinancingActivities


Debt Issuance Cost	$	(12,124,418)
Other Financing, Net	(394,807)
	$	(12,519,225)

(j) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities


Contribution from Parent			$	130,100,000

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

NOTES TO FINANCIAL STATEMENTS

Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Cormmission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.

(1) Background

CenterPoint Energy Houston Electric, LLC, (“CenterPoint Houston”) is an indirect, wholly-owned subsidiary of CenterPoint Energy, Inc. (“CenterPoint Energy”), a public utility holding company. CenterPoint Houston provides electric transmission and distribution services to approximately 64 Retail Electric Providers (REPs) serving approximately 2.7 million metered customers in the Texas Gulf Coast area that includes the city of Houston.

(2) Summary of Significant Accounting Policies

(a)Use of Estimates

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

(b)Revenues

CenterPoint Houston records revenue for electricity delivery under the accrual method and these revenues are recognized upon delivery to customers. Electricity deliveries not billed by month-end are accrued based on actual Advanced Metered Services (AMS) data, daily supply volumes and applicable tariff rates.

CenterPoint Houston records property, plant and equipment at historical cost and expenses repair and maintenance costs as incurred.

CenterPoint Houston periodically evaluates long-lived assets, including property, plant and equipment, and specifically identifiable intangibles subject to amortization, when events or changes in circumstances indicate that the carrying value of these assets may not be recoverable. Recoverability of long-lived assets is assessed by determining if a capital disallowance from a regulator is probable through monitoring the outcome of rate cases and other proceedings. No long-lived asset or intangible asset impairments were recorded in 2022 or 2021.

(d) Regulatory Assets and Liabilities

CenterPoint Houston applies the guidance for accounting for regulated operations. CenterPoint Houston collects revenues subject to refund pending final determination in rate proceedings. In connection with such revenues, estimated rate refund liabilities are recorded which reflect management’s current judgment of the ultimate outcomes of the proceedings.

CenterPoint Houston recognizes removal costs as a component of depreciation expense in accordance with regulatory treatment.

For further detail on CenterPoint Houston’s regulatory assets and liabilities, see Note 5.

(e) Depreciation and Amortization Expense

CenterPoint Houston computes depreciation and amortization using the straight-line method based on economic lives or regulatory-mandated recovery periods. Amortization expense includes amortization of certain regulatory assets and other intangibles.

(f) Capitalization and Deferral of Interest, including Allowance For Funds Used During Construction (AFUDC)

CenterPoint Houston capitalizes interest and AFUDC as a component of projects under construction and amortizes it over the assets’ estimated useful lives once the assets are placed in service. Additionally, CenterPoint Houston defers interest costs into a regulatory asset when amounts are probable of recovery. Deferred debt interest is amortized over the recovery period for rate-making purposes. AFUDC represents the composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction. Although AFUDC increases both utility plant and earnings, it is realized in cash when the assets are included in rates. The table below includes interest capitalized or deferred during the periods.


	Year Ended December 31,
	2022		2021
	(in millions)
Interest and AFUDC debt	$	14	$	13
AFUDC equity	24		20
Other deferred debt interest (1)	$	12	$	1

(1) Represents the amount of deferred debt interest on certain regulatory assets that are authorized to earn a return, storm restoration costs, and Temporary Emergency Electric Energy Facilities (TEEEF) (including returns on both regulatory and lease assets).

(g) Income Taxes

CenterPoint Houston is included in CenterPoint Energy’s U.S. federal consolidated income tax return. CenterPoint Houston reports its income tax provision on a separate entity basis pursuant to a tax sharing policy with CenterPoint Energy. Current federal and certain state income taxes are payable to or receivable from CenterPoint Energy.

CenterPoint Houston uses the asset and liability method of accounting for deferred income taxes. Deferred income tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. A valuation allowance is established against deferred tax assets for which management believes realization is not considered to be more likely than not. CenterPoint Houston recognizes interest and penalties as a component of income tax expense (benefit), as applicable, in its Statement of Income.

To the extent certain Excess Deferred Income Taxes (EDIT) of CenterPoint Houston may be recoverable or payable through future rates, regulatory assets and liabilities have been recorded, respectively. See Note 9 for further discussion.

CenterPoint Houston uses the portfolio approach to recognize income tax effects on other comprehensive income from accumulated other comprehensive income.

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

(h) Accounts Receivable and Allowance for Doubtful Accounts

Accounts receivable are recorded at the invoiced amount and do not bear interest. Management reviews historical write-offs, current available information, and reasonable and supportable forecasts to estimate and establish allowance for credit losses. Account balances are charged off against the allowance when management determines it is probable the receivable will not be recovered. The provisions for doubtful accounts in CenterPoint Houston’s Statement of Income for the Years Ended 2022 and 2021 was $1 million for each year. See Note 5 for further information about regulatory deferrals of bad debt expense, including those related to COVID-19 and the February 2021 Winter Storm Event.

(i) Inventory

Inventory consists of materials and supplies and is valued at the lower of average cost or market. Materials and supplies are recorded to inventory when purchased and subsequently charged to expense or capitalized to plant when installed.

(j) Derivative Instruments

CenterPoint Houston is exposed to various market risks. These risks arise from transactions entered into in the normal course of business. CenterPoint Energy has a Risk Oversight Committee composed of corporate and reportable segment officers that oversees commodity price, weather, and credit risk activities, including CenterPoint Energy’s risk management services and hedging activities. The committee’s duties are to establish CenterPoint Energy’s commodity risk policies, allocate board-approved commercial risk limits, approve the use of new products and commodities, monitor positions, and ensure compliance with CenterPoint Energy’s risk.

(k) Environmental Costs

CenterPoint Houston expenses or capitalizes environmental expenditures, as appropriate, depending on their future economic benefit. CenterPoint Houston expenses amounts that relate to an existing condition caused by past operations that do not have future economic benefit. CenterPoint Houston records undiscounted liabilities related to these future costs when environmental assessments and/or remediation activities are probable and the costs can be reasonably estimated.

(l) Cash and Cash Equivalents and Restricted Cash

For purposes of reporting cash flows, CenterPoint Houston considers cash equivalents to be short-term, highly liquid investments with maturities of three months or less from the date of purchase.

(m) New Accounting Pronouncements

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

(3) Property, Plant and Equipment

(a) Property, Plant and Equipment

Property, plant and equipment includes the following:


		December 31, 2022						December 31, 2021
	Weighted Average Useful Life (in years)	Property, Plant and Equipment, Gross		Accumulated Depreciation & Amortization		Property, Plant and Equipment, Net		Property, Plant and Equipment, Gross		Accumulated Depreciation & Amortization		Property, Plant and Equipment, Net
		(in millions)

Transmission & Distribution	38	$	14,826	$	3,714	$	11,112	$	13,338	$	3,708	$	9,630

Other	20	2,301		697		1,604		1,775		592		1,183

Total		$	17,127	$	4,411	$	12,716	$	15,113	$	4,300	$	10,813

(b) Depreciation and Amortization

The following table presents depreciation and amortization expense for 2022 and 2021:


	Year Ended December 31,
	2022		2021
	(in millions)
Depreciation	$	422	$	379

Other Amortization	44		36

Total Depreciation and Amortization	$	466	$	415

CenterPoint Houston recorded AROs associated with the removal of asbestos and asbestos-containing material in its buildings, including substation building structures. CenterPoint Houston also recorded AROs relating to treated wood poles for electric distribution, distribution transformers containing PCB (also known as Polychlorinated Biphenyl), and underground fuel storage tanks. The estimates of future liabilities were developed using historical information, and where available, quoted prices from outside contractors.

A reconciliation of the changes in the ARO liability recorded in Other non-current liabilities on CenterPoint Houston’s Comparative Balance Sheet is as follows:


	2022		2021
	(in millions)
Beginning balance	$	42	$	43
Accretion expense (1)	1		1
Revisions in estimates (2)	(7)		(2)
Ending balance	$	36	$	42

(1) Reflected in Regulatory assets on CenterPoint Houston’s Comparative Balance Sheet.

(2) In 2022, CenterPoint Houston reflected a decrease in its ARO liability, which is primarily attributable to increases in the long-term interest rates used for discounting in the ARO calculation.

(4) Revenue Recognition

In accordance with Accounting Standards Codification (ASC) 606, revenue is recognized when a customer obtains control of promised goods or services. The amount of revenue recognized reflects the consideration to which CenterPoint Houston expects to be entitled to receive in exchange for these goods or services.

The following table disaggregates revenues by major source:


	Year Ended December 31,
	2022		2021
	(in millions)
Revenue from contracts	$	3,211	$	2,878
Other (1)	(5)		16
Total revenues	$	3,206	$	2,894

(1) Primarily consists of income from Alternative Revenue Programs (ARPs) and leases. ARPs are contracts between the utility and its regulators, not between the utility and a customer. CenterPoint Houston 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. Lease income was not significant for the years ended December 31, 2022 and 2021.

Revenues from Contracts with Customers

CenterPoint Houston 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, such as the Public Utility Commission of Texas (PUCT), 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 provided by CenterPoint Houston is recognized upon completion of service based on the tariff rates set by the PUCT. Payments for electricity distribution and discretionary services are aggregated and received on a monthly basis. CenterPoint Houston 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 the regulator. Payments are received on a monthly basis.

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, CenterPoint Houston recognizes 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. CenterPoint Houston’s contract assets are included in Accrued Utility Revenues in its Comparative Balance Sheet. CenterPoint Houston’s contract liabilities are included in Deferred Credits in its Comparative Balance Sheet.

The opening and closing balances of Current and Accrued Assets, Accrued Utility Revenues, and Deferred Credits from contracts with customers are as follows:


	Current & Accrued Assets		Accrued Utility Revenues		Deferred Credits
	(in millions)
Closing Balance as of December 31, 2021	$	195	$	127	$	4
Closing Balance as of December 31, 2022	249		142		2
Increase (Decrease)	$	54	$	15	$	(2)

The amount of revenue recognized in the year ended December 31, 2022 that was included in the opening contract liability was $4 million. The difference between the opening and closing balances of the contract liabilities primarily results from the timing difference between CenterPoint Houston’s performance and the customer’s payment.

Allowance for Credit Losses and Bad Debt Expense

CenterPoint Houston had no material changes in its methodology to recognize losses on financial assets that fall under the scope of Topic 326, primarily due to the nature of its customers and regulatory environment. For a discussion of regulatory deferrals, including those related to COVID-19, see Note 5.

The table below summarizes CenterPoint Houston’s bad debt expense amounts for 2022 and 2021, net of regulatory deferrals, including those related to COVID-19:


	Year Ended December 31,
	2022		2021
	(in millions)
Bad debt expense	$	—	$	—
Bad debt expense deferred as regulatory asset	—		8

(5) Regulatory Matters

The following is a list of regulatory assets and liabilities reflected on CenterPoint Houston’s Comparative Balance Sheet as of December 31, 2022 and 2021:


	Year Ended December 31,
	2022		2021
	(in millions)
Regulatory Assets:
Future amounts recoverable from ratepayers related to:
Asset retirement obligations & other	$	29	$	29
Net deferred income taxes	34		27
Total future amounts recoverable from rate payers	63		56

Amounts deferred for future recover related to:
Hurricane and February 2021 Winter Storm restoration costs	114		105
Emergency Generation costs	702		171
COVID-19 incremental costs	8		8
Other regulatory assets	65		57
	889		341

Amounts currently recovered in customer rates related to:
Unamortized loss on reacquired debt and hedging	17		67
Regulatory assets related to TCJA	47		46
Hurricane Harvey restoration costs	30		43
Benefit Obligations (1)	18		24
Authorized trackers and costs deferrals	26		24
Other regulatory assets	—		—
Total amounts recovered in customer rates (2)	138		204
Total Regulatory Assets:	$	1,090	$	601

Regulatory Liabilities:
Current regulatory liabilities (3)	$	—	$	20

Non-current regulatory liabilities:	—		—
Regulatory liabilities related to TCJA	716		738
Other long-term regulatory liabilities	275		185
Total non-current regulatory liabilities	991		943

Total regulatory liabilities	$	991	$	943

Total regulatory assets and liabilities, net	$	99	$	(342)

(1) Pension and postretirement-related regulatory assets balances are measured annually, and the ending amortization period may change based on the actuarial valuation.

(2) Of the $138 million currently being recovered in customer rates, $121 million is earning a return. The weighted average recovery period of regulatory assets currently being recovered in base rates, not earning a return,

which totals $17 million is 26 years. Regulatory assets not earning a return with perpetual or undeterminable lives have been excluded from the weighted average recovery period calculation.

(3)Current regulatory liabilities are included in Deferred Credits in CenterPoint Houston’s Comparative Balance Sheet.

February 2021 Winter Storm Event

In February 2021, CenterPoint Houston experienced an extreme and unprecedented winter weather event that resulted in prolonged freezing temperatures, which impacted their businesses. In Texas, the February 2021 Winter Storm Event caused an electricity generation shortage that was severely disruptive to CenterPoint Houston’s service territory and the wholesale generation market. While demand for electricity reached extraordinary levels due to the extreme cold, the supply of electricity significantly decreased in part because of the inability of certain power generation facilities to supply electric power to the grid. CenterPoint Houston does not own or operate any electric generation facilities other than TEEEF. CenterPoint Houston transmits and distributes to customers of REPs electric power that the REPs obtain from power generation facilities owned by third parties. Electric Reliability Council of Texas (ERCOT) serves as the independent system operator and regional reliability coordinator for member electric power systems in most of Texas. To comply with ERCOT’s orders, CenterPoint Houston implemented controlled outages across its service territory, resulting in a substantial number of businesses and residents being without power, many for extended periods of time, in compliance with ERCOT’s directives as an emergency procedure to avoid prolonged large-scale state-wide blackouts and long-term damage to the electric system in Texas. In anticipation of this weather event, CenterPoint Houston implemented its emergency operations plan’s processes and procedures necessary to respond to such events, including establishing an incident command center and calling for mutual assistance from other utilities where needed, among other measures. Throughout the February 2021 Winter Storm Event, CenterPoint Houston remained in contact with its regulators and stakeholders, including federal, state and local officials, as well as the PUCT and ERCOT.

As of both December 31, 2022 and 2021, as authorized by the PUCT, CenterPoint Houston recorded a regulatory asset of $8 million for bad debt expenses resulting from REPs’ default on their obligation to pay delivery charges to CenterPoint Houston net of collateral. Additionally, as of December 31, 2022 and 2021, CenterPoint Houston recorded a regulatory asset of $16 million and $15 million, respectively, to defer operations and maintenance costs associated with the February 2021 Winter Storm Event.

TEEEF

Pursuant to legislation passed in 2021, CenterPoint Houston entered into two leases for TEEEF (mobile generation) which are detailed in Note 14. CenterPoint Houston sought initial recovery of the lease costs for the TEEEF and the operational costs for transportation, mobilization and demobilization, labor and materials for interconnections, fuel for commissioning, testing and operation, purchase and lease of auxiliary equipment, and labor and materials for operations in its 2022 Distribution Cost Recovery Factory (DCRF) application. CenterPoint Houston filed its DCRF application with the PUCT on April 5, 2022, and subsequently amended such filing on July 1, 2022 to show mobile generation in a separate Rider TEEEF, seeking recovery of deferred costs and the applicable return as of December 31, 2021 under these lease agreements of approximately $200 million. The annual revenue increase requested for these lease agreements is approximately $57 million. Intervenors in the proceeding filed testimony on September 16, 2022 challenging the acquisition and deployment of TEEEF and have recommended disallowances based on the overall contractual obligations. CenterPoint Houston’s rebuttal testimony was filed on October 5, 2022 responding to intervenor positions, including estimating a financial loss impact ranging from $335 million to $354 million if the PUCT disallows recovery of TEEEF costs and the termination clause under the long-term lease is exercised. The termination clause in the long-term lease agreement, as amended, contains certain provisions that allow CenterPoint Houston to terminate the lease within a specific window effective between October 1, 2022, and December 31, 2023 based upon a material adverse regulatory action. CenterPoint Houston’s exposure to loss in the event of a full disallowance of TEEEF related investments, and assuming CenterPoint Houston is unable to exercise the termination clause prior to its expiration, includes the lease costs deferred as a regulatory asset and finance Right of Use (ROU) assets further discussed in Note 14, in addition to the allowed return and other related costs incurred through the date of disallowance. On October 13, 2022, the PUCT staff filed a statement of position recommending a longer amortization period for the short-term lease, deferral of associated rate case expenses to the next base rate proceeding and exclusion of the retail transmission rate class from allocation of TEEEF costs. CenterPoint Houston indicated to the PUCT staff that it did not oppose their recommendations. The PUCT staff also reserved the right to take positions on additional issues after consideration of the evidence admitted into the record at the hearing. A hearing was held on October 18 through 20, 2022. Briefs were filed on November 16, 2022 and reply briefs were filed on December 2, 2022. On January 27, 2023, the administrative law judges issued a proposal for decision recommending that the leasing of the TEEEF was not prudent or reasonable

and necessary and that the PUCT deny recovery of all of the TEEEF costs. The PUCT is expected to consider the proposal for decision on March 9, 2023.

CenterPoint Houston defers costs associated with the short-term and long-term leases that are probable of recovery and would otherwise be charged to expense in a regulatory asset, including allowed returns, and determined that such regulatory assets remain probable of recovery as of December 31, 2022. ROU finance lease assets, such as assets acquired under the long-term leases, are evaluated for impairment under the long-lived asset impairment model by assessing if a capital disallowance from a regulator is probable through monitoring the outcome of rate cases and other proceedings. CenterPoint Houston continues to monitor the on-going proceedings and did not record any impairments on its right of use assets in the year ended December 31, 2022 or 2021. See Note 14 for further information.

COVID-19 Regulatory Matters

On March 26, 2020, the PUCT issued an order related to accrual of regulatory assets granting authority for utilities to record as a regulatory asset expenses resulting from the effects of COVID-19. In the order, the PUCT noted that it will consider whether a utility’s request for recovery of the regulatory asset is reasonable and necessary in a future proceeding.

In Texas, where CenterPoint Houston operates, the public utility commission has authorized utilities to employ deferred accounting authority for certain COVID-19 related costs which ensure the safety and health of customers, employees, and contractors, that would not have been incurred in the normal course of business.

(6) Employee Benefit Plans

(a) Pension Benefits

CenterPoint Houston participates in CenterPoint Energy’s non-contributory qualified defined benefit pension plan covering eligible employees, with benefits determined using a cash balance formula. In addition to the non-contributory qualified defined benefit pension plan, CenterPoint Energy maintains unfunded non-qualified benefit restoration plans which allow participants to receive the benefits to which they would have been entitled under CenterPoint Energy’s non-contributory qualified pension plan except for federally mandated limits on qualified plan benefits or on the level of compensation on which qualified plan benefits may be calculated.

CenterPoint Energy’s net periodic cost includes the following components relating to pension, including the non-qualified benefit restoration plan:


	Year Ended December 31,
	2022		2021
	(in millions)

Service cost (1)	$	29	$	39

Interest cost (2)	73		59

Expected return on plan assets (2)	(87)		(103)

Amortization of net loss (2)	31		36

Settlement Cost (2) (3)	126		38

Net periodic cost	$	172	$	69

(1)Amounts presented in the table above are included in Operation and maintenance expense in CenterPoint Houston’s Statement of Income, net of regulatory deferrals and amounts capitalized.

(2)Amounts presented in the table above are included in Other, net in CenterPoint Houston’s Statement of 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 2022 and 2021, CenterPoint Energy recognized non-cash settlement cost due to lump sum settlement payments.

CenterPoint Energy used the following assumptions to determine net periodic cost relating to pension benefits:


	Year Ended December 31,
	2022		2021
Discount Rate	2.80	%	2.45	%

Expected Return on Plan Assets	5.00		5.00

Rate of increase in compensation levels	4.95		5.05

In determining net periodic benefit cost, CenterPoint Energy uses fair value, as of the beginning of the year, as its basis for determining expected return on plan assets.

The following table summarizes changes in the benefit obligation, plan assets, the amounts recognized in the Comparative Balance Sheets as well as the key assumptions of CenterPoint Energy’s pension plans. The measurement dates for plan assets and obligations were December 31, 2022 and 2021.


	Year Ended December 31,
	2022		2021
	(in millions, except for actuarial assumptions)
Change in Benefit Obligation
Benefit obligation, beginning of year	$	2,298	$	2,507
Service cost	29		38
Interest cost	73		59
Benefits paid (4)	(509)		(285)
Actuarial (gain) loss (1)	(338)		(22)
Plan amendment	—		1
Benefit obligation, end of year	1,553		2,298
Change in Plan Assets
Fair value of plan assets, beginning of year	2,072		2,135
Employer contributions	35		61
Benefits paid (4)	(509)		(285)
Actual investment return	(386)		161
Fair value of plan assets, end of year	1,212		2,072
Funded status, end of year	(341)		(226)
Amounts Recognized in Balance Sheets
Non-current assets	—		6
Current liabilities-other	(7)		(7)
Other liabilities-benefit obligations	(334)		(225)
Net liability, end of year	(341)		(226)
Actuarial Assumptions
Discount rate (2)	5.15		2.80
Expected return on plan assets (3)	6.50		5.00
Rate of increase in compensation levels	4.99		4.95
Interest crediting rate	3.00		2.25

(1)Significant sources of gain for 2022 include the increase in discount rate from 2.80% to 5.15%, partially offset by significant sources of loss that include expected return on assets exceeding actual return on plan assets during 2022.

(2)The discount rate assumption was determined by matching the projected cash flows of CenterPoint Energy’s plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.

(3)The expected rate of return assumption was developed using the targeted asset allocation of CenterPoint Energy’s plans and the expected return for each asset class.

(4)Benefits paid for 2022 includes $136 million related to the 2022 Annuity Lift-Out.

The following table displays pension benefits related to CenterPoint Energy’s pension plans that have accumulated benefit obligations in excess of plan assets:


	December 31,
	2022				2021
	Pension (Qualified)		Pension (Non-Qualified)		Pension (Qualified)		Pension (Non-Qualified)
	(in millions)
Accumulated benefit obligation	$	1,497	$	51	$	2,216	$	62
Projected benefit obligation	1,502		51		2,237		62
Fair value of plan assets	1,212		—		2,072		—

The accumulated benefit obligation for all defined benefit pension plans on CenterPoint Energy’s Comparative Balance Sheet was $1,548 million and $2,278 million as of December 31, 2022 and 2021, respectively.

(b) Postretirement Benefits

CenterPoint Houston provides certain healthcare and life insurance benefits for eligible retired employees on both a contributory and non-contributory basis. CenterPoint Houston’s employees who were hired before January 1, 2018 and who have met certain age and service requirements at retirement, as defined in the plans, are eligible to participate in these benefit plans, provided, however, that life insurance benefits are available only for eligible retired employees who retired before January 1, 2022. Employees hired on or after January 1, 2018 are not eligible for these benefits, except that such employees represented by International Brotherhood of Electrical Workers (IBEW) Local Union 66 are eligible to participate in certain of the benefits, subject to the applicable age and service requirements. With respect to retiree medical and prescription drug benefits, and, effective January 1, 2021, dental and vision benefits, employees represented by the IBEW Local Union 66 who retire on or after January 1, 2017, and their dependents, receive any such benefits exclusively through the National Electrical Contractors Association (NECA)/IBEW Family Medical Care Plan pursuant to the terms of the applicable collective bargaining agreement. CenterPoint Houston is required to fund a portion of their obligations in accordance with rate orders. All other obligations are funded on a pay-as-you-go basis.

Postretirement benefits are accrued over the active service period of employees. The net postretirement benefit cost includes the following components:


	Year Ended December 31,
	2022		2021
	(in millions)

Interest cost	$	4	$	4
Expected return on plan assets	(4)		(3)
Amortization of prior service (credit)	(4)		(5)
Amortization of net loss	$	(2)
Net postretirement benefit cost (credit)	$	(6)	$	(4)

Amounts presented in the table above are included in Operation and maintenance expense in CenterPoint Houston’s Statement of Income, net of regulatory deferrals and amounts capitalized.

The following assumptions were used to determine net periodic cost relating to postretirement benefits:


	Year Ended December 31,
	2022		2021
Discount rate	2.85	%	2.50	%

Expected return on plan assets	3.32	%	3.30	%

The following table summarizes changes in the benefit obligation, plan assets, the amounts recognized in Comparative Balance Sheet and the key assumptions of the postretirement plans. The measurement dates for plan assets and benefit obligations were December 31, 2022 and 2021.


	Year Ended December 31,
	2022			2021
	(in millions)
Change in Benefit Obligation

Benefit obligation, beginning of year	$	148		$	168

Service cost	4			4

Interest cost	2			2

Participant contributions	(7)			(9)

Benefits paid	(32)			(22)

Actuarial (gain) loss (1)	—			5

Benefit obligation, end of year	115			148

Change in Plan Assets

Fair value of plan assets, beginning of year	104			106

Employer contributions	1			1

Participant contributions	2			2

Benefits paid	(7)			(9)

Actual investment return	(16)			4

Fair value of plan assets, end of year	84			104

Funded status, end of year	$	(31)		$	(44)

Amounts Recognized in Balance Sheets

Other liabilities-benefit obligations	$	(31)		$	(44)

Net liability, end of year	$	(31)		$	(44)

Actuarial Assumptions

Discount rate (2)	5.15		%	2.85		%

Expected return on plan assets (3)	3.75		%	3.32		%

Medical cost trend rate assumed for the next year - Pre-65	6.50		%	6.00		%

Medical/prescription drug cost trend rate assumed for the next year - Post-65	23.66		%	18.71		%

Prescription drug cost trend rate assumed for the next year - Pre-65	8.00		%	8.00		%

Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	4.50		%	4.50		%

Year that the cost trend rates reach the ultimate trend rate - Pre-65	2023			2029

Year that the cost trend rates reach the ultimate trend rate - Post-65	2023			2030

(1)Significant sources of gain for 2022 include updated life insurance rates and the increase in discount rate from 2.85% to 5.15%, offset by significant sources of loss including an increase in crediting rate and updated claims.

(2)The discount rate assumption was determined by matching the projected cash flows of the plans against a hypothetical yield curve of high-quality corporate bonds represented by a series of annualized individual discount rates from one-half to 99 years.

(3)The expected rate of return assumption was developed using the targeted asset allocation of the plans and the expected return for each asset class.

In managing the investments associated with the postretirement plans, CenterPoint Houston’s primary objective is to preserve and improve the funded status of the plan, while minimizing volatility. This objective is expected to be achieved through an investment strategy that manages liquidity requirements while maintaining a long-term horizon in making investment decisions and efficient and effective management of plan assets.

As part of the investment strategy discussed above, CenterPoint Houston maintained the following weighted average allocation targets for the postretirement plans as of December 31, 2022:


	CenterPoint Houston
	Minimum		Maximum
U.S. equities	13	%	23	%
International equities	3	%	13	%
Fixed income	69	%	79	%
Cash	0	%	2	%

The following table presents mutual funds by level, within the fair value hierarchy, CenterPoint Houston’s postretirement plan assets at fair value as of December 31, 2022 and 2021:


	Fair Value Measurements as of December 31,
	2022				2021
	Mutual Funds
	(Level 1)	(Level 2)	(Level 3)	Total	(Level 1)	(Level 2)	(Level 3)	Total
	(in millions)
CenterPoint Houston	84	—	—	84	105	—	—	105

The amounts invested in mutual funds were allocated as follows:


	As of December 31,
	2022		2021
Fixed income	74	%	73	%
U.S. equities	17	%	19	%
International equities	8	%	8	%

(d) Benefit Plan Contributions

CenterPoint Houston made the following contributions in 2022 and expect to make the following minimum contributions in 2023 to the indicated benefit plans below:


	Expected Minimum Contributions in 2022		Expected Minimum Contributions in 2023

	(in millions)
Qualified pension plans	$	—	$	—
Non-qualified pension plans	—		—
Postretirement benefit plans	1		1

The following benefit payments are expected to be paid by the pension and postretirement benefit plans:


	Postretirement Benefits

2023	$	6
2024	7
2025	8
2026	9
2027	9
2028-2032	49

(e) Savings Plan

CenterPoint Houston participates in the CenterPoint Energy Savings Plan, a tax-qualified employee savings plan that includes a cash or deferred arrangement under Section 401(k) of the Code, and an employee stock ownership plan under Section 4975(e)(7) of the Code. Under the plan, participating employees may make pre-tax or Roth contributions and, if eligible, after-tax contributions up to certain federally mandated limits. Participating Registrants provide matching contributions and, as of January 1, 2020, for certain eligible employees, nonelective contributions up to certain limits.

The CenterPoint Energy Savings Plan has significant holdings of Common Stock. As of December 31, 2022, 7,335,725 shares of Common Stock were held by the savings plan, which represented approximately 9% of its investments. Given the concentration of the investments in Common Stock, the savings plan and its participants have market risk related to this investment. The savings plan limits the percentage of future contributions that can be invested in Common Stock to 25% and prohibits transfers of account balances where the transfer would result in more than 25% of a participant’s total account balance invested in Common Stock.

CenterPoint Energy allocates the savings plan benefit expense to CenterPoint Houston related to their respective employees. The following table summarizes CenterPoint Houston’s savings plan benefit expense for 2022 and 2021:


	Year Ended December 31,
	2022		2021
	(in millions)

Savings plan benefit expenses (1)	$	23	$	20

(1) Amounts presented in the table above are included in Operation and maintenance expense in CenterPoint Houston’s Statement of Income and shown prior to any amounts capitalized.

(f) Other Benefits Plans

CenterPoint Houston participates in CenterPoint Energy’s plans that provide postemployment benefits for certain former or inactive employees, their beneficiaries and covered dependents, after employment but before retirement (primarily healthcare and life insurance benefits for participants in the long-term disability plan).

CenterPoint Houston participates in CenterPoint Energy’s non-qualified deferred compensation plans that provide benefits payable to eligible directors, officers and select employees or their designated beneficiaries at specified future dates or upon termination, retirement or death. Benefit payments are made from the general assets of CenterPoint Houston.

Expenses related to other benefit plans were recorded as follows:


	Year Ended December 31,
	2022		2021
	(in millions)
Postemployment benefits	$	1	$	1
Deferred Compensation Plans	—		—

Amounts related to other benefit plans were included in Benefit Obligations in CenterPoint Houston accompanying Comparative Balance Sheets as follows:


	December 31, 2022		December 31, 2021
	(in millions)
Postemployment benefits	$	3	$	3
Deferred compensation plans	4		6
Split-dollar life insurance arrangements	1		1

(g) Change in Control Agreements and Other Employee Matters

CenterPoint Energy has a change in control plan, which was amended and restated on May 1, 2017. The plan generally provides, to the extent applicable, in the case of a change in control of CenterPoint Energy and covered termination of employment, for severance benefits of up to three times annual base salary plus bonus, and other benefits. Certain CenterPoint Energy officers are participants under the plan.

As of December 31, 2022, CenterPoint Houston’s employees were covered by collective bargaining agreements as follows:


	Agreement Expiration	Houston Electric
IBEW Local 66	May 2023	54%

(7) Fair Value Measurements

Assets and liabilities that are recorded at fair value in CenterPoint Houston’s Comparative Balance Sheet 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, 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, and inputs other than quoted prices that are observable for the asset or liability. Fair value assets and liabilities that are generally included in this category are derivatives with fair values based on inputs from actively quoted markets.

Level 3: Inputs are unobservable for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability. Unobservable inputs reflect CenterPoint Houston’s judgment about the assumptions market participants would use in pricing the asset or liability since limited market data exists. CenterPoint Houston develops these inputs based on the best information available, including CenterPoint Houston’s own data.

CenterPoint Houston determines the appropriate level for each financial asset and liability on a quarterly basis and recognize transfers between levels at the end of the reporting period.

The following tables present information about CenterPoint Houston’s assets and liabilities (including derivatives that are presented net) measured at fair value on a recurring basis as of December 31, 2022 and December 31, 2021, and indicate the fair value hierarchy of the valuation techniques utilized by CenterPoint Houston to determine such fair value.


	December 31, 2022												December 31, 2021
	Level 1		Level 2		Level 3				Total				Level 1				Level 2				Level 3				Total
	(in millions)
Assets

Investments, including money market funds (1)	$	4	$	—	$	—			$	4			$	27			$	—			$	—			$	27

Total assets	$	4	$	—	$	—	$	—	$	4	$	—	$	27	$	—	$	—	$	—	$	—	$	—	$	27

(1) Amounts are included in Miscellaneous Deferred Debits in the Comparative Balance Sheets.

During 2022 and 2021, CenterPoint Houston did not have any assets or liabilities designated as Level 3.

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 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 CenterPoint Houston’s Comparative Balance Sheet, but for which the fair value is disclosed, would be classified as Level 2 in the fair value hierarchy.


	December 31, 2022				December 31, 2021
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(in millions)
Financial liabilities:

Long-term debt, including current maturities	$	6,036	$	5,194	$	4,958	$	5,732

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


	December 31, 2022				December 31, 2021
	Long-Term		Current (1)		Long-Term		Current (1)
	(in millions)


CenterPoint Houston:
General mortgage bonds 2.35% to 6.95% due 2026 to 2052 (2)	6,112		—		4,712		300
Other	1		—		—		—
Unamortized debt issuance costs	(50)		—		(36)		—
Unamortized discount and premium, net	(27)		—		(18)		—
Total CenterPoint Houston debt	$	6,036	$	—	$	4,658	$	300

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

(2) The general mortgage bonds issued by CenterPoint Houston subject CenterPoint Houston’s properties to a lien under the General Mortgage as further discussed below.

Debt Transactions

Debt Issuances. During 2022, the following debt instruments were issued or incurred:



Issuance Date	Debt Instrument	Aggregate Principal Amount		Interest Rate	Maturity Date

		(in millions)
February 2022	General Mortgage Bonds (1)	$	300	3.00%	2032
February 2022	General Mortgage Bonds (1)	500		3.60%	2052
September 2022	General Mortgage Bonds (2)	500		4.45%	2032
September 2022	General Mortgage Bonds (2)	300		4.85%	2052
		$	1,600

(1) Total proceeds, net of discounts and issuance expenses and fees, of approximately $784 million were used for general limited liability company purposes, including capital expenditures and the repayment of all or a portion of CenterPoint Houston’s borrowings under the CenterPoint Energy money pool.

(2) Total proceeds, net of discounts and issuance expenses and fees, of approximately $789 million were used for general limited liability company purposes, including capital expenditures, the repayment of all or a portion of CenterPoint Houston’s borrowings under the CenterPoint Energy money pool and the redemption of outstanding general mortgage bonds discussed below.

Debt Repayments and Redemptions. During 2022, the following debt instruments were repaid at maturity or redeemed:


Repayment/Redemption	Debt Instrument	Aggregate Principal		Interest Rate	Maturity Date
Date
		(in millions)
August 2022	General Mortgage Bonds	$	300	2.25%	2022
October 2022	General Mortgage Bonds (1)	200		5.60%	2023
	Total CenterPoint Houston	$	500

(1) In September 2022, CenterPoint Houston provided notice of redemption, and on October 17, 2022, CenterPoint Houston redeemed $200 million aggregate principal amount, plus accrued and unpaid interest of approximately $3 million and an applicable make-whole premium of approximately $2 million, for a total redemption price of $205 million.

CenterPoint Houston recorded a loss on early extinguishment of debt of $2 million during the year ended December 31, 2022, which was recorded as a regulatory asset.

Credit Facilities. On December 6, 2022, CenterPoint Houston replaced their existing revolving credit facilities with three revolving credit.

CenterPoint Houston had the following revolving credit facilities as of December 31, 2022:


Execution Date	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 December 31, 2021 (2)		Termination Date
	(in millions)
December 6, 2022	300	1.250	%	67.5%	(3)	54.4	%	December 6, 2027

(1)Based on credit ratings as of December 31, 2022.

(2)As defined in the revolving credit facility agreement,

(3)For CenterPoint Houston, the financial covenant limit will temporarily increase to 70% if CenterPoint Houston experiences damage from a natural disaster in its service territory and CenterPoint Houston

certifies to the administrative agent that CenterPoint Houston has incurred system restoration costs reasonably likely to exceed $100 million in a consecutive 12-month period, all or part of which CenterPoint Houston intends to seek to recover through securitization financing. Such temporary increase in the financial covenant would be in effect from the date CenterPoint Houston delivers its certification until the earliest to occur of (i) the completion of the securitization financing, (ii) the first anniversary of CenterPoint Houston’s certification or (iii) the revocation of such certification.

CenterPoint Houston was in compliance with all financial debt covenants as of December 31, 2022.

Maturities. As of December 31, 2022, maturities of long-term debt through 2027, were as follows:


	(in millions)

2023	$	—
2024	—
2025	—
2026	300
2027	300

Liens. As of December 31, 2022, CenterPoint Houston’s assets were subject to liens securing approximately $6.2 billion of general mortgage bonds outstanding under the General Mortgage, including approximately $68 million held in trust to secure pollution control bonds that mature in 2028 for which CenterPoint Energy is obligated. The general mortgage bonds that are held in trust to secure pollution control bonds are not reflected in CenterPoint Houston’s financial statements because of the contingent nature of the obligations. CenterPoint Houston may issue additional general mortgage bonds on the basis of retired bonds, 70% of property additions or cash deposited with the trustee. CenterPoint Houston could issue approximately $4.9 billion of additional general mortgage bonds on the basis of retired bonds and 70% of property additions as of December 31, 2022. No first mortgage bonds are outstanding under the Mortgage and Deed of Trust (M&DOT), and CenterPoint Houston is contractually obligated to not issue any additional first mortgage bonds under the M&DOT and is undertaking actions to release the lien of the M&DOT and terminate the M&DOT.

(9) Income Taxes

The components of CenterPoint Houston's income tax expense (benefit) were as follows:


	Year Ended December 31,
	2022		2021
	(in millions)
CenterPoint Houston
Current income tax expense:
Federal	$	64	$	(8)
State	17		21
Total current expense	81		13
Deferred income tax benefit:
Federal	48		61
State	(1)		2
Total deferred benefit	47		63
Total income tax expense	$	128	$	76

A reconciliation of income tax expense (benefit) using the federal statutory income tax rate to the actual income tax expense and resulting effective income tax rate is as follows:


	Year Ended December 31,
	2022			2021
	(in millions)
CenterPoint Houston (1) (2)
Income before income taxes	$	652		$	457
Federal statutory income tax rate	21		%	21		%
Expected federal income tax expense	137			96
Increase (decrease) in tax expense resulting from:
State income tax expense, net of federal income tax	12			18
Excess deferred income tax amortization	(18)			(41)
Other, net	(4)			3
Total	(9)			(20)
Total income tax expense	$	128		$	76
Effective tax rate	20		%	17		%

(1) Recognized a $18 million benefit for the amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions.

(2) Recognized a $41 million benefit for the amortization of the net regulatory EDIT liability as decreed by regulators in certain jurisdictions.

The tax effects of temporary differences that give rise to significant portions of deferred tax assets and liabilities were as follows:


	December 31,
	2022		2021
	(in millions)

Deferred tax assets:
Regulatory liabilities	$	184	$	175
Benefits and compensation	10		13
Asset retirement obligations	6		9
Other	13		10
Total deferred tax assets	213		207
Deferred tax liabilities:
Property, plant and equipment	1,330		1,215
Regulatory assets	112		114
Total deferred tax liabilities	1,442		1,329
Net deferred tax liabilities	$	1,229	$	1,122

(10) Commitments and Contingencies

Legal, Environmental and Other Matters

(a) Legal Matters

Litigation Related to the February 2021 Winter Storm Event. Various legal proceedings are still pending and new legal matters are being filed against numerous entities with respect to the February 2021 Winter Storm Event, including against CenterPoint Houston. Like other Texas energy companies and Transmission and distribution utility (TDUs), CenterPoint Houston has become involved in certain investigations, litigations and other regulatory and legal proceedings regarding their efforts to restore power during the storm and their compliance with North American Electric Reliability Corporation (NERC), Electric Reliability Council of Texas (ERCOT) and PUCT rules and directives.

CenterPoint Houston, along with hundreds of other defendants (including ERCOT, power generation companies, other TDUs, natural gas producers, REPs, and other entities) have received, and may continue to receive, claims and lawsuits filed by plaintiffs alleging wrongful death, personal injury, property damage and other injuries and damages.

The litigation is consolidated in Texas state court in Harris County, Texas, as part of a multi-district litigation proceeding. The judge overseeing the multi-district litigation issued an initial case management order and stayed all proceedings and discovery. Per the case management order, the judge entertained dispositive motions in five representative or “bellwether” cases and, in late January 2023, issued rulings on them. The judge ruled that ERCOT has sovereign immunity as a governmental entity and dismissed the suits against it. The judge also dismissed all claims against the REP defendants and some causes of action against the other defendants. As to the TDU and generator defendants, the judge dismissed some causes of action but denied the motions to dismiss claims for negligence, gross negligence, and nuisance, which denial the TDU defendants and generator defendants are asking the court of appeals to overturn. The judge allowed plaintiffs to file amended petitions, but otherwise the cases remain stayed for now as the judge addresses additional preliminary issues.

Following the initial rulings and around the two-year anniversary of the February 2021 Winter Storm Event, there have been voluminous amendments, non-suits, re-filings, and new filings of lawsuits, such that the pleadings are still being settled and the precise number of cases and claims against particular defendants and in total is still being determined. As of February 15, 2023, there are approximately 250 pending lawsuits that are in or will be added to the multi-district litigation proceeding related to the February 2021 Winter Storm Event, and CenterPoint Houston, along with numerous other entities, have been named as defendants in approximately 160 of those. One of the newly filed

lawsuits is a putative class action on behalf of everyone who received electric power via the ERCOT grid and sustained a power outage between February 10, 2021 and February 28, 2021. CenterPoint Houston intends to vigorously defend itself against the claims raised.

CenterPoint Houston has also responded to inquiries from the Texas Attorney General and the Galveston County District Attorney’s Office, and various other regulatory and governmental entities also conducted inquiries, investigations and other reviews of the February 2021 Winter Storm Event and the efforts made by various entities to prepare for, and respond to, the event, including the electric generation shortfall issues.

To date, there have not been demands, quantification, disclosure or discovery of damages by any party to any of the above legal matters that are sufficient to enable CenterPoint Houston to estimate exposure. Given that, as well as the preliminary nature of the proceedings, the numerosity of parties and complexity of issues involved, and the uncertainties of litigation, CenterPoint Houston is unable to predict the outcome or consequences of any of the foregoing matters or to estimate a range of potential losses. CenterPoint Houston has general and excess liability insurance policies that provide coverage for third party bodily injury and property damage claims. Given the nature of certain of the recent allegations, however, it is possible that the insurers for third party bodily injury and property damage claims could dispute coverage for other types of damage that may be alleged by plaintiffs. CenterPoint Houston intends to continue to pursue any and all available insurance coverage for all of the litigation related to the February 2021 Winter Storm Event.

(b) Environmental Matters

Asbestos. Some facilities owned by CenterPoint Houston contains or has contained asbestos insulation and other asbestos-containing materials. CenterPoint Houston is 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 CenterPoint Houston anticipates that additional claims may be asserted in the future. Although their ultimate outcome cannot be predicted at this time, CenterPoint Houston does 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 Environmental. From time to time, CenterPoint Houston identifies 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. CenterPoint Houston has and expects to continue to remediate any identified sites consistent with state and federal legal obligations. From time to time, CenterPoint Houston has received notices, and may receive notices in the future, from regulatory authorities or others regarding status as a Potentially responsible parties (PRP) in connection with sites found to require remediation due to the presence of environmental contaminants. In addition, CenterPoint Houston has 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, CenterPoint Houston does 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.

CenterPoint Houston is involved in other legal, environmental, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies regarding matters arising in the ordinary course of business. From time to time, CenterPoint Houston is also 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. CenterPoint Houston regularly analyzes current information and, as necessary, provides accruals for probable and reasonably estimable liabilities on the eventual disposition of these matters. CenterPoint Houston does not expect the disposition of these matters to have a material adverse effect on CenterPoint Houston’s financial condition, results of operations or cash flows.

(11) Major Customers

CenterPoint Houston’s revenues from major external customers are as follows:


	Year Ended December 31,
	2022		2021
	(in millions)
Affiliates of NRG	$	1,046	$	905

Affiliates of Vistra Energy Corp.	489		410

(12) Supplemental Disclosure of Cash Flow Information

The tables below provide supplemental disclosure of cash flow information:


	December 31,
	2022		2021
	(in millions)

Cash Payments/Receipts:

Interest, net of capitalized interest	$	208	$	186

Income taxes payments (refunds), net	142		20

Non-cash transactions:

Accounts payable related to capital expenditures	168		261
ROU assets obtained line exchanged for lease liabilities	6		—

The table below provides a reconciliation of cash and cash equivalents reported in the Statement of Cash Flows:


	December 31,
	2022		2021
	(in millions)

Cash and cash equivalents	$	1	$	127

(13) Related Party Transactions

CenterPoint Houston participates 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:


	December 31, 2022			December 31, 2021
	(in millions, except interest rates)
Money pool investments (borrowings) (1)	$	(642)		$	(512)
Weighted average interest rate	4.75		%	0.34		%

(1) Included in Accounts and notes receivable (payable) in CenterPoint Houston’s Comparative Balance Sheets.

CenterPoint Houston affiliate-related net interest income (expense) were as follows:


	Year Ended December 31,
	2022		2021
	(in millions)
Interest income (expense), net	$	—	$	—

CenterPoint Energy provides some corporate services to CenterPoint Houston. The costs of services have been charged directly to CenterPoint Houston using methods that management believes are reasonable. These methods include negotiated usage rates, dedicated asset assignment and proportionate corporate formulas based on operating expenses, assets, gross margin, employees and a composite of assets, gross margin and employees. CenterPoint Houston 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 CenterPoint Houston. 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 CenterPoint Houston and CERC not been affiliates.

Amounts charged for these services are included primarily in Operation and maintenance expenses:


	Year Ended December 31,
	2022		2021
	(in millions)
Corporate service charges	$	167	$	189
Net affiliate service charges (billings)	15		(7)

The table below presents transactions among CenterPoint Houston and its parent, Utility Holding.


	Year Ended December 31,
	2022		2021
	(in millions)
Cash dividends paid to parent	$	316	$	—
Cash contribution from parent	1,143		130
Property, plant and equipment from parent	—		—
Non-cash capital contribution from parent in payment for property, plant and equipment below	38		—
Cash paid to parent for property, plant and equipment below	65		—
Property, plant and equipment from parent (1)	103		—

(1) Property, plant and equipment purchased from CenterPoint Energy at its net carrying value on the date of purchase.

(14) Leases

An arrangement is determined to be a lease at inception based on whether CenterPoint Houston has the right to control the use of an identified asset. ROU assets represent CenterPoint Houston’ right to use the underlying asset for the lease term and lease liabilities represent CenterPoint Houston' 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 CenterPoint Houston is the lessee does 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. CenterPoint Houston uses the implicit rate for agreements in which it is a lessor. Lease income and expense for operating leases and ROU amortization for finance leases are recognized on a straight-line basis over the lease term.

CenterPoint Houston has 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 and mobile generators. 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. Sublease income is not significant to CenterPoint Houston.

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

CenterPoint Houston’s operating lease agreements are primarily equipment and real property leases, including land and office facility leases. CenterPoint Houston also has finance lease agreements for mobile generators. CenterPoint Houston’s lease terms may include options to extend or terminate a lease when it is reasonably certain that those options will be exercised. CenterPoint Houston has elected an accounting policy that exempts leases with terms of one year or less from balance sheet lease recognition requirements.

In 2021, CenterPoint Houston entered into a temporary short-term lease and long-term leases for mobile generation. The short-term lease agreement allows CenterPoint Houston to take delivery of TEEEF assets on a short-term basis

with an initial term ending on September 30, 2022 and extended until December 31, 2022. As of December 31, 2022, the short-term lease agreement has expired and all mobile generation assets are leased under the long-term lease agreement. Per CenterPoint Houston’s short-term lease accounting policy election, a ROU asset and lease liability are not reflected on CenterPoint Houston’s Comparative Balance Sheet. Expenses associated with the short-term lease, including carrying costs, are deferred to a regulatory asset and totaled $103 million and $20 million as of December 31, 2022 and 2021, respectively.

The long-term lease agreement includes up to 505 MW of TEEEF of which 380 MW and 125 MW was delivered as of December 31, 2022 and 2021, respectively, triggering lease commencement at delivery, and has an initial term ending in 2029 for all TEEEF leases. The total cash payments under the long-term lease totaled $664 million, with $179 million paid in 2021 and the remaining $485 million paid in 2022. These assets were previously available under the short-term lease agreement. CenterPoint Houston derecognized the finance lease liability when the extinguishment criteria in Topic 405 - Liabilities was achieved. Per the terms of the agreement, lease payments are due and made in full by CenterPoint Houston upon taking possession of the asset, relieving substantially all of the associated finance lease liability at that time. The remaining finance lease liability associated with the commenced long-term TEEEF agreement was not significant as of December 31, 2022 and 2021 and relates to removal costs that will be incurred at the end of the lease term. As of December 31, 2022, CenterPoint Houston has secured a first lien on the assets leased under the prepayment agreement, except for assets with lease payments totaling $113 million. The $113 million prepayment is being held in an escrow account, not controlled by CenterPoint Houston, and the funds will be released when a first lien can be secured by CenterPoint Houston. Expenses associated with the long-term lease, including depreciation expense on the right of use asset and carrying costs, are deferred to a regulatory asset and totaled $60 million and $1 million as of December 31, 2022 and 2021, respectively. The long-term lease agreement contains a termination clause that can be exercised in the event of material adverse regulatory actions. If the right to terminate is elected, subject to the satisfaction of certain conditions, 75% of CenterPoint Houston’s prepaid lease costs that is attributable to the period from the effective date of termination to the end of the lease term would be refunded. In December 2022, the long-term lease agreement was amended to include a disallowance reimbursement clause that can be exercised in the event that any regulatory proceeding or settlement agreement results in a disallowance of CenterPoint Houston’s recovery of deferred costs under either the long-term lease agreement, short-term lease agreement or any other quantifiable adverse financial impact to CenterPoint Houston. If the disallowance reimbursement clause is exercised, 85% of such disallowance up to $53 million would be paid to CenterPoint Houston. Any disallowance greater than $53 million would remain subject to the 75% limit set forth in the termination clause. For further discussion of the regulatory impacts, see Note 5.

CenterPoint Houston will also incur variable costs throughout the lease term for the operation and maintenance of the generators. Lease costs, including variable and ROU asset amortization costs, are deferred to Regulatory assets as incurred as a recoverable cost under the 2021 Texas legislation.

The components of lease cost, included in Operation and maintenance expense on CenterPoint Houston’s Statement of Income, is as follows:


	Year Ended December 31, 2022		Year Ended December 31, 2021
	(in millions)
Operating lease cost	$	1	$	1
Short-term lease cost	151		118
Total lease cost (1)	$	152	$	119

(1) CenterPoint Houston defers finance lease costs for TEEEF to Regulatory assets for recovery rather than to Depreciation and Amortization in the Statement of Income.

The components of lease income were as follows:

Year Ended December 31, 2022

Year Ended December 31, 2021

(in millions)


Operating lease income	$	1	$	1
Variable lease income		—		—
Total lease income	$	1	$	1

Supplemental balance sheet information related to leases was as follows:


	December 31, 2022				December 31, 2021

Assets:
Operating Lease (1)	$		6		$	1
Capital Lease			—		—
Total leased assets	$		6		$	1
Liabilities:

Current operating lease liability	$	—			$	—
Non-current operating lease liability		—				1
Total leased liabilities	$	—			$	1


Weighted-average remaining lease term (in years)		4.8				4.1
- operating leases
Weighted-average discount rate - capital leases		4.01		%		2.86	%
Weighted-average remaining lease term (in years)		6.5			7.5
- finance leases
Weighted-average discount		3.60		%	2.21		%

(1) Reported within Other assets in CenterPoint Houston’s Comparative Balance Sheet.

As of December 31, 2022, finance capital liabilities were not significant to CenterPoint Houston. As of December 31, 2022, maturities of operating lease liabilities were as follows:


		(in millions)
2023	$	1
2024		2
2025		2
2026		1
2027		1
2028 and beyond		—
Total lease payments		7
Less: Interest		1
Present value of lease liabilities	$	6

As of December 31, 2022, future minimum finance lease payments were not significant to CenterPoint Houston. As of December 31, 2022, maturities of undiscounted operating lease payments to be received are as follows:


		(in millions)
2023	$	1
2024		1
2025		1
2026		—
2027		—
2028 and beyond		—
Total lease payments		3

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No.	Item (a)	Unrealized Gains and Losses on Available-For-Sale Securities (b)	Minimum Pension Liability Adjustment (net amount) (c)	Foreign Currency Hedges (d)	Other Adjustments (e)	Other Cash Flow Hedges Interest Rate Swaps (f)	Other Cash Flow Hedges [Specify] (g)	Totals for each category of items recorded in Account 219 (h)	Net Income (Carried Forward from Page 116, Line 78) (i)	Total Comprehensive Income (j)
1	Balance of Account 219 at Beginning of Preceding Year		47,485					47,485
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3	Preceding Quarter/Year to Date Changes in Fair Value		64,540					64,540
4	Total (lines 2 and 3)		64,540					64,540	381,289,825	381,354,365
5	Balance of Account 219 at End of Preceding Quarter/Year		17,055					17,055
6	Balance of Account 219 at Beginning of Current Year		17,055					17,055
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8	Current Quarter/Year to Date Changes in Fair Value		26,691				(a) 0	26,691
9	Total (lines 7 and 8)		26,691					26,691	523,455,616	523,428,925
10	Balance of Account 219 at End of Current Quarter/Year		9,636					(b) 9,636

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: AccumulatedOtherComprehensiveIncomeLossOtherCashFlowHedgesChangesInFairValue

From time to time, CenterPoint Houston entered into forward interest rate agreements with certain counterparties designated as cash flow hedges. The objective of these cash flow hedges to reduce exposure to variability in cash flows related to interest payments on anticipated future fixed rate debt offerings or other exposure to variable rate debt.

(b) Concept: AccumulatedOtherComprehensiveIncomeLoss


Benefits Minimum Liability Adj./ASC 715 - Compensation Retirement Benefit			$	9,636

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No.	Classification (a)	Total Company For the Current Year/Quarter Ended (b)	Electric (c)	Gas (d)	Other (Specify) (e)	Other (Specify) (f)	Other (Specify) (g)	Common (h)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlantInServiceAbstract In Service
3	UtilityPlantInServiceClassified Plant in Service (Classified)	15,146,376,308	15,146,376,308
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified	898,664,872	898,664,872
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	16,045,041,180	16,045,041,180
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use	10,452,078	10,452,078
11	ConstructionWorkInProgress Construction Work in Progress	1,071,752,129	1,071,752,129
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	17,127,245,387	17,127,245,386
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	4,411,071,383	4,411,071,383
15	UtilityPlantNet Net Utility Plant (13 less 14)	12,716,174,004	12,716,174,003
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	4,151,042,545	4,151,042,545
19	AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights
20	AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights
21	AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant	260,028,837	260,028,837
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	4,411,071,383	4,411,071,383
23	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others
24	DepreciationUtilityPlantLeasedToOthers Depreciation
25	AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion
26	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25)
27	DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use
28	DepreciationUtilityPlantHeldForFutureUse Depreciation
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	4,411,071,383	4,411,071,383

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.	Description of item (a)	Balance Beginning of Year (b)	Changes during Year Additions (c)	Changes during Year Amortization (d)	Changes during Year Other Reductions (Explain in a footnote) (e)	Balance End of Year (f)
1	Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2	Fabrication
3	Nuclear Materials
4	Allowance for Funds Used during Construction
5	(Other Overhead Construction Costs, provide details in footnote)
6	SUBTOTAL (Total 2 thru 5)	0				0
7	Nuclear Fuel Materials and Assemblies
8	In Stock (120.2)
9	In Reactor (120.3)
10	SUBTOTAL (Total 8 & 9)
11	Spent Nuclear Fuel (120.4)
12	Nuclear Fuel Under Capital Leases (120.6)	0				0
13	(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)	0				0
14	TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)	0				0
15	Estimated Net Salvage Value of Nuclear Materials in Line 9
16	Estimated Net Salvage Value of Nuclear Materials in Line 11
17	Est Net Salvage Value of Nuclear Materials in Chemical Processing
18	Nuclear Materials held for Sale (157)
19	Uranium
20	Plutonium
21	Other (Provide details in footnote)
22	TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)	0				0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Report below the original cost of electric plant in service according to the prescribed accounts. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.	Account (a)	Balance Beginning of Year (b)	Additions (c)	Retirements (d)	Adjustments (e)	Transfers (f)	Balance at End of Year (g)
1	1. INTANGIBLE PLANT
2	(301) Organization
3	(302) Franchise and Consents
4	(303) Miscellaneous Intangible Plant	390,113,958	38,231,784	10,460,326		92,700,811	510,586,227
5	TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)	390,113,958	38,231,784	10,460,326		92,700,811	510,586,227
6	2. PRODUCTION PLANT
7	A. Steam Production Plant
8	(310) Land and Land Rights
9	(311) Structures and Improvements
10	(312) Boiler Plant Equipment
11	(313) Engines and Engine-Driven Generators
12	(314) Turbogenerator Units
13	(315) Accessory Electric Equipment
14	(316) Misc. Power Plant Equipment
15	(317) Asset Retirement Costs for Steam Production
16	TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
17	B. Nuclear Production Plant
18	(320) Land and Land Rights
19	(321) Structures and Improvements
20	(322) Reactor Plant Equipment
21	(323) Turbogenerator Units
22	(324) Accessory Electric Equipment
23	(325) Misc. Power Plant Equipment
24	(326) Asset Retirement Costs for Nuclear Production
25	TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26	C. Hydraulic Production Plant
27	(330) Land and Land Rights
28	(331) Structures and Improvements
29	(332) Reservoirs, Dams, and Waterways
30	(333) Water Wheels, Turbines, and Generators
31	(334) Accessory Electric Equipment
32	(335) Misc. Power Plant Equipment
33	(336) Roads, Railroads, and Bridges
34	(337) Asset Retirement Costs for Hydraulic Production
35	TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36	D. Other Production Plant
37	(340) Land and Land Rights
38	(341) Structures and Improvements
39	(342) Fuel Holders, Products, and Accessories
40	(343) Prime Movers
41	(344) Generators
42	(345) Accessory Electric Equipment
43	(346) Misc. Power Plant Equipment
44	(347) Asset Retirement Costs for Other Production
44.1	(348) Energy Storage Equipment - Production
45	TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
46	TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
47	3. Transmission Plant
48	(350) Land and Land Rights	215,084,539	1,149,796				216,234,335
48.1	(351) Energy Storage Equipment - Transmission
49	(352) Structures and Improvements	208,241,623	19,427,368	1,203,968			226,465,023
50	(353) Station Equipment	1,217,174,649	112,316,097	26,579,648		12,247,569	1,290,663,529
51	(354) Towers and Fixtures	1,376,319,563	194,703,561	14,572,729			1,556,450,395
52	(355) Poles and Fixtures	141,206,984	34,521,615	4,326,164			171,402,435
53	(356) Overhead Conductors and Devices	892,651,448	156,891,397	24,642,448			1,024,900,397
54	(357) Underground Conduit	38,232,025					38,232,025
55	(358) Underground Conductors and Devices	14,946,316					14,946,316
56	(359) Roads and Trails	277,086,690	116,801,391	136,938			393,751,143
57	(359.1) Asset Retirement Costs for Transmission Plant
58	TOTAL Transmission Plant (Enter Total of lines 48 thru 57)	4,380,943,837	635,811,225	71,461,895		12,247,569	4,933,045,598
59	4. Distribution Plant
60	(360) Land and Land Rights	47,350,302	75,483,927			49,301	122,883,530
61	(361) Structures and Improvements	147,783,076	420,336	1,759,924			145,602,816
62	(362) Station Equipment	1,338,882,994	100,791,698	23,585,157		11,651,473	1,427,741,008
63	(363) Energy Storage Equipment – Distribution
64	(364) Poles, Towers, and Fixtures	1,032,914,298	180,139,128	19,902,471			1,193,150,955
65	(365) Overhead Conductors and Devices	1,173,999,206	166,771,628	26,784,645			1,313,986,189
66	(366) Underground Conduit	703,580,378	40,171,518	7,458,920			736,292,976
67	(367) Underground Conductors and Devices	1,266,948,716	104,504,821	10,488,345			1,360,965,192
68	(368) Line Transformers	1,586,062,433	183,759,403	48,799,716			1,721,022,120
69	(369) Services	229,574,657	12,565,647	278,869			241,861,435
70	(370) Meters	260,769,573	39,558,332	6,147,901			294,180,004
71	(371) Installations on Customer Premises
72	(372) Leased Property on Customer Premises
73	(373) Street Lighting and Signal Systems	723,170,164	45,016,679	5,887,040			762,299,803
74	(374) Asset Retirement Costs for Distribution Plant	21,428,984	2,328,955				19,100,029
75	TOTAL Distribution Plant (Enter Total of lines 60 thru 74)	8,532,464,781	946,013,490	151,092,988		11,700,774	9,339,086,057
76	5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77	(380) Land and Land Rights
78	(381) Structures and Improvements
79	(382) Computer Hardware
80	(383) Computer Software
81	(384) Communication Equipment
82	(385) Miscellaneous Regional Transmission and Market Operation Plant
83	(386) Asset Retirement Costs for Regional Transmission and Market Oper
84	TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85	6. General Plant
86	(389) Land and Land Rights	21,886,491	7,984,173				29,870,664
87	(390) Structures and Improvements	260,248,062	4,494,747			1,299,655	266,042,464
88	(391) Office Furniture and Equipment	12,525,773	36,271,440			63,217	48,860,430
89	(392) Transportation Equipment	156,854,787	21,361,860	7,536,376		217,712	170,462,559
90	(393) Stores Equipment	394,082	88,499				482,581
91	(394) Tools, Shop and Garage Equipment	21,677,861	3,405,956	51,274			25,032,543
92	(395) Laboratory Equipment	23,583,466	1,514,874	204,777			24,893,563
93	(396) Power Operated Equipment	27,079,494	2,836,000	489,475			29,426,019
94	(397) Communication Equipment	566,587,610	42,586,150	15,955,524		55,643,403	648,861,639
95	(398) Miscellaneous Equipment	13,948,874	1,089,978	7,037		21,784	15,067,673
96	SUBTOTAL (Enter Total of lines 86 thru 95)	1,104,786,500	121,633,677	24,230,389		56,810,347	1,259,000,135
97	(399) Other Tangible Property		3,620,040	992,880	361,497		4,251,423
98	(399.1) Asset Retirement Costs for General Plant	7,936,083			361,497		7,574,586
99	TOTAL General Plant (Enter Total of lines 96, 97, and 98)	1,112,722,583	118,013,637	25,223,269		56,810,347	1,262,323,298
100	TOTAL (Accounts 101 and 106)	14,416,245,159	1,738,070,136	258,238,478		148,964,363	16,045,041,180
101	(102) Electric Plant Purchased (See Instr. 8)
102	(Less) (102) Electric Plant Sold (See Instr. 8)
103	(103) Experimental Plant Unclassified
104	TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)	14,416,245,159	1,738,070,136	258,238,478		148,964,363	16,045,041,180

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.	LesseeName Name of Lessee (a)	IndicationOfAssociatedCompany * (Designation of Associated Company) (b)	LeaseDescription Description of Property Leased (c)	CommissionAuthorization Commission Authorization (d)	ExpirationDateOfLease Expiration Date of Lease (e)	ElectricPlantLeasedToOthers Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47	TOTAL

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.	ElectricPlantHeldForFutureUseDescription Description and Location of Property (a)	ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b)	ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c)	ElectricPlantHeldForFutureUse Balance at End of Year (d)
1	Land and Rights:
2	(a) Clodine Sub-Alief-Stafford Transmission Line	01/01/1974	01/01/2033	503,260
3	(b) Wallis Prop-Brazos River Transmission Line	01/01/1978	01/01/2033	692,743
4	(c) Garden Villas South Transmission Line	01/01/1972	01/01/2033	1,289,112
5	Grimes County Property	01/01/2016	01/01/2031	927,769
6	W.A. Parish - Big Creek Transmission Line	01/01/1975	01/01/2033	378,293
7	(d) W.A. Parish - Wallis Sub. Transmission Line	01/01/1978	01/01/2033	1,304,876
8	Crosby North Substation	01/01/1984	01/01/2031	297,903
9	Zenith Transmission Line	01/01/1982	01/01/2031	524,987
10	(e) Salem-Zenith Transmission Line	01/01/1982	01/01/2031	3,536,446
11	(f) Other Land and Rights	01/01/1972	01/01/2022	723,165
12	Distribution Plant:
13	(g) Other Distribution Plant	01/01/1953	01/01/2033	223,977
14
15
21	Other Property:
22	General Plant:
23	(h) Other General Plant	01/01/1968	01/01/2033	49,547
47	TOTAL			10,452,078

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: ElectricPlantHeldForFutureUseDescription

Additional acquisition years include 1976 and 1977

(b) Concept: ElectricPlantHeldForFutureUseDescription

Additional acquisition years include 1980

Additional acquisition years include 1973, 1974, 1975, and 1977

(d) Concept: ElectricPlantHeldForFutureUseDescription

Additional acquisition years include 1979 and 1980

(e) Concept: ElectricPlantHeldForFutureUseDescription

Additional acquisition years include 1983

(f) Concept: ElectricPlantHeldForFutureUseDescription


Property for proposed Wallis - Brazos River Transmission line acquisition in 1978
Property for proposed Alvin-Angleton Transmission line acquired in 1958 and 1961
Property for proposed Clear Lake City-N.A.S.A. transmission line acquired in 1966
Property for proposed tap to Spencer Substation acquired in 1964, 1965, 1966 and 1970
Waller County, Timber Ridge and Grimes County, Delago Delta Subdivision acquired in 2016

(g) Concept: ElectricPlantHeldForFutureUseDescription


Broadway Substation acquired in 1953; Expected to be used in Utility Service in 2033
McHard Substation acquired in 1967
Lake Houston Distribution Line acquired in 1964; Expected to be used in Utility Service in 2033
Lee Substation acquired in 1985
Village Creek Substation acquired in 1982

(h) Concept: ElectricPlantHeldForFutureUseDescription


Energy Development Complex acquired in 1976
Hitchcock Service Center acquired in 1968

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Report below descriptions and balances at end of year of projects in process of construction (107). Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts). Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.	ConstructionWorkInProgressProjectDescription Description of Project (a)	ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b)
1	Ckt 25 FLEWELLEN TO PETERS UPGRADE-TRANS	63,116,939
2	Rebuild/Reconductor 138kV Ckt 93B	55,919,078
3	S90 TOWER REPLACEMENTS	30,340,500
4	FIELD CORRECTIVE MAINTENANCE INSTALL	29,967,283
5	COH-DISTRIBUTION PLANT	29,808,685
6	FACILITIES MODIFICATIONS	24,563,073
7	New Ckt.52 Jordan-Winfre-Eagle-MB	23,940,989
8	REP FAILED MAJOR EQUIP & PURCHASE SPARES	22,845,695
9	MOODY-STEWART CKT 63C-4	21,966,807
10	69kV Ckt 10: Grns Bayou-Texwall-Clinton	21,498,597
11	Distribution Operations	19,852,420
12	138kV Ckt 02B Burke-WAP	18,307,611
13	FIBER COMMUNICATIONS - EXPANSION	17,243,682
14	RED-TAILED HAWK INTERCONNECTION	15,387,277
15	Upgrade Limestone 345 kV React Bus Split	15,173,428
16	ENTD171 - Digital Delivery	14,623,917
17	STONE LAKE - NEW 35KV SUBSTATION	14,362,132
18	TRSM PREV MAINTENANCE PRGM - CAPITAL	12,391,479
19	FIGHTING JAYS INTERCONNECTION	12,253,639
20	ARCHER - GENERATOR INTERCONNECTION	10,881,569
21	GULFTIE GENERATOR INTERCONNECTION	10,866,450
22	FT BEND SOLAR INTERCONNECTION	9,296,932
23	COLLEGE SUB TAPS	9,179,693
24	GREENS BAYOU FLOOD CONTROL	9,110,513
25	SUBSTATION SYSTEM IMPROVEMENTS	8,775,853
26	Ckt.90A Reconductor	8,492,612
27	LINE CLEARANCE CORRECTIONS	8,210,547
28	LONGBOW INTERCONNECTION	8,139,745
29	MITIGATE GALLOPING on TRANSMISSION CKTS	8,019,002
30	MODIFY 138kV CKT 93C TXDOT NON CPAY	7,741,993
31	LIMBURG - NEW 35KV SUBSTATION	7,735,290
32	138kV Ckt 02A-1: Str #24713 Sienna-Dewal	7,568,289
33	SPACE CITY SOLAR INTERCONNECTION	7,373,008
34	OH RELIABILITY PROJECTS INSTALL	6,878,679
35	GEBHART-SEALY REBUILD CKT 65A-2	6,847,356
36	Substation Operations	6,640,633
37	ENTD179 - Digital Procurement/Coupa	6,541,935
38	MPLS NETWORK - INSTALL	6,522,944
39	ANGLETON-ADD 2 XFMRS AND 2 FEEDERS	6,444,433
40	REDE Infrastructure Replacement	6,375,446
41	LAKE HOUSTON - NEW 35KV SUBSTATION	6,320,647
42	COH-TRANSMISSION PLANT	6,276,862
43	Build new radial from Zenith - Village C	6,154,970
44	EXPLORER CORNER	6,072,953
45	SUBSTATION PHYSICAL SECURITY ENHANCEMENT	6,072,485
46	DANISH FIELDS SOLAR INTERCONNECTION	6,050,467
47	TWINWOOD - NEW 35KV SUBSTATION	6,000,572
48	Rebuild/Reconductor Lauder Sub Taps	5,976,290
49	69kV Ckt 32A: Dunlavy-Hyde Park-Downtown	5,936,965
50	BAILEY -JONES CREEK CONNECTION AND ASSOC. PROJECTS	5,840,647
51	SROW SUBSTATION PROPERTY ANALYSIS	5,595,595
52	WORTHAM - NEW 35KV SUBSTATION	5,518,228
53	Fort Bend W. Col Conversion	5,503,829
54	FREEMAN-CONVERT SUB TO 35KV	5,503,533
55	NEW V&D RADIO SYSTEM - INSTALL	5,425,663
56	WATERHOLE INTERCONNECTION	5,072,320
57	COH-SUBSTATION PLANT	5,071,573
58	Wallisville 138kV Conversion	5,031,553
59	GALENA PARK AREA CONVERSIONS	5,028,175
60	BRAZORIA WEST SOLAR INTERCONNECTION	5,016,523
61	CROCKETT-ADD 3RD XFMR/THREE FDRS	4,958,900
62	Heights Area Substation Conversion	4,912,918
63	FPM - Katy/Sealy Service Area	4,797,427
64	GRID RESILIENCY/MODERNIZATION	4,700,884
65	CKT29A1&2: THW-LIT YK - WHT OK, UPGRADE	4,633,802
66	Brazos River Crossing:Relocate Str#05429	4,571,028
67	RECONDUCTOR UNDERGROUND CIRCUITS	4,567,067
68	NEW SUBSTATION - FULSHEAR	4,496,882
69	ROW ACCESS CAPITAL IMPROVEMENTS	4,287,944
70	ENTD173-SL - Banner Soft Launch	4,198,383
71	POLE BRACING	4,147,917
72	CUTLASS SOLAR INTERCONNECTION	4,100,677
73	DISTRIBUTION DEVELOPMENT INSTALL	4,085,632
74	ENTB020-Enterprise Network Transformatio	4,081,990
75	FEEDER DEVELOPMENT UNPLANNED INSTALL	3,984,543
76	Transmission Operations	3,877,676
77	SEABROOK: BUILD 138KV SUB 2-50MVA & 6FDR	3,867,497
78	PLAZA-ADD 3RD XFMR AND 2 FEEDERS	3,803,002
79	RIVERSIDE SUB INTERCONNECTION	3,724,120
80	Garden Villas 138kV TR4 on Ckt.06G	3,647,990
81	ITBM032 - Security Hardening	3,507,926
82	HEBM025 - Field Service Management (FSM)	3,498,326
83	FPM - Greenspoint Service Area	3,390,069
84	ITB005 - Storage Capacity	3,229,939
85	AMS Full Deployment	3,226,655
86	Other Rotten Pole Replacement Install	3,218,528
87	TRANSMISSION RESTORATION	3,214,079
88	2021 Equipment and Hardware - GIS	3,211,760
89	SUBSTATION PROTECTION IMPROVMENTS	3,210,700
90	JONTE 138kV Switching Station	3,190,192
91	Convert Alvin sub to 138 kV, double tap	3,169,375
92	URD INSTALLATIONS INSTALL	3,112,594
93	BRINGHURST - REBUILD	2,938,825
94	GIS Network Migration - CEHE	2,914,847
95	OH TROUBLE INSTALL-2	2,904,441
96	ELECTROMECH RELAY PANEL REPLACEMENT-DIS	2,878,155
97	Major Underground	2,755,963
98	GRID HARDENING - INSTALL	2,738,944
99	Mykawa 138kV Switching Station	2,711,226
100	DISTRIBUTION DESIGN STUDIO CEHE	2,680,913
101	IG - ADMS FULL DEPLOYMENT	2,603,967
102	Central Complex Facilities Projects	2,591,345
103	DISTR. AUTO CONTROL SYS. (DACS)	2,516,335
104	HEBM015RM6-2022 TRM - Retail Market Tran	2,192,603
105	ITD172 - STAR Cloud Migration	2,174,509
106	MAJOR UNDG REHABILITATION - Install	2,152,723
107	HEBM015RM5-TRM - Retail MarketTransAct21	2,115,831
108	Rebuild/Reconductor Gulfgate Sub Taps	2,097,653
109	ROW SUPPORT FOR TRANSMISSION PROJECTS	2,092,330
110	CONVERT FREEWAY CROSSINGS TO UNDERGROUND	2,083,920
111	OH RELOCATIONS 5 POLES OR MORE INSTALL	2,022,466
112	Substation Security Upgrades	1,995,175
113	SNUG INTERCONNECT	1,985,800
114	SPLICE REPAIRS	1,950,173
115	Rebuild/Reconductor La Porte Sub Taps	1,941,070
116	FPM - Major Underground Facilities	1,932,902
117	TEX GULF BYPASS/CONVERT CKT 60C	1,919,558
118	Clinton 138kV Breaker Station	1,901,031
119	MYRTLE SOLAR INTERCONNECTION	1,864,733
120	SUB PROJECTS MINOR UNSCHEDULED CORR PROJ	1,860,381
121	MICROWAVE PROJECTS	1,846,864
122	URD INSTALLATIONS INSTALL-1	1,813,939
123	URD TROUBLE INSTALL	1,788,794
124	Rebuild Galena Park Distribution Sub	1,784,351
125	WATERFOWL SUBSTATION	1,781,675
126	SCENIC WOODS-ADD 2-35KV TFRs & 2 FDRS	1,707,509
127	POLE TREATMENT	1,704,648
128	WEATHER RELATED TROUBLE INSTALL	1,703,898
129	Fleet Services	1,581,253
130	DUAL PILOT 138KV LINE RELAYING	1,575,039
131	Tiki Island: 2-50 MVA Trf's & 4-12kV Fdr	1,574,587
132	PLEDGER - BUILD NEW SUBSTATION	1,529,023
133	ITB001 - Network Organic Growth	1,490,409
134	138kV Ckt 48A & 59A Stewart-West Bay	1,471,554
135	Alvin area 69 kV conversions	1,443,022
136	Rayford - Install 3rd transformer	1,434,201
137	RAMSEY SOLAR GENERATOR INTERCONNECTION	1,426,053
138	URD TROUBLE INSTALL-1	1,384,187
139	MUDG CAPITOL TROUBLE	1,351,873
140	EAST HVDC UPGRADES - MISC EACH YEAR	1,339,670
141	OH TROUBLE INSTALL-3	1,338,393
142	CKT29A2: UPGRADE WHITE OAK EQUIPMENT	1,336,619
143	ENTB013-CP-2022 Computing Platform Refre	1,316,241
144	MUDG - Feeder Development - Install	1,294,167
145	FT BD CTY - RELOCATE STR 24693 CKT80B-1	1,278,479
146	FIELD CORRECTIVE MAINTENANCE INSTALL-1	1,277,837
147	SUBSTATION COMPLIANCE NETWORK MODS	1,273,675
148	SUBSTATION TRANSFORMER FIREWALL PROGRAM	1,262,909
149	FOUNDATION REPLACEMENTS-ASR	1,250,248
150	OH RELIABILITY INSTALL	1,223,443
151	138kV Ckt 63C-1: Moody to West Galveston	1,217,989
152	CROSBY - INSTALL 35KV SUBSTATION	1,214,980
153	Central Logistics	1,205,433
154	MYKAWA SUB:NEW 138/12KV LOW PROFILE SUB	1,198,926
155	CKT 24 UPGRADES	1,189,040
156	Control Systems Projects	1,188,201
157	Upgrade Crosby 138 to 50kA	1,188,157
158	HEB017-3-2022 Advanced Data Management P	1,176,707
159	GREENS ROAD ADD 5TH, 6TH & 7TH FDRS	1,174,053
160	138kV Ckt 37C TECO-Garrott	1,127,870
161	ALEXANDER ISLAND CELL BARRIER REPLACEMEN	1,122,441
162	Rotten Pole Replacement Install-4	1,116,840
163	Streetlight LED Replacement	1,109,056
164	INSTALL TWS	1,063,519
165	ITB002 - Network Refresh	1,025,069
166	TELOPS MISC	1,015,011
167	URD TROUBLE INSTALL-2	1,002,931
168	Total CWIP under $1M	74,011,101
43	Total	1,071,752,129

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Explain in a footnote any important adjustments during year. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.	Item (a)	Total (c + d + e) (b)	Electric Plant in Service (c)	Electric Plant Held for Future Use (d)	Electric Plant Leased To Others (e)
Section A. Balances and Changes During Year
1	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance Beginning of Year	4,110,299,821	4,110,299,821
2	Depreciation Provisions for Year, Charged to
3	DepreciationExpenseExcludingAdjustments (403) Depreciation Expense	421,579,159	421,579,159
4	DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs
5	ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others
6	TransportationExpensesClearing Transportation Expenses-Clearing
7	OtherClearingAccounts Other Clearing Accounts	12,207,778	12,207,778
8	OtherAccounts Other Accounts (Specify, details in footnote):
9.1	Other Accounts (Specify, details in footnote):
10	DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)	433,786,937	433,786,937
11	Net Charges for Plant Retired:
12	BookCostOfRetiredPlant Book Cost of Plant Retired	246,785,716	246,785,716
13	CostOfRemovalOfPlant Cost of Removal	206,222,434	206,222,434
14	SalvageValueOfRetiredPlant Salvage (Credit)	37,155,994	37,155,994
15	NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)	415,852,156	415,852,156
16	OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote):
17.1	Other Debit or Cr. Items (Describe, details in footnote):	22,807,943	(a) 22,807,943
18	BookCostOfAssetRetirementCosts Book Cost or Asset Retirement Costs Retired
19	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)	4,151,042,545	4,151,042,545
Section B. Balances at End of Year According to Functional Classification
20	AccumulatedDepreciationSteamProduction Steam Production
21	AccumulatedDepreciationNuclearProduction Nuclear Production
22	AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional
23	AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage
24	AccumulatedDepreciationOtherProduction Other Production
25	AccumulatedDepreciationTransmission Transmission	656,634,835	656,634,835
26	AccumulatedDepreciationDistribution Distribution	3,018,748,992	3,018,748,992
27	AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation	475,658,718	475,658,718
28	AccumulatedDepreciationGeneral General
29	AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28)	4,151,042,545	4,151,042,545

FOOTNOTE DATA

(a) Concept: OtherAdjustmentsToAccumulatedDepreciation


Inter Asset Transfer	$	21,993,893
Adjustments	10,591
Accrual from CCNC	(2,884)
Asset Retirement obligation - Depreciation	806,343
	$	22,807,943

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Report below investments in Account 123.1, Investments in Subsidiary Companies. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f). Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.	DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a)	DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b)	DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c)	InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d)	EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e)	InterestAndDividendRevenueFromInvestments Revenues for Year (f)	InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g)	InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h)
1	CenterPoint Energy Transition Bond Company II, LLC - Other Investments in Subsidiaries	12/03/2004		1,000
2	CenterPoint Energy Transition Bond Company III, LLC - Other Investments in Subsidiaries	08/30/2007		1,000			1,000
3	CenterPoint Energy Restoration Bond Company LLC - Other Investments in Subsidiaries	08/06/2009		3,325,295			1,000
4	CenterPoint Energy Transition Bond Company IV, LLC - Other Investments in Subsidiaries	10/14/2011		8,476,000			8,476,000
42	Total Cost of Account 123.1 $		Total	11,803,295			8,478,000

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

MATERIALS AND SUPPLIES
For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.	Account (a)	Balance Beginning of Year (b)	Balance End of Year (c)	Department or Departments which Use Material (d)
1	Fuel Stock (Account 151)	0	0
2	Fuel Stock Expenses Undistributed (Account 152)	0	0
3	Residuals and Extracted Products (Account 153)	0	0
4	Plant Materials and Operating Supplies (Account 154)
5	Assigned to - Construction (Estimated)
6	Assigned to - Operations and Maintenance
7	Production Plant (Estimated)
8	Transmission Plant (Estimated)
9	Distribution Plant (Estimated)
10	Regional Transmission and Market Operation Plant (Estimated)
11	Assigned to - Other (provide details in footnote)	(a) 257,880,852	(b) 433,536,326	Electric
12	TOTAL Account 154 (Enter Total of lines 5 thru 11)	257,880,852	433,536,326
13	Merchandise (Account 155)	0	0
14	Other Materials and Supplies (Account 156)	0	0
15	Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)	0	0
16	Stores Expense Undistributed (Account 163)	1,431,584	738	Electric
17
18
19
20	TOTAL Materials and Supplies	259,312,436	433,535,588

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesOther

Because of the structure of CenterPoint Houston accounting system, Plant Materials and Operating Supplies cannot be supplied by primary functional classification. The majority of account 154 is assigned to Operations and Maintenance.


2021 Inventory work in progress	$	63,430
2021 Plant Materials and Operating Supplies	257,817,422
Total	$	257,880,852

(b) Concept: PlantMaterialsAndOperatingSuppliesOther


2022 Inventory work in progress	$	111,197
2022 Plant Materials and Operating Supplies	433,425,129
Total	$	433,536,326

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	SO2 Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)
5	Returned by EPA
6
7
8	Purchases/Transfers:
9
10
11
12
13
14
15	Total
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22	Charges to Acct 219/447
23
24
25
26
27
28	Total
29	Balance-End of Year
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	NOx Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)
5	Returned by EPA
6
7
8	Purchases/Transfers:
9
10
11
12
13
14
15	Total
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22
23
24
25
26
27
28	Total
29	Balance-End of Year
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a)	ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b)	ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c)	ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d)	ExtraordinaryPropertyLossesWrittenOff Amount (e)	ExtraordinaryPropertyLosses Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20	TOTAL					0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a)	UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b)	UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e)	UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49	TOTAL					0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.	DescriptionOfStudyPerformed Description (a)	StudyCostsIncurred Costs Incurred During Period (b)	StudyCostsAccountCharged Account Charged (c)	StudyCostsReimbursements Reimbursements Received During the Period (d)	StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1	Transmission Studies
2	(a) See Footnote		—		—
3			—		—
20	Total
21	Generation Studies
22	(b) See Footnote
23			—		4560
24	WHARTON COUNTY GENERATION/TGF SUB		—	50,000	4560
25	BLACK MOUNTAIN ENERGY/CITADEL BESS		—	50,000	4560
26	CUTLASS SOLAR II/ROWLAND		—	40,000	4560
27	RECURRENT ENERGY GROUP/CASCADE STORAGE		—	50,000	4560
28	BRUSH SOLAR/MALEZA SOLAR II		—	50,000	4560
29	BROAD REACH POWER/CHARON		—	50,000	4560
30	BROAD REACH POWER/BACHMAN		—	50,000	4560
31	BLACK MOUNTAIN ENERGY/SOHO BESS		—	50,000	4560
32	TX GULF SOLAR/SECOND DIVISION SOLAR		—	50,000
33	RWE RENEWABLES AMERICA/PEYTON CREEK WIND II		—	50,000	4560
34	AP SOLAR 8/PARLIAMENT SOLAR		—	50,000	4560
35	THERMAL ENERGY CORP/TECO GTG2		—	50,000	4560
36	JUPITER POWER/PAMELA HEIGHTS		—	50,000	4560
37	TOTAL RENEWABLES USA, INC		—	50,000	4560
38	BROAD REACH POWER/BRP ARTEMIS		—	50,000	4560
39	SOLAR PROPONENT/EAST CANEY CREEK SOLAR			50,000	4560
40	RED TAILED HAWK SOLAR			50,000	4560
41	COMMODORE US HOLDING CORP/CRADLE SOLAR		0	5,000	4560
42	CEDAR HOLDCO		—	50,000	4560
43	SUNNYSIDE ENERGY BESS		—	50,000	4560
44	SOLAR PROPONENT/HOLLOW BRANCH CREEK SOLAR		—	50,000	4560
45	WHITE ROCK SOLAR LLC/CAMP CREEK STORAGE		—	50,000	4560
46	SMT ENERGY		—	50,000	4560
47	ACE DEVELOPEMENT COMPANY LLC		—	50,000	4560
48	ROCK N ROLL SOLAR LLC		—	50,000	4560
49	APV LONESTAR ENERGY LLC/APV Plumwood Storage		—	50,000	4560
50	APEX CLEAN ENERGY/HYACINTH STORAGE		—	50,000	4560
51	PROENERGY MARK II		—	50,000	4560
52	BLACK MOUNTAIN ENERGY STORAGE/MERCHANT BESS		—	50,000	4560
53	RECURRENT ENERGY GROUP/NORTH SHORE ENERGY STORAGE		—	50,000	4560
54	X-ELIO NORTH AMERICA/MURAT STORAGE		—	50,000	4560
55	GULFSTAR POWER/GULFSTAR SOLAR		—	35,000	4560
56	GULFSTAR POWER/GULFSTAR STORAGE		—	50,000	4560
57	BDPU SOLAR MARATUA		—	50,000	4560
58	JUPITER POWER, LLC/Brushwood EnergyStorage		—	50,000	4560
59	X-ELIO NORTH AMERICA		—	30,000	4560
60	HANWHA Q CELLS USA CORP/Shoshana Storage		—	50,000	4560
61	BLACK MOUNTAIN ENERGY STORAGE/Outer Loop BESS		—	50,000	4560
62	MYRTLE STORAGE LLC		—	40,000	4560
63	WHITE ROCK SOLAR LLC/Camp Creek Solar		—	42,000	4560
64	RWE RENEWABLES AMERICA/Crowned HeronBESS		—	50,000	4560
65	HIGH CHAPARRAL SOLAR PROJECT LLC		—	75,000	4560
66	BLACK MOUNTAIN ENERGY STORAGE		—	50,000	4560
67	COTTONWOOD BAYOU SOLAR II LLC		—	50,000	4560
68	AUSTIN BAYOU SOLAR LLC		—	50,000	4560
69	HANWHA Q CELLS USA CORP/ Coneflower Storage		—	50,000	4560
70	DESTINY STORAGE LLC		—	50,000	4560
71	ELIO ENERGY LLC		—	50,000	4560
72	BRP BLUE TOPAZ 1 LLC		—	50,000	4560
73	LONGROAD DEVELOPMENT COMPANY LLC/High Plains Storage		—	50,000	4560
74	VDA SOLAR TEXAS 1, LLC/Duffy Solar		—	30,000	4560
75	COTTONWOOD BAYOU SOLAR, LLC		—	50,000	4560
76	REMY JADE GENERATING, LLC/Remy Jade II Power Station		—	50,000	4560
77	NRG TEXAS POWER LLC/GREENS BA YOU UNIT 9 CT 345		—	50,000	4560
78	NRG TEXAS POWER LLC/GREENS BA YOU UNIT 9 CT 138		—	50,000	4560
79	CITADEL BESS LLC		—	30,000	4560
39	Total
40	Grand Total			2,777,000

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: DescriptionOfStudyPerformed

During 2022, the Company did not separately track the time employees spent performing transmission service interconnection studies. As a result, the information requested on page 231 of the 2022 FERC Form 1 is not separately identifiable in the company's books and records.

(b) Concept: DescriptionOfStudyPerformed

During 2022, the Company did not separately track the time employees spent performing generator interconnection studies. As a result, the information requested on page 231 of the 2022 FERC Form 1 is not separately identifiable in the company's books and records. For 2022, reimbursements shown represent a flat fee collected for these studies.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
				CREDITS
Line No.	DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a)	OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b)	IncreaseDecreaseInOtherRegulatoryAssets Debits (c)	OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d)	OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e)	OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1	(a) Net-Of Tax Debt AFUDC	93,165		282	12,827	80,338
2	(b) Equity AFUDC	29,396,241	6,378,374	282	1,349,999	34,424,616
3	(c) Excess Accum. Deferred Taxes & Other	44,648,810	1,791,489	190/411.1	776,605	45,663,694
4	(d) Investment Tax Credit	411,969		282	39,852	372,117
5	Postretirement	24,260,739		283/411.1	(l) 6,640,783	17,619,956
6	Texas Margin Tax	(k) 19,517,015	23,952,086	408.1	19,403,680	24,065,421
7	(e) Reg Assets - Hurricane Harvey Costs	47,454,435	3,702,640	407.3	12,881,229	38,275,846
8	Assets Retirement Obligation--ASC410	27,060,037	2,831,481	230	804,990	29,086,528
9	(f) Reg Assets - Expedited Switch	767,585		407.3	231,821	535,764
10	Reg Assets - ADFIT Credit Over Under			456.0
11	(g) Reg Assets - Smart Meter Texas	9,991,232		407.3	1,387,826	8,603,406
12	Reg Assets - Bad Debt	9,202,629		407.3/451.0/131.0	(m) 354,847	8,847,782
13	Reg Assets - Property Insurance Reserve	17,341,896	4,065,224	N/A		21,407,120
14	Regulatory Assets - EECRF OU	25,887,146	25,230,852	456.0/928.0/254.0	32,495,958	18,622,040
15	Relief Prog Incremental Costs	7,534,886	675,739	N/A		8,210,625
16	Regulatory Assets - Storm Costs Other	38,927,583	2,941,131	N/A		41,868,714
17	(h) Reg Assets - Hedges Gain Loss	17,587,228	288,373	431.0	877,594	16,998,007
18	EECRF RCE 2022		33,288	182.3		33,288
19	(i) Regulatory Assets-Emergency Generation ST	20,269,958	86,314,612	N/A		106,584,570
20	(j) Emergency Gen LT	150,911,054	444,867,808	N/A		595,778,862
21	2021 Hurricane Nicholas	46,323,592	708,373	N/A		47,031,965
22	2021 Winter Storm Uri	15,111,247	922,851	N/A		16,034,098
23	EECRF RCE 2021	25,272	1,358	N/A	26,630
24	Reg Assets - TC2 TC3 Refund		418,972	N/A		418,972
25	Reg Assets - LLTF Carrying Costs		5,180,332	N/A		5,180,332
26	Reg Assets - Rate Case		873,826	N/A		873,826
27	Reg Assets - Load Mgmt		2,984,847	N/A		2,984,847
28				N/A
44	TOTAL	552,723,719	614,163,656		77,284,641	1,089,602,734

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Amortization using same life as the associated asset.

(b) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Amortization using same life as the associated asset.

(d) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Amortization using same life as the associated asset.

(e) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Amortization period 04/23/2020 to 04/22/2025 based on Docket No. 49421

(f) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Amortization period 04/23/2020 to 04/22/2025 based on Docket No. 49421

(g) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Amortization period 04/23/2020 to 04/22/2025 based on Docket No. 49421

(h) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Amortization period various - throughout life of associated debt based on Docket No. 49421

(i) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Emergency Generation is also referred to as Mobile Generation.

(j) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Emergency Generation is also referred to as Mobile Generation.

(k) Concept: OtherRegulatoryAssets

Amortization period 01/2023 to 12/2023 based on Docket No. 49421

(l) Concept: OtherRegulatoryAssetsWrittenOffRecovered

Amortization period over 5 years beginning April 2020 based on Docket No. 49421

(m) Concept: OtherRegulatoryAssetsWrittenOffRecovered

Amortization period 04/23/2020 to 04/22/2025 based on Docket No. 49421

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

MISCELLANEOUS DEFFERED DEBITS (Account 186)
Report below the particulars (details) called for concerning miscellaneous deferred debits. For any deferred debit being amortized, show period of amortization in column (a) Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
				CREDITS
Line No.	Description of Miscellaneous Deferred Debits (a)	Balance at Beginning of Year (b)	Debits (c)	Credits Account Charged (d)	Credits Amount (e)	Balance at End of Year (f)
1	Policy Loan-DCP, EICP, BRP	326,444,468	12,096,355	131/165	14,851,635	329,199,748
2	Cash Surrender Value	332,364,808	22,286,989	(b) 165/186/242/426.2/228.3	19,358,956	335,292,841
3	Death Benefits Policy loan	34,957,957	787,704	131/165	742,126	34,912,379
4	Post Retirement Assets for IBEW	8,046,387	133,448	146/421	4,402,396	3,777,439
5	DBP Cash Surrender Value	34,578,245	743,685	165/186/426.1	782,788	34,539,142
6	Miscellaneous Deferred Debits	36,275,518	(a) 105,876,752	(c) 165/146/182.3/228.2/101.1/227	(d) 38,149,671	104,002,599
47	Miscellaneous Work in Progress	4,502,355				4,518,673
48	Deferred Regulatroy Comm. Expenses (See pages 350 - 351)
49	TOTAL	54,364,888				118,018,567

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: IncreaseInMiscellaneousDeferredExpense


	Debit		Credit		Total
Mobile Generation	$	72,172,160	$	11,289,881	$	60,882,279
Other	33,704,592		26,859,790		$	6,844,802
Total	$	105,876,752	$	38,149,671	$	67,727,081

(b) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged

165/186/242/228.3/426.1

186 - Account charged to other line item on this page.

165/186/227/228.2/232/101.1

186 - Account charged to other line item on this page.

(d) Concept: DecreaseInMiscellaneousDeferredExpense


	Debit		Credit		Total
Mobile Generation	$	72,172,160	$	11,289,881	$	60,882,279
Other	33,704,592		26,859,790		$	6,844,802
Total	$	105,876,752	$	38,149,671	$	67,727,081

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Report the information called for below concerning the respondent’s accounting for deferred income taxes. At Other (Specify), include deferrals relating to other income and deductions.
Line No.	DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a)	AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b)	AccumulatedDeferredIncomeTaxes Balance at End of Year (c)
1	Electric
2	Employee Benefits	12,872,702	9,764,317
3	ARO Liabilities	8,759,402	6,474,078
4	Regulatory Liabilities	25,781,700	39,614,707
5	Injuries and Damages	5,615,266	6,430,800
6	Acc Def Income Tax on Excess Def Income Tax on Regulatory Liability	182,566,263	177,671,639
7	Other	(a) 977,950	(b) 30,241,942
8	TOTAL Electric (Enter Total of lines 2 thru 7)	236,573,283	270,197,483
9	Gas
15	Other
16	TOTAL Gas (Enter Total of lines 10 thru 15)
17.1	Other (Specify)
17	Other (Specify)
18	TOTAL (Acct 190) (Total of lines 8, 16 and 17)	236,573,283	270,197,483

Notes

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxes


	Balance Beginning of Year		Balance End of Year

Environmental Liability	$	715,402	$	367,500
Bad Debts	238,899		238,899
Intercompany Transaction	—		27,366,975
Other	23,649		2,268,568
Total	$	977,950	$	30,241,942

(b) Concept: AccumulatedDeferredIncomeTaxes


	Balance Beginning of Year		Balance End of Year

Environmental Liability	$	715,402	$	367,500
Bad Debts	238,899		238,899
Intercompany Transaction	—		27,366,975
Other	23,649		2,268,568
Total	$	977,950	$	30,241,942

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

CAPITAL STOCKS (Account 201 and 204)
Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.	Class and Series of Stock and Name of Stock Series (a)	Number of Shares Authorized by Charter (b)	Par or Stated Value per Share (c)	Call Price at End of Year (d)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f)	Held by Respondent As Reacquired Stock (Acct 217) Shares (g)	Held by Respondent As Reacquired Stock (Acct 217) Cost (h)	Held by Respondent In Sinking and Other Funds Shares (i)	Held by Respondent In Sinking and Other Funds Amount (j)
1	Common Stock (Account 201)
2	Divisional Equity					1,000
4	Total					1,000
5	Preferred Stock (Account 204)
6
7
8
9	Total					0
1	Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5	Total

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2023-04-18

Year/Period of Report

End of:

2022

Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.	Item (a)	Amount (b)
1	DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208)
2	DonationsReceivedFromStockholders Beginning Balance Amount
3.1	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Increases (Decreases) from Sales of Donations Received from Stockholders
4	DonationsReceivedFromStockholders Ending Balance Amount
5	ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209)
6	ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount
7.1	IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8	ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount
9	GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10	GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount	2,669,598,394
11.1	IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock	1,057,588,943
12	GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount	(a) 3,727,187,337
13	MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211)
14	MiscellaneousPaidInCapital Beginning Balance Amount
15.1	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Miscellaneous Paid-In Capital
16	MiscellaneousPaidInCapital Ending Balance Amount
17	OtherPaidInCapitalAbstract Historical Data - Other Paid in Capital
18	OtherPaidInCapitalDetail Beginning Balance Amount
19.1	IncreasesDecreasesInOtherPaidInCapital Increases (Decreases) in Other Paid-In Capital
20	OtherPaidInCapitalDetail Ending Balance Amount
40	OtherPaidInCapital Total	3,727,187,337

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2023-04-18

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: GainOnResaleOrCancellationOfReacquiredCapitalStock


	Ending Balance Amount

2001 Stock Option Tax (A)	$	(2,533,554)
Benefit Transfers	37,541,289
Transfer retained earnings to APIC	(1,169,928,106)
Asset Transfers	128,145,003
Unamortized ITC	9,159,445
HIGP Tax Payment	1,733,771
Post APIC/RE recl entries-2002 restructure	(1,030,380,281)
Dividend to UHC	1,010,621,151
Reclass Balance from Division	(127,302,934)
Capital contribution	(2,583,400,000)
Corporate Tax Allocations	(76,280,675)
FAS 123R / ASC 718	(3,973,503)
Service Company Asset Pushdown	(38,120,395)
Intercompany clearning before during after VUHI restructuring	117,531,452
Total	$	(3,727,187,337)

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

CAPITAL STOCK EXPENSE (Account 214)
Report the balance at end of the year of discount on capital stock for each class and series of capital stock. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.	NameOfClassAndSeriesOfStock Class and Series of Stock (a)	CapitalStockExpense Balance at End of Year (b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22	TOTAL	0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

LONG-TERM DEBT (Account 221, 222, 223 and 224)
Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.	ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a)	RelatedAccountNumber Related Account Number (b)	Principal Amount of Debt Issued (c)	LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d)	LongTermDebtIssuanceExpenses Total Expense (e)	LongTermDebtPremium Total Premium (f)	LongTermDebtDiscount Total Discount (g)	NominalDateOfIssue Nominal Date of Issue (h)	DateOfMaturity Date of Maturity (i)	AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j)	AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k)	Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l)	Interest for Year Amount (m)
1	Bonds (Account 221)
2	6.95% Series K - General Mortgage	217010/277020	312,275,000		3,059,031		1,789,336	03/13/2003	03/15/2033	03/13/2003	03/15/2033	312,275,000	21,703,113
3	5.60% Series L - General Mortgage	217010/277020	200,000,000					05/23/2003	07/01/2023	05/23/2003	07/01/2023	0	(f) 8,866,668
4	2.25% Series V - General Mortgage	217010/277020	300,000,000					08/10/2012	08/01/2022	08/10/2012	08/01/2022	0	3,937,500
5	3.55% Series W - General Mortgage	217010/277020	500,000,000		5,036,616		1,280,000	08/10/2012	08/01/2042	08/10/2012	08/01/2042	500,000,000	17,750,000
6	3.0% Series AG - General Mortgage	217010/277020	300,000,000		2,669,008		1,389,000	02/28/2022	03/01/2032	02/28/2022	03/01/2032	300,000,000	7,525,000
7	3.60% Series AH - General Mortgage	217010/277020	500,000,000		5,573,347		6,515,000	02/28/2022	03/01/2052	02/28/2022	03/01/2052	500,000,000	15,050,000
8	4.45% Series AI - General Mortgage	217010/277020	500,000,000		4,482,827		1,775,000	09/15/2022	10/01/2032	09/15/2022	10/01/2032	500,000,000	6,551,389
9	4.85% Series AJ - General Mortgage	217010/277020	300,000,000		3,364,696			09/15/2022	10/01/2052	09/15/2022	10/01/2052	300,000,000	4,284,167
10	4.5% Series X- General Mortgage	217010/277020	600,000,000		6,389,579		6,450,000	03/17/2014	04/01/2044	03/17/2014	04/01/2044	600,000,000	27,000,000
11	2.40 % Series Z - General Mortgage	217010/277020	300,000,000		2,616,008		715,539	08/11/2016	09/01/2026	08/11/2016	09/01/2026	300,000,000	7,200,000
12	3.00% Series AA - General Mortgage	217010/277020	300,000,000		2,617,661		(a) 2,525,980	01/12/2017	02/01/2027	01/12/2017	02/01/2027	300,000,000	9,000,000
13	3.95% Series AB - General Mortgage	217010/277020	400,000,000		4,405,679		(b) 3,466,602	02/28/2018	03/01/2048	02/28/2018	03/01/2048	400,000,000	15,800,000
14	4.25% Series AC - General Mortgage	217010/277020	700,000,000		7,649,479		(c) 29,108,667	01/15/2019	02/01/2049	01/15/2019	02/01/2049	700,000,000	29,750,000
15	2.90% Series AD - General Mortgage	217010/277020	300,000,000		3,496,632		(d) 603,000	06/05/2020	07/01/2050	06/05/2020	07/01/2050	300,000,000	8,700,000
16	2.35% Series AE - General Mortgage	217010/277020	400,000,000		3,497,024		(e) 1,708,000	03/11/2021	04/01/2031	03/11/2021	04/01/2031	400,000,000	9,400,000
17	3.35% Series AF - General Mortgage	217010/277020	700,000,000		7,718,220		2,779,000	03/11/2021	04/01/2051	03/11/2021	04/01/2051	700,000,000	23,450,000
18	Subtotal		6,612,275,000		62,575,807		51,740,842					(g) 6,112,275,000	215,967,837
19	Reacquired Bonds (Account 222)
20
21
22
23	Subtotal											0
24	Advances from Associated Companies (Account 223)
25
26
27
28	Subtotal											0
29	Other Long Term Debt (Account 224)
30
31
32
33	Subtotal											0
33	TOTAL		6,612,275,000									6,112,275,000	215,967,837

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: BondsDiscount

Discount includes Interest Rate Hedges Gain/Loss per Docket No 49421.

(b) Concept: BondsDiscount

Discount includes Interest Rate Hedges Gain/Loss per Docket No 49421.

(d) Concept: BondsDiscount

Discount includes Interest Rate Hedges Gain/Loss per Docket No 49421.

(e) Concept: BondsDiscount

Discount includes Interest Rate Hedges Gain/Loss per Docket No 49421.

(f) Concept: InterestExpenseBonds

Interest for the year does not include interest expense related to associated companies.

(g) Concept: Bonds

Long-term debt previously recorded in FERC Accounts 221 and 224, are now currently being recorded in FERC Account 221.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.	Particulars (Details) (a)	Amount (b)
1	Net Income for the Year (Page 117)	523,455,616
2	Reconciling Items for the Year
3
4	Taxable Income Not Reported on Books
5	CIAC	64,621,587
6	Total	64,621,587
9	Deductions Recorded on Books Not Deducted for Return
10	Federal Income Taxes	113,059,833
11	Regulatory Assets & Liabilities
12	(a) Other	37,701,867
13	Total	150,761,700
14	Income Recorded on Books Not Included in Return
15	AFUDC EQUITY	23,994,834
16	COLI	8,746,019
17	Total	32,740,853
19	Deductions on Return Not Charged Against Book Income
20	Depreciation and Other PP&E Differences	574,660,316
21	(b) Other	65,078,219
22	Total	509,582,097
27	Federal Tax Net Income
28	Show Computation of Tax:
29	Federal Tax Net Income	196,515,953
30	Tax Rate	21
31	Federal Income Tax at 21% of Federal Taxable Income	41,268,350
32	Charitable Contribution Utilization
33	Research Credits	2,324,055
34	Prior Period Adjustments	25,073,319
35	Restricted Stock Excess Tax Benefit
36	Current Federal Income Tax	64,017,614

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: DeductionsRecordedOnBooksNotDeductedForReturnDescription


Deferred State Income Taxes	$	(894,743)
Injuries & Damage Reserves	3,883,493
Lobbying Cost	2,172,310
Non-Deductible Parking and Transit	517,933
Fines & Penalties	(1,532,000)
Meals & Entertainment	39,570
Federal NOL	28,262,618
Non-Deductible Dues	103,438
Non-Deferred Basis Flowback	5,196,590
Other Permanent Items	(47,342)
Total	$	37,701,867

(b) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription


Regulatory Asset	$	4,850,311
Regulatory Liabilities	(63,095,701)
Employee Benefits	2,183,150
R&D Amortization Cost	1,656,678
	(10,689,054)
Other	16,397
Total	$	(65,078,219)

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d). Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
					BALANCE AT BEGINNING OF YEAR					BALANCE AT END OF YEAR		DISTRIBUTION OF TAXES CHARGED
Line No.	DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a)	TypeOfTax Type of Tax (b)	TaxJurisdiction State (c)	TaxYear Tax Year (d)	TaxesAccrued Taxes Accrued (Account 236) (e)	PrepaidTaxes Prepaid Taxes (Include in Account 165) (f)	TaxesCharged Taxes Charged During Year (g)	TaxesPaid Taxes Paid During Year (h)	TaxAdjustments Adjustments (i)	TaxesAccrued Taxes Accrued (Account 236) (j)	PrepaidTaxes Prepaid Taxes (Included in Account 165) (k)	TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l)	IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m)	AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n)	TaxesIncurredOther Other (o)
1	Federal Income				24,761,348	0	64,017,614	67,962,581	(b) 25,073,319	131,668,224	0	65,690,812			1,673,198
2					0	0				0	0
3	Subtotal Federal Tax				24,761,348	0	64,017,614	67,962,581	25,073,319	131,668,224	0	65,690,812			1,673,198
4	State Margin				19,509,651	0	2,856,165	12,729,501	(c) 7,222,091	27,873,226	0	16,629,337			13,773,172
5	Subtotal State Tax				19,509,651	0	2,856,165	12,729,501	7,222,091	27,873,226	0	16,629,337			13,773,172
6	Subtotal Local Tax				0	0				0	0
7	Subtotal Other Tax				0	0				0	0
8	Property - 2017	Property Tax		2017	468,792	0		3,475		465,317	0
9	Property - 2019	Property Tax		2019	577,174	0		4,540		572,634	0
10	Property - 2020	Property Tax		2020	125,730	0		4,499		121,231	0
11	Property - 2021	Property Tax		2021	101,633,607	0	424,779	101,354,470		145,642	0	424,779
12	Property - 2022	Property Tax		2022	0	0	113,700,000	216,986		113,483,014	0	112,975,084
13	Subtotal Property Tax				102,805,303	0	113,275,221	101,583,969		114,496,554	0	112,550,305
14	Subtotal Real Estate Tax				0	0				0	0
15	Unemployment - 2020	Unemployment Tax		2020	1	0			1	0	0
16	Unemployment - 2021	Unemployment Tax		2021	6,994	0	(a) 2,811	9,805		0	0	2,749
17	Unemployment - 2022	Unemployment Tax		2022	0	0	389,932	376,747		13,185	0	389,932
18	Subtotal Unemployment Tax				6,993	0	392,743	386,552	1	13,185	0	392,681
19	Direct Pay Use Tax - 2021	Sales And Use Tax		2021	7,790,678	0		7,789,730	(d) 948	0	0
20	Direct Pay Use Tax - 2022	Sales And Use Tax		2022	0	0	85,896,647	77,136,633	(e) 19,457	8,740,557	0	24,240
21	Subtotal Sales And Use Tax				7,790,678	0	85,896,647	84,926,363	20,405	8,740,557	0	24,240
22	Subtotal Income Tax				0	0				0	0
23	Subtotal Excise Tax				0	0				0	0
24	Subtotal Fuel Tax				0	0				0	0
25	FICA - 2021	Federal Insurance Tax		2021	8,215,889	0	1,767,582	6,448,307		0	0	1,794,112
26	FICA - 2022	Federal Insurance Tax		2022	0	0	27,070,161	24,223,033		2,847,128	0	27,142,304			72,144
27	Employee FICA W/H - 2020	Federal Insurance Tax		2020	1	0			(f) 1	0	0
28	Employee FICA W/H - 2021	Federal Insurance Tax		2021	210	0	210			0	0
29	Employee FICA W/H - 2022	Federal Insurance Tax		2022	0	0	24,298,102	24,297,680		422	0
30	Subtotal Federal Insurance Tax				8,215,680	0	49,600,891	54,969,020	1	2,847,550	0	25,348,192			72,144
31	Franchise Fees - 2021	Franchise Tax		2021	2,916,234	0	149,086,732	149,622,830		2,380,136	0	149,086,732
32	Subtotal Franchise Tax				2,916,234	0	149,086,732	149,622,830		2,380,136	0	149,086,732
33	Subtotal Miscellaneous Other Tax				0	0				0	0
34	Employee Fed W/H - 2021	Other Federal Tax		2021	223	0	223			0	0
35	Employee Fed W/H - 2022	Other Federal Tax		2022	0	0	45,636,309	45,629,739		6,570	0
36	Subtotal Other Federal Tax				223	0	45,636,532	45,629,739		6,570	0
37	Subtotal Other State Tax				0	0				0	0
38	Subtotal Other Property Tax				0	0				0	0
39	Subtotal Other Use Tax				0	0				0	0
40	Subtotal Other Advalorem Tax				0	0				0	0
41	Subtotal Other License And Fees Tax				0	0				0	0
42	Subtotal Payroll Tax				0	0				0	0
43	Subtotal Advalorem Tax				0	0				0	0
44	Subtotal Other Allocated Tax				0	0				0	0
45	Subtotal Severance Tax				0	0				0	0
46	Subtotal Penalty Tax				0	0				0	0
47	Other Employee Related Taxes	Other License And Fees Tax			0	0				0	0	(g) 12,506,955
48	City Drainage Fees	Other License And Fees Tax			0	0				0	0	891,958
49	Subtotal Other Taxes And Fees				0	0				0	0	11,614,997
40	TOTAL				166,005,664	0	510,762,545	356,426,391	32,315,815	288,026,002	0	358,107,302			15,374,226

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: TaxesCharged


Reversal Accrual for 2022	$	(538)
2022 True Up	3,306
Other	43
Total	$	2,811

(b) Concept: TaxAdjustments

Reclass Adjustment


Reclass Adjustment

(d) Concept: TaxAdjustments

To reclass prior year dollars to correct year for reporting purposes.

(e) Concept: TaxAdjustments

To reclass prior year dollars to correct year for reporting purposes.

(f) Concept: TaxAdjustments

To reclass prior year dollars to correct year for reporting purposes.

(g) Concept: TaxesAccruedPrepaidAndCharged


Service Company Plan Benefit Overhead Payroll Tax:	$	281,379
Business Unit Plan Benefit Overhead Payroll Tax	(10,233,196)
Business Unit Allocation Structure for Tax W/I Payroll Burden	(6,046,403)
Service Company Allocation Structure for Tax W/I Payroll Burden	3,491,265
Total	$	(12,506,955)

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.
			Deferred for Year		Allocations to Current Year's Income
Line No.	Account Subdivisions (a)	Balance at Beginning of Year (b)	Account No. (c)	Amount (d)	Account No. (e)	Amount (f)	Adjustments (g)	Balance at End of Year (h)	Average Period of Allocation to Income (i)	ADJUSTMENT EXPLANATION (j)
1	Electric Utility
2	3%
3	4%
4	7%
5	10%
8	TOTAL Electric (Enter Total of lines 2 thru 7)
9	Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10										`
11	10%
12	8%
47	OTHER TOTAL
48	GRAND TOTAL	0						0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

OTHER DEFERRED CREDITS (Account 253)
Report below the particulars (details) called for concerning other deferred credits. For any deferred credit being amortized, show the period of amortization. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
			DEBITS
Line No.	Description and Other Deferred Credits (a)	Balance at Beginning of Year (b)	Contra Account (c)	Amount (d)	Credits (e)	Balance at End of Year (f)
1	Deferred Revenue	3,557,380	454.0	13,533,435	11,720,742	1,744,687
2	Deferred Compensation	5,720,996	(a) 236/242/254/219/232/930.2	2,613,742	471,530	3,578,784
3	ODC-Deferred Com-Misc	8,473			150	8,623
4	Other Deferred Credits	577,458	234/232	74,964	694,359	1,196,853
5	Environmental Liability	1,656,678	588.0	1,656,678
6	Deferred Equity Interests	100,020,123	456/182.3	42,099,440	27,763,968	85,684,651
47	TOTAL	111,541,108		59,978,259	40,650,749	92,213,598

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: DecreaseInOtherDeferredCreditsContraAccount

254

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)

Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
For other (Specify),include deferrals relating to other income and deductions.
Use footnotes as required.

CHANGES DURING YEAR

ADJUSTMENTS

Debits

Credits

Line No.

Account

(a)

Balance at Beginning of Year

(b)

Amounts Debited to Account 410.1

(c)

Amounts Credited to Account 411.1

(d)

Amounts Debited to Account 410.2

(e)

Amounts Credited to Account 411.2

(f)

Account Credited

(g)

Amount

(h)

Account Debited

(i)

Amount

(j)

Balance at End of Year

(k)

Accelerated Amortization (Account 281)

Electric

Defense Facilities

Pollution Control Facilities

Other

5.1

Other (provide details in footnote):

TOTAL Electric (Enter Total of lines 3 thru 7)

Gas

Defense Facilities

Pollution Control Facilities

Other

12.1

Other (provide details in footnote):

TOTAL Gas (Enter Total of lines 10 thru 14)

Other

16.1

Other

16.2

Other

TOTAL (Acct 281) (Total of 8, 15 and 16)

Classification of TOTAL

Federal Income Tax

State Income Tax

Local Income Tax

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 282
2	Electric	1,215,264,089	146,742,552	33,193,951			230	2,710,887	182.3	4,323,067	1,330,424,870
3	Gas						—		—
4	Other (Specify)						—		—
5	Total (Total of lines 2 thru 4)	1,215,264,089	146,742,552	33,193,951			230	2,710,887	182.3	4,323,067	1,330,424,870
6							—		—
9	TOTAL Account 282 (Total of Lines 5 thru 8)	1,215,264,089	146,742,552	33,193,951			230	2,710,887	182.3	4,323,067	1,330,424,870
10	Classification of TOTAL
11	Federal Income Tax	1,215,264,089	146,742,552	33,193,951			230	2,710,887	182.3	4,323,067	1,330,424,870
12	State Income Tax						—		—
13	Local Income Tax						—		—

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. For other (Specify),include deferrals relating to other income and deductions. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 283
2	Electric
3		173,014,271	48,656,264	98,037,094			182.3, 216, 219	27,240,984	182.3, 230, 216	63,510,548	159,903,005
9	TOTAL Electric (Total of lines 3 thru 8)	173,014,271	48,656,264	98,037,094				27,240,984		63,510,548	159,903,005
10	Gas
11
12
13
14
15
16
17	TOTAL Gas (Total of lines 11 thru 16)
18	TOTAL Other
19	TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)	173,014,271	48,656,264	98,037,094				27,240,984		63,510,548	159,903,005
20	Classification of TOTAL
21	Federal Income Tax	169,597,205	47,692,066	96,911,748			182.3, 216, 219	27,128,953	182.3, 230, 216	63,510,548	156,759,118
22	State Income Tax	3,417,065	964,198	1,125,346				112,031			3,143,886
23	Local Income Tax
NOTES

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
			DEBITS
Line No.	Description and Purpose of Other Regulatory Liabilities (a)	Balance at Beginning of Current Quarter/Year (b)	Account Credited (c)	Amount (d)	Credits (e)	Balance at End of Current Quarter/Year (f)
1	(a) Regulatory Liability - TCRF	17,276,081	456.0	93,365,486	192,872,405	116,783,000
2	Regulatory Liability - Other ADFIT Credit	319,322	456.0	319,323	1
3	(b) Regulatory Liability - Pension Deferral	81,262,043	930.2/926.0/407.4	26,691,580	10,663,288	65,233,751
4	(c) Regulatory Noncurrent Liability EDIT - Plant	697,729,484	190.0/410.1	20,020,539		677,708,945
5	(d) Regulatory Noncurrent Liability EDIT - Plant Other	3	190.0/410.1	4,297,209	4,297,210	2
6	Regulatory Liability - Post Retirement	78,807,865	926.0/228.3	6,960,996	14,187,976	86,034,845
7	Regulatory Liability - EECRF		182.3	14,611,521	14,611,521
8	(e) Regulatory Liability - Other Ike Residual	3,264,513	407.4	806,175		2,458,338
9	(f) Regulatory Noncurrent Liability EDIT - ARAM AMORT	40,466,948	254.0	1,879,982		38,586,966
10	(g) Regulatory Lability (Tax) - Interest Rate Hedge	3,693,317	283.0	123,737		3,569,580
11	Reg Liability-ADFIT	318,713	456.0	207,782	212,840	323,771
12	Current Regulatory Liability	19,740,782	142.1	20,159,754	418,972
41	TOTAL	942,879,065		189,444,085	237,264,213	990,699,193

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Amortization period for December filing is 03/2023 to 08/2023 and for June filing is 09/2023 to 02/2024

(b) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Docket 49421 Amortization 04/23/2020 - 04/22/2025

Docket 49421 Amortize using the average rate assumption method over the regulatory lives of the underlying plant assets

(d) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Amortization period - 30-36 months from effective date of PUCT Docket 49421 final order 3/9/20

(e) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Docket 49421 Amortization 04/23/2020 - 04/22/2025

(f) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Amortization period - 30-36 months from effective date of PUCT Docket 49421 final order 3/9/20

(g) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Amortization period various - throughout life of associated debt.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.	Title of Account (a)	Operating Revenues Year to Date Quarterly/Annual (b)	Operating Revenues Previous year (no Quarterly) (c)	MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d)	MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e)	AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f)	AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1	SalesOfElectricityHeadingAbstract Sales of Electricity
2	ResidentialSalesAbstract (440) Residential Sales	1,484,610,847	1,228,479,927	33,675,901	30,650,030	2,383,284	2,334,695
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	888,874,307	822,077,316	27,442,878	25,666,132	317,350	313,884
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	449,079,066	358,107,473	38,861,550	40,497,154	2,070	2,069
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	24,259,909	23,352,765	81,747	85,137	914	889
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	2,846,824,129	2,432,017,481	100,062,076	96,898,453	2,703,618	2,651,537
11	SalesForResaleAbstract (447) Sales for Resale
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	2,846,824,129	2,432,017,481	100,062,076	96,898,453	2,703,618	2,651,537
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	2,846,824,129	2,432,017,481	100,062,076	96,898,453	2,703,618	2,651,537
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts	51,210	653,883
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	(a) 32,720,119	(c) 31,540,693
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	38,176,869	36,775,158
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	(b) 62,426,793	(d) 103,547,616
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	350,140,524	289,552,085
23	RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues
24	MiscellaneousRevenue (457.2) Miscellaneous Revenues
25	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
26	OtherOperatingRevenues TOTAL Other Operating Revenues	358,661,929	462,069,435
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	3,205,486,058	2,894,086,916
Line12, column (b) includes $ 14,204,414 of unbilled revenues.
Line12, column (d) includes 148,446 MWH relating to unbilled revenues

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: MiscellaneousServiceRevenues


Grants to Others (formerly Temp Right of Way Access)	$	7,436,757
Connect/Disconnect/Reconnects	16,933,884
Temporary Service Connections	3,922,524
Pole Attachment Application Fees	994,480
Land Right of Way Processing Fees	3,580
Other	3,428,894
	$	32,720,119

(b) Concept: OtherElectricRevenue


Amortization for Pre-Tax equity earnings (recovery of certain qualified cost and storm restoration costs)	$	42,311,252
Energy Efficiency Performance Bonus Amortization	1,335,095
Unprotected Excess Deferred Income Taxes Credit Rider	(3,320)
Royalty Revenues	34,563
Energy Efficiency Over/Under	(8,610,923)
Transmission Cost Recovery Factor Over/Under	(99,506,919)
Accumulated Deferred Income Tax Credits	(763,541)
Interconnection Study	2,777,000
	$	(62,426,793)



Grants to Others (formerly Temp Right of Way Access)	$	6,031,333
Connect/Disconnect/Reconnects	16,662,810
Temporary Service Connections	5,225,490
Pole Attachment Application Fees	467,545
Commercial Land Lease	6,000
Land Right of Way Processing Fees	16,130
Other	3,131,385
	$	31,540,693

(d) Concept: OtherElectricRevenue


Amortization for Pre-Tax equity earnings (recovery of certain qualified cost and storm restoration costs)	$	40,461,171
Energy Efficiency Performance Bonus Amortization	10,385,734
Unprotected Excess Deferred Income Taxes Credit Rider	(32,271,842)
Royalty Revenues	201,189
Energy Efficiency Over/Under	3,672,356
Transmission Cost Recovery Factor Over/Under	82,398,143
Accumulated Deferred Income Tax Credits	(2,912,135)
Interconnection Study	1,613,000
	$	103,547,616

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.	Description of Service (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46	TOTAL

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	440 Residential Sales RS	33,484,769	1,471,996,800	2,383,284	14,050	0.0440
41	TOTAL Billed Residential Sales	33,484,769	1,471,996,800	2,383,284	14,050	0.0440
42	TOTAL Unbilled Rev. (See Instr. 6)	191,132	12,614,047			0.0660
43	TOTAL	33,675,901	1,484,610,847	2,383,284	14,130	0.0441

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	442-1 Commercial Sales
2	SVS	886,499	33,904,906	154,964	5,721	0.0382
3	SVL	24,732,235	786,401,388	145,909	169,504	0.0318
4	PVS	1,610,766	34,175,346	682	2,361,538	0.0212
5	MLS	45,830	3,186,798	11,220	4,085	0.0695
6	SLS	97,625	31,802,396	4,575	21,341	0.3258
41	TOTAL Billed Small or Commercial	27,372,955	889,470,834	317,350	2,562,189	0.0325
42	TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)	69,923	596,527			0.0090
43	TOTAL Small or Commercial	27,442,878	888,874,307	317,350	86,475	0.0324

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	442-2 Industrial Sales
2	SVL	7,234,349	181,270,658	1,492	4,849,572	0.0251
3	PVS	2,678,507	51,884,985	350	7,654,700	0.0194
4	TVS	29,357,342	213,685,556	228	128,525,394	0.0073
41	TOTAL Billed Large (or Ind.) Sales	39,270,198	446,841,199	2,070	141,029,666	0.0114
42	TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)	408,648	2,237,867			0.0055
43	TOTAL Large (or Ind.)	38,861,550	449,079,066	2,070	18,772,940	0.0116

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41	TOTAL Billed Commercial and Industrial Sales
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	444 Municipal Sales
2	SLS	82,600	24,310,883	914	90,372	0.2943
41	TOTAL Billed Public Street and Highway Lighting	82,600	24,310,883	914	90,372	0.2943
42	TOTAL Unbilled Rev. (See Instr. 6)	853	50,974			0.0600
43	TOTAL	81,747	24,259,909	914	90,372	0.2968

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
41	TOTAL Billed - All Accounts	100,210,522	2,832,619,716	2,703,618	143,696,277	0.0283
42	TOTAL Unbilled Rev. (See Instr. 6) - All Accounts	148,446	14,204,413			0.0957
43	TOTAL - All Accounts	100,062,076	2,846,824,129	2,703,618	143,696,277	0.0285

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

SALES FOR RESALE (Account 447)
Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326). Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k). In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24. Footnote entries as required and provide explanations following all required data.
					ACTUAL DEMAND (MW)			REVENUE
Line No.	Name of Company or Public Authority (Footnote Affiliations) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Average Monthly Billing Demand (MW) (d)	Average Monthly NCP Demand (e)	Average Monthly CP Demand (f)	Megawatt Hours Sold (g)	Demand Charges ($) (h)	Energy Charges ($) (i)	Other Charges ($) (j)	Total ($) (h+i+j) (k)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15	Subtotal - RQ
16	Subtotal-Non-RQ
17	Total

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures, explain in footnote.
Line No.	Account (a)	Amount for Current Year (b)	Amount for Previous Year (c) (c)
1	PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES
2	SteamPowerGenerationAbstract A. Steam Power Generation
3	SteamPowerGenerationOperationAbstract Operation
4	OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering
5	FuelSteamPowerGeneration (501) Fuel
6	SteamExpensesSteamPowerGeneration (502) Steam Expenses
7	SteamFromOtherSources (503) Steam from Other Sources
8	SteamTransferredCredit (Less) (504) Steam Transferred-Cr.
9	ElectricExpensesSteamPowerGeneration (505) Electric Expenses
10	MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses
11	RentsSteamPowerGeneration (507) Rents
12	Allowances (509) Allowances
13	SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12)
14	SteamPowerGenerationMaintenanceAbstract Maintenance
15	MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering
16	MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures
17	MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant
18	MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant
19	MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant
20	SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19)
21	PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
22	NuclearPowerGenerationAbstract B. Nuclear Power Generation
23	NuclearPowerGenerationOperationAbstract Operation
24	OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering
25	NuclearFuelExpense (518) Fuel
26	CoolantsAndWater (519) Coolants and Water
27	SteamExpensesNuclearPowerGeneration (520) Steam Expenses
28	SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources
29	SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr.
30	ElectricExpensesNuclearPowerGeneration (523) Electric Expenses
31	MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses
32	RentsNuclearPowerGeneration (525) Rents
33	NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32)
34	NuclearPowerGenerationMaintenanceAbstract Maintenance
35	MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering
36	MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures
37	MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment
38	MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant
39	MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant
40	NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39)
41	PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42	HydraulicPowerGenerationAbstract C. Hydraulic Power Generation
43	HydraulicPowerGenerationOperationAbstract Operation
44	OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering
45	WaterForPower (536) Water for Power
46	HydraulicExpenses (537) Hydraulic Expenses
47	ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses
48	MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses
49	RentsHydraulicPowerGeneration (540) Rents
50	HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49)
51	HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued)
52	HydraulicPowerGenerationMaintenanceAbstract Maintenance
53	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering
54	MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures
55	MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways
56	MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant
57	MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant
58	HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57)
59	PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60	OtherPowerGenerationAbstract D. Other Power Generation
61	OtherPowerGenerationOperationAbstract Operation
62	OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering
63	Fuel (547) Fuel
64	GenerationExpenses (548) Generation Expenses
64.1	OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment
65	MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses
66	RentsOtherPowerGeneration (550) Rents
67	OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67)
68	OtherPowerGenerationMaintenanceAbstract Maintenance
69	MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering
70	MaintenanceOfStructures (552) Maintenance of Structures
71	MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant
71.1	MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment
72	MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant
73	OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72)
74	PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
75	OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses
76	PurchasedPower (555) Purchased Power
76.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations	0
77	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching
78	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses
79	OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)
80	PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)
81	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
82	TransmissionExpensesOperationAbstract Operation
83	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	11,057,403	12,262,162
85	LoadDispatchReliability (561.1) Load Dispatch-Reliability	59,496	58,603
86	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System	3,559,737	3,694,092
87	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling	208,858	183,458
88	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services	950,856	744,869
89	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development	858,826	892,591
90	TransmissionServiceStudies (561.6) Transmission Service Studies
91	GenerationInterconnectionStudies (561.7) Generation Interconnection Studies	173,930	166,263
92	ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services
93	StationExpensesTransmissionExpense (562) Station Expenses	272,513	282,710
93.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
94	OverheadLineExpense (563) Overhead Lines Expenses	774,553	1,020,835
95	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses	1,390	3,764
96	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	1,076,928,309	999,786,927
97	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	3,101,410	3,279,971
98	RentsTransmissionElectricExpense (567) Rents	49,298	63,644
99	TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98)	1,097,996,579	1,022,439,889
100	TransmissionMaintenanceAbstract Maintenance
101	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering
102	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	617,150	879,745
103	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware
104	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software
105	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment
106	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant
107	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	10,726,606	11,293,074
107.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
108	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	14,909,868	20,516,249
109	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines	1,390	3,764
110	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	355,672	327,739
111	TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110)	26,610,686	33,020,571
112	TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111)	1,124,607,265	1,055,460,460
113	RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES
114	RegionalMarketExpensesOperationAbstract Operation
115	OperationSupervision (575.1) Operation Supervision
116	DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation
117	TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation
118	CapacityMarketAdministration (575.4) Capacity Market Facilitation
119	AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation
120	MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance
121	MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services
122	RentsRegionalMarketExpenses (575.8) Rents
123	RegionalMarketOperationExpense Total Operation (Lines 115 thru 122)
124	RegionalMarketExpensesMaintenanceAbstract Maintenance
125	MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements
126	MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware
127	MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software
128	MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment
129	MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant
130	RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129)
131	RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)
132	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
133	DistributionExpensesOperationAbstract Operation
134	OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering	27,708,316	38,470,958
135	LoadDispatching (581) Load Dispatching	2,682,388	2,603,083
136	StationExpensesDistribution (582) Station Expenses	1,127,048	1,137,577
137	OverheadLineExpenses (583) Overhead Line Expenses	2,393,726	3,385,312
138	UndergroundLineExpenses (584) Underground Line Expenses	12,071,255	12,427,648
138.1	OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment
139	StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses	70,685	83,023
140	MeterExpenses (586) Meter Expenses	27,056,539	27,963,298
141	CustomerInstallationsExpenses (587) Customer Installations Expenses	2,875,924	3,110,916
142	MiscellaneousDistributionExpenses (588) Miscellaneous Expenses	26,745,575	25,406,245
143	RentsDistributionExpense (589) Rents	51,634	63,644
144	DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143)	102,783,090	114,651,704
145	DistributionExpensesMaintenanceAbstract Maintenance
146	MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering	4,187,904	4,626,955
147	MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures	817,397	799,050
148	MaintenanceOfStationEquipment (592) Maintenance of Station Equipment	12,327,271	12,061,985
148.1	MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment
149	MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines	68,943,094	70,445,069
150	MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines	12,015,754	11,989,080
151	MaintenanceOfLineTransformers (595) Maintenance of Line Transformers	4,768,082	3,968,386
152	MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems	2,022,391	1,374,399
153	MaintenanceOfMeters (597) Maintenance of Meters	5,448,682	8,487,513
154	MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant	1,113,493	1,389,858
155	DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154)	111,644,068	115,142,295
156	DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155)	214,427,158	229,793,999
157	CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES
158	CustomerAccountsExpensesOperationsAbstract Operation
159	SupervisionCustomerAccountExpenses (901) Supervision
160	MeterReadingExpenses (902) Meter Reading Expenses	1,416,571	2,382,772
161	CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses	18,260,494	17,803,700
162	UncollectibleAccounts (904) Uncollectible Accounts	1,667	1,391
163	MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses
164	CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)	19,678,732	20,187,863
165	CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166	CustomerServiceAndInformationalExpensesOperationAbstract Operation
167	SupervisionCustomerServiceAndInformationExpenses (907) Supervision	600,404	730,329
168	CustomerAssistanceExpenses (908) Customer Assistance Expenses	33,645,532	36,528,591
169	InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses	215,385	196,806
170	MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses	97,653	210,371
171	CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)	34,558,974	37,666,097
172	SalesExpenseAbstract 7. SALES EXPENSES
173	SalesExpenseOperationAbstract Operation
174	SupervisionSalesExpense (911) Supervision
175	DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses
176	AdvertisingExpenses (913) Advertising Expenses
177	MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses
178	SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
179	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
180	AdministrativeAndGeneralExpensesOperationAbstract Operation
181	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	4,376,422	3,912,947
182	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	808,992	767,909
183	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit
184	OutsideServicesEmployed (923) Outside Services Employed	1,176,956	1,156,436
185	PropertyInsurance (924) Property Insurance	12,251,129	11,620,369
186	InjuriesAndDamages (925) Injuries and Damages	21,296,412	19,356,356
187	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	54,995,518	55,548,340
188	FranchiseRequirements (927) Franchise Requirements
189	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	69,063	31,879
190	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.
191	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	233,217	194,153
192	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	131,661,035	142,968,161
193	RentsAdministrativeAndGeneralExpense (931) Rents	9,926,725	9,363,773
194	AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193)	236,795,469	244,920,323
195	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
196	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	1,348,844	1,140,903
197	AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196)	238,144,313	246,061,226
198	OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)	1,631,416,442	1,589,169,645

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

PURCHASED POWER (Account 555)
Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13. Footnote entries as required and provide explanations following all required data.
					Actual Demand (MW)				POWER EXCHANGES		COST/SETTLEMENT OF POWER
Line No.	NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c)	AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d)	AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e)	AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f)	MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g)	MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h)	EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i)	EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j)	DemandChargesOfPurchasedPower Demand Charges ($) (k)	EnergyChargesOfPurchasedPower Energy Charges ($) (l)	OtherChargesOfPurchasedPower Other Charges ($) (m)	SettlementOfPower Total (k+l+m) of Settlement ($) (n)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15	TOTAL						0	0	0	0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c). In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. Report in column (i) and (j) the total megawatthours received and delivered. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. Footnote entries and provide explanations following all required data.
									TRANSFER OF ENERGY		REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Line No.	PaymentByCompanyOrPublicAuthority Payment By (Company of Public Authority) (Footnote Affiliation) (a)	TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName Energy Received From (Company of Public Authority) (Footnote Affiliation) (b)	TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c)	StatisticalClassificationCode Statistical Classification (d)	RateScheduleTariffNumber Ferc Rate Schedule of Tariff Number (e)	TransmissionPointOfReceipt Point of Receipt (Substation or Other Designation) (f)	TransmissionPointOfDelivery Point of Delivery (Substation or Other Designation) (g)	BillingDemand Billing Demand (MW) (h)	TransmissionOfElectricityForOthersEnergyReceived Megawatt Hours Received (i)	TransmissionOfElectricityForOthersEnergyDelivered Megawatt Hours Delivered (j)	Demand Charges ($) (k)	Energy Charges ($) (l)	Other Charges ($) (m)	RevenuesFromTransmissionOfElectricityForOthers Total Revenues ($) (k+l+m) (n)
1	AEP TEXAS										39,371,571.75		225,985	39,145,587
2	ALTOP ENERGY TRADING TEXAS, LLC (QSE)											1,306		1,306
3	ALTOP ENERGY TRADING TEXAS, LLC (SQ3)											2,200		2,200
4	AUSTIN CITY OF DBA AUSTIN ENERGY (TDSP)										16,900,617.98		97,541	16,803,077
5	BANDERA ELECTRIC CO OP INC (TDSP)										955,703.76		5,217	950,487
6	BARTLETT CITY OF										16,434.31		94	16,340
7	BASTROP CITY OF (TDSP)										107,360.41		621	106,739
8	BELLVILLE CITY OF (TDSP)										80,840.19		490	80,350
9	BLUEBONNET ELECTRIC CO OP INC (TDSP)										3,305,920.67		17,331	3,288,590
10	BOERNE CITY OF (TDSP)										215,513.19		1,216	214,297
11	BRADY CITY OF										90,239.86		548	89,692
12	BRAZOS ELECTRIC POWER CO OP INC(TDSP)										22,958,654.23		131,821	22,826,833
13	BRENHAM CITY OF (TDSP)										356,262.66		2,162	354,101
14	BRIDGEPORT CITY OF										84,623.72		511	84,112
15	BROWNSVILLE PUBLIC UTILITY BOARD (TDSP)										1,700,935.35		9,952	1,690,983
16	BRYAN TEXAS UTILITIES (TDSP)										2,462,680.48		13,692	2,448,988
17	BURNET CITY OF (TDSP)										120,910.30		710	120,200
18	CENTRAL TEXAS ELECTRIC CO OP INC (TDSP)										878,808.72		5,307	873,502
19	COLEMAN CITY OF (TDSP)										54,601.96		249	54,353
20	COLLEGE STATION CITY OF (TDSP)										1,322,784.92		7,582	1,315,203
21	CONOCO PHILLIPS COMPANY (QSE)											22,018		22,018
22	CUERO CITY OF (TDSP)										132,470.17		789	131,681
23	CWP ENERGY INC (QSE)											61,491		61,491
24	DENTON MUNICIPAL ELECTRIC (TDSP)										2,221,880.07		13,070	2,208,810
25	DYNASTY POWER INC											43,473		43,473
26	DYNASTY POWER INC (SQ3)											8,431		8,431
27	ETC ENDURE ENERGY LLC											33,866		33,866
28	EVERGY KANSAS CENTRAL (QSE)											102,786		102,786
29	FARMERSVILLE, CITY OF										48,762.41		285	48,477
30	FAYETTE ELECTRIC CO OP INC (TDSP)										386,571.34		2,265	384,306
31	FLATONIA CITY OF (TDSP)										36,812.42		212	36,600
32	FLORESVILLE ELECTRIC POWER										478,924.71		3,089	475,836
33	FREDERICKSBURG CITY OF (TDSP)										202,734.18		1,262	201,472
34	GARLAND CITY OF (TDSP)										2,851,383.81		16,822	2,834,562
35	GEORGETOWN CITY OF (TDSP)										986,238.17		5,549	980,689
36	GEUS (formerly GREENVILLE ELECTRIC)										690,819.91		4,073	686,747
37	GIDDINGS CITY OF (TDSP)										78,781.95		463	78,319
38	GOLDEN SPREAD										1,712,356.03		7,259	1,705,097
39	GOLDSMITH CITY OF										6,051.06		52	5,999
40	GOLDTHWAITE CITY OF (TDSP)										33,489.81		199	33,291
41	GONZALES CITY OF (TDSP)										114,972.68		663	114,309
42	GRANBURY MUNICIPAL UTILITIES (TDSP)										134,742.56		818	133,924
43	GUADALUPE VALLEY ELECTRIC CO OP INC (TDSP)										2,733,640.87		15,038	2,718,603
44	GUZMAN ENERGY LLC											24,119		24,119
45	HALLETTSVILLE CITY OF (TDSP)										55,879.73		337	55,543
46	HAMILTON COUNTY ELECTRIC CO OP (LCRA)										255,564.95		1,397	254,168
47	HEARNE CITY OF MUNICIPAL ELECTRIC SYSTEM (TDSP)										68,748.72		413	68,336
48	HEMPSTEAD CITY OF (TDSP)										75,190.41		466	74,724
49	KERRVILLE PUBLIC UTILITY BOARD (TDSP)										686,600.13		4,158	682,442
50	LA GRANGE CITY OF (TDSP)										91,998.11		577	91,422
51	LAMPASAS CITY OF (TDSP)										149,714.78		906	148,809
52	LAMR										348,810.87		1,967	346,844
53	LEXINGTON CITY OF (TDSP)										18,084.60		100	17,985
54	LLANO CITY OF (TDSP)										62,935.72		401	62,535
55	LOCKHART CITY OF (TDSP)										165,850.82		991	164,860
56	Lubbock Power & Light										2,658,178.96			2,658,179
57	LULING CITY OF (TDSP)										80,974.23		462	80,512
58	LYNTEGAR ELECTRIC CO OP INC (TDSP)												1,151	1,151
59	MAG ENERGY SOLUTIONS INC.											62,476		62,476
60	MAG ENERGY SOLUTIONS INC. (SQ1)											21,489		21,489
61	MASON CITY OF (TDSP)										36,108.62		206	35,903
62	MFT ENERGY US 1 LLC (SQ1)											1		1
63	MOULTON CITY OF (TDSP)										15,039.30		86	14,953
64	NEW BRAUNFELS UTILITIES (TDSP)										1,974,424.76		10,805	1,963,620
65	ONCR										168,370,212.57		975,466	167,394,747
66	PEDERNALES ELEC CO OP INC AEP (TDSP)										37,987.87		207	37,780
67	PEDERNALES ELECTRIC CO OP INC (TDSP)										10,054,473.70		52,556	10,001,918
68	RAINBOW ENERGY MARKETING CORPORATION											360,366		360,366
69	RAYBURN COUNTRY										6,335,177.55		30,287	6,304,891
70	RIO GRANDE ELECTRIC CO OP										340,996.41		2,434	338,563
71	ROBSTOWN CITY OF										127,637.58		768	126,869
72	SAN ANTONIO CITY PUBLIC SERVICE (TDSP)										30,256,703.57		173,131	30,083,573
73	SAN BERNARD ELECTRIC CO OP (TDSP)										924,811.63		5,146	919,666
74	SAN MARCOS CITY OF (TDSP)										813,621.06		4,784	808,837
75	SAN SABA CITY OF (TDSP)										58,446.34		337	58,109
76	SANGER City of										91,702.94		585	91,118
77	SCHULENBURG CITY OF (TDSP)										82,889.76		512	82,378
78	SEGUIN CITY OF (TDSP)										424,202.42		2,422	421,781
79	SEMPRA GAS AND POWER MARKETING (QSE)											7,420		7,420
80	SEYMOUR CITY OF										44,942.92		268	44,675
81	SHINER CITY OF (TDSP)										63,784.16		375	63,409
82	SMITHVILLE CITY OF (TDSP)										62,927.33		360	62,567
83	SOUTH TEXAS ELECTRIC CO OP INC										8,171,064.69		48,127	8,122,938
84	SOUTHWEST TEXAS ELECTRIC CO OP INC (TDSP)												1,721	1,721
85	TEC ENERGY INC (QSE)											1,064		1,064
86	TENASKA POWER SERVICES (QSE)											20,725		20,725
87	TEXAS-NEW MEXICO POWER CO (TDSP)										12,644,675.46		67,667	12,577,008
88	TEX-LA ELECTRIC CORP										966,244.98		4,679	961,566
89	TRANSALTA ENERGY MARKETING(US)INC 3(QSE)											4,684		4,684
90	VITOL INC											17,511		17,511
91	WAELDER CITY OF (TDSP)										28,836.66		176	28,660
92	WEATHERFORD MUNICIPAL UTILITY SYSTEM (TDSP)										578,189.75		3,564	574,626
93	WEIMAR CITY OF (TDSP)										42,905.80		299	42,607
94	WESTERN FARMERS ELECTRIC COOPERATIVE (TDSP)										4,557.36		25	4,532
95	WHITEBORO, CITY OF										56,393.87			56,394
96	YOAKUM CITY OF (TDSP)										126,500.63		739	125,762
97	ERCOT CORRECTION											50,000		50,000
98	Rounding Difference												5	5
35	TOTAL							0	0	0	351,289,088.33	845,426	1,993,990	350,140,524

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

TRANSMISSION OF ELECTRICITY BY ISO/RTOs
Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a). In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided. In column (d) report the revenue amounts as shown on bills or vouchers. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.	Payment Received by (Transmission Owner Name) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Total Revenue by Rate Schedule or Tariff (d)	Total Revenue (e)
1
2
3
4
5
6
7
8
9
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12
13
14
15
16
17
18
19
20
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25
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35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40	TOTAL

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
			TRANSFER OF ENERGY		EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.	NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c)	TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d)	DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e)	EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f)	OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g)	ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1	AEP TEXAS				155,539,086			155,539,086
2	AUSTIN CITY OF DBA AUSTIN ENERGY (TDSP)				22,192,606			22,192,606
3	BANDERA ELECTRIC CO OP INC (TDSP)				1,458,840			1,458,840
4	BRAZOS ELECTRIC POWER CO OP INC(TDSP)				34,696,287			34,696,287
5	BROWNSVILLE PUBLIC UTILITY BOARD (TDSP)				2,583,230			2,583,230
6	BRYAN TEXAS UTILITIES (TDSP)				9,386,291			9,386,291
7	COLLEGE STATION CITY OF (TDSP)				1,014,412			1,014,412
8	CROSS TEXAS TRANSMISSION				18,243,150			18,243,150
9	DEEP EAST TEXAS ELECTRIC CO OP INC				38,406			38,406
10	DENTON MUNICIPAL ELECTRIC (TDSP)				15,463,616			15,463,616
11	EAST TEXAS ELECTRIC COOP				190,111			190,111
12	ELECTRIC TRANSMISSION TEXAS (ETT)				86,156,882			86,156,882
13	FANNIN COUNTY ELECTRIC CO OP INC				40,241			40,241
14	FARMERS ELECTRIC CO OP INC DBA FEC ELECTRIC				181,765			181,765
15	FLORESVILLE ELECTRIC POWER				118,282			118,282
16	GARLAND CITY OF (TDSP)				16,685,119			16,685,119
17	GEUS (formerly GREENVILLE ELECTRIC)				847,273			847,273
18	GOLDEN SPREAD				647,129			647,129
19	GRAYSON COLLIN ELECTRIC CO OP INC				417,247			417,247
20	HOUSTON COUNTY ELECTRIC COOP				370,065			370,065
21	LAMR				75,911			75,911
22	Lone Star Transmission				24,943,824			24,943,824
23	LCRA Corporation				147,277,730			147,277,730
24	Lubbock Power & Light				5,034,160			5,034,160
25	LYNTEGAR ELECTRIC CO OP INC (TDSP)				208,642			208,642
26	SHARYLAND UTILITIES LP (TDSP)				7,719,047			7,719,047
27	NORTH TEXAS UTILITY				59,230,050			59,230,050
28	ONCR				313,853,828			313,853,828
29	RAYBURN COUNTRY				6,717,782			6,717,782
30	RIO GRANDE ELECTRIC CO OP				190,686			190,686
31	SAN ANTONIO CITY PUBLIC SERVICE (TDSP)				56,622,514			56,622,514
32	SAN BERNARD ELECTRIC CO OP (TDSP)				1,047,707			1,047,707
33	SAN MIGUEL ELECTRIC CO OP INC (TDSP)				376,363			376,363
34	SOUTH TEXAS ELECTRIC CO OP INC				23,674,462			23,674,462
35	SOUTHWEST TEXAS ELECTRIC CO OP INC (TDSP)				17,459			17,459
36	TMPA				7,994,477			7,994,477
37	TEXAS-NEW MEXICO POWER CO (TDSP)				29,535,035			29,535,035
38	CHEROKEE COUNTY ELECTRIC CO OP ASSOC				53,092			53,092
39	WOOD COUNTY ELEC CO OP				34,862			34,862
40	TRINITY VALLEY ELECTRIC COOP				196,672			196,672
41	Wind Energy Transmission Texas				26,234,152			26,234,152
42	Miscellaneous write-offs				38			38
	TOTAL		0	0	1,076,928,309	0	0	1,076,928,309

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.	Description (a)	Amount (b)
1	IndustryAssociationDues Industry Association Dues
2	NuclearPowerResearchExpenses Nuclear Power Research Expenses
3	OtherExperimentalAndGeneralResearchExpenses Other Experimental and General Research Expenses
4	PublicationAndDistributionExpensesForSecuritiesToStockholders Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
5	OtherMiscellaneousGeneralExpenses Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6	See Footnote	(a) 131,661,035
46	MiscellaneousGeneralExpenses TOTAL	131,661,035

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: OtherMiscellaneousGeneralExpenses


Company Staff Pay or Expense
Labor	8,885,069
CenterPoint Energy Employee Related Expenses	1,340,633
	$	10,225,702
Miscellaneous
Research and Development	57,146
Contract Services Expense	10,144,288
Utility Expense	79,520
Telecommunications	2,614,177
Fleet Expenses	127,993
Information & Technology Services	94,547
CenterPoint Energy Business Support Services	102,774,188
Other Support Services	(175,831)
Transportation Depreciation Expenses	100,750
Memberships	1,312,655
Materials & Supplies	1,761,221
A & G Other	2,157,536
Customers and Marketing	5,929
	$	121,054,119
Sponsorships & Contributions
AMERICAN LEADERSHIP FO	5,000
UNITED NEGRO COLLEGE F	5,000
PP SER-JOBS FOR PROGRE	5,000
HERMANN PARK CONSERVAN	5,000
HCC FOUNDATION	5,000
SQ HOUSTON AREA URBAN	5,000
PP SER-JOBS FOR PROGRE	5,000
HERMANN PARK CONSERVAN	5,000
HCC FOUNDATION	5,000
SQ HOUSTON AREA URBAN	5,000
BIOHOUSTON INC	5,000
CITY OF RICHMOND	5,000
SSP LITERACYFORTBEND	5,000
IN TODAYS HARBOR FOR	5,000
BAYTOWN AREA-WEST CHAMBERS COUNTY	5,000
UNIVERSITY OF HOUSTON	5,000
SEHCE DC INC	5,000
UH HONORS COLLEGE	5,000
ELLIOTT CHANDLE	5,150
BUFFALO BAYOU PART	6,000
PEARLAND ECONOMIC DEVELOPMENT CORP	6,000
PARTNERSHIP LAKE HOUST	7,500
GALV ECO DEV PARTNERSP	7,500
WPY ISAT	7,500
PARTNERSHIP LAKE HOUST	7,500
GALV ECO DEV PARTNERSP	7,500
WPY ISAT	7,500
TOMBALL ECONOMIC DEVELOPMENT CORP	8,000
SALVATION ARMY WOMENS	10,000
BAY AREA HOUSTON ECONO	10,000


FORT BEND EDC	10,000
ECON DEV BRAZORIA CTY	10,000
BAY AREA HOUSTON ECONO	10,000
FORT BEND EDC	10,000
ECON DEV BRAZORIA CTY	10,000
TEXAS ECONOMIC DEVELOP	10,000
HOUSTON HISPANIC CHAMB	10,000
IN KATY AREA ECONOMIC	10,000
WALLER COUNTY ECONOMIC	10,000
SP ALLIANCEPORTREGIO	10,300
HOUSTON HISPANIC CHAMB	15,000
THE GRIDWISE ALLIANCE INC	20,000
TEXAS A&M ENGINEERING EXPERIMENT	50,000
Miscellaneous items under $5,000	15,764

	$	381,214

TOTAL	$	131,661,035

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405). Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
	A. Summary of Depreciation and Amortization Charges
Line No.	FunctionalClassificationAxis Functional Classification (a)	DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b)	DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c)	AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d)	AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e)	DepreciationAndAmortization Total (f)
1	Intangible Plant				41,813,152	41,813,152
2	Steam Production Plant
3	Nuclear Production Plant
4	Hydraulic Production Plant-Conventional
5	Hydraulic Production Plant-Pumped Storage
6	Other Production Plant
7	Transmission Plant	98,932,713		2,018,361		100,951,074
8	Distribution Plant	273,884,800		18,246		273,903,045
9	Regional Transmission and Market Operation
10	General Plant	48,761,646		18,387		48,780,033
11	Common Plant-Electric
12	TOTAL	421,579,159		2,054,994	41,813,152	465,447,304

B. Basis for Amortization Charges

	C. Factors Used in Estimating Depreciation Charges
Line No.	AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a)	DepreciablePlantBase Depreciable Plant Base (in Thousands) (b)	UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c)	UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d)	UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e)	MortalityCurveType Mortality Curve Type (f)	UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g)
12	Intangible Plant:
13	303 - 5 Year Life		5 years		20
14	303 - 7 Year Life		7 years		14
15	303 - 10 Year Life		10 years		10
16	303 - 15 Year Life		15 years		6.67
17	Gas & Oil-Steam Units:
18	311
19	312
20	314
21	315
22	316
23	Gas&Coal-Steam Units:
24	Nuclear Production:
25	321
26	322
27	323
28	324
29	325
30	Other Production:
31	341
32	342
33	343
34	344
35	345
36	346
37	Transmission:
38	350.2				1.31
39	352				1.74
40	353				2.05
41	354				2.15
42	355				2.47
43	356				3.21
44	357				1.73
45	358				2.35
46	359				1.9
47	Distribution:
48	360.2				1.55
49	361				1.68
50	362				2.14
51	364				3.84
52	365				3.24
53	366				1.96
54	367				3.34
55	368				3.71
56	369				3.76
57	370				3.32
58	370.3				4.77
59	373				3.09
60	374				3.09
61	General
62	389.2				1.8
63	390				2.05
64	391				4.17
65	392				6.73
66	393				5.26
67	394				5.56
68	395				4
69	396				5.1
70	397 (General)				5.08
71	397 (Computer)				12.5
72	398				5
73	OtherTangibleProperty:
74	399.2
75	399.391
76	399.392
77	399.394
78	399.395
79	399.3971
80	399.3972
81	399.398
82	399.40005
83	399.40010
84	399.40015
85	399.40020
86	399.40030
87	399.40040

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

REGULATORY COMMISSION EXPENSES
Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts. Minor items (less than $25,000) may be grouped.
						EXPENSES INCURRED DURING YEAR				AMORTIZED DURING YEAR
						CURRENTLY CHARGED TO
Line No.	RegulatoryCommissionDescription Description (Furnish name of regulatory commission or body the docket or case number and a description of the case) (a)	RegulatoryExpensesAssessedByRegulatoryCommission Assessed by Regulatory Commission (b)	RegulatoryExpensesOfUtility Expenses of Utility (c)	RegulatoryCommissionExpensesAmount Total Expenses for Current Year (d)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 at Beginning of Year (e)	NameOfDepartmentRegulatoryCommissionExpensesCharged Department (f)	AccountNumberRegulatoryCommissionExpensesCharged Account No. (g)	RegulatoryComissionExpensesIncurredAndCharged Amount (h)	RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets Deferred to Account 182.3 (i)	DeferredRegulatoryCommissionExpensesAmortizedInContraAccount Contra Account (j)	DeferredRegulatoryCommissionExpensesAmortized Amount (k)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 End of Year (l)
1	Reg Assets - EECRF Rate Case Expenses DKT 52194				69,063					928.0	69,063
2	Reg Assets - EECRF Rate Case Expenses DKT 53677				25,272		234.0	26,588	26,588			51,860
3	Reg Assets - EECRF Rate Case Expenses 2022						234.0	33,288	33,288			33,288
46	TOTAL				94,335			59,876	59,876		69,063	85,148

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts). Indicate in column (a) the applicable classification, as shown below: Classifications: Electric R, D and D Performed Internally: Generation hydroelectric Recreation fish and wildlife Other hydroelectric Fossil-fuel steam Internal combustion or gas turbine Nuclear Unconventional generation Siting and heat rejection Transmission Overhead Underground Distribution Regional Transmission and Market Operation Environment (other than equipment) Other (Classify and include items in excess of $50,000.) Total Cost Incurred Electric, R, D and D Performed Externally: Research Support to the electrical Research Council or the Electric Power Research Institute Research Support to Edison Electric Institute Research Support to Nuclear Power Groups Research Support to Others (Classify) Total Cost Incurred Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e). Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est."" Report separately research and related testing facilities operated by the respondent.
					AMOUNTS CHARGED IN CURRENT YEAR
Line No.	ResearchDevelopmentAndDemonstrationClassification Classification (a)	ResearchDevelopmentAndDemonstrationDescription Description (b)	ResearchDevelopmentAndDemonstrationCostsIncurredInternally Costs Incurred Internally Current Year (c)	ResearchDevelopmentAndDemonstrationCostsIncurredExternally Costs Incurred Externally Current Year (d)	AccountNumberForResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Account (e)	ResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Amount (f)	ResearchDevelopmentAndDemonstrationExpenditures Unamortized Accumulation (g)
1	A. Electric Utility R, D & D
2	Performed Internally
3	B. Electric Utility R, D & D
4	Performed Externally
5		EPRI-Transmission Protection Support Tools		111,053	—	111,053
6		EPRI-Distribution Protection		98,006	—	98,006
7		EPRI- Distribution Planning		143,743	—	143,743
8		EPRI- Energy Storage & DG - Strategic Intelligence and Analysis		47,321	—	47,321
9		EPRI-System Planning Methods, Tools, and Analytics with Emerging Technologies		93,314	—	93,314
10		EPRI-DER Modeling and Simulation		84,113	—	84,113
11		EPRI-DER Tech Transfer & Industry Coordination		42,113	—	42,113
12		EPRI-Model Development, Validation, and Management		111,053	—	111,053
13		EPRI-Special Planning Study Methods and Tools		111,053	—	111,053
14		EPRI-Transformer Life Management		156,693	—	156,693
15		EPRI-Performance of External Insulation in Contaminated Environments		40,514	—	40,514
16		EPRI-Transmission Asset Management, P34.001 -.003		110,482	—	110,482
17		EPRI-Ovhd Trans Share 35.001-005, 011, 012, 015		364,491	—	364,491
18		EPRI-Overhead and Underground Distribution Asset Analytics		91,958	—	91,958
19		EPRI-Lightning Performance and Grounding of Transmission Lines		73,884	—	73,884
20		EPRI-Transmission Asset Management		56,089	—	56,089
21		EPRI-Ovhd Trans Share 35.007, 008, 013, 014, 18,19		317,347	—	317,347
22		EPRI-Underground Transmission		513,400	—	513,400
23		EPRI-Substations: 37.104, 114 (Grounding, GIS Subs & Lines)		94,731	—	94,731
24		EPRI-Live Working: Research, Techniques and Procedures		65,440	—	65,440
25		EPRI-Grid Operations		418,441	—	418,441
26		EPRI-Cyber Security and Privacy		262,489	—	262,489
27		EPRI-Risk Mitigation Strategies		78,821	—	78,821
28		EPRI-Emerging Technologies and Technology Transfer & Telecomunication		133,916	—	133,916
29		Total Research, Development & Demonstration		3,620,466	—	3,620,466

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

DISTRIBUTION OF SALARIES AND WAGES
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.
Line No.	Classification (a)	Direct Payroll Distribution (b)	Allocation of Payroll Charged for Clearing Accounts (c)	Total (d)
1	SalariesAndWagesElectricAbstract Electric
2	SalariesAndWagesElectricOperationAbstract Operation
3	SalariesAndWagesElectricOperationProduction Production
4	SalariesAndWagesElectricOperationTransmission Transmission	14,088,455
5	SalariesAndWagesElectricOperationRegionalMarket Regional Market
6	SalariesAndWagesElectricOperationDistribution Distribution	67,907,700
7	SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts	5,402,736
8	SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational	1,512,699
9	SalariesAndWagesElectricOperationSales Sales
10	SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General	6,656,397
11	SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10)	95,567,987
12	SalariesAndWagesElectricMaintenanceAbstract Maintenance
13	SalariesAndWagesElectricMaintenanceProduction Production
14	SalariesAndWagesElectricMaintenanceTransmission Transmission	10,608,703
15	SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market
16	SalariesAndWagesElectricMaintenanceDistribution Distribution	38,769,309
17	SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General
18	SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17)	49,378,012
19	SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance
20	SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13)
21	SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14)	24,697,158
22	SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15)
23	SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16)	106,677,009
24	SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7)	5,402,736
25	SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8)	1,512,699
26	SalariesAndWagesElectricSales Sales (Transcribe from line 9)
27	SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17)	6,656,397
28	SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27)	144,945,999	13,599,687	158,545,686
29	SalariesAndWagesGasAbstract Gas
30	SalariesAndWagesGasOperationAbstract Operation
31	SalariesAndWagesGasOperationProductionManufacturedGas Production - Manufactured Gas
32	SalariesAndWagesGasOperationProductionNaturalGas Production-Nat. Gas (Including Expl. And Dev.)
33	SalariesAndWagesGasOperationOtherGasSupply Other Gas Supply
34	SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing Storage, LNG Terminaling and Processing
35	SalariesAndWagesGasOperationTransmission Transmission
36	SalariesAndWagesGasOperationDistribution Distribution
37	SalariesAndWagesGasCustomerAccounts Customer Accounts
38	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational
39	SalariesAndWagesGasSales Sales
40	SalariesAndWagesGasOperationAdministrativeAndGeneral Administrative and General
41	SalariesAndWagesGasOperation TOTAL Operation (Enter Total of lines 31 thru 40)
42	SalariesAndWagesGasMaintenanceAbstract Maintenance
43	SalariesAndWagesGasMaintenanceProductionManufacturedGas Production - Manufactured Gas
44	SalariesAndWagesGasMaintenanceProductionNaturalGas Production-Natural Gas (Including Exploration and Development)
45	SalariesAndWagesGasMaintenanceOtherGasSupply Other Gas Supply
46	SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing
47	SalariesAndWagesGasMaintenanceTransmission Transmission
48	SalariesAndWagesGasMaintenanceDistribution Distribution
49	SalariesAndWagesGasMaintenanceAdministrativeAndGeneral Administrative and General
50	SalariesAndWagesGasMaintenance TOTAL Maint. (Enter Total of lines 43 thru 49)
51	SalariesAndWagesGasOperationAndMaintenanceAbstract Total Operation and Maintenance
52	SalariesAndWagesGasProductionManufacturedGas Production-Manufactured Gas (Enter Total of lines 31 and 43)
53	SalariesAndWagesGasProductionNaturalGas Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54	SalariesAndWagesGasOtherGasSupply Other Gas Supply (Enter Total of lines 33 and 45)
55	SalariesAndWagesGasStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing (Total of lines 31 thru
56	SalariesAndWagesGasTransmission Transmission (Lines 35 and 47)
57	SalariesAndWagesGasDistribution Distribution (Lines 36 and 48)
58	SalariesAndWagesGasCustomerAccounts Customer Accounts (Line 37)
59	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational (Line 38)
60	SalariesAndWagesGasSales Sales (Line 39)
61	SalariesAndWagesGasAdministrativeAndGeneral Administrative and General (Lines 40 and 49)
62	SalariesAndWagesGasOperationAndMaintenance TOTAL Operation and Maint. (Total of lines 52 thru 61)
63	SalariesAndWagesOtherUtilityDepartmentsAbstract Other Utility Departments
64	SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance Operation and Maintenance
65	SalariesAndWagesOperationsAndMaintenance TOTAL All Utility Dept. (Total of lines 28, 62, and 64)	144,945,999	13,599,687	158,545,686
66	SalariesAndWagesUtilityPlantAbstract Utility Plant
67	SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments)
68	SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant	194,117,533		194,117,533
69	SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant
70	SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote):
71	SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70)	194,117,533		194,117,533
72	SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments)
73	SalariesAndWagesPlantRemovalElectricPlant Electric Plant	14,073,729		14,073,729
74	SalariesAndWagesPlantRemovalGasPlant Gas Plant
75	SalariesAndWagesPlantRemovalOther Other (provide details in footnote):
76	SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75)	14,073,729		14,073,729
77	SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote):
78	SalariesAndWagesOtherAccountsDescription Other Accounts (Specify, provide details in footnote):
79	SalariesAndWagesOtherAccountsDescription
80	SalariesAndWagesOtherAccountsDescription
81	SalariesAndWagesOtherAccountsDescription
82	SalariesAndWagesOtherAccountsDescription
83	SalariesAndWagesOtherAccountsDescription
84	SalariesAndWagesOtherAccountsDescription
85	SalariesAndWagesOtherAccountsDescription
86	SalariesAndWagesOtherAccountsDescription
87	SalariesAndWagesOtherAccountsDescription
88	SalariesAndWagesOtherAccountsDescription
89	SalariesAndWagesOtherAccountsDescription
90	SalariesAndWagesOtherAccountsDescription
91	SalariesAndWagesOtherAccountsDescription
92	SalariesAndWagesOtherAccountsDescription
93	SalariesAndWagesOtherAccountsDescription
94	SalariesAndWagesOtherAccountsDescription
95	SalariesAndWagesOtherAccounts TOTAL Other Accounts
96	SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES	353,137,261	13,599,687	366,736,948

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

COMMON UTILITY PLANT AND EXPENSES
Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.	Description of Item(s) (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	Energy
2	Net Purchases (Account 555)
2.1	Net Purchases (Account 555.1)
3	Net Sales (Account 447)
4	Transmission Rights
5	Ancillary Services
6	Other Items (list separately)
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46	TOTAL

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff. In columns for usage, report usage-related billing determinant and the unit of measure. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
		Amount Purchased for the Year			Amount Sold for the Year
		Usage - Related Billing Determinant			Usage - Related Billing Determinant
Line No.	Type of Ancillary Service (a)	Number of Units (b)	Unit of Measure (c)	Dollar (d)	Number of Units (e)	Unit of Measure (f)	Dollars (g)
1	Scheduling, System Control and Dispatch		MW			MW
2	Reactive Supply and Voltage		MW			MW
3	Regulation and Frequency Response
4	Energy Imbalance
5	Operating Reserve - Spinning
6	Operating Reserve - Supplement
7	Other
8	Total (Lines 1 thru 7)

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Firm Network Service for Self (e)	Firm Network Service for Others (f)	Long-Term Firm Point-to-point Reservations (g)	Other Long-Term Firm Service (h)	Short-Term Firm Point-to-point Reservation (i)	Other Service (j)
	NAME OF SYSTEM: 0
1	January
2	February
3	March
4	Total for Quarter 1				0	0	0			0
5	April
6	May
7	June
8	Total for Quarter 2				0	0	0			0
9	July
10	August
11	September
12	Total for Quarter 3				0	0	0			0
13	October
14	November
15	December
16	Total for Quarter 4				0	0	0			0
17	Total				0	0	0	0	0	0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

Monthly ISO/RTO Transmission System Peak Load
Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f). Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Import into ISO/RTO (e)	Exports from ISO/RTO (f)	Through and Out Service (g)	Network Service Usage (h)	Point-to-Point Service Usage (i)	Total Usage (j)
	NAME OF SYSTEM: 0
1	January
2	February
3	March
4	Total for Quarter 1				0	0	0	0	0	0
5	April
6	May
7	June
8	Total for Quarter 2				0	0	0	0	0	0
9	July
10	August
11	September
12	Total for Quarter 3				0	0	0	0	0	0
13	October
14	November
15	December
16	Total for Quarter 4				0	0	0	0	0	0
17	Total Year to Date/Year				0	0	0	0	0	0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2023-04-18

Year/Period of Report

End of:

2022

ELECTRIC ENERGY ACCOUNT
Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.
Line No.	Item (a)	MegaWatt Hours (b)	Line No.	Item (a)	MegaWatt Hours (b)
1	SOURCES OF ENERGY		21	DISPOSITION OF ENERGY
2	Generation (Excluding Station Use):		22	Sales to Ultimate Consumers (Including Interdepartmental Sales)	100,062,076
3	Steam		23	Requirements Sales for Resale (See instruction 4, page 311.)
4	Nuclear		24	Non-Requirements Sales for Resale (See instruction 4, page 311.)
5	Hydro-Conventional		25	Energy Furnished Without Charge
6	Hydro-Pumped Storage		26	Energy Used by the Company (Electric Dept Only, Excluding Station Use)
7	Other		27	Total Energy Losses
8	Less Energy for Pumping		27.1	Total Energy Stored
9	Net Generation (Enter Total of lines 3 through 8)		28	TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES
10	Purchases (other than for Energy Storage)	0
10.1	Purchases for Energy Storage	0
11	Power Exchanges:
12	Received	0
13	Delivered	0
14	Net Exchanges (Line 12 minus line 13)
15	Transmission For Other (Wheeling)
16	Received
17	Delivered
18	Net Transmission for Other (Line 16 minus line 17)
19	Transmission By Others Losses
20	TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

MONTHLY PEAKS AND OUTPUT
Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system. Report in column (b) by month the system’s output in Megawatt hours for each month. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.	MonthAxis Month (a)	EnergyActivity Total Monthly Energy (b)	NonRequiredSalesForResaleEnergy Monthly Non-Requirement Sales for Resale & Associated Losses (c)	MonthlyPeakLoad Monthly Peak - Megawatts (d)	DayOfMonthlyPeak Monthly Peak - Day of Month (e)	HourOfMonthlyPeak Monthly Peak - Hour (f)
	NAME OF SYSTEM: 0
29	January
30	February
31	March
32	April
33	May
34	June
35	July
36	August
37	September
38	October
39	November
40	December
41	Total	0	0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.	Item (a)	Plant Name: Plant 1	Plant Name: Plant 10	Plant Name: Plant 2	Plant Name: Plant 3	Plant Name: Plant 4	Plant Name: Plant 5	Plant Name: Plant 6	Plant Name: Plant 7	Plant Name: Plant 8	Plant Name: Plant 9
1	PlantKind Kind of Plant (Internal Comb, Gas Turb, Nuclear)
2	PlantConstructionType Type of Constr (Conventional, Outdoor, Boiler, etc)
3	YearPlantOriginallyConstructed Year Originally Constructed
4	YearLastUnitOfPlantInstalled Year Last Unit was Installed
5	InstalledCapacityOfPlant Total Installed Cap (Max Gen Name Plate Ratings-MW)
6	NetPeakDemandOnPlant Net Peak Demand on Plant - MW (60 minutes)
7	PlantHoursConnectedToLoad Plant Hours Connected to Load
8	NetContinuousPlantCapability Net Continuous Plant Capability (Megawatts)
9	NetContinuousPlantCapabilityNotLimitedByCondenserWater When Not Limited by Condenser Water
10	NetContinuousPlantCapabilityLimitedByCondenserWater When Limited by Condenser Water
11	PlantAverageNumberOfEmployees Average Number of Employees
12	NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh
13	CostOfLandAndLandRightsSteamProduction Cost of Plant: Land and Land Rights
14	CostOfStructuresAndImprovementsSteamProduction Structures and Improvements
15	CostOfEquipmentSteamProduction Equipment Costs
16	AssetRetirementCostsSteamProduction Asset Retirement Costs
17	CostOfPlant Total cost (total 13 thru 20)
18	CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 17/5) Including
19	OperationSupervisionAndEngineeringExpense Production Expenses: Oper, Supv, & Engr
20	FuelSteamPowerGeneration Fuel
21	CoolantsAndWater Coolants and Water (Nuclear Plants Only)
22	SteamExpensesSteamPowerGeneration Steam Expenses
23	SteamFromOtherSources Steam From Other Sources
24	SteamTransferredCredit Steam Transferred (Cr)
25	ElectricExpensesSteamPowerGeneration Electric Expenses
26	MiscellaneousSteamPowerExpenses Misc Steam (or Nuclear) Power Expenses
27	RentsSteamPowerGeneration Rents
28	Allowances Allowances
29	MaintenanceSupervisionAndEngineeringSteamPowerGeneration Maintenance Supervision and Engineering
30	MaintenanceOfStructuresSteamPowerGeneration Maintenance of Structures
31	MaintenanceOfBoilerPlantSteamPowerGeneration Maintenance of Boiler (or reactor) Plant
32	MaintenanceOfElectricPlantSteamPowerGeneration Maintenance of Electric Plant
33	MaintenanceOfMiscellaneousSteamPlant Maintenance of Misc Steam (or Nuclear) Plant
34	PowerProductionExpensesSteamPower Total Production Expenses		0				0	0			0
35	ExpensesPerNetKilowattHour Expenses per Net kWh

35	FuelKindAxis Plant Name
36	FuelKind Fuel Kind
37	FuelUnit Fuel Unit
38	QuantityOfFuelBurned Quantity (Units) of Fuel Burned
39	FuelBurnedAverageHeatContent Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
40	AverageCostOfFuelPerUnitAsDelivered Avg Cost of Fuel/unit, as Delvd f.o.b. during year
41	AverageCostOfFuelPerUnitBurned Average Cost of Fuel per Unit Burned
42	AverageCostOfFuelBurnedPerMillionBritishThermalUnit Average Cost of Fuel Burned per Million BTU
43	AverageCostOfFuelBurnedPerKilowattHourNetGeneration Average Cost of Fuel Burned per kWh Net Gen
44	AverageBritishThermalUnitPerKilowattHourNetGeneration Average BTU per kWh Net Generation

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

Hydroelectric Generating Plant Statistics

Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
If net peak demand for 60 minutes is not available, give that which is available specifying period.
If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.

Line No.	Item (a)	FERC Licensed Project No. Plant Name:	FERC Licensed Project No. Plant Name:	FERC Licensed Project No. Plant Name:	FERC Licensed Project No. Plant Name:	FERC Licensed Project No. Plant Name:
1	PlantKind Kind of Plant (Run-of-River or Storage)
2	PlantConstructionType Plant Construction type (Conventional or Outdoor)
3	YearPlantOriginallyConstructed Year Originally Constructed
4	YearLastUnitOfPlantInstalled Year Last Unit was Installed
5	InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW)
6	NetPeakDemandOnPlant Net Peak Demand on Plant-Megawatts (60 minutes)
7	PlantHoursConnectedToLoad Plant Hours Connect to Load
8	NetPlantCapabilityAbstract Net Plant Capability (in megawatts)
9	NetPlantCapabilityUnderMostFavorableOperatingConditions (a) Under Most Favorable Oper Conditions
10	NetPlantCapabilityUnderMostAdverseOperatingConditions (b) Under the Most Adverse Oper Conditions
11	PlantAverageNumberOfEmployees Average Number of Employees
12	NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh
13	CostOfPlantAbstract Cost of Plant
14	CostOfLandAndLandRightsHydroelectricProduction Land and Land Rights
15	CostOfStructuresAndImprovementsHydroelectricProduction Structures and Improvements
16	CostOfReservoirsDamsAndWaterwaysHydroelectricProduction Reservoirs, Dams, and Waterways
17	EquipmentCostsHydroelectricProduction Equipment Costs
18	CostOfRoadsRailroadsAndBridgesHydroelectricProduction Roads, Railroads, and Bridges
19	AssetRetirementCostsHydroelectricProduction Asset Retirement Costs
20	CostOfPlant Total cost (total 13 thru 20)
21	CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 20 / 5)
22	ProductionExpensesAbstract Production Expenses
23	OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering
24	WaterForPower Water for Power
25	HydraulicExpenses Hydraulic Expenses
26	ElectricExpensesHydraulicPowerGeneration Electric Expenses
27	MiscellaneousHydraulicPowerGenerationExpenses Misc Hydraulic Power Generation Expenses
28	RentsHydraulicPowerGeneration Rents
29	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration Maintenance Supervision and Engineering
30	MaintenanceOfStructuresHydraulicPowerGeneration Maintenance of Structures
31	MaintenanceOfReservoirsDamsAndWaterways Maintenance of Reservoirs, Dams, and Waterways
32	MaintenanceOfElectricPlantHydraulicPowerGeneration Maintenance of Electric Plant
33	MaintenanceOfMiscellaneousHydraulicPlant Maintenance of Misc Hydraulic Plant
34	PowerProductionExpensesHydraulicPower Total Production Expenses (total 23 thru 33)
35	ExpensesPerNetKilowattHour Expenses per net kWh

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

Pumped Storage Generating Plant Statistics
Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings). If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number. If net peak demand for 60 minutes is not available, give that which is available, specifying period. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses." Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.	Item (a)	FERC Licensed Project No. 0 Plant Name: 0
1	PlantConstructionType Type of Plant Construction (Conventional or Outdoor)
2	YearPlantOriginallyConstructed Year Originally Constructed
3	YearLastUnitOfPlantInstalled Year Last Unit was Installed
4	InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW)
5	NetPeakDemandOnPlant Net Peak Demaind on Plant-Megawatts (60 minutes)
6	PlantHoursConnectedToLoad Plant Hours Connect to Load While Generating
7	NetContinuousPlantCapability Net Plant Capability (in megawatts)
8	PlantAverageNumberOfEmployees Average Number of Employees
9	NetGenerationExcludingPlantUse Generation, Exclusive of Plant Use - kWh
10	EnergyUsedForPumping Energy Used for Pumping
11	NetOutputForLoad Net Output for Load (line 9 - line 10) - Kwh	0
12	CostOfPlantAbstract Cost of Plant
13	CostOfLandAndLandRightsPumpedStoragePlant Land and Land Rights
14	CostOfStructuresAndImprovementsPumpedStoragePlant Structures and Improvements
15	CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant Reservoirs, Dams, and Waterways
16	CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant Water Wheels, Turbines, and Generators
17	CostOfAccessoryElectricEquipmentPumpedStoragePlant Accessory Electric Equipment
18	CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant Miscellaneous Powerplant Equipment
19	CostOfRoadsRailroadsAndBridgesPumpedStoragePlant Roads, Railroads, and Bridges
20	AssetRetirementCostsPumpedStoragePlant Asset Retirement Costs	0
21	CostOfPlant Total cost (total 13 thru 20)
22	CostPerKilowattOfInstalledCapacity Cost per KW of installed cap (line 21 / 4)
23	ProductionExpensesAbstract Production Expenses
24	OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering
25	WaterForPower Water for Power
26	PumpedStorageExpenses Pumped Storage Expenses
27	ElectricExpensesPumpedStoragePlant Electric Expenses
28	MiscellaneousPumpedStoragePowerGenerationExpenses Misc Pumped Storage Power generation Expenses
29	RentsPumpedStoragePlant Rents
30	MaintenanceSupervisionAndEngineeringPumpedStoragePlant Maintenance Supervision and Engineering
31	MaintenanceOfStructuresPumpedStoragePlant Maintenance of Structures
32	MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant Maintenance of Reservoirs, Dams, and Waterways
33	MaintenanceOfElectricPlantPumpedStoragePlant Maintenance of Electric Plant
34	MaintenanceOfMiscellaneousPumpedStoragePlant Maintenance of Misc Pumped Storage Plant	0
35	PowerProductionExpenseBeforePumpingExpenses Production Exp Before Pumping Exp (24 thru 34)
36	PumpingExpenses Pumping Expenses
37	PowerProductionExpensesPumpedStoragePlant Total Production Exp (total 35 and 36)
38	ExpensesPerNetKilowattHour Expenses per kWh (line 37 / 9)
39	ExpensesPerNetKilowattHourGenerationAndPumping Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))	0

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

GENERATING PLANT STATISTICS (Small Plants)
Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating). Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402. If net peak demand for 60 minutes is not available, give the which is available, specifying period. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
									Production Expenses
Line No.	PlantName Name of Plant (a)	YearPlantOriginallyConstructed Year Orig. Const. (b)	InstalledCapacityOfPlant Installed Capacity Name Plate Rating (MW) (c)	NetPeakDemandOnPlant Net Peak Demand MW (60 min) (d)	NetGenerationExcludingPlantUse Net Generation Excluding Plant Use (e)	CostOfPlant Cost of Plant (f)	PlantCostPerMw Plant Cost (Incl Asset Retire. Costs) Per MW (g)	OperatingExpensesExcludingFuel Operation Exc'l. Fuel (h)	FuelProductionExpenses Fuel Production Expenses (i)	MaintenanceProductionExpenses Maintenance Production Expenses (j)	FuelKind Kind of Fuel (k)	FuelCostPerMmbtus Fuel Costs (in cents (per Million Btu) (l)	GenerationType Generation Type (m)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

ENERGY STORAGE OPERATIONS (Large Plants)
Large Plants are plants of 10,000 Kw or more. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy. In column (k) report the MWHs sold. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.	Name of the Energy Storage Project (a)	Functional Classification (b)	Location of the Project (c)	MWHs (d)	MWHs delivered to the grid to support Production (e)	MWHs delivered to the grid to support Transmission (f)	MWHs delivered to the grid to support Distribution (g)	MWHs Lost During Conversion, Storage and Discharge of Energy Production (h)	MWHs Lost During Conversion, Storage and Discharge of Energy Transmission (i)	MWHs Lost During Conversion, Storage and Discharge of Energy Distribution (j)	MWHs Sold (k)	Revenues from Energy Storage Operations (l)	Power Purchased for Storage Operations (555.1) (Dollars) (m)	Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars) (n)	Other Costs Associated with Self-Generated Power (Dollars) (o)	Project Costs included in (p)	Production (Dollars) (q)	Transmission (Dollars) (r)	Distribution (Dollars) (s)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

TRANSMISSION LINE STATISTICS
Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g). Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
	DESIGNATION		VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase)			LENGTH (Pole miles) - (In the case of underground lines report circuit miles)				COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way)			EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.	TransmissionLineStartPoint From	TransmissionLineEndPoint To	OperatingVoltageOfTransmissionLine Operating	DesignedVoltageOfTransmissionLine Designated	SupportingStructureOfTransmissionLineType Type of Supporting Structure	LengthForStandAloneTransmissionLines On Structure of Line Designated	LengthForTransmissionLinesAggregatedWithOtherStructures On Structures of Another Line	NumberOfTransmissionCircuits Number of Circuits	SizeOfConductorAndMaterial Size of Conductor and Material	CostOfLandAndLandRightsTransmissionLines Land	ConstructionAndOtherCostsTransmissionLines Construction Costs	OverallCostOfTransmissionLine Total Costs	OperatingExpensesOfTransmissionLine Operation Expenses	MaintenanceExpensesOfTransmissionLine Maintenance Expenses	RentExpensesOfTransmissionLine Rents	OverallExpensesOfTransmissionLine Total Expenses
	(a)	(b)	(c)	(d)	(e)	(f)	(g)	(h)	(i)	(j)	(k)	(l)	(m)	(n)	(o)	(p)
1	[01A] GALVESTON 26TH ST	SEAWALL	138.00	138.00	(4) UNDER	1.71	0.00		1250 CUDP
2	[01B] WEBSTER PLANT	GALVESTON 26TH ST	138.00	138.00	(3) STEEL	28.61	0.00		795 ACSR
3	[01B] WEST GALVESTON	TAP	138.00	138.00	(1) STEEL	0.06	0.00		795 AAC
4	[01X] P.H. ROBINSON PLANT	YGF (TNMP)	138.00	138.00	(3) STEEL	0.41	0.00		2-959 ACSS
5	[02A] BLUERIDGE	TAP	138.00	138.00	(2) WOOD	0.08	0.00		795 AAC
6	[02A] DEWALT	W.A. PARISH PLANT	138.00	138.00	(3) STEEL	11.07	0.00		795 AAC
7	[02A] H.O. CLARK PLANT	DEWALT	138.00	138.00	(3) STEEL	8.66	0.00		2-795 AAC
8	[02A] MISSOURI CITY	TAP	138.00	138.00	(1) CONC	0.02	0.00		959 ACSS
9	[02A] MULA_	TAP	138.00	138.00	(1) WOOD	2.22	0.00		795 AAC
10	[02A] QUAIL VALLEY	TAP	138.00	138.00	(3) STEEL	3.33	0.00		795 ACSR
11	[02A] SIENNA	TAP	138.00	138.00	(1) CONC	2.71	0.00		1433 ACSS
12	[02A] TELVIEW	TAP	138.00	138.00	(3) STEEL	2.99	0.00		795 ACSR
13	[02B] NASH	BURKE	138.00	138.00	(3) STEEL	0.08	3.57		2-795 AAC
14	[02B] W.A. PARISH PLANT	NASH	138.00	138.00	(3) STEEL	23.61	0.00		2-795 AAC
15	[02C] HOFFMAN	LAKE JACKSON	138.00	138.00	(3) STEEL	4.83	0.00		795 ACSR
16	[02C] LAKE JACKSON	RETRIEVE	138.00	138.00	(3) STEEL	5.49	0.00		2-795 ACSR
17	[02D] BASF_	HOFFMAN	138.00	138.00	(3) STEEL	3.07	0.00		795 ACSR
18	[02E] BASF_	BRAZOSPORT	138.00	138.00	(3) STEEL	2.78	0.00		2-795 ACSR
19	[02E] BRAZOSPORT	COPPER	138.00	138.00	(3) STEEL	0.06	1.82		2-795 ACSR
20	[02F] JONES CREEK	SEADOC	138.00	138.00	(3) STEEL	0.99	2.78		2-959ACSS
21	[02F] SEAWAY SWITCHYARD	TAP	138.00	138.00	(1) CONC	0.13	0.00		2-795 ACSR
22	[02G] JONES CREEK	VELASCO	138.00	138.00	(1) STEEL	2.40	0.00		4-959ACSS
23	[02I] RETRIEVE	WEST COLUMBIA	138.00	138.00	(3) STEEL	12.28	0.00		2-795 ACSR
24	[02J] BURKE	WEST COLUMBIA	138.00	138.00	(3) STEEL	5.58	1.94		2-795 AAC
25	[02K] EAGLE NEST	YHE (TNMP)	138.00	138.00	(3) STEEL	1.92	0.85		2-795 AAC
26	[02X] P.H. ROBINSON PLANT	BIGVUE	138.00	138.00	(3) STEEL	0.41	0.00		2-795AAC
27	[03A] PSARCO	BAYTOWN	138.00	138.00	(3) STEEL	0.67	0.16		2-795 AAC
28	[03B] CEDAR BAYOU PLANT	TAP	138.00	138.00	(3) STEEL	11.45	3.97		795 AAC
29	[03B] KENNY_	TAP	138.00	138.00	(3) STEEL	0.03	0.00		2000 AAC
30	[03B] TRINITY BAY-1	TAP	138.00	138.00	(1) CONC	0.08	0.00		2-795AAC
31	[03B] TRINITY BAY-2	TAP	138.00	138.00	(1) CONC	0.05	0.00		2-795AAC
32	[03B] TRINITY BAY	WHITE OAK	138.00	138.00	(1) CONC	0.04	0.00		2-795AAC
33	[03D] GREENS BAYOU PLANT	TAP	138.00	138.00	(3) STEEL	0.00	14.48		2-795 AAC
34	[03D] LIBERTY	TAP	138.00	138.00	(3) STEEL	0.05	0.00		795 AAC
35	[03F] EXPLOR	TAP	138.00	138.00	(3) STEEL	0.05	0.00		795 AAC
36	[03F] LYONDELL	TAP	138	138	(2) WOOD	0.04	0.00		795 AAC
37	[03F] PSARCO	GREENS BAYOU PLANT	138	138	(3) STEEL	7.42	0.00		2-795 ACSR
38	[03F] UVALDE	TAP	138	138	(1) STEEL	0.16	0.00		795 AAC
39	[03G] BIGVUE	CHANNELVIEW	138	138	(3) STEEL	6.11	0.00		2-795 AAC
40	[03H] LYNCH_	EXXON_	138	138	(3) STEEL	4.41	0.00		2000 AAC
41	[03I] CHANNELVIEW	LYNCH_	138	138	(3) STEEL	5.68	0.00		2-795 AAC
42	[03X] P.H. ROBINSON PLANT	YFP (TNMP)	138	138	(3) STEEL	0.41	0.00		2-795AAC
43	[04A] FRIENDSWOOD	TAP	138	138	(3) STEEL	2.27	0.00		795 ACSR
44	[04A] MUSTANG BAYOU	HUDSON	138	138	(3) STEEL	7.49	2.06		2-959 ACSS
45	[04A] WEBSTER PLANT	MUSTANG BAYOU	138	138	(3) STEEL	1.38	13.85		2-795 ACSR
46	[04B] HUDSON	MONSAN	138	138	(3) STEEL	3.99	0.00		2-927 ACAR
47	[04C] DANBURY	LIVERPOOL	138	138	(3) STEEL	0.39	0.00		2-959 ACSS
48	[04C] LIVERPOOL	PETSON	138	138	(3) STEEL	5.14	0.00		2-959 ACSS
49	[04D] PETSON	MONSAN	138	138	(2) WOOD	0.92	0.00		795 AAC
50	[04E] ANGLETON	WEST COLUMBIA	138	138	(2) WOOD	16.13	0.00		2-397 ACSR
51	[04G] ANGLETON	DANBURY	138	138	(3) STEEL	10.81	0.00		2-959 ACSS
52	[04X] P.H. ROBINSON PLANT	XSZ (TNMP)	138	138	(3) STEEL	0.46	0.00		2-795AAC
53	[05A] BLUERIDGE	TAP	138	138	(3) STEEL	0.08	0.00		795 AAC
54	[05A] H.O. CLARK PLANT	W.A. PARISH PLANT	138	138	(3) STEEL	19.71	0.00		2-795 ACSR
55	[05A] MISSOURI CITY	TAP	138	138	(1) WOOD	0.07	0.00		795 AAC
56	[05A] SIENNA	TAP	138	138	(1) CONC	0.00	2.72		1433 ACSS
57	[05B] FRIENDSWOOD	TAP	138	138	(3) STEEL	0.12	2.09		795 ACSR
58	[05B] H.O. CLARK PLANT	SOUTHWYCK	138	138	(3) STEEL	0.26	8.78		2-397 ACSR
59	[05B] INTERMEDIATE	TAP	138	138	(1) STEEL	0.05	0.00		2000 AAC
60	[05B] LIMBURG	SOUTHWYCK	138	138	(3) STEEL	5.03	0.00		2-959ACSS
61	[05B] LIMBURG	WEBSTER PLANT	138	138	(3) STEEL	19.09	0.00		2-959ACSS
62	[05D] IMPERIAL	TAP	138	138	(1) CONC	2.74	0.00		795 AAC
63	[05D] JEANETTA	WESTCHASE	138	138	(3) STEEL	0.37	1.28		2-795 ACSR
64	[05D] MISSOURI CITY	TAP	138	138	(2) WOOD	3.74	0.00		795 AAC
65	[05D] STAFFORD	TAP	138	138	(1) STEEL	0.15	0.00		795 AAC
66	[05D] WESTCHASE	W.A. PARISH PLANT	138	138	(3) STEEL	0.00	20.71		795 ACSR
67	[05E] BELLAIRE	JEANETTA	138	138	(3) STEEL	5.59	0.00		2-795 ACSR
68	[05E] DUNVALE	TAP	138	138	(1) WOOD	0.85	0.00		795 AAC
69	[05E] HILLCROFT	TAP	138	138	(1) WOOD	0.06	0.00		795 AAC
70	[05E] SHARPSTOWN	TAP	138	138	(1) WOOD	1.58	0.00		795 AAC
71	[05X] WEST COLUMBIA	YWC (TNMP)	138.00	138.00	(3) STEEL	0.05	0.00		2-795ACSR
72	[06A] QUANAB	S.R. BERTRON PLANT	138.00	138.00	(3) STEEL	1.46	0.00		2-959 ACSS
73	[06B] FAIRMONT	QUANAB	138.00	138.00	(2) WOOD	6.18	0.00		2-795 AAC
74	[06B] UNDERWOOD	TAP	138.00	138.00	(2) WOOD	0.03	0.00		795 AAC
75	[06C] NASA_	FAIRMONT	138.00	138.00	(2) WOOD	7.21	0.00		2-795 AAC
76	[06D] NASA_	WEBSTER PLANT	138.00	138.00	(2) WOOD	5.74	0.00		2-795 AAC
77	[06E] JEFFERSON	SOUTH CHANNEL	138.00	138.00	(1) CONC	1.00	0.00		2-959 ACSS
78	[06F] GARDEN VILLAS	HOLMES	138.00	138.00	(3) STEEL	5.76	0.00		2-795 AAC
79	[06F] HOLMES	PLAZA	138.00	138.00	(1) WOOD	2.94	0.00		2000 AAC
80	[06G] COLLEGE	TAP	138.00	138.00	(1) WOOD	1.68	0.00		795 AAC
81	[06G] DROUET	PASADENA	138.00	138.00	(3) STEEL	6.10	0.00		2-795 AAC
82	[06G] GARDEN VILLAS	DROUET	138.00	138.00	(3) STEEL	2.21	0.00		795 AAC
83	[06G] PASADENA	JEFFERSON	138.00	138.00	(3) STEEL	0.68	4.49		2-795 AAC
84	[06G] SPENCER	TAP	138.00	138.00	(3) STEEL	2.80	2.20		795 AAC
85	[06H] TRAVIS	SOUTH CHANNEL	138.00	138.00	(3) STEEL	0.88	0.78		2000 AAC
86	[06I] TIDAL_	TRAVIS	138.00	138.00	(3) STEEL	3.43	0.00		2000 AAC
87	[06J] PATRIK	TUCKER	138.00	138.00	(3) STEEL	2.12	0.00		2000 AAC
88	[06J] TIDAL_	PATRIK	138.00	138.00	(3) STEEL	0.62	0.00		2000 AAC
89	[06K] ELLINGTON	TAP	138.00	138.00	(1) CONC	0.10	0.00		795 AAC
90	[06K] HALL	TAP	138.00	138.00	(3) STEEL	1.02	0.00		795 AAC
91	[06K] MARY'S CREEK	TAP	138.00	138.00	(3) STEEL	0.00	3.51		795 ACSR
92	[06K] MYKAWA	TELEPHONE	138.00	138.00	(3) STEEL	2.83	0.00		2-795 AAC
93	[06K] PEARLAND	TAP	138.00	138.00	(3) STEEL	2.73	0.00		795 ACSR
94	[06K] PILGRIM	TAP	138.00	138.00	(3) STEEL	1.19	0.00		2-795 AAC
95	[06K] TELEPHONE	P.H. ROBINSON PLANT	138.00	138.00	(3) STEEL	22.35	0.00		795 AAC
96	[06L] GULFGATE	TAP	138.00	138.00	(3) STEEL	4.68	0.00		795 AAC
97	[06L] KNIGHT	TAP	138.00	138.00	(3) STEEL	0.01	0.00		2-795 AAC
98	[06L] MYKAWA	PLAZA	138.00	138.00	(3) STEEL	12.41	0.00		2-795 AAC
99	[06M] ESFORK	S.R. BERTRON PLANT	138.00	138.00	(3) STEEL	2.16	0.00		2000 AAC
100	[06M] ROLLEN	ESFORK	138.00	138.00	(3) STEEL	1.11	0.00		2-795 AAC
101	[06N] TUCKER	ROLLEN	138.00	138.00	(3) STEEL	0.55	0.00		2-795 AAC
102	[06X] WEST COLUMBIA	YWC (TNMP)	138.00	138.00	(3) STEEL	0.05	0.00		2-795ACSR
103	[07A] ALMEDA	TAP	138.00	138.00	(3) STEEL	0.00	3.17		397 ACSR
104	[07A] CHOCOLATE BAYOU	TAP	138.00	138.00	(3) STEEL	1.47	0.00		397 ACSR
105	[07A] ELLINGTON	TAP	138.00	138.00	(1) CONC	0.09	0.00		795AAC
106	[07A] PILGRIM	TAP	138.00	138.00	(3) STEEL	0.00	1.21		2-795 AAC
107	[07A] WEBSTER PLANT	GARDEN VILLAS	138.00	138.00	(3) STEEL	13.96	7.01		2-795 AAC
108	[08A] PSARCO	LYCHEM	138.00	138.00	(3) STEEL	0.80	0.82		2-795 AAC
109	[08B] BUNKER	STADIUM	138.00	138.00	(1) STEEL	1.52	1.96		2-795AAC
110	[08B] KNIGHT	TAP	138.00	138.00	(3) STEEL	0.01	0.00		2000 AAC
111	[08B] STADIUM	FANNIN	138.00	138.00	(1) STEEL	0.00	0.82		2-795 ACSR
112	[08C] MAGNOLIA PARK	NINTH_	138.00	138.00	(3) STEEL	1.13	0.00		2000 AAC
113	[08D] BUSCH	ANBUSH	138.00	138.00	(3) STEEL	0.35	0.00		2-795 ACSR
114	[08D] CLINTON	NINTH_	138.00	138.00	(3) STEEL	0.47	0.00		2-795 ACSR
115	[08D] NINTH_	CLINTON	138.00	138.00	(3) STEEL	2.24	0.00		2-795 ACSR
116	[08E] ANBUSH	OATES	138.00	138.00	(3) STEEL	1.84	0.00		2-795 ACSR
117	[08E] OATES	GREENS BAYOU PLANT	138.00	138.00	(3) STEEL	4.58	0.00		2-795 ACSR
118	[08F] GREENS BAYOU PLANT	MOORE	138.00	138.00	(3) STEEL	4.75	0.00		2-795 ACSR
119	[08F] LYONDELL	TAP	138.00	138.00	(1) CONC	0.03	0.00		795 AAC
120	[08F] MOORE	LYCHEM	138.00	138.00	(3) STEEL	2.92	0.41		2-795 ACSR
121	[08F] UVALDE	TAP	138.00	138.00	(1) STEEL	0.09	0.00		795 AAC
122	[08G] CROSBY	PSARCO	138.00	138.00	(1) CONC	8.28	0.00		2-959ACSS
123	[08G] HIGHLANDS	TAP	138.00	138.00	(1) STEEL	4.66	0.00		795AAC
124	[08H] CROSBY	DAYTON (CORNER)	138.00	138.00	(1) CONC	0.00	9.44		1-795 AAC
125	[08I] PLAZA	GRANT	138.00	138.00	(4) UNDER	0.42	0.00		3500XLPE
126	[08I] PLAZA	GRANT	138.00	138.00	(1) WOOD	2.04	0.00		2000 AAC
127	[08K] GRANT	FANNIN	138.00	138.00	(1) STEEL	2.16	0.00		2-795 AAC
128	[08L] BUNKER	H.O. CLARKE	138.00	138.00	(3) STEEL	2.31	0.24		2-795AAC
129	[09A] ALIEF	W.A. PARISH PLANT	138.00	138.00	(2) WOOD	16.44	0.00		2-795 ACSR
130	[09A] BRITMOORE	HAYES	138.00	138.00	(3) STEEL	3.36	0.00		2-795 ACSR
131	[09A] HAYES	ALIEF	138.00	138.00	(3) STEEL	3.82	0.00		2-795 ACSR
132	[09A] STAFFORD	TAP	138.00	138.00	(2) WOOD	0.02	0.00		2-795 ACSR
133	[09B] BELLAIRE	BRAYS	138.00	138.00	(3) STEEL	3.22	0.00		1-795 AAC
134	[09B] BRAYS	H.O. CLARK PLANT	138.00	138.00	(3) STEEL	0.31	2.32		2000 AAC
135	[09C] BELLAIRE	SAN FELIPE	138.00	138.00	(3) STEEL	2.07	0.00		2-795 AAC
136	[09D] EUREKA	WHITE OAK	138.00	138.00	(3) STEEL	1.57	0.00		2-2167 ACSR
137	[09D] SAN FELIPE	EUREKA	138.00	138.00	(1) STEEL	0.00	3.31		2-795 AAC
138	[09E] BRITMOORE	ADDICKS	138.00	138.00	(3) STEEL	2.15	0.00		795 AAC
139	[09F] READING	FORT BEND	138.00	138.00	(3) STEEL	2.54	0.00		795 AAC
140	[09F] READING	CRABB RIVER ROAD	138.00	138.00	(1) CONC	3.87	0.00		795 ACSR
141	[09F] W.A. PARISH PLANT	CRABB RIVER ROAD	138.00	138.00	(1) CONC	9.42	0.00		2-795 AAC
142	[09G] BRAZOS VALLEY	FORT BEND	138.00	138.00	(3) STEEL	5.82	0.00		2-795 AAC
143	[09G] FLEWELLEN	BRAZOS VALLEY	138.00	138.00	(3) STEEL	5.09	0.00		2-795 ACSR
144	[09H] FLEWELLEN	FRANZ	138.00	138.00	(3) STEEL	6.32	9.20		2-795 ACSR
145	[09H] KATY	TAP	138.00	138.00	(3) STEEL	0.02	0.00		2-795 AAC
146	[09I] CAMPBELL	TAP	138.00	138.00	(3) STEEL	0.04	0.00		795 AAC
147	[09I] TODD	TAP	138.00	138.00	(3) STEEL	0.01	0.00		795 AAC
148	[09I] WHITE OAK	ADDICKS	138.00	138.00	(3) STEEL	9.27	0.00		2-795 AAC
149	[09J] CYFAIR	TAP	138.00	138.00	(3) STEEL	0.03	0.00		795 ACSR
150	[09J] FRY RD	TAP	138.00	138.00	(3) CONC	0.05	0.00		795 AAC
151	[09J] GERTIE	TAP	138.00	138.00	(3) STEEL	4.27	0.00		795 ACSR
152	[09J] ZENITH	KLUGE	138.00	138.00	(3) STEEL	13.37	0.00		2-959ACSS
153	[09K] FRANZ	VILLAGE CREEK	138.00	138.00	(3) STEEL	2.75	1.48		2-959ACSS
154	[09K] VILLAGE CREEK	ZENITH	138.00	138.00	(3) STEEL	3.62	0.00		795 AAC
155	[14A] CEDAR BAYOU PLANT	KENNY_	138.00	138.00	(3) STEEL	6.75	0.00		2-795 AAC
156	[18A] JONES CREEK	SOUTH TEXAS	345.00	345.00	(3) STEEL	43.05	0.00		2-795 ACSR
157	[18B] DOW345	OASIS	345.00	345.00	(3) STEEL	0.00	36.03		2-795 ACSR
158	[18C] OASIS	W.A. PARISH PLANT	345.00	345.00	(3) STEEL	19.52	0.00		1-433 ACSS
159	[18D] JONES CREEK	DOW 345	345.00	345.00	(3) STEEL	3.88	0.00		2-795 ACSR
160	[18E] ZENITH	GIBBCK PLANT	345.00	345.00	(1) STEEL	3.40	55.09		3-959 ACSS
161	[21A] GABLE STREET	GREENS BAYOU PLANT	138.00	138.00	(3) STEEL	13.27	0.00		2000AAC
162	[21A] LIBERTY	TAP	138.00	138.00	(3) STEEL	0.03	0.00		1-795 AAC
163	[21A] NORTHSIDE	TAP	138.00	138.00	(3) STEEL	0.03	0.00		2000AAC
164	[21B] GABLE STREET	FRANKLIN	138.00	138.00	(3) STEEL	1.98	0.00		2-795 AAC
165	[21C] DAVSON	STRAWBERRY BELT	138.00	138.00	(3) STEEL	1.72	0.00		795 AAC
166	[21C] DEER PARK	TAP	138.00	138.00	(1) STEEL	0.06	0.00		2-795 AAC
167	[21C] NOBEL_	STATE_	138.00	138.00	(3) STEEL	0.19	0.00		2-795 AAC
168	[21C] STRAWBERRY BELT	NOBEL_	138.00	138.00	(3) STEEL	7.24	0.00		2-795 AAC
169	[21C] UNDERWOOD	TAP	138.00	138.00	(2) WOOD	0.05	0.00		2000 AAC
170	[21D] SOLMER	S.R. BERTRON PLANT	138.00	138.00	(3) STEEL	1.67	0.00		2-795 AAC
171	[21E] MOMENT	SOLMER	138.00	138.00	(3) STEEL	0.45	0.00		2-795 AAC
172	[21F] DIABOX	MOMENT	138.00	138.00	(3) STEEL	0.65	0.00		2-795 AAC
173	[21G] CAMRON	T.H. WHARTON PLANT	138.00	138.00	(3) STEEL	8.21	0.00		2-959 ACSS
174	[21G] WORTHAM	TAP	138.00	138.00	(2) STEEL	0.04	0.00		2-959 ACSS
175	[21H] ADDICKS	WHITE OAK	138.00	138.00	(3) STEEL	9.28	0.00		795 AAC
176	[21H] CAMPBELL	TAP	138.00	138.00	(3) STEEL	0.00	0.01	0	795 AAC
177	[21H] TODD	TAP	138.00	138.00	(3) STEEL	0.00	0.03	0	795 AAC
178	[21I] CAMRON	KLUGE	138.00	138.00	(3) STEEL	8.67	0.00	0	795 ACSR
179	[21I] CYFAIR	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	795 ACSR
180	[21J] AIRLINE	WHITE OAK	138.00	138.00	(3) STEEL	3.03	0.00	0	795 AAC
181	[21J] HARDY	AIRLINE	138.00	138.00	(3) STEEL	2.13	0.00	0	2-795 AAC
182	[21K] FIDELITY	DAVSON	138.00	138.00	(3) STEEL	0.00	6.80	0	795 AAC
183	[21K] FIDELITY	GREENS BAYOU PLANT	138.00	138.00	(1) CONC	6.01	0.00	0	2-959ACSS
184	[21K] WITTER	TAP	138.00	138.00	(3) STEEL	0.07	0.00	0	795 AAC
185	[21L] STATE_	S.R. BERTRON PLANT	138.00	138.00	(3) STEEL	1.11	0.82	0	2-795 AAC
186	[21M] FRANKLIN	CROCKETT	138.00	138.00	(3) STEEL	1.21	0.25	0	2000AAC
187	[22A] DIABOX	S.R. BERTRON PLANT	138.00	138.00	(3) STEEL	2.30	0.00	0	2-795 AAC
188	[22B] RAYFORD	SPRINGWOOD	138.00	138.00	(3) STEEL	2.84	4.21	0	2-959ACSS
189	[22B] ROTHWOOD	SPRINGWOOD	138.00	138.00	(3) STEEL	0.11	3.02	0	2-959ACSS
190	[22B] ROTHWOOD	RAYFORD	138.00	138.00	(3) STEEL	4.48	0.00	0	2-959ACSS
191	[24A] ADDICKS	TAP	138.00	138.00	(3) STEEL	0.22	0.00	0	1-795ACSR
192	[24A] BRITMOORE	SATSUMA	138.00	138.00	(3) STEEL	0.06	6.13	0	2-795 ACSR
193	[24A] SATSUMA	T.H. WHARTON PLANT	138.00	138.00	(3) STEEL	0.28	6.48	0	2-795 AAC
194	[24A] TANNER	TAP	138.00	138.00	(3) STEEL	1.00	0.00	0	1-795ACSR
195	[24B] BELLAIRE	TAP	138.00	138.00	(1) WOOD	0.12	0.00	0	795 AAC
196	[24B] BELLAIRE	BRITMOORE	138.00	138.00	(3) STEEL	0.19	12.88	0	2-795 ACSR
197	[24B] DUNVALE	TAP	138.00	138.00	(1) WOOD	1.10	0.00	0	795 AAC
198	[24B] HAYES	TAP	138.00	138.00	(1) WOOD	0.05	0.00	0	795 ACSR
199	[24B] HILLCROFT	TAP	138.00	138.00	(1) WOOD	0.05	0.00	0	795 AAC
200	[24B] ULRICH	TAP	138.00	138.00	(1) STEEL	1.04	0.00	0	795 AAC
201	[24B] WESTCHASE	TAP	138.00	138.00	(1) WOOD	0.06	0.00	0	795 AAC
202	[25A] FONDREN	H.O. CLARK PLANT	138.00	138.00	(3) STEEL	5.14	0.00	0	795 AAC
203	[25A] H.O. CLARK PLANT	TAP	138.00	138.00	(3) STEEL	0.02	0.00	0	2-795 AAC
204	[25A] JEANETTA	FONDREN	138.00	138.00	(3) STEEL	5.54	0.00	0	795 AAC
205	[25A] SHARPSTOWN	TAP	138.00	138.00	(1) WOOD	2.67	0.00	0	2-927 ACAR
206	[25A] WESTWOOD	TAP	138.00	138.00	(1) WOOD	0.05	0.00	0	2-795 ACSR
207	[25B] ROARK-1	TAP	138.00	138.00	(1) STEEL	0.01	0.00	0	2000 AAC
208	[25B] ROARK	JEANETTA	138.00	138.00	(3) STEEL	5.36	0.00	0	795 AAC
209	[25B] ROARK	CLODINE	138.00	138.00	(2) WOOD	3.74	0.00	0	795 AAC
210	[25B] ROARK-2	TAP	138.00	138.00	(1) STEEL	0.02	0.00	0	2000 AAC
211	[25B] WESTWOOD	TAP	138.00	138.00	(1) WOOD	0.05	0.00	0	2-795 ACSR
212	[25C] OBRIEN	CLODINE	138.00	138.00	(3) STEEL	5.98	0.00	0	2-795 ACSR
213	[25D] FLEWELLEN	TAP	138.00	138.00	(1) WOOD	0.01	0.00	0	795AAC
214	[25D] MASON ROAD	FLEWELLEN	138.00	138.00	(3) STEEL	11.66	0.00	0	2-795 ACSR
215	[25D] OBRIEN	MASON ROAD	138.00	138.00	(3) STEEL	5.34	0.00	0	2-795 ACSR
216	[25E] FLEWELLEN	FOSTER	138.00	138.00	(1) CONC	1.86	0.00	0	2-959ACSS
217	[25E] FOSTER	PETERS	138.00	138.00	(2) WOOD	27.33	0.00	0	1-795AAC
218	[26A] ALMEDA	TAP	138.00	138.00	(3) STEEL	0.13	0.00	0	397 ACSR
219	[26A] CHOCOLATE BAYOU	TAP	138.00	138.00	(3) STEEL	5.77	0.00	0	397 ACSR
220	[26A] H.O. CLARK PLANT	KARSTEN	138.00	138.00	(3) STEEL	14.87	0.00	0	2000 AAC
221	[26A] INTERMEDIATE	TAP	138.00	138.00	(1) STEEL	0.04	0.00	0	2000 AAC
222	[26A] QUAIL VALLEY	TAP	138.00	138.00	(3) STEEL	5.49	0.00	0	795 ACSR
223	[26A] TELVIEW	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	795 ACSR
224	[26B] ANGLETON	WINMIL	138.00	138.00	(3) STEEL	1.47	0.00	0	2000 AAC
225	[26B] ROSHARON	KARSTEN	138.00	138.00	(3) STEEL	9.53	0.00	0	2000 AAC
226	[26B] WINMIL	ROSHARON	138.00	138.00	(3) STEEL	7.90	0.00	0	2000 AAC
227	[26C] ANGLETON	STRATT	138.00	138.00	(3) STEEL	13.81	0.00	0	927 ACAR
228	[26D] STRATT	SINTEK	138.00	138.00	(3) STEEL	6.40	0.00	0	927 ACAR
229	[26E] CAMDEN	SINTEK	138.00	138.00	(3) STEEL	0.68	0.00	0	1-959ACSS
230	[26F] CAMDEN	VELASCO	138.00	138.00	(3) STEEL	0.79	0.00	0	2-1433ACSS
231	[26G] DOW345	VELASCO	138.00	138.00	(3) STEEL	0.58	0.00	0	1-959ACSS
232	[27A] DOW345	JONES CREEK	345.00	345.00	(3) STEEL	0.23	3.64	0	2-795 ACSR
233	[27B] DOW345	OASIS	345.00	345.00	(3) STEEL	36.04	0.00	0	2-795 ACAR
234	[27C] REFUGE	SOUTH TEXAS	345.00	345.00	(3) STEEL	0.25	12.33	0	2-795 ACSR
235	[27D] JONES CREEK	REFUGE	345.00	345.00	(3) STEEL	0.58	30.83	0	2-795 ACSR
236	[35A] CLEAR LAKE	TAP	138.00	138.00	(1) STEEL	1.75	0.00	0	795 AAC
237	[35A] FAIRMONT	P.H. ROBINSON PLANT	138.00	138.00	(3) STEEL	19.05	0.00	0	2-927 ACAR
238	[35A] GENOA	TAP	138.00	138.00	(1) CONC	0.68	0.00	0	1-795 AAC
239	[35A] POLARIS	TAP	138.00	138.00	(2) WOOD	0.05	0.00	0	795 AAC
240	[35A] WEBSTER	TAP	138.00	138.00	(1) WOOD	0.10	0.00	0	795 AAC
241	[35B] ARMAND	FAIRMONT	138.00	138.00	(3) STEEL	2.41	0.00	0	2-795 AAC
242	[35C] LOMAX_	CELNEC	138.00	138.00	(3) STEEL	2.98	0.00	0	2-795 AAC
243	[35E] BELLAIRE	ULRICH	138.00	138.00	(1) WOOD	3.40	0.00	0	2000 AAC
244	[35F] LOMAX_	ARMAND	138.00	138.00	(3) STEEL	1.59	0.00	0	2-795 AAC
245	[36A] BOOSTR	TAP	138.00	138.00	(1) CONC	0.18	0.00	0	795ACSR
246	[36A] COPPER	JONES CREEK	138.00	138.00	(3) STEEL	5.30	2.04	0	2-795ACSR
247	[36A] SEADOC	TAP	138.00	138.00	(3) STEEL	0.04	0.00	0	2-959ACSS
248	[36A] SEAWAY	TAP	138.00	138.00	(3) STEEL	3.13	0.00	0	795ACSR
249	[36B] JONES CREEK	VELASCO	138.00	138.00	(1) STEEL	0.00	2.40	0	4-959ACSS
250	[37A] BELLAIRE	KIRBY	138.00	138.00	(1) STEEL	0.52	1.38	0	2-959 ACSS
251	[37A] KIRBY	GARROTT	138.00	138.00	(1) STEEL	0.08	2.27	0	2-959 ACSS
252	[37B] SAN FELIPE	BELLAIRE	138.00	138.00	(3) STEEL	2.13	0.00	0	2-795 AAC
253	[37C] BLODGETT	TECO_	138.00	138.00	(1) WOOD	3.12	0.00	0	2000 AAC
254	[37C] BLODGETT	GARROTT	138.00	138.00	(1) STEEL	1.69	0.00	0	2-959ACSS
255	[37D] TECO_	GRANT	138.00	138.00	(3) STEEL	0.13	0.00	0	2000 AAC
256	[39A] DANEVANG (CORNER)	SOUTH TEXAS	345.00	345.00	(3) STEEL	19.39	0.00	0	2-795 ACSR
257	[39A] W.A. PARISH PLANT	COLORADO RIVER (TIE)	345.00	345.00	(3) STEEL	34.72	0.00	0	2-795 ACSR
258	[39B] ADDICKS	OBRIEN	345.00	345.00	(3) STEEL	18.10	0.00	0	2-2167 ACSR
259	[48A] WEST BAY	STEWART	138.00	138.00	(1) WOOD	14.00	0.00	0	266 ACSS
260	[48B] ENPROD	JORDAN	138.00	138.00	(3) STEEL	0.73	0.00	0	2-795AAC
261	[48C] DUNCAN	ENPROD	138.00	138.00	(1) STEEL	0.00	0.44	0	2-959ACSS
262	[48D] DUNCAN	JORDAN	138.00	138.00	(3) STEEL	0.24	0.72	0	2-795AAC
263	[48E] MARINE	VELASCO	138.00	138.00	(1) STEEL	0.51	4.81	0	2-959ACSS
264	[48F] JONES CREEK	CORTEZ	138.00	138.00	(1) STEEL	5.93	0.00	0	1-1433ACSS
265	[48G] MARINE	CORTEZ	138.00	138.00	(1) STEEL	0.59	2.52	0	1-1433ACSS
266	[50A] BELLAIRE	W.A. PARISH PLANT	345.00	345.00	(3) STEEL	0.00	24.99	0	2-795 ACSR
267	[50B] ZENITH	GIBBCK PLANT	345.00	345.00	(1) STEEL	58.45	0.00	0	3-959 ACSS
268	[52A] JORDAN	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	2-959 ACSS
269	[52A] JORDAN	WINFRE	138.00	138.00	(3) STEEL	0.08	0.95	0	2-959 ACSS
270	[52B] EAGLE	WINFRE	138.00	138.00	(3) STEEL	0.08	2.98	0	2-959 ACSS
271	[52C] EAGLE	MOUNT BELVIEU	138.00	138.00	(3) STEEL	0.08	0.19	0	2-795 AAC
272	[57A] BAILEY	JONES CREEK	345.00	345.00	(3) STEEL	52.93	0.00	0	3-959 ACSS
273	[59A] WEST BAY	STEWART	138.00	138.00	(1) WOOD	0.18	13.81	0	266 ACSS
274	[59B] JORDAN	RALYND	138.00	138.00	(3) STEEL	1.97	0.00	0	2-795AAC
275	[59C] NORTON	RALYND	138.00	138.00	(1) CONC	0.09	0.85	0	2-959 ACSS
276	[59D] HACHER	NORTON	138.00	138.00	(3) STEEL	1.30	0.00	0	2-959 ACSS
277	[59E] BARHIL	HACHER	138.00	138.00	(3) STEEL	0.00	1.03	0	795 ACSR
278	[59F] JORDAN	BARHIL	138.00	138.00	(1) STEEL	0.00	1.08	0	2-959ACSS
279	[59G] SURFSI	VELASCO	138.00	138.00	(1) CONC	2.40	0.00	0	2-959ACSS
280	[59H] BRYAN	FREEPORT	138.00	138.00	(1) CONC	2.39	0.00	0	2-959ACSS
281	[59H] FREEPORT	SURFSI	138.00	138.00	(1) STEEL	1.97	0.07	0	2-959ACSS
282	[59H] JONES CREEK	FREEPORT	138.00	138.00	(1) STEEL	0.42	2.42	0	2-959ACSS
283	[60A] BEASLY	ORCHARD	138.00	138.00	(1) CONC	0.61	0.00	0	2-959ACSS
284	[60A] FORT BEND	ROSENBERG	138.00	138.00	(1) CONC	0.62	0.00	0	2-959ACSS
285	[60A] MARICK	ORCHARD	138.00	138.00	(1) CONC	3.64	0.00	0	2-959ACSS
286	[60A] ROSENBERG	MARICK	138.00	138.00	(1) CONC	8.40	0.00	0	2-959ACSS
287	[60B] CANEY CREEK N	TAP	138.00	138.00	(1) STEEL	0.80	0.00	0	795 AAC
288	[60B] CANEY CREEK S	TAP	138.00	138.00	(1) STEEL	0.02	1.30	0	795 AAC
289	[60B] DYANN	WHARTON	138.00	138.00	(1) CONC	4.02	0.00	0	2-959 ACSS
290	[60B] HUNGERFORD	WHARTON	138.00	138.00	(1) CONC	9.63	0.00	0	2-959 ACSS
291	[60C] NEW GULF	GULFTIE	138.00	138.00	(3) STEEL	3.85	0.00	0	2-959 ACSS
292	[60C] SOUTH LANE CITY	NEW GULF	138.00	138.00	(3) STEEL	9.00	0.00	0	2-959 ACSS
293	[60D] DYANN	SOUTH LANE CITY	138.00	138.00	(1) CONC	8.08	0.91	0	2-959 ACSS
294	[60E] FLEWELLEN	FORT BEND	138.00	138.00	(3) STEEL	10.10	0.07	0	927ACAR
295	[60F] EAST BERNARD	BEASLY	138.00	138.00	(1) CONC	6.69	0.00	0	2-959ACSS
296	[60G] EAST BERNARD	HUNGERFORD	138.00	138.00	(1) CONC	5.36	0.00	0	2-959 ACSS
297	[60H] SAN BERNARD	WEST COLUMBIA	138.00	138.00	(3) STEEL	13.48	0.00	0	2-959 ACSS
298	[60J] GULFTIE	SAN BERNARD	138.00	138.00	(3) STEEL	26.00	8.00	0	2-959 ACSS
299	[60J] Pledger	TAP	138.00	138.00	(1) CONC	0.01	0.00	0	4/0 AAAC
300	[62A] BAILEY	JONES CREEK	345.00	345.00	(3) STEEL	0.00	52.93	0	3-959 ACSS
301	[63A] GALVESTON 26TH ST	WEST GALVESTON	138.00	138.00	(1) CONC	2.27	0.00	0	795 AAC
302	[63B] GALVESTON 26TH ST	SEAWALL	138.00	138.00	(4) UNDER	0.00	1.70	0	1250 CUOP
303	[63C] MOODY	STEWART	138.00	138.00	(4) UNDER	0.00	0.63	0	750AL XLPE
304	[63C] MOODY	STEWART	138.00	138.00	(1) CONC	3.82	0.00	0	2000 AAC
305	[63C] MOODY	STEWART	138.00	138.00	(4) UNDER	0.62	0.00	0	2500 CUOP
306	[63C] WEST GALVESTON	MOODY	138.00	138.00	(1) WOOD	4.06	0.00	0	2000 AAC
307	[63D] LA MARQUE	WEBSTER PLANT	138.00	138.00	(3) STEEL	0.00	15.99	0	795ACSR
308	[63E] STEWART	LA MARQUE	138.00	138.00	(4) UNDER	3.15	0.00	0	2-1243XLPE
309	[63E] STEWART	LA MARQUE	138.00	138.00	(3) STEEL	9.17	0.00	0	556ACSR
310	[63E] TIKI	TAP	138.00	138.00	(3) STEEL	0.12	0.00	0	556ACSR
311	[64A] JEANETTA	W.A. PARISH PLANT	345.00	345.00	(3) STEEL	20.05	0.00	0	2-2167 ACSR
312	[64B] BELLAIRE	JEANETTA	345.00	345.00	(3) STEEL	5.51	0.00	0	2-2167 ACSR
313	[64C] W.A. PARISH PLANT	WOLF	345.00	345.00	(3) STEEL	0.24	12.06	0	1-1433 ACSS
314	[64D] HILLJE	SOUTH TEXAS	345.00	345.00	(3) STEEL	19.50	0.00	0	2-795 ACSR
315	[64E] HILLJE	WOLF	345.00	345.00	(3) STEEL	0.16	36.66	0	1-1433 ACSS
316	[65A] SEALY	GEBHRT	138.00	138.00	(1) CONC	2.49	0.00	0	2-959 ACSS
317	[65A] SEALY	PETERS	138.00	138.00	(1) CONC	5.10	0.00	0	2-959 ACSS
318	[65B] HOCKLEY	PETERS	138.00	138.00	(2) STEEL	24.19	4.33	0	795 ACSR
319	[65B] WALLER	TAP	138.00	138.00	(3) STEEL	0.00	2.41	0	795 ACSR
320	[65C] EAST BERNARD	WALLIS	138.00	138.00	(1) CONC	8.18	0.00	0	2-959 ACSS
321	[65C] WALLIS	GEBHRT	138.00	138.00	(1) CONC	9.61	0.00	0	795 AAC
322	[66A] FLEWELLEN	FREEMAN	138.00	138.00	(3) STEEL	12.64	0.00	0	2-795 ACSR
323	[66A] FREEMAN	BETKA	138.00	138.00	(2) WOOD	10.97	0.00	0	397ACSR
324	[66A] KATY	TAP	138.00	138.00	(3) STEEL	0.02	0.00	0	2-795 AAC
325	[66B] HOCKLEY	STONE LAKE	138.00	138.00	(1) CONC	7.58	0.00	0	795 AAC
326	[66B] STONE LAKE	TOMBALL	138.00	138.00	(1) CONC	8.39	0.00	0	795 AAC
327	[66C] LOUETTA	TAP	138.00	138.00	(1) WOOD	0.03	0.00	0	795 AAC
328	[66C] ROTHWOOD	WESTFIELD	138.00	138.00	(3) STEEL	6.47	2.50	0	2-959 ACSS
329	[66D] HUMBLE	TREASCHWIG	138.00	138.00	(1) CONC	6.90	2.37	0	2-959 ACSS
330	[66D] TREASCHWIG	WESTFIELD	138.00	138.00	(3) STEEL	8.45	0.00	0	2-959 ACSS
331	[66E] ATASCOCITA	LAKE HOUSTON	138.00	138.00	(1) CONC	3.83	0.21	0	2-959 ACSS
332	[66E] CROSBY	ATASCOCITA	138.00	138.00	(1) CONC	12.59	0.00	0	2-959 ACSS
333	[66F] BAYTOWN	GARTH	138.00	138.00	(3) STEEL	4.29	0.00	0	2-927 ACAR
334	[66F] GARTH	HANEY	138.00	138.00	(3) STEEL	2.90	0.00	0	2-927 ACAR
335	[66F] HANEY	CROSBY	138.00	138.00	(3) STEEL	3.96	0.00	0	2-927 ACAR
336	[66F] HIGHLANDS	TAP	138.00	138.00	(1) CONC	2.89	0.00	0	795AAC
337	[66G] EXXON_	BAYTOWN	138.00	138.00	(3) STEEL	0.00	1.92	0	2000 AAC
338	[66H] BETKA	HOCKLEY	138.00	138.00	(1) CONC	0.25	0.89	0	959 ACSS
339	[66I] TOMBALL	ROTHWOOD	138.00	138.00	(3) STEEL	8.61	0.00	0	2-795 ACSR
340	[66J] KINGWOOD	HUMBLE	138.00	138.00	(1) CONC	7.78	0.00	0	2-959 ACSS
341	[66J] LAKE HOUSTON	KINGWOOD	138.00	138.00	(1) CONC	1.11	3.97	0	2-959 ACSS
342	[67A] BAMMEL	NORTH BELT	138.00	138.00	(3) STEEL	4.63	9.30	0	2-927 ACSR
343	[67A] BAMMEL	TAP	138.00	138.00	(1) CONC	0.04	0.00	0	2-959ACSS
344	[67A] GEARS	TAP	138.00	138.00	(3) STEEL	1.89	0.00	0	795 ACSR
345	[67A] HIDDEN VALLEY_1	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	795 ACSR
346	[67A] HIDDEN VALLEY_2	TAP	138.00	138.00	(3) STEEL	0.00	2.58	0	795 ACSR
347	[67A] JESTER	TAP	138.00	138.00	(1) CONC	2.90	0.00	0	795 ACSR
348	[67A] VETRAN	TAP	138.00	138.00	(1) STEEL	0.02	0.00	0	795AAC
349	[67B] NORTH BELT	DRILCO	138.00	138.00	(3) STEEL	2.61	0.00	0	2-795 AAC
350	[67C] DRILCO	INTERCONTINENTAL	138.00	138.00	(3) STEEL	2.70	0.00	0	2-795 ACSR
351	[67C] INTEQ_	TAP	138.00	138.00	(1) STEEL	0.00	0.03	0	2-795 ACSR
352	[67C] INTEQ_	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	2-795 ACSR
353	[67C] INTERCONTINENTAL	WESTFIELD	138.00	138.00	(3) STEEL	6.07	0.00	0	2-795 AAC
354	[69B] GREENS BAYOU PLANT	DEEPWATER	345.00	345.00	(3) STEEL	0.45	7.01	7	3-959 ACSS
355	[70A] UNIVERSITY	MAGNOLIA PARK	138.00	138.00	(3) STEEL	2.52	0.00	0	2000 AAC
356	[70A] UNIVERSITY	TAP	138.00	138.00	(3) STEEL	0.05	0.00	0	2000 AAC
357	[70B] GDYEAR	MAGNOLIA PARK	138.00	138.00	(3) STEEL	5.15	0.09	0	2-959 ACSS
358	[70C] DEEPWATER	CHANEL	138.00	138.00	(3) STEEL	3.02	0.00	0	2-959ACSS
359	[70D] LYDELL	GREENS BAYOU PLANT	138.00	138.00	(3) STEEL	7.93	0.00	0	2-795 AAC
360	[70E] BRANUM	GDYEAR	138.00	138.00	(3) STEEL	0.56	0.00	0	2-959ACSS
361	[70F] EASTSIDE	GABLE STREET	138.00	138.00	(3) STEEL	1.57	0.00	0	2-959ACSS
362	[70G] CHANEL	BRANUM	138.00	138.00	(3) STEEL	0.38	0.89	1	2-959ACSS
363	[70H] LYDELL	DEEPWATER	138.00	138.00	(3) STEEL	0.00	0.62	1	2-959ACSS
364	[71A] T.H. WHARTON PLANT	ADDICKS	345.00	345.00	(3) STEEL	10.68	0.00	0	2-795 ACSR
365	[71B] ADDICKS	WHITE OAK	345.00	345.00	(3) STEEL	9.52	0.00	0	2-795 ACSR
366	[71C] T.H. WHARTON PLANT	ZENITH	345.00	345.00	(3) STEEL	15.10	0.00	0	2-927 ACAR
367	[71D] OBRIEN	ZENITH	345.00	345.00	(3) STEEL	16.77	0.00	0	2-795ACSR
368	[72A] JEANETTA	W.A. PARISH PLANT	345.00	345.00	(3) STEEL	0.00	20.07	20	2-2167 ACSR
369	[72B] JEANETTA	WHITE OAK	345.00	345.00	(3) STEEL	12.03	0.00	0	2-2167 ACSR
370	[72C] CEDAR CREEK	WHALEY	345.00	345.00	(4) UNDER	6.81	0.00	0	2-1433ACSS
371	[72D] BAILEY	BLUE	345.00	345.00	(4) UNDER	8.82	0.00	0	2-1433ACSS
372	[72E] CEDAR CREEK	BAILEY	345.00	345.00	(4) UNDER	14.98	0.00	0	2-1433ACSS
373	[72F] W.A. PARISH PLANT	WHALEY	345.00	345.00	(3) STEEL	9.02	0.00	0	2-1433ACSS
374	[72G] BLUE	HILLJE	345.00	345.00	(3) STEEL	10.10	0.00	0	2-1433ACSS
375	[73A] BRITMOORE	SAUER	138.00	138.00	(3) STEEL	1.72	0.00	0	795 AAC
376	[73B] BARKER	TAP	138.00	138.00	(3) STEEL	1.61	0.00	0	795 AAC
377	[73B] BRITMOORE	WESTHEIMER	138.00	138.00	(3) STEEL	5.38	1.82	2	2-795 ACSR
378	[73B] MEMORIAL	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	795 ACSR
379	[73B] WESTHEIMER	CLODINE	138.00	138.00	(1) STEEL	4.61	0.00	0	2-795 ACSR
380	[73B] WOODCREEK	TAP	138.00	138.00	(3) STEEL	0.00	0.25	0	795 ACSR
381	[73C] OBRIEN	CLODINE	138.00	138.00	(3) STEEL	0.00	5.96	6	2-795 ACSR
382	[73D] OBRIEN	FLEWELLEN	138.00	138.00	(3) STEEL	0.00	6.64	7	2-795 ACSR
383	[73E] WIRT	WHITE OAK	138.00	138.00	(1) STEEL	1.07	0.00	0	3000XLPE
384	[73E] WIRT	WHITE OAK	138.00	138.00	(3) STEEL	0.00	3.95	4	795AAC
385	[73F] ECHO	WIRT	138.00	138.00	(1) STEEL	2.51	0.00	0	3000XLPE
386	[73G] SAUER	ECHO	138.00	138.00	(4) UNDER	2.20	0.00	0	3000XLPE
387	[74A] GREENS BAYOU PLANT	KING	345.00	345.00	(3) STEEL	7.43	0.00	0	2-927 ACSR
388	[74B] KUYKENDAHL	TAP	345.00	345.00	(3) STEEL	0.05	0.00	0	2-795 ACSR
389	[74B] TOMBALL	ROTHWOOD	345.00	345.00	(3) STEEL	10.10	0.00	0	2-1590 ACSR
390	[74C] TOMBALL	SINGLETON	345.00	345.00	(3) STEEL	46.55	0.00	0	2-1590 ACSR
391	[74D] TP&L JEWETT	LIMESTONE	345.00	345.00	(3) STEEL	10.50	0.00	0	2-1590 ACSR
392	[74E] LIMESTONE	TP&L TWIN OAK	345.00	345.00	(3) STEEL	23.67	0.00	0	2-1590 ACSR
393	[74F] DEEPWATER	SHELDON	345.00	345.00	(1) STEEL	14.11	0.00	0	3-959ACSS
394	[74G] SINGLETON	TP&L TIE	345.00	345.00	(3) STEEL	33.97	0.00	0	2-795 ACSR
395	[74H] KING	ROTHWOOD	345.00	345.00	(3) STEEL	25.54	0.00	0	2-1590 ACSR
396	[75A] GREENS BAYOU PLANT	KING	345.00	345.00	(3) STEEL	0.00	7.43	0	2-927 ACAR
397	[75B] KUYKENDAHL	TAP	345.00	345.00	(1) STEEL	0.08	0.00	0	2-795 ACSR
398	[75B] ROANS PRAIRIE	ROTHWOOD	345.00	345.00	(3) STEEL	0.26	46.68	0	2-1590 ACSR
399	[75C] GREENS BAYOU PLANT	SHELDON	345.00	345.00	(1) STEEL	0.57	6.17	0	2-2167 ACSR
400	[75D] ROANS PRAIRIE	SINGLETON	345.00	345.00	(3) STEEL	0.50	5.51	0	2-1590 ACSR
401	[75H] KING	ROTHWOOD	345.00	345.00	(3) STEEL	0.14	25.42		2-1590 ACSR
402	[75X] LIMESTONE PLANT	NAVARRO	345.00	345.00	(1) STEEL	0.11	0.00	0	2-959 ACSS
403	[76A] FRY RD	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	1-795AAC
404	[76A] GERTIE	TAP	138.00	138.00	(3) STEEL	0.14	4.15	0	795 ACSR
405	[76A] SATSUMA	TAP	138.00	138.00	(1) WOOD	0.04	0.00	0	795 AAC
406	[76A] TANNER	TAP	138.00	138.00	(3) STEEL	1.00	0.00	0	2-959ACSS
407	[76A] WORTHAM	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	2-959 ACSS
408	[76A] ZENITH	ADDICKS	138.00	138.00	(3) STEEL	0.00	20.51	0	2-959ACSS
409	[77A] GREENS BAYOU PLANT	CITFIL	138.00	138.00	(3) STEEL	0.00	6.99	0	795 AAC
410	[77A] NORMANDY	TAP	138.00	138.00	(3) STEEL	1.94	0.00	0	2000 AAC
411	[77B] HOCKLEY	WALLER	138.00	138.00	(3) STEEL	6.79	0.00	0	795 ACSR
412	[77C] HOCKLEY	MACEDONIA (LCRA)	138.00	138.00	(3) STEEL	0.00	1.61	0	1433ACSS
413	[78A] CLODINE	BARKER	138.00	138.00	(3) STEEL	0.00	4.23	0	795 ACSR
414	[79A] BAYWAY	SEPTON	138.00	138.00	(3) STEEL	0.00	2.15	0	2-795 AAC
415	[79A] POWELL	BIGBAY	138.00	138.00	(3) STEEL	1.16	0.00	0	2-795 AAC
416	[79A] SEPTON	SHORE_	138.00	138.00	(3) STEEL	0.29	0.59	0	2-795ACSR
417	[79A] SHORE_	POWELL	138.00	138.00	(3) STEEL	0.00	0.53	0	2-795 ACSR
418	[79B] BAYOU_	ORION_	138.00	138.00	(3) STEEL	0.00	0.22	0	2-795 ACSR
419	[79B] LA PORTE	TAP	138.00	138.00	(1) WOOD	1.71	0.00	0	795 AAC
420	[79B] ORION_	SYLVAN	138.00	138.00	(3) STEEL	0.00	2.16	0	2-795 AAC
421	[79B] SYLVAN	MORGANS POINT	138.00	138.00	(3) STEEL	0.00	2.93	0	2-795 AAC
422	[79C] BIGBAY	BAYOU_	138.00	138.00	(3) STEEL	0.25	0.00	0	2-795 AAC
423	[79E] RED BLUFF	TERMINAL	138.00	138.00	(3) STEEL	0.53	0.90	0	2-795 ACSR
424	[79E] RED BLUFF	BAYWAY	138.00	138.00	(3) STEEL	1.16	1.84	0	2-795 ACSR
425	[79F] HANNA_1	TAP	138.00	138.00	(3) STEEL	0.00	0.01	0	2-795 AAC
426	[79F] HANNA_2	TAP	138.00	138.00	(3) STEEL	0.01	0.00	0	2-795 AAC
427	[79F] P.H. ROBINSON PLANT	HUNTER	138.00	138.00	(3) STEEL	10.06	0.00	0	2-795 AAC
428	[79I] TERMINAL	HUNTER	138.00	138.00	(3) STEEL	0.42	0.00	0	2-795 AAC
429	[80A] KARSTEN	W.A. PARISH PLANT	138.00	138.00	(3) STEEL	0.00	12.45	0	2-795 ACSR
430	[80A] THOMPSONS	TAP	138.00	138.00	(1) STEEL	0.05	0.00	0	795 ACSR
431	[80B] CRABB RIVER	TAP	138.00	138.00	(1) CONC	0.06	0.13	0	795 AAC
432	[80B] W.A. PARISH PLANT	IMPERIAL	138.00	138.00	(1) CONC	9.25	5.04	0	2-795 AAC
433	[81A] T.H. WHARTON PLANT	WILLOW	138.00	138.00	(3) STEEL	5.94	0.00	0	2-959 ACSS
434	[81B] LOUETTA	TAP	138.00	138.00	(1) WOOD	0.04	0.00	0	795 AAC
435	[81B] TOMBALL	WESTFIELD	138.00	138.00	(3) STEEL	0.00	12.47	0	2-795 ACSR
436	[81C] DEIHL	WHITE OAK	138.00	138.00	(1) STEEL	4.14	0.00	0	2000 AAC
437	[81C] FAIRBANKS	DEIHL	138.00	138.00	(1) STEEL	3.61	0.00	0	2000 AAC
438	[81C] T.H. WHARTON PLANT	FAIRBANKS	138.00	138.00	(1) STEEL	3.77	0.00	0	2000 AAC
439	[81D] BRITMOORE	SAUER	138.00	138.00	(3) STEEL	0.00	1.78	0	795 AAC
440	[81E] BRITMOORE	MEMORIAL	138.00	138.00	(3) STEEL	0.00	4.77	0	795 ACSR
441	[81E] WOODCREEK	TAP	138.00	138.00	(3) STEEL	0.25	0.00	0	795 ACSR
442	[81F] KLUGE	KLEIN	138.00	138.00	(1) STEEL	0.00	4.04	0	2-959 ACSS
443	[81F] WILLOW	KLEIN	138.00	138.00	(3) STEEL	2.38	0.00	0	2-959 ACSS
444	[81G] KLUGE	PINEHURST	138.00	138.00	(3) STEEL	15.58	0.00	0	2-795 ACSR
445	[81G] PINEHURST	TOMBALL	138.00	138.00	(1) STEEL	0.08	7.16	0	2-959 ACSS
446	[81H] SAUER	ECHO	138.00	138.00	(4) UNDER	2.23	0.00	0	3000XLPE
447	[81I] ECHO	WIRT	138.00	138.00	(4) UNDER	2.47	0.00	0	3000XLPE
448	[81J] WIRT	WHITE OAK	138.00	138.00	(3) STEEL	2.40	1.56	0	795 AAC
449	[81J] WIRT	WHITE OAK	138.00	138.00	(4) UNDER	1.10	0.00	0	795 AAC
450	[81K] BAMMEL	T.H. WHARTON PLANT	138.00	138.00	(3) STEEL	0.00	5.16	0	795 ACSR
451	[81K] JESTER	TAP	138.00	138.00	(1) CONC	0.00	2.91	0	795 ACSR
452	[81K] VETRAN	TAP	138.00	138.00	(1) CONC	0.03	0.00	0	795AAC
453	[82A] ARCOLA	W.A. PARISH PLANT	138.00	138.00	(3) STEEL	10.25	0.00	0	2-927 ACAR
454	[82A] KARSTEN	ARCOLA	138.00	138.00	(3) STEEL	2.30	0.00	0	2-927 ACAR
455	[82A] THOMPSONS	TAP	138.00	138.00	(1) STEEL	0.04	0.00	0	795 ACSR
456	[82C] ANGLETON	RIWOOD	138.00	138.00	(3) STEEL	14.18	0.00	0	927 ACAR
457	[82D] GLOBAL	VELASCO	138.00	138.00	(3) STEEL	1.13	1.47	0	2-959 ACSS
458	[82E] VELASCO	DOW345	138.00	138.00	(3) STEEL	0.09	0.41	0	2-2000 AAC
459	[82F] CAVERN	BIPORT	138.00	138.00	(3) STEEL	3.30	0.00	0	927 ACAR
460	[82F] RIWOOD	CAVERN	138.00	138.00	(3) STEEL	2.11	0.00	0	927 ACAR
461	[82G] OYSTER CREEK	BIPORT	138.00	138.00	(1) STEEL	0.19	2.61	0	2-959 ACSS
462	[82H] GLOBAL	OYSTER CREEK	138.00	138.00	(1) STEEL	2.62	0.00	0	2-959 ACSS
463	[83A] DECKER	CEDAR BAYOU PLANT	138.00	138.00	(3) STEEL	0.00	7.63	0	2000 AAC
464	[83B] DECKER	EXXON_	138.00	138.00	(3) STEEL	0.26	0.73	0	2000 AAC
465	[84A] CRSBAY	BORDEN	138.00	138.00	(3) STEEL	0.72	0.00	0	2-959ACSS
466	[84A] EPOTH_	DEPOT	138.00	138.00	(3) STEEL	0.23	0.00	0	2-795 AAC
467	[84A] JACINTOPORT	EPOTH_	138.00	138.00	(3) STEEL	0.22	0.00	0	2-795 AAC
468	[84A] JACINTOPORT	BORDEN	138.00	138.00	(3) STEEL	0.21	0.00	0	2-795 AAC
469	[84B] CRSBAY	DOWLAP	138.00	138.00	(3) STEEL	0.05	4.52	0	2-795 AAC
470	[84C] CONIAL	PHILIP	138.00	138.00	(3) STEEL	0.39	0.60	0	2-795 ACSR
471	[84C] HADEN_	INDUSTRIAL	138.00	138.00	(3) STEEL	0.92	0.00	0	2-795 AAC
472	[84C] HADEN_	PARKES	138.00	138.00	(3) STEEL	1.30	0.00	0	2-795 AAC
473	[84C] INDUSTRIAL	PORT_	138.00	138.00	(1) CONC	0.13	0.00	0	2000 AAC
474	[84C] PARKES	CHANNELVIEW	138.00	138.00	(3) STEEL	2.44	0.00	0	2-795 AAC
475	[84C] PORT_	TAYLOR	138.00	138.00	(1) STEEL	0.56	0.00	0	2000 AAC
476	[84C] TAYLOR	WASHBURN	138.00	138.00	(3) STEEL	1.49	0.00	0	2000 AAC
477	[84C] WASHBURN	CONIAL	138.00	138.00	(3) STEEL	6.97	0.23	0	2-795 ACSR
478	[84D] CEDAR BAYOU	TAP	138.00	138.00	(3) STEEL	0.06	0.00	0	795 AAC
479	[84D] CEDAR BAYOU PLANT	HOPSON	138.00	138.00	(3) STEEL	8.62	0.00	0	2-927 ACAR
480	[84E] WARVUE	MONT BELVIEU	138.00	138.00	(3) STEEL	0.39	0.00	0	795 AAC
481	[84F] MORGANS POINT	RUSSEL	138.00	138.00	(3) STEEL	0.00	2.91	0	2-795 ACSR
482	[84G] RANGER	DEPOT_	138.00	138.00	(3) STEEL	0.19	0.00	0	2-959ACSS
483	[84H] CHANNELVIEW	RANGER	138.00	138.00	(3) STEEL	2.63	0.00	0	2-795 AAC
484	[84I] ALEXANDER ISLAND	TAP	138.00	138.00	(1) CONC	0.05	0.00	0	1-795 AAC
485	[84I] DOWLAP	S.R. BERTRON PLANT	138.00	138.00	(3) STEEL	0.12	1.34	0	2-795 AAC
486	[84J] DOWLAP	RUSSEL	138.00	138.00	(3) STEEL	0.00	0.70	0	2-795 ACSR
487	[84K] HOPSON	WARVUE	138.00	138.00	(3) STEEL	1.29	0.00	0	2-927 ACAR
488	[85A] CEDAR BAYOU PLANT	WALKER	138.00	138.00	(3) STEEL	11.42	0.00	0	2000 AAC
489	[85A] WALKER	QUANUM	138.00	138.00	(3) STEEL	0.08	0.00	0	2000 AAC
490	[85B] AIRPRO	BOGGY	138.00	138.00	(3) STEEL	4.59	0.00	0	2000 AAC
491	[85D] QUANUM	AIRPRO	138.00	138.00	(3) STEEL	0.00	2.40	0	2000 AAC
492	[85E] SOUTH CHANNEL	DERICK	138.00	138.00	(3) STEEL	0.59	0.00	0	2000 AAC
493	[85E] SOUTH CHANNEL	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	795 AAC
494	[85G] BOGGY_	DERICK	138.00	138.00	(3) STEEL	2.18	0.00	0	2000 AAC
495	[86A] CEDAR BAYOU PLANT	CHEVRON	138.00	138.00	(3) STEEL	1.68	6.72	0	2-795 AAC
496	[86B] CHEVRON	LANGSTON	138.00	138.00	(3) STEEL	0.43	2.46	0	2-795 ACSR
497	[86C] LNGSTN	MONT BELVIEU	138.00	138.00	(3) STEEL	1.10	0.00	0	2-795AAC
498	[86D] CROSBY	PLACID	138.00	138.00	(3) STEEL	6.40	1.40	0	2-959ACSS
499	[86E] ALDINE	HARDY	138.00	138.00	(3) STEEL	6.29	0.00	0	2000 AAC
500	[86E] CROSBY	NEWPORT	138.00	138.00	(3) STEEL	8.79	0.00	0	795 AAC
501	[86E] GREENS ROAD	TAP	138.00	138.00	(3) STEEL	0.79	0.00	0	795 AAC
502	[86E] LOCKWOOD	TAP	138.00	138.00	(1) CONC	0.07	0.00	0	795 AAC
503	[86E] NEWPORT	ALDINE	138.00	138.00	(3) STEEL	20.72	0.00	0	795 ACSR
504	[86E] RITTENHOUSE	TAP	138.00	138.00	(1) WOOD	1.02	0.00	0	2-927 ACAR
505	[86E] SCENIC WOODS	TAP	138.00	138.00	(3) STEEL	3.90	0.00	0	1-795 AAC
506	[86F] RIGBY_	CONNOR	138.00	138.00	(3) STEEL	0.13	0.00	0	2-959ACSS
507	[86H] BRINE	MONT BELVIEU	138.00	138.00	(3) STEEL	2.81	0.00	0	2-927ACAR
508	[86H] BRINE	DALTON	138.00	138.00	(3) STEEL	0.82	0.00	0	2-927ACAR
509	[86I] CITIES	JORDAN	138.00	138.00	(3) STEEL	0.67	0.00	0	2-959 ACSS
510	[86I] DALTON	CITIES	138.00	138.00	(3) STEEL	0.43	0.00	0	2-959 ACSS
511	[86J] BENDER	JORDAN	138.00	138.00	(3) STEEL	1.03	0.00	0	2-959ACSS
512	[86J] CONNOR	BENDER	138.00	138.00	(3) STEEL	0.48	0.84	0	2-959ACSS
513	[86L] PLACID	RIGBY_	138.00	138.00	(1) CONC	0.58	0.00	0	2-959ACSS
514	[87A] STRANG_	CEDAR BAYOU PLANT	138.00	138.00	(3) STEEL	9.49	0.00	0	2-795 ACSR
515	[87B] CHORIN	STRANG_	138.00	138.00	(3) STEEL	0.28	0.00	0	2-795 ACSR
516	[87C] ALEXANDER ISLAND	TAP	138.00	138.00	(3) STEEL	0.06	0.00	0	1-795 AAC
517	[87C] S.R. BERTRON PLANT	CHORIN	138.00	138.00	(3) STEEL	2.37	2.40	0	2-795 ACSR
518	[87E] CEDAR BAYOU	TAP	138.00	138.00	(3) STEEL	0.06	0.00	0	2-795 AAC
519	[87E] TEXAS	CEDAR BAYOU PLANT	138.00	138.00	(3) STEEL	6.71	0.00	0	2-959ACSS
520	[87F] TEXAS	S. R. BERTRON PLANT	138.00	138.00	(3) STEEL	2.56	3.45	0	2000 AAC
521	[88A] BAYTOWN	CEDAR BAYOU PLANT	138.00	138.00	(3) STEEL	8.13	0.00	0	2-795 ACSR
522	[88B] BARNES	MILLER	138.00	138.00	(3) STEEL	0.43	0.00	0	2000 AAC
523	[88B] ROHMAS	BARNES	138.00	138.00	(3) STEEL	3.13	0.00	0	2000 AAC
524	[88C] ROHMAS	PAIR_	138.00	138.00	(3) STEEL	0.37	0.00	0	2000 AAC
525	[88D] BOGGY	PAIR_	138.00	138.00	(3) STEEL	0.16	0.71	0	2000 AAC
526	[88E] BAYTOWN	MILLER	138.00	138.00	(3) STEEL	3.68	0.06	0	2-959ACSS
527	[88F] BOGGY	EAST BELT	138.00	138.00	(3) STEEL	0.58	1.72	0	2000 AAC
528	[88F] EAST BELT	SOUTH CHANNEL	138.00	138.00	(3) STEEL	0.14	0.94	0	2000 AAC
529	[89A] BIG CREEK	FORT BEND	138.00	138.00	(1) CONC	7.72	0.00	0	2-959ACSS
530	[89A] DAMON	NEEDVILLE	138.00	138.00	(1) CONC	10.23	0.00	0	795AAC
531	[89A] NEEDVILLE	BIG CREEK	138.00	138.00	(1) STEEL	9.03	0.00	0	795AAC
532	[89A] WEST COLUMBIA	DAMON	138.00	138.00	(1) WOOD	11.26	0.00	0	795AAC
533	[90A] H.O. CLARK PLANT-1	GARROTT	138.00	138.00	(3) STEEL	9.45	0.00	0	2-795 AAC
534	[90A] H.O. CLARK PLANT-2	TAP	138.00	138.00	(3) STEEL	0.06	0.00	0	2-795 AAC
535	[90A] KIRBY-1	TAP	138.00	138.00	(1) CONC	0.06	0.00	0	2000AAC
536	[90A] KIRBY-2	TAP	138.00	138.00	(1) CONC	0.11	0.00	0	2000AAC
537	[90B] POLK	MIDTOWN	138.00	138.00	(4) UNDER	0.99	0.00	0	3000CU
538	[90C] GREENS ROAD	TAP	138.00	138.00	(3) STEEL	0.00	0.80	0	795 ACSR
539	[90C] LAUDER	TAP	138.00	138.00	(1) WOOD	2.34	0.00	0	795 AAC
540	[90C] LOCKWOOD	TAP	138.00	138.00	(1) CONC	0.08	0.00	0	795 AAC
541	[90C] NORTH BELT	SCENIC WOODS	138.00	138.00	(3) STEEL	9.01	0.00	0	2500 CU
542	[90C] SCENIC WOODS	TAP	138.00	138.00	(3) STEEL	0.04	0.00	0	795AAC
543	[90D] GARROTT	MIDTOWN	138.00	138.00	(4) UNDER	1.40	0.00	0	3000CU
544	[91A] EL DORADO	TAP	138.00	138.00	(3) STEEL	0.00	0.72	0	927ACAR
545	[91A] ELLINGTON	TAP	138.00	138.00	(1) CONC	0.10	0.00	0	795AAC
546	[91A] ENCO	TELEPHONE	138.00	138.00	(3) STEEL	0.00	13.40	0	2-795 AAC
547	[91A] PEARLAND	TAP	138.00	138.00	(3) STEEL	0.00	2.76	0	795 AAC
548	[91A] SOUTH HOUSTON	TAP	138.00	138.00	(1) CONC	4.07	0.00	0	795 AAC
549	[91A] SPENCER	TAP	138.00	138.00	(3) STEEL	3.99	0.00	0	795 AAC
550	[91A] TELEPHONE	MYKAWA	138.00	138.00	(3) STEEL	2.79	0.00	0	2-795 AAC
551	[91B] EASTSIDE	UNIVERSITY	138.00	138.00	(3) STEEL	2.82	0.00	0	2-959 ACSS
552	[91B] UNIVERSITY	TAP	138.00	138.00	(1) CONC	0.07	0.00	0	795 AAC
553	[91C] EASTSIDE	POLK	138.00	138.00	(4) UNDER	0.00	0.71	0	2500 CU
554	[91D] P.H. ROBINSON PLANT	ENCO	138.00	138.00	(3) STEEL	0.61	8.46	0	2-795 AAC
555	[91E] DOWNTOWN	CROCKETT	138.00	138.00	(1) WOOD	1.77	0.00	0	2000 AAC
556	[91F] CROCKETT	HARDY	138.00	138.00	(1) WOOD	4.82	0.00	0	2000 AAC
557	[91F] NORTHSIDE	TAP	138.00	138.00	(1) STEEL	0.03	0.00	0	2000 AAC
558	[91G] DOWNTOWN	POLK	138.00	138.00	(4) UNDER	0.00	0.99	0	2000 AAC
559	[91H] COUGAR	UNIVERSITY	138.00	138.00	(3) STEEL	0.14	0.00	0	2000 AAC
560	[91I] COUGAR	MYKAWA	138.00	138.00	(3) STEEL	8.42	0.00	0	2-795 AAC
561	[91I] GULFGATE	TAP	138.00	138.00	(1) WOOD	1.92	0.00	0	2-927 ACAR
562	[92A] EL DORADO	TAP	138.00	138.00	(3) STEEL	0.69	0.00	0	795 AAC
563	[92A] KEMAH	TAP	138.00	138.00	(3) STEEL	0.04	0.00	0	2-397 ACSR
564	[92A] SCRDLE	P.H. ROBINSON PLANT	138.00	138.00	(3) STEEL	12.07	7.56	0	2-795AAC
565	[92A] WEBSTER	TAP	138.00	138.00	(1) WOOD	0.06	0.00	0	795 AAC
566	[92B] GARDEN VILLAS	SCRDLE	138.00	138.00	(3) STEEL	0.00	14.02	0	2-795AAC
567	[92B] HALL	TAP	138.00	138.00	(3) STEEL	0.00	1.03	0	795 AAC
568	[92B] MARY'S CREEK	TAP	138.00	138.00	(3) STEEL	3.51	0.00	0	795 ACSR
569	[92B] SOUTH HOUSTON	TAP	138.00	138.00	(3) STEEL	0.00	2.83	0	795 AAC
570	[93A] P.H. ROBINSON PLANT	WEBSTER PLANT	138.00	138.00	(3) STEEL	0.75	11.31	0	2-959 ACSS
571	[93A] WEBSTER	TAP	138.00	138.00	(1) WOOD	0.07	0.00	0	795 AAC
572	[93B] ALTA LOMA	HITCHCOCK	138.00	138.00	(2) WOOD	6.39	0.00	0	2-795 AAC
573	[93B] LA MARQUE	HITCHCOCK	138.00	138.00	(3) STEEL	4.95	0.00	0	2-397ACSR
574	[93B] P.H. ROBINSON PLANT	ALTA LOMA	138.00	138.00	(3) STEEL	22.32	0.00	0	2-795 AAC
575	[93C] LA MARQUE	WEST GALVESTON	138.00	138.00	(3) STEEL	10.76	0.00	0	795AAC
576	[94A] GREENS BAYOU PLANT	HUMBLE	138.00	138.00	(3) STEEL	7.00	6.83	0	2-795 ACSR
577	[94A] KING	TAP	138.00	138.00	(1) CONC	0.26	0.00	0	795 ACSR
578	[94A] PARKWAY	TAP	138.00	138.00	(3) STEEL	0.02	0.00	0	2-795 ACSR
579	[94B] DEUSEN	CHAMON	138.00	138.00	(3) STEEL	12.69	0.00	0	2-795 ACSR
580	[94B] KING	TAP	138.00	138.00	(1) CONC	0.00	0.26	0	795 ACSR
581	[94C] METALS SWITCH	METALS	138.00	138.00	(1) WOOD	2.13	0.00	0	397 ACSR
582	[94C] METALS SWITCH	RIVERSIDE	138.00	138.00	(3) STEEL	0.14	0.37	0	2-795 ACSR
583	[94C] METALS SWITCH	PSARCO	138.00	138.00	(3) STEEL	3.28	3.07	0	2-795 ACSR
584	[94D] CELWST	HIMONT	138.00	138.00	(3) STEEL	0.00	1.19	0	2-795 AAC
585	[94E] FAIRMONT	BYPARK	138.00	138.00	(3) STEEL	0.00	5.38	0	2-795ACSR
586	[94E] LUZBAY	BYPARK	138.00	138.00	(3) STEEL	0.85	0.00	0	2-795AAC
587	[94E] LUZBAY	HIMONT	138.00	138.00	(3) STEEL	0.66	0.00	0	2-927 ACAR
588	[94F] CHAMON	RIVERSIDE	138.00	138.00	(3) STEEL	0.13	0.15	0	2-795 ACSR
589	[94G] BAYWAY	CELWST	138.00	138.00	(3) STEEL	0.65	1.44	0	2-795 AAC
590	[94H] HUMBLE	DEUSEN	138.00	138.00	(3) STEEL	6.54	0.00	0	2-795 ACSR
591	[94I] CELNEC	BAYWAY	138.00	138.00	(3) STEEL	1.84	0.00	0	2-795 AAC
592	[94J] CROWN	JEFFERSON	138.00	138.00	(1) CONC	2.22	0.00	0	2-959 ACSS
593	[94K] CROWN_	TANKER	138.00	138.00	(3) STEEL	3.22	0.00	0	2-959 ACSS
594	[94L] DROUET	TAP	138.00	138.00	(1) WOOD	0.01	0.00	0	795 AAC
595	[94L] GARDEN VILLAS	FAIRMONT	138.00	138.00	(3) STEEL	21.33	0.00	0	2-795 AAC
596	[94M] GALENA PARK	CITFIL	138.00	138.00	(3) STEEL	1.59	0.00	0	2000 AAC
597	[94M] NORMANDY	TAP	138.00	138.00	(3) STEEL	1.96	0.00	0	795 AAC
598	[94N] GALENA PARK	TAP	138.00	138.00	(1) WOOD	0.12	0.00	0	2-397 ACSR
599	[94N] TANKER	GALENA PARK	138.00	138.00	(3) STEEL	1.31	0.00	0	2-959 ACSS
600	[95A] GEARS	TAP	138.00	138.00	(3) STEEL	0.00	1.89	0	795 AAC
601	[95A] HIDDEN VALLEY	TAP	138.00	138.00	(3) STEEL	2.59	0.00	0	795 AAC
602	[95A] T.H. WHARTON PLANT	NORTH BELT	138.00	138.00	(3) STEEL	9.77	0.00	0	2-795 ACSR
603	[95A] T.H. WHARTON PLANT	TAP	138.00	138.00	(1) WOOD	0.06	0.00	0	2000AAC
604	[95B] BERRY	NORTH BELT	138.00	138.00	(3) STEEL	7.32	0.00	0	795 AAC
605	[95B] HARDY	BERRY	138.00	138.00	(3) STEEL	1.73	0.00	0	2000 AAC
606	[95B] LAUDER	TAP	138.00	138.00	(1) WOOD	3.01	0.00	0	2-795 AAC
607	[95B] RITTENHOUSE	TAP	138.00	138.00	(1) WOOD	1.31	0.00	0	2000 AAC
608	[95C] BERTWOOD	HARDY	138.00	138.00	(1) WOOD	4.09	0.00	0	2-795 ACSR
609	[95C] GLENWOOD	BERTWOOD	138.00	138.00	(1) WOOD	3.37	0.00	0	795 AAC
610	[95C] GREENS BAYOU PLANT	GLENWOOD	138.00	138.00	(3) STEEL	7.01	0.00	0	2-927 ACAR
611	[95C] PARKWAY	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	795 ACSR
612	[95F] CLEAR LAKE	TAP	138.00	138.00	(1) STEEL	0.00	1.75	0	2-795 AAC
613	[95F] FAIRMONT	TAP	138.00	138.00	(3) STEEL	0.07	0.00	0	795 AAC
614	[95F] GENOA	TAP	138.00	138.00	(1) CONC	0.00	0.68	0	2-795 AAC
615	[95F] KEMAH	TAP	138.00	138.00	(3) STEEL	0.03	0.00	0	2-795 ACSR
616	[95F] POLARIS	TAP	138.00	138.00	(2) WOOD	0.05	0.00	0	795 AAC
617	[95F] SOUTH_	P.H. ROBINSON PLANT	138.00	138.00	(3) STEEL	0.00	24.54	0	795 AAC
618	[96A] P.H. ROBINSON PLANT	BAYOU_	138.00	138.00	(3) STEEL	11.43	0.00	0	2-795 AAC
619	[96B] BAYOU_	MCCABE	138.00	138.00	(3) STEEL	1.54	0.00	0	2-795 ACSR
620	[96B] MCCABE	MIRAGE	138.00	138.00	(3) STEEL	1.10	0.00	0	2-795 ACSR
621	[96B] MIRAGE	BIMONT	138.00	138.00	(3) STEEL	0.74	0.00	0	2-795 ACSR
622	[96C] BEARLE	SOUTH CHANNEL	138.00	138.00	(3) STEEL	1.20	0.00	0	2-795 ACSR
623	[96D] ALKANE	MORGANS POINT	138.00	138.00	(3) STEEL	1.99	0.00	0	2000 AAC
624	[96E] CARDIFF	SOUTH_	138.00	138.00	(3) STEEL	0.00	1.86	0	795 ACSR
625	[96E] DEER PARK	TAP	138.00	138.00	(1) STEEL	1.71	0.00	0	2-795 ACSR
626	[96E] MORGANS POINT	SOUTH_	138.00	138.00	(3) STEEL	9.76	0.00	0	2-795ACSR
627	[96F] BIMONT	SANDY POINT	138.00	138.00	(3) STEEL	2.26	3.82	0	2-795ACSR
628	[96F] LA PORTE	TAP	138.00	138.00	(1) WOOD	0.79	0.00	0	2000 AAC
629	[96F] SANDY POINT	ALKANE	138.00	138.00	(1) STEEL	0.34	0.37	0	2-795ACSR
630	[96G] BEARLE	PHILIP	138.00	138.00	(3) STEEL	0.19	0.00	0	2-795 AAC
631	[97A] T.H. WHARTON PLANT	NORTH BELT	345.00	345.00	(3) STEEL	10.09	0.00	0	2-927 ACAR
632	[97B] NORTH BELT	KING	345.00	345.00	(3) STEEL	10.10	0.00	0	2-1433 ACSS
633	[97C] KING	JORDAN	345.00	345.00	(3) STEEL	19.68	0.00	0	2-1433 ACSS
634	[97D] CEDAR BAYOU PLANT	CENTER	345.00	345.00	(3) STEEL	9.55	8.53	0	3-959 ACSS
635	[97E] CHAMBERS	CEDAR BAYOU PLANT	345.00	345.00	(3) STEEL	3.08	0.00	0	2-1433 ACSS
636	[97F] CENTER	P.H. ROBINSON PLANT	345.00	345.00	(3) STEEL	25.09	0.00	0	2-795 ACSR
637	[97G] JORDAN	CHAMBERS	345.00	345.00	(3) STEEL	6.38	0.00	0	2-1433 ACSS
638	[98A] BELLAIRE	SMITHERS	345.00	345.00	(3) STEEL	24.94	0.47	0	2-1433 ACSS
639	[98B] W.A. PARISH PLANT	OBRIEN	345.00	345.00	(3) STEEL	17.01	0.00	0	2-795 ACSR
640	[98D] SINGLETON	ZENITH	345.00	345.00	(3) STEEL	0.18	53.11	0	2-795ACSR
641	[98E] TP&L JEWETT	LIMESTONE	345.00	345.00	(3) STEEL	0.00	10.50	0	2-1590 ACSR
642	[98F] LIMESTONE	TP&L TWIN OAK	345.00	345.00	(3) STEEL	0.00	23.67	0	2-1590 ACSR
643	[98G] SMITHERS	W.A. PARISH PLANT	345.00	345.00	(3) STEEL	0.53	0.00	0	2-1433 ACSS
644	[98H] SINGLETON	TP&L TIE	345.00	345.00	(3) STEEL	0.03	33.95	0	2-795 ACSR
645	[98I] T.H. WHARTON PLANT	ZENITH	345.00	345.00	(3) STEEL	0.23	14.85	0	2-927 ACAR
646	[99A] P.H. ROBINSON PLANT	MEADOW	345.00	345.00	(3) STEEL	17.37	0.00	0	2-927 ACAR
647	[99B] OASIS	W.A. PARISH PLANT	345.00	345.00	(3) STEEL	0.18	19.36	0	1-433 ACSS
648	[99C] W.A. PARISH PLANT	OBRIEN	345.00	345.00	(3) STEEL	0.39	16.62	0	2-795 ACSR
649	[99D] SINGLETON	ZENITH	345.00	345.00	(3) STEEL	53.29	0.00	0	2-795ACSR
650	[99E] MEADOW	OASIS	345.00	345.00	(3) STEEL	3.15	0.00	0	2-927 ACAR
651	[99F] OBRIEN	ZENITH	345.00	345.00	(3) STEEL	0.26	16.52	0	2-795ACSR
652	[99G] NORTH BELT	JORDAN	345.00	345.00	(3) STEEL	0.00	29.78	0	2-1433ACSS
653	[99H] JORDAN	CEDAR BAYOU PLANT	345.00	345.00	(3) STEEL	9.28	0.08	0	2-1433ACSS
654	[99X] LIMESTONE PLANT	NAVARRO	345.00	345.00	(1) STEEL	0.13	0.00	0	2-959ACSS
655	138 kV		0.00	0.00		0.00	0.00	290
656	345 kV		0.00	0.00		0.00	0.00	70
657	69 kV		0.00	0.00		215.52	0.00	26
36	TOTAL					2,799.89	1,174.37	433

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

TRANSMISSION LINES ADDED DURING YEAR

Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines.
Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m).
If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.

LINE DESIGNATION

SUPPORTING STRUCTURE

CIRCUITS PER STRUCTURE

CONDUCTORS

LINE COST

Line No.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

(o)

(p)

(q)

[02J] BURKE

EAGLE NEST

7.52

(3) STEEL

2-795 AAC

138

[02K] EAGLE NEST

WEST COLUMBIA

2.77

(3) STEEL

2-795 AAC

138

[04C] DANBURY

LIVERPOOL

0.39

(3) STEEL

2-959 ACSS

138

[04G] ANGLETON

DANBURY

10.81

(3) STEEL

2-959 ACSS

138

[06K] MYKAWA

TELEPHONE

2.83

(3) STEEL

2-795 AAC

138

[06L] MYKAWA

PLAZA

12.41

(3) STEEL

2-795 AAC

138

[52A] JORDAN

WINFRE

1.03

(3) STEEL

2-959 ACSS

138

[52B] EAGLE

WINFRE

3.06

(3) STEEL

2-959 ACSS

138

[52C] EAGLE

MOUNT BELVIEU

0.27

(3) STEEL

2-795 AAC

138

[60A] BEASLY

ORCHARD

0.61

(1) CONC

2-959ACSS

138

[60B] HUNGERFORD

WHARTON

9.63

(1) CONC

2-959 ACSS

138

[60C] NEW GULF

GULFTIE

3.85

(3) STEEL

2-959 ACSS

138

[60C] SOUTH LANE CITY

NEW GULF

9.00

(3) STEEL

2-959 ACSS

138

[60F] EAST BERNARD

BEASLY

6.69

(1) CONC

2-959ACSS

138

[60G] EAST BERNARD

HUNGERFORD

5.36

(1) CONC

2-959 ACSS

138

[60H] SAN BERNARD

WEST COLUMBIA

13.48

(3) STEEL

2-959 ACSS

138

[60J] GULFTIE

SAN BERNARD

34.00

(3) STEEL

2-959 ACSS

138

[64C] W.A. PARISH PLANT

WOLF

12.30

(3) STEEL

1-1433 ACSS

345

[64E] HILLJE

WOLF

36.82

(3) STEEL

1-1433 ACSS

345

[66B] HOCKLEY

STONE LAKE

7.58

(1) CONC

795 AAC

138

[66B] STONE LAKE

TOMBALL

8.39

(1) CONC

795 AAC

138

[72C] CEDAR CREEK

WHALEY

6.81

(3) STEEL

2-1433ACSS

345

[72D] BAILEY

BLUE

8.82

(3) STEEL

2-1433ACSS

345

[72F] W.A. PARISH PLANT

WHALEY

9.02

(3) STEEL

2-1433ACSS

345

[72G] BLUE

HILLJE

10.10

(3) STEEL

2-1433ACSS

345

[85B] AIRPRO

BOGGY

4.59

(3) STEEL

2000 AAC

138

[88D] BOGGY

PAIR_

0.87

(3) STEEL

2000 AAC

138

[88F] BOGGY

EAST BELT

2.30

(3) STEEL

2000 AAC

138

[91A] TELEPHONE

MYKAWA

2.79

(3) STEEL

2-795 AAC

138

[91I] COUGAR

MYKAWA

8.42

(3) STEEL

2-795 AAC

138

[94C] METALS SWITCH

RIVERSIDE

0.51

(3) STEEL

2-795 ACSR

138

[94F] CHAMON

RIVERSIDE

0.28

(3) STEEL

2-795 ACSR

138

[96C] BEARLE

SOUTH CHANNEL

1.20

(3) STEEL

2-795 ACSR

138

[96G] BEARLE

PHILIP

0.19

(3) STEEL

2-795 AAC

138

TOTAL

245

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

SUBSTATIONS
Report below the information called for concerning substations of the respondent as of the end of the year. Substations which serve only one industrial or street railway customer should not be listed below. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f). Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
		Character of Substation		VOLTAGE (In MVa)						Conversion Apparatus and Special Equipment
Line No.	SubstationNameAndLocation Name and Location of Substation (a)	SubstationCharacterDescription Transmission or Distribution (b)	SubstationCharacterAttendedOrUnattended Attended or Unattended (b-1)	PrimaryVoltageLevel Primary Voltage (In MVa) (c)	SecondaryVoltageLevel Secondary Voltage (In MVa) (d)	TertiaryVoltageLevel Tertiary Voltage (In MVa) (e)	SubstationInServiceCapacity Capacity of Substation (In Service) (In MVa) (f)	NumberOfTransformersInService Number of Transformers In Service (g)	Number of Spare Transformers (h)	ConversionApparatusAndSpecialEquipmentType Type of Equipment (i)	NumberOfConversionApparatusAndSpecialEquipmentUnits Number of Units (j)	CapacityOfConversionApparatusAndSpecialEquipment Total Capacity (In MVa) (k)
1	Addicks - HARRIS_1	Transmission	Unattended	345.00	138.00	23.00	1693	5
2	Addicks - HARRIS_2	Transmission	Unattended	138.00	12.00
3	Airline - Houston	Distribution	Unattended	138.00	12.00		150	3
4	Aldine - HARRIS	Distribution	Unattended	138.00	12.00		144	3
5	Alexander Island - La Porte	Distribution	Unattended	138.00	12.00		100	2
6	Alief- Houston	Distribution	Unattended	138.00	12.00		141	3
7	Almeda - Houston	Distribution	Unattended	138.00	12.00		150	3
8	Alta Loma - GALVESTON	Distribution	Unattended	138.00	12.00		97	2
9	Alvin - BRAZORIA	Distribution	Unattended	69.00	12.00		30	1
10	Angleton - BRAZORIA	Distribution	Unattended	138.00	12.00		50	1
11	Arcola - BRAZORIA	Distribution	Unattended	138.00	35.00		293	3
12	Atascocita - Huffman	Distribution	Unattended	138.00	35.00		94	2
13	Bammel - Houston_1	Distribution	Unattended	138.00	35.00		342	5
14	Bammel - Houston_2	Distribution	Unattended	138.00	12.00
15	Barker - Alief	Distribution	Unattended	138.00	35.00		293	3
16	Baytown - HARRIS	Distribution	Unattended	138.00	12.00		94	2
17	Bayway - HARRIS	Distribution	Unattended	138.00	12.00		144	3
18	Bailey-Brazoria	Transmission	Unattended	345.00
19	Beasley-Fort Bend	Transmission	Unattended	138.00
20	Bellaire - HARRIS_1	Transmission	Unattended	345.00	138.00	23.00	3340	9	1	STATIC VAR CONVERTER	3	155
21	Bellaire - HARRIS_2	Transmission	Unattended	138.00	12.00
22	Bellaire - HARRIS_3	Transmission	Unattended	138.00	35.00
23	Berry - Houston	Distribution	Unattended	138.00	12.00		147	3
24	Bertron, S.R. - HARRIS	Transmission	Unattended
25	Bertwood - Houston	Distribution	Unattended	138.00	12.00		56	2
26	Big Creek - FORT BEND	Distribution	Unattended	138.00	12.00		100	2
27	Blodgett - Houston	Distribution	Unattended	138.00	12.00		150	3
28	Blue Ridge - HARRIS	Distribution	Unattended	138.00	12.00		144	3
29	Blue-Wharton	Transmission	Unattended	345.00
30	Brays - Houston	Distribution	Unattended	138.00	12.00		144	3
31	Brazosport - BRAZORIA	Distribution	Unattended	138.00	12.00		144	3
32	Brazos Valley - Richmond	Distribution	Unattended	138.00	35.00		200	2
33	Bringhurst - Houston	Distribution	Unattended	69.00	12.00		97	2
34	Britmoore - Houston	Distribution	Unattended	138.00	12.00		144	3
35	Burke-Brazoria	Transmission	Unattended	138.00
36	Busch, August A. - Houston	Distribution	Unattended	138.00	12.00		100	2
37	Campbell - Houston	Distribution	Unattended	138.00	12.00		147	3
38	Cardiff -Pasadena	Distribution	Unattended	138.00	12.00		147	3
39	Cedar Bayou - Baytown	Distribution	Unattended	138.00	12.00		141	3
40	Cedar Bayou -Plant -Baytown	Transmission	Unattended	345.00	138.00	23.00	2200	4
41	Cedar Creek	Transmission	Unattended	345.00
42	Center - SHELBY	Transmission	Unattended	345.00
43	CHAMBERS	Transmission	Unattended	138.00
44	Channelview • HARRIS	Distribution	Unattended	138.00	12.00		150	3
45	Chocolate Bayou -Houston	Distribution	Unattended	138.00	12.00		56	2
46	Clarke, H.O. - Houston_1	Transmission	Unattended	138.00	69.00	12.00	350	4
47	Clarke, H.O. - Houston_2	Transmission	Unattended	69.00	12.00
48	Clear Lake - Houston	Distribution	Unattended	138.00	12.00		144	3
49	Clinton - Houston	Distribution	Unattended	138.00	12.00		97	2
50	Clodine - HARRIS	Distribution	Unattended	138.00	12.00		191	4
51	College - South Houston	Distribution	Unattended	138.00	12.00		94	2
52	Crabb River Rd. - FT. BEND	Distribution	Unattended	138.00	35.00		286	3
53	Crockett - Houston	Distribution	Unattended	138.00	12.00		97	2
54	Crosby - HARRIS	Distribution	Unattended	138.00	12.00		56	2	1	STATIC VAR CONV&REAC	4	255
55	Cy-Fair - HARRIS	Distribution	Unattended	138.00	35.00		300	3
56	Danbury - Brazoria	Transmission	Unattended	138.00
57	Damon - BRAZORIA	Distribution	Unattended	138.00	12.00		100	2
58	Deepwater· HARRIS_1	Transmission	Unattended	345.00	138.00	23.00	800	1
59	Deepwater· HARRIS_2	Transmission	Unattended	69.00
60	Deer Park - HARRIS	Distribution	Unattended	138.00	12.00		94	2
61	Deihl - HARRIS	Distribution	Unattended	138.00	12.00		144	3
62	Dewalt - FORT BEND	Distribution	Unattended	138.00	35.00		286	3
63	Downtown - Houston_1	Distribution	Unattended	138.00	69.00		633	9
64	Downtown - Houston_2	Distribution	Unattended	69.00	12.00
65	(a) Dow-Velasco - Freeport	Transmission	Unattended	138.00	138.00	23.00	1600	2
66	Drouet - Houston	Distribution	Unattended	138.00	12.00		144	3
67	Dunlavy - Houston	Distribution	Unattended	69.00	12.00		147	3
68	Dunvale - Houston	Distribution	Unattended	138.00	12.00		141	3
69	Dyann - WHARTON	Transmission	Unattended	138.00
70	Eagle Nest - Brazoria	Transmission	Unattended	138.00
71	East Bernard - WHARTON	Distribution	Unattended	138.00	12.00		56	2
72	East Side - Houston	Distribution	Unattended	138.00	12.00		100	2
73	Echo - Houston	Distribution	Unattended	138.00	12.00		191	4
74	El Dorado - Webster	Distribution	Unattended	138.00	12.00		94	2
75	Ellington - HARRIS	Distribution	Unattended	138.00	12.00		147	3
76	Eureka - Houston	Distribution	Unattended	138.00	12.00		144	3
77	Fairbanks - HARRIS	Distribution	Unattended	138.00	35.00		300	3
78	Fairmont - HARRIS	Distribution	Unattended	138.00	12.00		150	3
79	Fannin, HARRIS	Distribution	Unattended	138.00	35.00		200	2
80	Flewellen - FORT BEND	Distribution	Unattended	138.00	35.00		294	3
81	Fondren - Houston	Distribution	Unattended	138.00	12.00		191	4
82	Fort Bend - Rosenburg	Transmission	Unattended	138.00
83	Franklin-Houston	Distribution	Unattended	138.00	35.00		193	2
84	Franz-Katy	Distribution	Unattended	138.00	35.00		386	4
85	Freeman-(Near Katy)	Distribution	Unattended	138.00	12.00		22	2
86	Freeport - BRAZORIA	Distribution	Unattended	138.00	12.00		100	2
87	Friendswood -HARRIS	Distribution	Unattended	138.00	12.00		94	2
88	Fry Road - HARRIS	Distribution	Unattended	138.00	35.00		300	3
89	Gable St. - Houston_1	Distribution	Unattended	138.00	69.00	12.00	607	8
90	Gable St. - Houston_2	Distribution	Unattended	69.00	12.00
91	Gelena Park - Galena Park_1	Distribution	Unattended	138.00	69.00	12.00	289	3
92	Gelena Park - Galena Park_2	Distribution	Unattended	69.00	12.00
93	Galveston - GALVESTON	Distribution	Unattended	138.00	12.00		141	3
94	Garden Villas - Houston_1	Distribution	Unattended	138.00	69.00		328	4
95	Garden Villas - Houston_2	Distribution	Unattended	138.00	12.00
96	Garden Villas - Houston_3	Distribution	Unattended	69.00	12.00
97	Garrot - Houston	Distribution	Unattended	138.00	12.00		147	3
98	Garth - HARRIS	Distribution	Unattended	138.00	12.00		100	2
99	Gears - HARRIS_1	Distribution	Unattended	138.00	35.00		293	3
100	Gertie - HARRIS_2	Distribution	Unattended	138.00	35.00		286	3
101	Glenwood - Houston	Distribution	Unattended	138.00	12.00		100	2
102	Grant - Houston_1	Distribution	Unattended	138.00	35.00		474	7
103	Grant - Houston_2	Distribution	Unattended	138.00	12.00
104	Greens Bayou -HARRIS_1	Transmission	Unattended	345.00	138.00	23.00	1800	3
105	Greens Bayou -HARRIS_2	Transmission	Unattended	138.00	69.00	12.00
106	Greens Road - Houston	Distribution	Unattended	138.00	12.00		100	2
107	Gulftie-Brazoria	Transmission	Unattended	138.00
108	Gulfgate - Houston	Distribution	Unattended	138.00	12.00		141	3
109	Hall - Houston	Distribution	Unattended	138.00	12.00		147	3
110	Haney - Houston	Distribution	Unattended	138.00	12.00		100	2
111	Hardy - Houston	Distribution	Unattended	138.00	12.00		78	2
112	Harrisburg - Houston	Distribution	Unattended	69.00	12.00		119	3
113	Hayes - Houston	Distribution	Unattended	138.00	12.00		144	3
114	Heights -Houston	Distribution	Unattended	69.00	12.00		197	4
115	Hidden Valley - Houston_1	Distribution	Unattended	138.00	12.00		297	4
116	Hidden Valley - Houston_2	Distribution	Unattended	138.00	35.00
117	Highlands - HARRIS	Distribution	Unattended	138.00	12.00		100	2
118	Hillcroft - Houston	Distribution	Unattended	138.00	12.00		144	3
119	Hillje - El Campo	Transmission	Unattended	345.00
120	Hitchcock - GALVESTON	Distribution	Unattended	138.00	12.00		78	2
121	Hockley - HARRIS	Distribution	Unattended	138.00	35.00		200	2
122	Holmes - Houston	Distribution	Unattended	138.00	12.00		144	3
123	Humble - HARRIS_1	Distribution	Unattended	138.00	35.00		322	5
124	Humble - HARRIS_2	Distribution	Unattended	138.00	12.00
125	Hungerford-Wharton	Transmission	Unattended	138.00
126	Hyde Park - Houston	Distribution	Unattended	69.00	12.00		150	3
127	Imperial - Sugarland	Distribution	Unattended	138.00	35.00		286	3
128	Industrial - HARRIS	Distribution	Unattended	138.00	12.00		97	2
129	Intercontinental (Airport)- HARRIS_1	Distribution	Unattended	138.00	12.00		147	3
130	Intercontinental (Airport)- HARRIS_2	Distribution	Unattended	138.00	35.00
131	Intermediate - HARRIS	Distribution	Unattended	138.00	12.00		100	2
132	Jacintoport - HARRIS	Distribution	Unattended	138.00	12.00		144	3
133	Jeanetta - Houston_1	Transmission	Unattended	138.00	12.00
134	Jeanetta - Houston_2	Transmission	Unattended	345.00	138.00	23.00	1347	5
135	Jefferson - HARRIS	Transmission	Unattended	138.00
136	Jones Creek - BRAZORIA_1	Transmission	Unattended	345.00	138.00	23.00	2500	5
137	Jones Creek - BRAZORIA_2	Transmission	Unattended	138.00	12.00
138	Jordan - Baytown_1	Transmission	Unattended	345.00	138.00	23.00	2600	5
139	Jordan - Baytown_2	Transmission	Unattended	138.00	35.00
140	Karsten - Arcola	Transmission	Unattended	138.00	69.00	12.00	112	1
141	Katy - WALLER	Distribution	Unattended	138.00	35.00		286	3
142	Kemah - GALVESTON	Distribution	Unattended	138.00	12.00		97	2
143	King- HARRIS	Distribution	Unattended	138.00	35.00		200	2
144	Kingwood - HARRIS	Distribution	Unattended	138.00	35.00		286	3
145	Kirby - Houston	Distribution	Unattended	138.00	12.00		247	5
146	Klein - HARRIS	Distribution	Unattended	138.00	35.00		286	3
147	Kluge - Houston	Distribution	Unattended	138.00	35.00		300	3
148	Knight - Houston	Distribution	Unattended	138.00	12.00		100	2
149	Kuykendahl - HARRIS	Distribution	Unattended	345.00	35.00		200	2	1
150	Lake Houston- HARRIS	Distribution	Unattended	138.00	35.00		200	2
151	Lake Jackson - BRAZORIA	Distribution	Unattended	138.00	12.00		141	3
152	La Marque· GALVESTON	Distribution	Unattended	138.00	12.00		30	1
153	La Porte HARRIS	Distribution	Unattended	138.00	12.00		100	2
154	Lauder - HARRIS	Distribution	Unattended	138.00	12.00		94	2
155	Liberty - Houston	Distribution	Unattended	138.00	12.00		100	2
156	Limburg- BRAZORIA	Distribution	Unattended	138.00	35.00		200	2
157	Limestone - JEWETT	Transmission	Attended	345.00	138.00	35.00	400	2		REACTOR	1	75
158	Little York - Houston	Distribution	Unattended	69.00	12.00		144	3
159	Liverpool - BRAZORIA	Distribution	Unattended	138.00	12.00		21	2
160	Lockwood - HARRIS	Distribution	Unattended	138.00	35.00		300	3
161	Louetta - HARRIS_1	Distribution	Unattended	138.00	35.00		251	4
162	Louetta - HARRIS_2	Distribution	Unattended	138.00	12.00
163	Lyondell - HARRIS	Distribution	Unattended	138.00	35.00		300	3
164	Magnolia Park - Houston	Distribution	Unattended	138.00	12.00		188	4
165	Manvel - BRAZORIA	Distribution	Unattended	69.00	12.00		56	2
166	Marys Creek - BRAZORIA	Distribution	Unattended	138.00	12.00		144	3
167	Mason Road - Katy	Distribution	Unattended	138.00	35.00		293	3
168	Memorial - Houston	Distribution	Unattended	138.00	12.00		150	3
169	Meadow - Alvin	Transmission	Unattended	345.00	138.00	23.00	1000	2
170	Midtown - Houston	Distribution	Unattended	138.00	12.00		100	2
171	Missouri City - FORT BEND	Distribution	Unattended	138.00	12.00		147	3
172	Moody - GALVESTON	Distribution	Unattended	138.00	12.00		97	2
173	Morgans Point-HARRIS	Transmission	Unattended	138.00
174	Mont Belvieu - CHAMBERS	Distribution	Unattended	138.00	12.00		150	3
175	Mustang Bayou - BRAZORIA	Distribution	Unattended	138.00	12.00		56	2
176	Nash - BRAZORIA_1	Transmission	Unattended	138.00	12.00		100	2
177	Nash - BRAZORIA_2	Transmission	Unattended
178	Needville - FORT BEND	Distribution	Unattended	138.00	12.00		100	2
179	New Gulf - WHARTON	Distribution	Unattended	138.00	12.00		56	2
180	Newport - HARRIS	Distribution	Unattended	138.00	35.00		94	2
181	Normandy - Houston	Distribution	Unattended	138.00	12.00		94	2
182	North Belt - HARRIS_1	Transmission	Unattended	345.00	138.00	23.00	2000	5
183	North Belt - HARRIS_2	Transmission	Unattended	138.00	35.00
184	North Side - Houston	Distribution	Unattended	138.00	12.00		147	3
185	Oasis - Alvin	Transmission	Unattended	345.00
186	Oates - Houston	Distribution	Unattended	138.00	12.00		97	2
187	Obrien - FORT BEND_1	Transmission	Unattended	345.00	138.00	23.00	2700	6	0	REACTOR	2	50
188	Obrien - FORT BEND_2	Transmission	Unattended	138.00	35.00
189	Orchard - FORT BEND	Distribution	Unattended	138.00	12.00		68	3
190	Oyster Creek Brazoria	Transmission	Unattended
191	Parish, W.A. - FORT BEND	Transmission	Unattended	345.00	138.00
192	Parkway - HARRIS	Distribution	Unattended	138.00	12.00		100	2
193	Pasadena - HARRIS	Distribution	Unattended	138.00	12.00		144	3
194	Pearland - BRAZORIA	Distribution	Unattended	138.00	12.00		100	2
195	Peters -AUSTIN	Transmission	Unattended	138.00
196	Pilgrim (Near Friendswood) - HARRIS	Distribution	Unattended	138.00	12.00		100	2
197	Pinehurst - MONTGOM ERY	Distribution	Unattended	138.00	35.00		300	3
198	Plaza - Houston	Distribution	Unattended	138.00	35.00		286	3
199	Pledger -MATAGORDA	Distribution	Unattended	138.00	12.00		11	1
200	Polaris - Houston	Distribution	Unattended	138.00	12.00		144	3
201	Polk - Houston_1	Distribution	Unattended	138.00	35.00		427	6
202	Polk - Houston_2	Distribution	Unattended	138.00	12.00
203	Quail Valley - Stafford	Distribution	Unattended	138.00	12.00		144	3
204	Rayford - Spring_1	Distribution	Unattended	138.00	35.00		186	2
205	Rayford - Spring_2	Distribution	Unattended	138.00	12.00
206	Reading - Houston_1	Distribution	Unattended	138.00	12.00		294	4
207	Reading - Houston_2	Distribution	Unattended		35.00
208	Red Bluff-HARRIS	Distribution	Unattended	138.00	12.00		150	3
209	Refuge Matagorda	Transmission	Unattended	345.00
210	Retrieve - BRAZORIA	Distribution	Unattended	138.00	12.00		30	1
211	Rittenhouse - Houston	Distribution	Unattended	138.00	12.00		94	2
212	Riverside - Harris	Transmission	Unattended	138.00
213	Roans Praire - GRIMES	Transmission	Unattended	345.00
214	Roark -Stafford_1	Distribution	Unattended	138.00	35.00		283	4
215	Roark -Stafford_2	Distribution	Unattended	138.00	12.00
216	Robinson, P.H. -San Leon_1	Transmission	Unattended	138.00	12.00		3256	6		3
217	Robinson, P.H. -San Leon_2	Transmission	Unattended	345.00	138.00	23.00
218	Rosenberg -FORT BEND	Distribution	Unattended	138.00	12.00		100	2
219	Rosharon -BRAZORIA	Distribution	Unattended	138.00	12.00		56	2
220	Rothwood - HARRIS	Transmission	Unattended	345.00	138.00	23.00	1600	2
221	San Felipe - Houston	Distribution	Unattended	138.00	35.00		477	7
222	Sandy Point - HARRIS	Distribution	Unattended	138.00	12.00		100	2
223	San Berneard - Brazoria	Transmission	Unattended	138.00
224	Satsuma - Jersey Village	Distribution	Unattended	138.00	35.00		386	4
225	Sauer - Houston	Distribution	Unattended	138.00	12.00		191	4
226	Scenic Woods - Houston	Distribution	Unattended	138.00	12.00		294	4
227	Sealy - AUSTIN_1	Distribution	Unattended	138.00	12.00		154	4
228	Sealy - AUSTIN_2	Distribution	Unattended	138.00	35.00
229	Seawall - Galveston	Distribution	Unattended	138.00	12.00		144	3
230	Sharpstown - Houston	Distribution	Unattended	138.00	12.00		191	4
231	South Channel - Houston_1	Transmission	Unattended	138.00	69.00	12.00	300	3
232	South Channel - Houston_2	Transmission	Unattended	138.00	12.00
233	Sheldon - HARRIS	Transmission	Unattended	345.00
234	Sienna - HARRIS	Distribution	Unattended	138.00	35.00		300	3
235	Singleton - Beclias	Transmission	Unattended	345.00
236	Smithers - FORT BEND	Transmission	Unattended	345.00
237	South Houston - HARRIS	Distribution	Unattended	138.00	12.00		147	3
238	South Lane City -WHARTON	Distribution	Unattended	138.00	12.00		21	2
239	(b) South Texas(Near Bay City) - MATAGORDA	Transmission	Attended	345.00						REACTOR	2	300
240	Southwyck. - BRAZORIA	Distribution	Unattended	138.00	35.00		300	3
241	Spencer - Houston	Distribution	Unattended	138.00	12.00		141	3
242	Springwoods-HARRIS	Distribution	Unattended	138.00	35.00		500	5
243	Stadium - Houston	Distribution	Unattended	138.00	4.00		32	3
244	Stafford - FORT BEND_1	Distribution	Unattended	138.00	12.00		294	4
245	Stafford - FORT BEND_2	Distribution	Unattended	138.00	35.00
246	Stewart - Galveston	Distribution	Unattended	138.00	12.00		56	2
247	Stone Lake- Harris	Distribution	Unattended	138.00	35.00		200	2
248	Strawberry Belt - Pasadena	Distribution	Unattended	138.00	12.00		97	2
249	Tanner- HARRIS	Distribution	Unattended	138.00	35.00		200	2
250	Telephone - Houston	Distribution	Unattended	138.00	12.00		147	3
251	Telview - Houston	Distribution	Unattended	138.00	12.00		100	2
252	Thompsons - FORT BEND	Distribution	Unattended	138.00	12.00		21	2
253	Tliki Island - Galveston	Distribution	Unattended	138.00	12.00		20	1
254	Todd - Houston	Distribution	Unattended	138.00	12.00		141	3
255	Tomball -HARRIS_1	Transmission	Unattended	345.00	138.00	23.00	1956	7		REACTOR	1	50
256	Tomball -HARRIS_2	Transmission	Unattended	138.00	35.00
257	Tomball -HARRIS_3	Transmission	Unattended	138.00	12.00
258	Treascbwing (Near Spring) - HARRIS	Distribution	Unattended	138.00	35.00		186	2
259	Trinity Bay -CHAMBERS	Distribution	Unattended	138.00	12.00		300	4
260	Ulrich - Houston	Distribution	Unattended	138.00	12.00		290	4
261	Underwood - Deer Park	Distribution	Unattended	138.00	12.00		100	2
262	University - Houston_1	Distribution	Unattended	138.00	12.00	12.00	147	3
263	University - Houston_2	Distribution	Unattended	69.00	12.00
264	Uvalde - Houston	Distribution	Unattended	138.00	12.00		94	2
265	Velasco - Freeport	Distribution	Unattended	138.00	12.00		100	2
266	Village Creek - Houston_1	Distribution	Unattended	138.00	35.00		200	2
267	Village Creek - Houston_2	Distribution	Unattended
268	Waller - WALLER	Distribution	Unattended	138.00	35.00	12.00	200	2
269	Wallis -AUSTIN	Distribution	Unattended	138.00	35.00		147	2
270	Wallisville - Houston	Distribution	Unattended	69.00	12.00		50	2
271	Webster - HARRIS_1	Transmission	Unattended	138.00	69.00	12.00	341	4
272	Webster - HARRIS_2	Transmission	Unattended	138.00	12.00
273	(c) WELSH-TITUS	Transmission	Unattended	345.00						D.C. CONVERTOR		600
274	WESTBAY-GALVESTON	Distribution	Unattended	138.00	12.00		53	2
275	Westchase (Near Alief) - HARRIS	Distribution	Unattended	138.00	35.00		286	3
276	West Columbia - BRAZORIA_1	Transmission	Unattended	138.00	12.00		11	1
277	West Columbia - BRAZORIA_2	Transmission	Unattended	69.00	12.00
278	Westfield - HARRIS_1	Distribution	Unattended	138.00	35.00		387	5
279	Westfield - HARRIS_2	Distribution	Unattended	138.00	12.00
280	West Galveston - GALVESTON	Distribution	Unattended	138.00	12.00		150	3
281	Westheimer - Houston_1	Distribution	Unattended	138.00	12.00		294	4
282	Sum of Distribution						42658	583
283	Sum of Transmission						28583	71
284	Westheimer - Houston_2	Distribution	Unattended	138.00	35.00
285	Westwood - Houston	Distribution	Unattended	138.00	12.00		141	3
286	Wharton - WHARTON	Distribution	Unattended	138.00	12.00		94	2
287	Wharton, T.H. - HARRIS_1	Transmission	Unattended	345.00	138.00	23.00	1993	6
288	Wharton, T.H. - HARRIS_2	Transmission	Unattended	138.00	35.00
289	Wharton, T.H. - HARRIS_3	Transmission	Unattended	138.00	69.00	12.00
290	Whaley-FortBend	Transmission	Unattended	345.00
291	Wolf- Fort Bend	Transmission	Unattended	345.00
292	White Oak - Houston_1	Transmission	Unattended	345.00	138.00	23.00	1765	8
293	White Oak - Houston_2	Transmission	Unattended	138.00	69.00	12.00
294	White Oak - Houston_3	Transmission	Unattended	138.00	12.00
295	Willow - HARRIS_1	Distribution	Unattended	138.00	12.00		418	6
296	Willow - HARRIS_2	Distribution	Unattended	138.00	35.00
297	Wirt - Houston	Distribution	Unattended	138.00	12.00		141	3
298	Witter -Pasadena	Distribution	Unattended	138.00	12.00		94	2
299	Woodcreek - Houston	Distribution	Unattended	138.00	35.00		186	2
300	Wortham-HARRIS	Distribution	Unattended	138.00	35.00		200	2
301	Zenith-HARRIS	Transmission	Unattended	345.00	138.00	23.00	2400	3
302	Total											1,485

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: SubstationNameAndLocation

Dow Velasco Substation – CenterPoint Energy has a permanent easement granted by The Dow Chemical Company for this substation on Dow Chemical’s property. CenterPoint Energy has installed & maintains equipment on this property/easement.

(b) Concept: SubstationNameAndLocation

South Texas Substation - This substation is a jointly owned facility of CenterPoint Energy (30.8%), City Public Service of San Antonio (28.0%), Austin Energy (16.0%), and AEP-Texas Central Company (25.2%). None of the partners are associated companies. The facilities are operated by CenterPoint Energy and the costs apportioned by pro rata share of ownership.

Welsh Substation - This substation is jointly owned by CenterPoint Energy (33 1/3%), ONCOR (16 2/3%), SWEPCO (25%) and AEP-Texas (25%). While Oncor is owned by two investors (indirect majority owner, Sempra Energy, and minority owner, Texas Transmission Investment LLC), Oncor is managed by its Board of Directors, which is comprised of a majority of disinterested directors.

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general". Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.	Description of the Good or Service (a)	Name of Associated/Affiliated Company (b)	Account(s) Charged or Credited (c)	Amount Charged or Credited (d)
1	Non-power Goods or Services Provided by Affiliated
2	Business & Operations Support	CERC	(a) See Footnote	2,788,523
3	Company Benefits	CERC	(b) See Footnote	95,147
4	Customer Operations	CERC	9030	33
5	Distribution Support	CERC	(c) See Footnote	10,419,167
6	Meter Reading	CERC	5860	99
7	Regulatory	CERC	1823	2,907
8	Technology Operations	CERC	(d) See Footnote	248,650
9	Transmission	CERC	(e) See Footnote	36,425
10	Transportation	CERC	(f) See Footnote	2,732
11	Business & Operations Support	CNP Service Company, LLC	(g) See Footnote	29,644,608
12	Communications	CNP Service Company, LLC	(h) See Footnote	2,699,029
13	Community Relations	CNP Service Company, LLC	(i) See Footnote	1,261,942
14	Continuous Improvement	CNP Service Company, LLC	(j) See Footnote	1,277,570
15	Company Benefits	CNP Service Company, LLC	(k) See Footnote	9,124
16	Customer Operations	CNP Service Company, LLC	(l) See Footnote	16,449,548
17	Distribution Support	CNP Service Company, LLC	(m) See Footnote	12,760,782
18	Executive Management	CNP Service Company, LLC	(n) See Footnote	8,080,047
19	Finance	CNP Service Company, LLC	(o) See Footnote	17,592,255
20	Government Affairs	CNP Service Company, LLC	(p) See Footnote	3,629,854
21	Human Resources	CNP Service Company, LLC	(q) See Footnote	6,670,279
22	Legal	CNP Service Company, LLC	(r) See Footnote	10,284,895
23	Meter Reading	CNP Service Company, LLC	5860	32,007
24	Regulatory	CNP Service Company, LLC	(s) See Footnote	11,042,197
25	Technology Operations	CNP Service Company, LLC	(t) See Footnote	115,941,559
26	Transmission	CNP Service Company, LLC	(u) See Footnote	55,352
27	Transportation	CNP Service Company, LLC	(v) See Footnote	18,097
28	Other Corp	CNP Service Company, LLC	(w) See Footnote	27,495,925
19
20	Non-power Goods or Services Provided for Affiliated
21	Business & Operations Support	CERC	(x) See Footnote	5,482,348
22	Company Benefits	CERC	(y) See Footnote	658,522
23	Customer Operations	CERC	(z) See Footnote	2,710
24	Distribution Support	CERC	(aa) See Footnote	10,879,983
25	Meter Reading	CERC	5860	2,899
26	Technology Operations	CERC	Clearing	3,441,728
27	Transmission	CERC	(ab) See Footnote	43,103
28	Transportation	CERC	(ac) See Footnote	2,077,968
29	Business & Operations Support	CNP Service Company, LLC	(ad) See Footnote	251,740
30	Company Benefits	CNP Service Company, LLC	(ae) See Footnote	21,673
31	Customer Operations	CNP Service Company, LLC	5860	588
32	Distribution Support	CNP Service Company, LLC	(af) See Footnote	5,394
33	Meter Reading	CNP Service Company, LLC	9302	2,318
34	Transportation	CNP Service Company, LLC	Clearing	40,216
35	Business & Operations Support	Indiana Gas Company, Inc.	(ag) See Footnote	631,225
36	Company Benefits	Indiana Gas Company, Inc.	(ah) See Footnote	53,267
37	Customer Operations	Indiana Gas Company, Inc.	9030	92
38	Distribution Support	Indiana Gas Company, Inc.	(ai) See Footnote	502,796
39	Meter Reading	Indiana Gas Company, Inc.	5860	276
40	Technology Operations	Indiana Gas Company, Inc.	Clearing	25,063
41	Transmission	Indiana Gas Company, Inc.	5630	900
42	Business & Operations Support	Southern IN Gas & Elec Co	(aj) See Footnote	668,107
43	Company Benefits	Southern IN Gas & Elec Co	(ak) See Footnote	80,071
44	Customer Operations	Southern IN Gas & Elec Co	9030	7
45	Distribution Support	Southern IN Gas & Elec Co	(al) See Footnote	440,346
46	Meter Reading	Southern IN Gas & Elec Co	5860	184,473
47	Technology Operations	Southern IN Gas & Elec Co	Clearing	24,608
48	Transmission	Southern IN Gas & Elec Co	(am) See Footnote	9,563
49	Business & Operations Support	Vctrn Enrgy Dlvry OH,Inc.	(an) See Footnote	416,321
50	Company Benefits	Vctrn Enrgy Dlvry OH,Inc.	(ao) See Footnote	38,697
51	Distribution Support	Vctrn Enrgy Dlvry OH,Inc.	(ap) See Footnote	304,182
52	Technology Operations	Vctrn Enrgy Dlvry OH,Inc.	Clearing	16,633
53	Transmission	Vctrn Enrgy Dlvry OH,Inc.	(aq) See Footnote	859
54	Business & Operations Support	Vctrn Utility Hldngs,Inc.	Clearing	1,402,670
55	Distribution Support	Vctrn Utility Hldngs,Inc.	Clearing	16,523
56	Technology Operations	Vctrn Utility Hldngs,Inc.	Clearing	2,206,810
57	Transportation	Vctrn Utility Hldngs,Inc.	Clearing	4
42

Name of Respondent:

CenterPoint Energy Houston Electric, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/18/2023

Year/Period of Report

End of:

2022

FOOTNOTE DATA

(a) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Business & Operations Support	CERC	1070	$	51,625
Business & Operations Support	CERC	4081	27,001
Business & Operations Support	CERC	4261	41
Business & Operations Support	CERC	4263	41
Business & Operations Support	CERC	4264	41
Business & Operations Support	CERC	4265	587
Business & Operations Support	CERC	5600	5
Business & Operations Support	CERC	5800	37
Business & Operations Support	CERC	9200	23
Business & Operations Support	CERC	9210	60,283
Business & Operations Support	CERC	9302	16,935
Business & Operations Support	CERC	Clearing	2,555,766
Business & Operations Support	CERC	Various	76,138
Business & Operations Support Total			$	2,788,523

(b) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Company Benefits	CERC	9250	$	544
Company Benefits	CERC	9260	94,603
Company Benefits Total			$	95,147


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Distribution Support	CERC	5800	$	87,105
Distribution Support	CERC	5830	123
Distribution Support	CERC	5840	10,047,250
Distribution Support	CERC	5870	33
Distribution Support	CERC	5880	771
Distribution Support	CERC	5900	155,453
Distribution Support	CERC	5930	5,338
Distribution Support	CERC	5940	58
Distribution Support	CERC	5960	2,031
Distribution Support	CERC	5970	674
Distribution Support	CERC	Clearing	87,211
Distribution Support	CERC	Various	33,120
Distribution Support Total			$	10,419,167

(d) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Technology Operations	CERC	1070	$	208,556
Technology Operations	CERC	Various	40,094
Technology Operations Total			$	248,650

(e) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Transmission	CERC	5600	$	36,185
Transmission	CERC	5630	48
Transmission	CERC	5660	80
Transmission	CERC	5710	112
Transmission Total			$	36,425

(f) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Transportation	CERC	5600	$	31
Transportation	CERC	5800	69
Transportation	CERC	5860	230
Transportation	CERC	5880	414
Transportation	CERC	5900	137
Transportation	CERC	9030	153
Transportation	CERC	9070	3
Transportation	CERC	9080	126
Transportation	CERC	Clearing	669
Transportation	CERC	Various	900
Transportation Total			$	2,732

(g) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Business & Operations Support	CNP Service Company, LLC	1070	$	19,678,563
Business & Operations Support	CNP Service Company, LLC	1810	3,674,328
Business & Operations Support	CNP Service Company, LLC	2282	—
Business & Operations Support	CNP Service Company, LLC	4030	(279,710)
Business & Operations Support	CNP Service Company, LLC	4081	88,586
Business & Operations Support	CNP Service Company, LLC	4261	7,794
Business & Operations Support	CNP Service Company, LLC	4265	5,042
Business & Operations Support	CNP Service Company, LLC	5600	(72,722)
Business & Operations Support	CNP Service Company, LLC	5700	—
Business & Operations Support	CNP Service Company, LLC	5800	(162,227)
Business & Operations Support	CNP Service Company, LLC	5900	(324,456)
Business & Operations Support	CNP Service Company, LLC	9200	4,807
Business & Operations Support	CNP Service Company, LLC	9210	58,668
Business & Operations Support	CNP Service Company, LLC	9250	1,130
Business & Operations Support	CNP Service Company, LLC	9260	207,723
Business & Operations Support	CNP Service Company, LLC	9302	2,634,038
Business & Operations Support	CNP Service Company, LLC	Clearing	4,262,573
Business & Operations Support	CNP Service Company, LLC	Various	(139,529)
Business & Operations Support Total			$	29,644,608

(h) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Communications	CNP Service Company, LLC	4081	$	99,768
Communications	CNP Service Company, LLC	4261	(112)
Communications	CNP Service Company, LLC	4265	11,709
Communications	CNP Service Company, LLC	9250	1,749
Communications	CNP Service Company, LLC	9260	262,161
Communications	CNP Service Company, LLC	9302	2,323,754
Communications Total			$	2,699,029

(i) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Community Relations	CNP Service Company, LLC	4081	$	40,063
Community Relations	CNP Service Company, LLC	4261	(1,185)
Community Relations	CNP Service Company, LLC	4265	3,903
Community Relations	CNP Service Company, LLC	9250	724
Community Relations	CNP Service Company, LLC	9260	105,790
Community Relations	CNP Service Company, LLC	9302	1,112,647
Community Relations Total			$	1,261,942

(j) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Continuous Improvement	CNP Service Company, LLC	4081	$	44,714
Continuous Improvement	CNP Service Company, LLC	9250	616
Continuous Improvement	CNP Service Company, LLC	9260	113,161
Continuous Improvement	CNP Service Company, LLC	9302	1,119,079
Continuous Improvement Total			$	1,277,570

(k) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Company Benefits	CNP Service Company, LLC	9250	$	5,847
Company Benefits	CNP Service Company, LLC	9260	3,277
Company Benefits Total			$	9,124

(l) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Customer Operations	CNP Service Company, LLC	4081	$	515,964
Customer Operations	CNP Service Company, LLC	4261	8,286
Customer Operations	CNP Service Company, LLC	4265	9,148
Customer Operations	CNP Service Company, LLC	9030	9,170,930
Customer Operations	CNP Service Company, LLC	9080	8,631
Customer Operations	CNP Service Company, LLC	9090	265
Customer Operations	CNP Service Company, LLC	9250	8,963
Customer Operations	CNP Service Company, LLC	9260	1,355,214
Customer Operations	CNP Service Company, LLC	9302	5,118,842
Customer Operations	CNP Service Company, LLC	9310	253,305
Customer Operations Total			$	16,449,548

(m) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Distribution Support	CNP Service Company, LLC	1070	$	296,119
Distribution Support	CNP Service Company, LLC	4081	95,723
Distribution Support	CNP Service Company, LLC	4265	1,779
Distribution Support	CNP Service Company, LLC	5800	31,723
Distribution Support	CNP Service Company, LLC	5810	2,578
Distribution Support	CNP Service Company, LLC	5820	6,892
Distribution Support	CNP Service Company, LLC	5830	21,332
Distribution Support	CNP Service Company, LLC	5840	21,222
Distribution Support	CNP Service Company, LLC	5850	848
Distribution Support	CNP Service Company, LLC	5870	5,668
Distribution Support	CNP Service Company, LLC	5880	31,492
Distribution Support	CNP Service Company, LLC	5900	20,689
Distribution Support	CNP Service Company, LLC	5910	493
Distribution Support	CNP Service Company, LLC	5920	11,166
Distribution Support	CNP Service Company, LLC	5930	55,139
Distribution Support	CNP Service Company, LLC	5940	23,082
Distribution Support	CNP Service Company, LLC	5960	4,314
Distribution Support	CNP Service Company, LLC	5980	17
Distribution Support	CNP Service Company, LLC	9070	64
Distribution Support	CNP Service Company, LLC	9250	265,530
Distribution Support	CNP Service Company, LLC	9260	248,266
Distribution Support	CNP Service Company, LLC	9302	2,535,545
Distribution Support	CNP Service Company, LLC	Clearing	9,055,697
Distribution Support	CNP Service Company, LLC	Various	25,404
Distribution Support Total			$	12,760,782

(n) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Executive Management	CNP Service Company, LLC	4081	$	338,248
Executive Management	CNP Service Company, LLC	4261	23,152
Executive Management	CNP Service Company, LLC	4265	195,235
Executive Management	CNP Service Company, LLC	9250	2,171
Executive Management	CNP Service Company, LLC	9260	521,094
Executive Management	CNP Service Company, LLC	9302	7,000,147
Executive Management Total			$	8,080,047

(o) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Finance	CNP Service Company, LLC	4081	$	642,138
Finance	CNP Service Company, LLC	4261	3,586
Finance	CNP Service Company, LLC	4265	251,181
Finance	CNP Service Company, LLC	9250	11,105
Finance	CNP Service Company, LLC	9260	1,677,970
Finance	CNP Service Company, LLC	9302	15,006,275
Finance Total			$	17,592,255

(p) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Government Affairs	CNP Service Company, LLC	4081	$	43,245
Government Affairs	CNP Service Company, LLC	4261	6,829
Government Affairs	CNP Service Company, LLC	4264	2,447,140
Government Affairs	CNP Service Company, LLC	9250	735
Government Affairs	CNP Service Company, LLC	9260	112,201
Government Affairs	CNP Service Company, LLC	9302	1,019,704
Government Affairs Total			$	3,629,854

(q) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Human Resources	CNP Service Company, LLC	4081	$	242,199
Human Resources	CNP Service Company, LLC	4261	(28)
Human Resources	CNP Service Company, LLC	4265	11,192
Human Resources	CNP Service Company, LLC	9030	422,130
Human Resources	CNP Service Company, LLC	9250	4,070
Human Resources	CNP Service Company, LLC	9260	627,528
Human Resources	CNP Service Company, LLC	9302	5,363,188
Human Resources Total			$	6,670,279

(r) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Legal	CNP Service Company, LLC	1070	$	952,576
Legal	CNP Service Company, LLC	1810	215,550
Legal	CNP Service Company, LLC	4081	334,144
Legal	CNP Service Company, LLC	4261	6,711
Legal	CNP Service Company, LLC	4264	420
Legal	CNP Service Company, LLC	4265	12,747
Legal	CNP Service Company, LLC	9250	5,745
Legal	CNP Service Company, LLC	9260	871,604
Legal	CNP Service Company, LLC	9302	7,856,518
Legal	CNP Service Company, LLC	Clearing	28,880
Legal Total			$	10,284,895

(s) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Regulatory	CNP Service Company, LLC	1823	$	3,051,929
Regulatory	CNP Service Company, LLC	4081	347,866
Regulatory	CNP Service Company, LLC	4261	6,449
Regulatory	CNP Service Company, LLC	4264	634,933
Regulatory	CNP Service Company, LLC	4265	3,306
Regulatory	CNP Service Company, LLC	9250	6,426
Regulatory	CNP Service Company, LLC	9260	929,170
Regulatory	CNP Service Company, LLC	9302	6,062,118
Regulatory Total			$	11,042,197

(t) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Technology Operations	CNP Service Company, LLC	1070	$	54,456,072
Technology Operations	CNP Service Company, LLC	4081	940,226
Technology Operations	CNP Service Company, LLC	4261	110
Technology Operations	CNP Service Company, LLC	4265	2,679
Technology Operations	CNP Service Company, LLC	5600	8,433,815
Technology Operations	CNP Service Company, LLC	5800	20,630,500
Technology Operations	CNP Service Company, LLC	5840	4,455
Technology Operations	CNP Service Company, LLC	5860	9,330
Technology Operations	CNP Service Company, LLC	5870	776
Technology Operations	CNP Service Company, LLC	5880	3,110
Technology Operations	CNP Service Company, LLC	5930	2,509
Technology Operations	CNP Service Company, LLC	5940	1,564
Technology Operations	CNP Service Company, LLC	9020	1,416,575
Technology Operations	CNP Service Company, LLC	9030	412,565
Technology Operations	CNP Service Company, LLC	9080	996
Technology Operations	CNP Service Company, LLC	9200	1,539
Technology Operations	CNP Service Company, LLC	9250	15,300
Technology Operations	CNP Service Company, LLC	9260	2,422,462
Technology Operations	CNP Service Company, LLC	9302	27,072,331
Technology Operations	CNP Service Company, LLC	Clearing	37,118
Technology Operations	CNP Service Company, LLC	Various	77,527
Technology Operations Total			$	115,941,559

(u) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Transmission	CNP Service Company, LLC	5600	$	13,291
Transmission	CNP Service Company, LLC	5611	52
Transmission	CNP Service Company, LLC	5612	856
Transmission	CNP Service Company, LLC	5613	135
Transmission	CNP Service Company, LLC	5614	2,524
Transmission	CNP Service Company, LLC	5615	1,341
Transmission	CNP Service Company, LLC	5617	60
Transmission	CNP Service Company, LLC	5620	1,783
Transmission	CNP Service Company, LLC	5630	4,034
Transmission	CNP Service Company, LLC	5660	8,657
Transmission	CNP Service Company, LLC	5690	2,898
Transmission	CNP Service Company, LLC	5700	8,941
Transmission	CNP Service Company, LLC	5710	9,383
Transmission	CNP Service Company, LLC	5730	1,397
Transmission Total			$	55,352

(v) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Transportation	CNP Service Company, LLC	1070	$	366
Transportation	CNP Service Company, LLC	Clearing	17,731
Transportation Total			$	18,097

(w) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Other Corp	CNP Service Company, LLC	4081	$	288
Other Corp	CNP Service Company, LLC	4261	1,466
Other Corp	CNP Service Company, LLC	4265	14,305
Other Corp	CNP Service Company, LLC	9250	(18,075)
Other Corp	CNP Service Company, LLC	9260	4,589,443
Other Corp	CNP Service Company, LLC	9302	22,908,498
Other Corp Total			$	27,495,925

(x) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Business & Operations Support	CERC	1070	$	41
Business & Operations Support	CERC	4081	197,707
Business & Operations Support	CERC	4261	18,144
Business & Operations Support	CERC	9200	(3,023)
Business & Operations Support	CERC	9302	913,984
Business & Operations Support	CERC	Clearing	4,300,930
Business & Operations Support	CERC	Various	54,565
Business & Operations Support Total			$	5,482,348

(y) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Company Benefits	CERC	9250	$	68,460
Company Benefits	CERC	9260	590,062
Company Benefits Total			$	658,522

(z) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Customer Operations	CERC	9030	$	464
Customer Operations	CERC	9080	2,246
Customer Operations Total			$	2,710

(aa) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited

Distribution Support	CERC	5800	$	209,869
Distribution Support	CERC	5810	—
Distribution Support	CERC	5820	2,440
Distribution Support	CERC	5830	151,629
Distribution Support	CERC	5840	5,940
Distribution Support	CERC	5870	464
Distribution Support	CERC	5880	2,650,842
Distribution Support	CERC	5900	4,221
Distribution Support	CERC	5910	510
Distribution Support	CERC	5920	5,854
Distribution Support	CERC	5930	10,287
Distribution Support	CERC	5940	14,003
Distribution Support	CERC	5960	236
Distribution Support	CERC	Clearing	7,774,027
Distribution Support	CERC	Various	49,661
Distribution Support Total			$	10,879,983

(ab) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Transmission	CERC	5600	$	27,965
Transmission	CERC	5620	645
Transmission	CERC	5630	7,888
Transmission	CERC	5660	1,385
Transmission	CERC	5690	1,336
Transmission	CERC	5700	3,884
Transmission Total			$	43,103

(ac) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Transportation	CERC	1070	$	12,715
Transportation	CERC	5880	442
Transportation	CERC	5940	498
Transportation	CERC	Clearing	2,064,313
Transportation Total			$	2,077,968

(ad) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Business & Operations Support	CNP Service Company, LLC	4081	$	7,150
Business & Operations Support	CNP Service Company, LLC	9302	197,647
Business & Operations Support	CNP Service Company, LLC	Clearing	38,412
Business & Operations Support	CNP Service Company, LLC	Various	8,531
Business & Operations Support Total			$	251,740

(ae) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Company Benefits	CNP Service Company, LLC	9250	$	139
Company Benefits	CNP Service Company, LLC	9260	21,534
Company Benefits Total			$	21,673

(af) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Distribution Support	CNP Service Company, LLC	5800	$	537
Distribution Support	CNP Service Company, LLC	5830	596
Distribution Support	CNP Service Company, LLC	5870	144
Distribution Support	CNP Service Company, LLC	5880	2,330
Distribution Support	CNP Service Company, LLC	5930	1,357
Distribution Support	CNP Service Company, LLC	5940	295
Distribution Support	CNP Service Company, LLC	5960	72
Distribution Support	CNP Service Company, LLC	Clearing	63
Distribution Support Total			$	5,394

(ag) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Business & Operations Support	Indiana Gas Company, Inc.	4081	$	17,714
Business & Operations Support	Indiana Gas Company, Inc.	9302	35,484
Business & Operations Support	Indiana Gas Company, Inc.	Clearing	579,186
Business & Operations Support	Indiana Gas Company, Inc.	Various	(1,159)
Business & Operations Support Total			$	631,225

(ah) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Company Benefits	Indiana Gas Company, Inc.	9250	$	372
Company Benefits	Indiana Gas Company, Inc.	9260	52,895
Company Benefits Total			$	53,267

(ai) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Distribution Support	Indiana Gas Company, Inc.	5800	$	345
Distribution Support	Indiana Gas Company, Inc.	5830	17,448
Distribution Support	Indiana Gas Company, Inc.	5870	92
Distribution Support	Indiana Gas Company, Inc.	5880	321,593
Distribution Support	Indiana Gas Company, Inc.	5930	805
Distribution Support	Indiana Gas Company, Inc.	5940	160
Distribution Support	Indiana Gas Company, Inc.	5960	47
Distribution Support	Indiana Gas Company, Inc.	Clearing	157,977
Distribution Support	Indiana Gas Company, Inc.	Various	4,329
Distribution Support Total			$	502,796

(aj) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Business & Operations Support	Southern IN Gas & Elec Co	4081	$	26,499
Business & Operations Support	Southern IN Gas & Elec Co	4261	1,856
Business & Operations Support	Southern IN Gas & Elec Co	9302	78,348
Business & Operations Support	Southern IN Gas & Elec Co	Clearing	561,081
Business & Operations Support	Southern IN Gas & Elec Co	Various	323
Business & Operations Support Total			$	668,107

(ak) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Company Benefits	Southern IN Gas & Elec Co	9250	$	555
Company Benefits	Southern IN Gas & Elec Co	9260	79,516
Company Benefits Total			$	80,071

(al) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Distribution Support	Southern IN Gas & Elec Co	5800	$	49,716
Distribution Support	Southern IN Gas & Elec Co	5810	1,134
Distribution Support	Southern IN Gas & Elec Co	5820	79
Distribution Support	Southern IN Gas & Elec Co	5830	2,397
Distribution Support	Southern IN Gas & Elec Co	5840	583
Distribution Support	Southern IN Gas & Elec Co	5870	7
Distribution Support	Southern IN Gas & Elec Co	5880	246,900
Distribution Support	Southern IN Gas & Elec Co	5920	89
Distribution Support	Southern IN Gas & Elec Co	5930	61
Distribution Support	Southern IN Gas & Elec Co	5940	12
Distribution Support	Southern IN Gas & Elec Co	5960	3
Distribution Support	Southern IN Gas & Elec Co	Clearing	139,365
Distribution Support Total			$	440,346

(am) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Transmission	Southern IN Gas & Elec Co	5600	$	6,776
Transmission	Southern IN Gas & Elec Co	5614	2,524
Transmission	Southern IN Gas & Elec Co	5620	22
Transmission	Southern IN Gas & Elec Co	5630	125
Transmission	Southern IN Gas & Elec Co	5690	28
Transmission	Southern IN Gas & Elec Co	5700	88
Transmission Total			$	9,563

(an) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Business & Operations Support	Vectren Energy Delivery OH,Inc.	4081	$	12,861
Business & Operations Support	Vectren Energy Delivery OH,Inc.	9302	27,791
Business & Operations Support	Vectren Energy Delivery OH,Inc.	Clearing	375,669
Business & Operations Support Total			$	416,321

(ao) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Company Benefits	Vectren Energy Delivery OH,Inc.	9250	$	270
Company Benefits	Vectren Energy Delivery OH,Inc.	9260	38,427
Company Benefits Total			$	38,697

(ap) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Distribution Support	Vectren Energy Delivery OH,Inc.	5800	$	3,466
Distribution Support	Vectren Energy Delivery OH,Inc.	5830	7,342
Distribution Support	Vectren Energy Delivery OH,Inc.	5880	196,241
Distribution Support	Vectren Energy Delivery OH,Inc.	Clearing	95,673
Distribution Support	Vectren Energy Delivery OH,Inc.	Various	1,460
Distribution Support Total			$	304,182

(aq) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies


Non-power of Goods or Services Provided by Affiliate	Name of Associated/Affiliated Company	Account Charged or Credited	Amount Charged or Credited
Transmission	Vectren Energy Delivery OH,Inc.	5600	$	473
Transmission	Vectren Energy Delivery OH,Inc.	5630	386
Transmission Total			$	859




FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature

FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose

Who Must Submit

What and Where to Submit

When to Submit

Where to Send Comments on Public Reporting Burden.

GENERAL INSTRUCTIONS

EXCERPTS FROM THE LAW

GENERAL PENALTIES

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report