CNPCenterPoint Energy
This combined Form 10-K is filed separately by three registrants: CenterPoint Energy, Inc., CenterPoint Energy Houston Electric, LLC and CenterPoint Energy Resources Corp. 10-K, Item 1
- Headquarters
- Houston, TX
- CEO
- Jason Wells
- Next results
- around Feb 18, 2027
26 paragraphs in Risk Factors of the 10-K filed Feb 19, 2026 with nothing like them in the 10-K filed Feb 20, 2025. Quoted exactly. Paragraphs that were only edited are under 10-K change.
Compared with the Risk Factors in the latest 10-K of the other 30 Utilities companies: a paragraph with at least half its words the same at another company is called similar, and the companies are listed under it. A paragraph most of them have is marked boilerplate. No line means no other company has one like it. This counts text; it does not say how serious a risk is.
Electric’s 2022/2023 IRP recommended the conversion of F.B. Culley Unit 3 from coal to natural gas by 2027, the 2025 IRP re-evaluated this conversion in light of customer affordability concerns, among other things, and deferred the decision regarding F.B. Culley Unit 3’s replacement to a future IRP. If Indiana Electric is unable to implement its generation transition plan, it may have an adverse effect on CenterPoint Energy’s ability to execute on its energy transition goals, execute on its growth strategy, achieve its financial goals, and otherwise impact its business, financial condition, results of operations and cash flows.
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or any completed future transactions may not be realized fully or at all, or may not be realized in the anticipated timeframe, which could adversely impact our business, financial condition, results of operations and cash flows. Finally, if such transactions are successful and thereby result in Houston Electric having fewer TEEEF units to deploy in its service territory, and conditions occur that could be or are perceived to have the potential to be addressed by Houston Electric’s deployment of TEEEF, Houston Electric could be subject to claims, demands, litigation, liability, regulatory scrutiny and loss of reputation.
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Inherent in the regulatory process is some level of risk that jurisdictional regulatory authorities may challenge the reasonableness or prudency of operating expenses incurred or capital investments made by the Registrants or their subsidiaries and deny the full recovery of their cost of service in rates. For example, concerns about customer affordability could cause regulators to approve lesser amounts in ratemaking or cost recovery proceedings. From time to time, reviews and investigations
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Our successful execution and completion of capital projects and programs, including those within our 10-year capital plan, are subject to substantial risks, and our business, financial condition, results of operations and cash flows could be materially affected should such efforts not be executed and completed as planned.
We are managing ongoing, and planning future, significant capital projects relating to, among other things, improvements to our electric and natural gas transmission and distribution infrastructure. The execution of our capital projects, including those within our 10-year capital plan, may not be completed in accordance with current expectations or produce the desired results. Our ability to execute and complete our capital projects, including Houston Electric’s proposed 765 kV and other transmission projects, in a timely and cost-effective manner and within budget is contingent upon many variables and subject to substantial risks. These variables and risks include, but are not limited to, availability of and costs for materials, equipment, commodities and qualified labor; cost and availability of financing; cost of regulatory compliance; economic and market conditions; regulatory approvals, licensing and permitting; land and easement acquisition (including requirements and constraints relating to eminent domain); regulatory, political, public and community relations risks (including in relation to customer affordability concerns); tax law; our ability to capitalize on business opportunities and such opportunities providing desirable rates of return; load growth (including our forecasts thereof) and our ability to capitalize on opportunities relating thereto; safety and environmental requirements; the ability of third parties to provide timely and satisfactory performance under their contracts; delays and cost increases; and supply chains and material constraints. Certain events that may be beyond our control may occur that materially affect the schedule, cost and performance of these projects, including Houston Electric’s proposed 765 kV and other transmission projects. These events may relate to facing public and policymaker opposition to the projects or the real or perceived cost of such projects; delays in obtaining permits; challenges in securing sufficient land/easements for projects (including challenges to our use of eminent domain); shortages in materials and qualified labor; third parties not performing as expected or required under their contracts and/or experiencing financial problems that inhibit their ability to fulfill their obligations under contracts; supply chain delays or disruptions; changes in the scope and timing of projects; strikes; and adverse weather conditions. For example, our failure to capitalize on the opportunities presented by these developments or potential large load customers delaying or cancelling their planned projects could lead to delays or the cancellation of the projects
Similar paragraph at 1 of 30 other Utilities companies: ETRincluded in our 10-year capital plan. Additionally, regulators may investigate the prudence of costs in our rates and examine, among other things, the reasonableness or prudence of our level of expenditures (including costs associated with our capital projects). If we do not execute or complete our capital projects, including those within our 10-year capital plan, in accordance with current expectations or if our capital plan does not produce the desired results, our business, financial condition, results of operations and cash flows could be materially affected.
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decrease in demand for our services. For further discussion, see “Business—Environmental Matters” in Item 1 and “ —Our natural gas businesses must compete with…”
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Indiana Electric’s coal generation; execution of the retirement or fuel conversion of Indiana Electric’s coal facilities on anticipated timelines or at all; the ability to construct and/or permit new natural gas pipelines; the ability to procure resources needed to build at a reasonable cost, the lack of or scarcity of resources and labor, any project cancellations, construction delays or overruns (including as a result of changes in U.S. or foreign trade policies) and the ability to appropriately estimate costs of new generation; impact of any supply chain disruptions; changes in applicable standards, metrics, methodologies or frameworks; and enhancement of energy efficiencies.
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In the planning and management of our operations, we must address existing and proposed laws and regulations regarding safety, reliability and other matters, as well as potential changes in regulatory frameworks, including reinterpretation of such regulations, initiatives by federal and state legislatures, regional transmission organizations (e.g., ERCOT and MISO), utility regulators, and taxing authorities, and actions by local jurisdictions regarding such matters. As has occurred in the past, if it were determined that we failed to comply with applicable laws and regulations or with applicable tariff provisions regarding such matters, we could become subject to fines, penalties, refund or disgorgement orders, or disallowed costs, or be required to implement additional compliance or remediation programs, the cost of which could be material. We cannot predict the impact of new laws, rules, regulations, tariffs, principles, or practices by federal or state agencies or regional transmission operators, or challenges or changes to present laws, rules, regulations, tariffs, principles, or practices and the interpretation of any adoption or change. Significant changes in the nature of the regulation of our businesses, including expiration or discontinuation of, or significant changes to, existing regulatory mechanisms, and the current federal administration’s approach to U.S. energy policy and resultant changes in regulatory enforcement priorities, and/or evolving interpretations of existing regulatory requirements, could require changes to our business planning, strategy and management of our businesses and could adversely affect our business, financial condition, results of operations and cash flows.
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In addition, external sources of capital may not be adequate or available on reasonable terms. If we are unable to arrange future financings on acceptable terms, our ability to finance our operations and capital expenditures, including our 10-year capital plan announced in 2025 and increased in February 2026 (through which CenterPoint Energy plans to invest at least $65.5 billion through 2035), or refinance our outstanding indebtedness could be limited. Any of these outcomes could have a material adverse effect on our business, financial condition, results of operations and cash flows. Our future financing activities may be significantly affected by, among other things:
•general economic and capital market conditions, including inflation and recession;
Similar paragraph at 1 of 30 other Utilities companies: PEG•investor confidence in us, our regulatory environment, our industry and the markets in which we operate;
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10 more
•timing and adequacy of future cost recovery, including securitizations, by jurisdictions in which we operate;
•changes in regulation, governmental policy (including tax and trade policy, such as tariffs) or governmental programs (including tax incentives or tax credits, loans, grants, guarantees and other subsidies); and
•provisions of relevant securities laws and our ability to obtain required regulatory authorization for issuances of securities.
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The U.S. government has taken executive action and proposed additional measures intended to alter the U.S. approach to international trade policy, the terms of certain existing bilateral or multi‐lateral trade agreements and trading arrangements with foreign countries. Such changes to U.S. international trade policy, and retaliatory trade measures that foreign governments have taken and may take in the future in response, including the imposition of tariffs, bans, sanctions, export or import controls, or other measures that restrict international trade, or the threat of such actions, and uncertainties about tariffs and their effects on trading relationships, may affect, and in some cases have affected, the Registrants’ ability to access the capital markets, contribute to inflation in the markets in which the Registrants operate, increase costs and cost volatility, impact availability of goods, materials and services (including those necessary for our business and capital plan), further extend lead times or otherwise negatively impact the global supply chain. While the U.S. government has announced various trade deals, many such agreements are preliminary and may be subject to change. Further, any future disagreement between the U.S. government and other countries over the implementation of trade deals or any failure to obtain required governmental approvals or otherwise reach a final agreement could result in prolonged uncertainty regarding the scope and duration of such trade actions by the U.S. government and other countries. Such announcements, rescissions of tariffs on foreign jurisdictions and other trade actions have increased uncertainty regarding the ultimate effects of the tariffs on economic conditions. In addition, related geopolitical and domestic political developments, such as existing and potential trade wars, uncertainty regarding changes in trade policy and other events beyond our control, have increased and may continue to increase levels of political and economic unpredictability globally and the volatility of global financial markets. Such developments could adversely affect our business, financial condition, results of operations and cash flows.
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obligations pursuant to these parental guarantees to date but may be required to do so in the future. For further information, see Note 14(b) to the consolidated financial statements.
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From time to time we have made, and may continue to make, acquisitions or divestitures of, or other similar transactions involving, businesses and assets, such as our announced sale of our Ohio natural gas LDC business, Houston Electric’s release
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•shifting governmental policies may impact governmental support for strategic transactions.
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We are subject to transition risk relating to climate change, as well. In the long term, climate change could cause shifts in population, including customers moving away from our service territories. When we cannot deliver electricity or natural gas to
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significant developments with such companies, could cause increased volatility in stock prices of certain companies in our industry.
Higher electric power demand and load growth could also significantly increase the prices of energy and capacity, which could in turn affect customer rates or be perceived to affect customer rates and raise affordability concerns, as well as raise resource adequacy and reliability concerns, particularly if that increased demand outpaces the addition of firm generation capacity and in transmission constrained zones. For example, there has been increasing media attention and public claims regarding the link between large load customers such as data centers and increased customer bills. Increased customer rates or the perception that customer rates are increasing to address large load customers could attract political and regulatory scrutiny, increase regulatory uncertainty for our capital investment plans and programs and present reputational risks. Additionally, projected load growth across the ERCOT system could, if not sufficiently addressed through system design and reliability measures, negatively impact electric infrastructure reliability and potentially cause system-wide stresses. This resource adequacy challenge presents reliability concerns, as well as potential for increasing energy and capacity prices that could place pressure on customer bills, attract political and regulatory scrutiny, increase regulatory uncertainty for our capital investment plans and programs and present reputational risks. These matters could have an adverse effect on our business, financial condition, results of operations and cash flows.
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We have risks associated with aging infrastructure assets, including the failure of equipment or processes and potential breakdowns due to such aging. These risks have in the past and may continue to be driven by threats such as, but not limited to, electrical faults, mechanical failure, internal and external corrosion, ground movement and stress corrosion and/or cracking. The age of certain of our assets, including each of Indiana Electric’s coal generating facilities, which were constructed in 1973 and 1966, respectively, have in the past resulted and may continue to result in a need for replacement, higher level of maintenance costs, reduced generation output and unscheduled outages because of, among other things, our risk-based federal and state compliant integrity management programs. The failure to operate our assets as desired could result in interruption of service, safety concerns, major component failure at generating facilities and electric substations, events such as gas leaks, and an inability to meet service and compliance obligations, which could adversely impact revenues, and could also result in increased
capital expenditures and maintenance costs. As part of our capital plan and various plans and projects thereunder, we continue to make upgrades to our aging infrastructure assets to enhance the reliability of our infrastructure. Failure to achieve timely and full recovery of expenses associated with our aging infrastructure could adversely impact revenues and could result in increased capital expenditures or expenses. In addition, the nature of information available on aging infrastructure assets, which in some cases is incomplete, may make operation of the infrastructure, inspections, maintenance, upgrading and replacement of the assets particularly challenging. Missing or incorrect infrastructure data may lead to difficulty properly locating facilities, which can result in excavator damage and operational or emergency response issues; configuration and control risks associated with the modification of system operating pressures in connection with turning off or turning on service to customers, which can result in unintended outages or operating pressures; and other potential risks related to missing or incorrect infrastructure data. Also, additional maintenance and inspections are required in some instances to improve infrastructure information and records and address emerging regulatory or risk management requirements, resulting in increased costs.
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•the inability to maintain the reliability of our utility services or meet generation capacity obligations;
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•regulatory noncompliance, compliance mandates and penalties from our regulators;
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New in the latest 10-Q
24 paragraphs in the 10-Q filed Oct 27, 2026 with nothing like them in the 10-Q filed Jul 28, 2026 (at least half the words must differ; new numbers alone do not count). Quoted exactly, grouped by the item heading above them. This is text that changed, not a judgement of how serious it is.
Financial statements and notes
Adjustment to pension and other postretirement plans (net of tax expense of $0, $0, $0, and $0 respectively) 1 (2) 2 (1)
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Reclassification of deferred gain from cash flow hedges realized in net income (net of tax benefit of $0, $0, $0 and $0) (1) — (1) (1)
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CenterPoint Energy and CERC perform goodwill impairment tests at least annually and evaluate goodwill when events or changes in circumstances indicate that its carrying value may not be recoverable. Goodwill is evaluated for impairment by performing a qualitative assessment or using a quantitative test. CenterPoint Energy and CERC performed their annual goodwill impairment tests in the third quarter of 2026 and determined that no goodwill impairment charge was required for any reporting unit as a result of those tests.
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In May 2026, the FASB issued ASU 2026-02, Environmental Credits and Environmental Credit Obligations (Topic 818), which establishes recognition, measurement, presentation, and disclosure requirements for environmental credits and related
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or disallowances on its right of use assets or TEEEF regulatory assets during the three and nine months ended September 30, 2026 or 2025.
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$ 31.01666668 per share for all such outstanding shares of WBD Common upon the completion of the Paramount and WBD Merger. For further information related to the merger, see Note 16.
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rate will be subject to adjustment in some events (as described in the 2029 Convertible Notes Indenture) but will not be adjusted for any accrued and unpaid interest.
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Junior Subordinated Notes. In August 2026, CenterPoint Energy issued $ 700 million aggregate principal amount of 6.400 % Fixed-to-Fixed Reset Rate Junior Subordinated Notes, Series E, due 2058 (the “Series E Notes”). Interest on the Series E Notes accrues from August 3, 2026 and is payable semiannually in arrears on February 15 and August 15 of each year, beginning on February 15, 2027, and maturing on August 15, 2058. The Series E Notes bear interest (i) from and including August 3, 2026 to, but excluding, August 15, 2033 at the rate of 6.400 % per annum and (ii) from and including August 15, 2033, during each five-year period following August 15, 2033 (each such five-year period, a “Series E Interest Reset Period”), at a rate per annum equal to the Five-Year Treasury Rate (as defined in the Junior Subordinated Notes Indenture) as of two business days prior to the beginning of the applicable Series E Interest Reset Period plus a spread of 1.885 % with such rate per annum to be reset on each five-year anniversary of August 15, 2033. So long as no event of default (as defined in the Junior Subordinated Notes Indenture) with respect to the Series E Notes has occurred and is continuing, CenterPoint Energy may, at its option, defer interest payments on the Series E Notes, from time to time, for one or more deferral periods of up to 20 consecutive semiannual interest payment periods, except that no such optional deferral period (as defined in the Junior Subordinated Notes Indenture) may extend beyond the final maturity date of the Series E Notes or end on a day other than the day immediately preceding an interest payment date.
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During any optional deferral period, CenterPoint Energy (and its majority-owned subsidiaries, as applicable) will not (subject to certain exceptions as described in the Junior Subordinated Notes Indenture): (i) declare or pay any dividends or distributions on any of CenterPoint Energy’s capital stock; (ii) redeem, purchase, acquire or make a liquidation payment with respect to any of CenterPoint Energy’s capital stock; (iii) pay any principal, interest (to the extent such interest is deferrable) or premium on, or repay, repurchase or redeem any of CenterPoint Energy’s indebtedness that ranks equally with or junior to the Series E Notes in right of payment (including debt securities of other series, such as the other series of the junior subordinated notes issued); or (iv) make any payments with respect to any guarantees by CenterPoint Energy of any indebtedness if such guarantees rank equally with or junior to the Series E Notes in right of payment.
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In August 2026, CenterPoint Energy settled all of its outstanding principal amount of the 2026 Convertible Notes, which matured on August 15, 2026. Upon conversion, CenterPoint Energy paid $ 1.0 billion in aggregate principal amount and approximately $ 21 million in interest, in each case in cash, and issued 4,120,719 shares of its common stock to settle the conversion premium as the conversion value exceeded the principal amount of the 2026 Convertible Notes.
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Credit Facilities and Commercial Paper. On September 9, 2026, CenterPoint Energy, Houston Electric, CERC and SIGECO replaced their existing revolving credit facilities with four revolving credit facilities totaling $ 4.6 billion in aggregate commitments. In addition, Houston Electric established a commercial paper program under which it may issue short-term, unsecured commercial paper notes in an aggregate principal amount not to exceed $ 1.0 billion outstanding at any time. Houston Electric's commercial paper program is backstopped by its revolving credit facility. Further, in connection with replacing the credit facilities, CenterPoint Energy decreased the size of its commercial paper program to permit the issuance of commercial paper notes in an aggregate principal amount not to exceed $ 2.2 billion and CERC increased its commercial paper program to permit the issuance of commercial paper notes in an aggregate principal amount not to exceed $ 1.1 billion. The Registrants had the following revolving credit facilities as of September 30, 2026:
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events may require remedial activities which are not presently foreseen, and those costs may not be subject to PRP or insurance recovery.
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Dividends Declared Per Share Dividends Paid Per Share Three Months Ended September 30, Nine Months Ended September 30, Three Months Ended September 30, Nine Months Ended September 30, 2026 2025 2026 2025 2026 2025 2026 2025 Common Stock $ 0.480 $0.440 $ 0.710 $0.660 $ 0.240 $0.220 $ 0.700 $0.660
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As described in Note 8, the Paramount and WBD Merger closed on October 6, 2026. As such, CenterPoint Energy has established October 21, 2026 as an additional interest regular record date under the terms of its indenture governing the outstanding ZENS. Additional interest of $ 5.39122 per ZENS note will be paid on November 4, 2026 to holders of record of the ZENS as of the close of business on the additional interest regular record date. The additional interest of $ 5.39122 per ZENS note was calculated as the product of 0.173817 share of WBD Common per ZENS note and the $ 31.01666668 per share cash merger consideration paid to the holders of WBD Common.
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After the closing of the Paramount and WBD Merger, the reference shares for each ZENS note consisted of 0.7185 share of AT&T Common and 0.061382 share of Charter Common.
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On October 20, 2026, CenterPoint Energy, through its indirect, wholly-owned subsidiary SIGECO, entered into a bond purchase agreement with certain institutional investors, under which SIGECO agreed to sell, and each investor agreed to severally purchase (i) on October 20, 2026, $ 130 million aggregate principal amount of SIGECO’s 5.99 % First Mortgage Bonds, Series 2026A, Tranche A due 2031 (the “Series 2026A Bonds”); (ii) on December 15, 2026, $ 80 million aggregate principal amount of SIGECO’s 6.15 % First Mortgage Bonds, Series 2026B, Tranche A due 2033 (the “Series 2026B Bonds”); and (iii) on February 25, 2027, $ 50 million aggregate principal amount of SIGECO’s 6.33 % First Mortgage Bonds, Series 2027A, Tranche A due 2037 (the “Series 2027A Bonds”) in the series and tranche as set forth in the bond purchase agreement. The proceeds of the Series 2026A Bonds, Series 2026B Bonds and the Series 2027A Bonds are expected to be used for general corporate purposes, including repaying short-term debt, refunding long-term debt at maturity or otherwise, and funding capital expenditures.
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Three months ended September 30, 2026 compared to three months ended September 30, 2025
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Nine Months Ended September 30, 2026 compared to nine months ended September 30, 2025
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Electric (in millions) ──────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────── Net changes in commercial paper outstanding $ 499 $ — $ 539 Net changes in proceeds from issuances of Common Stock 165 — — Net changes in long-term debt and term loans outstanding, excluding commercial paper 74 379 573 Net changes in debt issuance costs (23) (6) — Net changes in short-term borrowings 3 — 3 Increased payment of dividends on Common Stock (30) — — Net change in notes payable to affiliated companies — (54) (118) Change in dividend to parent — 182 — Change in contribution from parent — (111) 635 Change in proceeds from customer advances for construction 339 331 8 Change in refunds of customer advances for construction (135) (135) — Other (12) (1) (1) $ 880 $ 585 $ 1,639
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cost allocation mechanism and FERC’s subsequent procedural denial of the rehearing requests on the March 19 order. On August 12, 2026, Indiana Electric filed a Motion to Intervene in the D.C. Circuit in response to the Sierra Club and Environmental Law & Policy Center’s appeal of the FERC’s March 19 Order granting Indiana Electric’s Section 202(c) cost allocation complaint against MISO. Indiana Electric intervened as the owner of F.B. Culley Unit 2 that is the subject of the underlying FERC Order at issue on appeal. On August 20, 2026, FERC filed an unopposed motion to hold in abeyance the appeal of its March 19 Order, which was granted on September 1, 2026, pending the outcome of the consolidated Culley and Schahfer DOE Order appeals, which were themselves being held in abeyance pending the outcome of the Consumers Energy DOE Order appeal.
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Pursuant to House Enrolled Act 1002 (HEA 1002), Indiana Electric is required to file a multi-year rate case in January 2028.
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TEEEF N/A May 2025 March 2026 March 2026 Seeks authorization to lease small, 200 kW to 1,250 kW TEEEF units for 36 months in accordance with the TEEEF Rule. Among other things, the TEEEF Rule generally requires that a utility obtain preapproval prior to renewing or entering into a new lease of TEEEF units, with exceptions for emergency situations or if the lease includes a provision allowing for the alteration of the lease based on applicable PUCT orders or rules. Approval of Houston Electric’s request in this filing had no cost...
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Tax Act Rider $(5) July 2026 TBD TBD Resulting from the Texas Gas Rate Case, the third Tax Act Rider Calculation was filed on July 25, 2026 pursuant to Docket No. OS-23-00015513 to recover the effects of the IRA and certain other tax-related costs for rates that will become effective January 1, 2027. These effects include the return on the CAMT deferred tax asset (“DTA”) resulting from the IRA, income tax credits resulting from the IRA and the return on the increment or decrement in the net operating loss DTA included in the...
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Item 6
Number †10.9 Letter Agreement Amending Confirmations by and between CenterPoint Energy, Inc. and Bank of America, N.A., dated August 19, 2026 x †10.10 Letter Agreement Amending Confirmations by and between CenterPoint Energy, Inc. and JPMorgan Chase Bank, National Association, dated August 19, 2026 x †10.11 Letter Agreement Amending Confirmations by and between CenterPoint Energy, Inc. and Mizuho Markets Americas LLC, dated August 19, 2026 x †10.12 Second Amendment to CenterPoint Energy, Inc. Short Term Incentive Plan, as amended and restated effective January 1, 2022. x †31.1.1 Rule 13a-14(a)/15d-14(a) Certification of Jason P. Wells x †31.1.2 Rule 13a-14(a)/15d-14(a) Certification of Jesus Soto, Jr. x †31.1.3 Rule 13a-14(a)/15d-14(a) Certification of Jesus Soto, Jr. x †31.2.1 Rule 13a-14(a)/15d-14(a) Certification of Christopher A. Foster x †31.2.2 Rule 13a-14(a)/15d-14(a) Certification of Christopher A. Foster x †31.2.3 Rule 13a-14(a)/15d-14(a) Certification of Christopher A. Foster x †32.1.1 Section 1350 Certification of Jason P. Wells x †32.1.2 Section 1350 Certification of Jesus Soto, Jr. x ───────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────────── 10.3 Partial Termination Amendment to CenterPoint Energy Savings Restoration Plan, effective as of July 15, 2026 CenterPoint Energy’s Form 10-Q for the quarter ended June 30, 2026 1-31447 10.3 x 10.4 Partial Termination Amendment to CenterPoint Energy 2005 Deferred Compensation Plan, effective as of July 15, 2026 CenterPoint Energy’s Form 10-Q for the quarter ended June 30, 2026 1-31447 10.4 x 10.5 $2,200,000,000 Third Amended and Restated Credit Agreement dated as of September 9, 2026 among CenterPoint Energy, Inc., as Borrower, JPMorgan Chase Bank, N.A., as Administrative Agent, the financial institutions as bank parties thereto and the other parties thereto. CenterPoint Energy’s Form 8-K dated September 9, 2026 1-31447 10.1 x 10.6 $1,000,000,000 Third Amended and Restated Credit Agreement dated as of September 9, 2026 among CenterPoint Energy Houston Electric, LLC, as Borrower, JPMorgan Chase Bank, N.A., as Administrative Agent, the financial institutions as bank parties thereto and the other parties thereto. CenterPoint Energy’s Form 8-K dated September 9, 2026 1-31447 10.2 x 10.7 $1,100,000,000 Third Amended and Restated Credit Agreement dated as of September 9, 2026 among CenterPoint Energy Resources Corp., as Borrower, JPMorgan Chase Bank, N.A., as Administrative Agent, the financial institutions as bank parties thereto and the other parties thereto. CenterPoint Energy’s Form 8-K dated September 9, 2026 1-31447 10.3 x 10.8 $300,000,000 Amended and Restated Credit Agreement dated as of September 9, 2026 among Southern Indiana Gas and Electric Company, as Borrower, JPMorgan Chase Bank, N.A., as Administrative Agent, the financial institutions as bank parties thereto and the other parties thereto. CenterPoint Energy’s Form 8-K dated September 9, 2026 1-31447 10.4 x
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The 10-Q's risk factors against the 10-K
Item 1A of the 10-Q filed Oct 27, 2026 against Item 1A of the 10-K filed Feb 19, 2026.
A 10-Q repeats only the risks that changed, so a 10-K paragraph that is missing from it is not counted as removed.
Added is a paragraph with nothing like it in the 10-K, Reworded a sentence that is in both with several words changed,
Quiet changes a sentence in both where one to four words changed and one is a hedge or a modal
(cut words struck through, new words highlighted and underlined).
Text on the page, not a score; each links to the filing at sec.gov.
What the 10-Q itself says about its risk factors:
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There have been no material changes from the risk factors disclosed in the Registrants’ combined 2025 Form 10-K.
1 paragraph in the 10-Q's Item 1A, and none of them adds, rewords or quietly edits a paragraph of the 10-K's.
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