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Regulatory Matters | 12 Months Ended
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Dec. 31, 2024
Regulated Operations [Abstract] |
Regulatory Matters | Regulatory Matters The following is a list of regulatory assets and liabilities reflected on the Registrants’ respective Consolidated Balance Sheets as of December 31, 2024 and 2023:
| December 31, 2024
| CenterPoint Energy |  | Houston Electric |  | CERC
| (in millions)
Regulatory Assets: |  |  |  |  |
Future amounts recoverable from ratepayers related to: |  |  |  |  |
Benefit obligations (1) | $ | 373 |  |  | $ | — |  |  | $ | 4 |
Asset retirement obligations & other | 304 |  |  | 80 |  |  | 188 |
Net deferred income taxes | 144 |  |  | 47 |  |  | 69 |
Total future amounts recoverable from ratepayers | 821 |  |  | 127 |  |  | 261 |
Amounts deferred for future recovery related to: |  |  |  |  |
Cost recovery riders | 145 |  |  | — |  |  | 83 |
Hurricanes and February 2021 Winter Storm Event Restoration Costs | 145 |  |  | 145 |  |  | — |
May 2024 Storm Events | 86 |  |  | 86 |  |  | — |
Hurricane Beryl | 458 |  |  | 458 |  |  | — |
Hurricane Francine | 19 |  |  | 19 |  |  | — |
Other regulatory assets | 177 |  |  | 87 |  |  | 74 |
Decoupling | 12 |  |  | — |  |  | 12 |
Temporary generation costs | 71 |  |  | 71 |  |  | — |
Unrecognized equity return (2) | (115) |  |  | (77) |  |  | (30) |
Total amounts deferred for future recovery | 998 |  |  | 789 |  |  | 139 |
Amounts currently recovered in customer rates related to: |  |  |  |  |
Authorized trackers and cost deferrals | 600 |  |  | 47 |  |  | 440 |
Securitized regulatory assets | 343 |  |  | — |  |  | — |
Unamortized loss on reacquired debt and hedging | 93 |  |  | 63 |  |  | 10 |
Gas recovery costs | 122 |  |  | — |  |  | 122 |
Decoupling | 38 |  |  | — |  |  | 38 |
Extraordinary gas costs | 133 |  |  | — |  |  | 133 |
Regulatory assets related to TCJA | 47 |  |  | 47 |  |  | — |
Hurricanes and February 2021 Winter Storm Event Restoration Costs | 31 |  |  | 5 |  |  | 26 |
Other regulatory assets | 34 |  |  | — |  |  | 34 |
Benefit obligations | 4 |  |  | 4 |  |  | — |
Temporary generation costs | 219 |  |  | 219 |  |  | — |
Unrecognized equity return (3) | (136) |  |  | (17) |  |  | (62) |
Total amounts recovered in customer rates (5) | 1,528 |  |  | 368 |  |  | 741 |
Total Regulatory Assets | $ | 3,347 |  |  | $ | 1,284 |  |  | $ | 1,141 |
Total Current Regulatory Assets | $ | 239 |  |  | $ | — |  |  | $ | 238 |
Total Non-Current Regulatory Assets | $ | 3,108 |  |  | $ | 1,284 |  |  | $ | 903 |
Regulatory Liabilities: |  |  |  |  |
Regulatory liabilities related to TCJA | $ | 1,346 |  |  | $ | 673 |  |  | $ | 501 |
Estimated removal costs | 1,247 |  |  | — |  |  | 1,191 |
Other regulatory liabilities | 454 |  |  | 195 |  |  | 235 |
Total Regulatory Liabilities | $ | 3,047 |  |  | $ | 868 |  |  | $ | 1,927 |
Total Current Regulatory Liabilities (6) | $ | 48 |  |  | $ | 7 |  |  | $ | 40 |
Total Non-Current Regulatory Liabilities | $ | 2,999 |  |  | $ | 861 |  |  | $ | 1,887 |
| December 31, 2023
| CenterPoint Energy |  | Houston Electric |  | CERC
| (in millions)
Regulatory Assets: |  |  |  |  |
Future amounts recoverable from ratepayers related to: |  |  |  |  |
Benefit obligations (1) | $ | 379 |  |  | $ | — |  |  | $ | 5 |
Asset retirement obligations & other | 290 |  |  | 75 |  |  | 186 |
Net deferred income taxes | 96 |  |  | 41 |  |  | 42 |
Total future amounts recoverable from ratepayers | 765 |  |  | 116 |  |  | 233 |
Amounts deferred for future recovery related to: |  |  |  |  |
Cost recovery riders | 113 |  |  | — |  |  | 73 |
Hurricanes and February 2021 Winter Storm Event restoration costs | 149 |  |  | 123 |  |  | 26 |
Other regulatory assets | 147 |  |  | 59 |  |  | 72 |
Gas recovery costs | 27 |  |  | — |  |  | 27 |
Decoupling | 17 |  |  | — |  |  | 17 |
COVID-19 incremental costs | 12 |  |  | 8 |  |  | 4 |
Temporary generation costs | 48 |  |  | 48 |  |  | — |
Unrecognized equity return (2) | (63) |  |  | (39) |  |  | (16) |
Total amounts deferred for future recovery | 450 |  |  | 199 |  |  | 203 |
Amounts currently recovered in customer rates related to: |  |  |  |  |
Authorized trackers and cost deferrals | 535 |  |  | 44 |  |  | 375 |
Securitized regulatory assets | 434 |  |  | 74 |  |  | — |
Unamortized loss on reacquired debt and hedging | 106 |  |  | 72 |  |  | 11 |
Gas recovery costs | 34 |  |  | — |  |  | 34 |
Extraordinary gas costs | 208 |  |  | — |  |  | 208 |
Regulatory assets related to TCJA | 47 |  |  | 47 |  |  | — |
Hurricane Harvey restoration costs | 17 |  |  | 17 |  |  | — |
Benefit obligations | 11 |  |  | 11 |  |  | — |
Temporary generation costs | 208 |  |  | 208 |  |  | — |
Unrecognized equity return (4) | (141) |  |  | (36) |  |  | (53) |
Total amounts recovered in customer rates | 1,459 |  |  | 437 |  |  | 575 |
Total Regulatory Assets | $ | 2,674 |  |  | $ | 752 |  |  | $ | 1,011 |
Total Current Regulatory Assets | $ | 161 |  |  | $ | — |  |  | $ | 161 |
Total Non-Current Regulatory Assets | $ | 2,513 |  |  | $ | 752 |  |  | $ | 850 |
Regulatory Liabilities: |  |  |  |  |
Regulatory liabilities related to TCJA | $ | 1,377 |  |  | $ | 695 |  |  | $ | 505 |
Estimated removal costs | 1,322 |  |  | 91 |  |  | 1,150 |
Other regulatory liabilities | 548 |  |  | 245 |  |  | 260 |
Total Regulatory Liabilities | $ | 3,247 |  |  | $ | 1,031 |  |  | $ | 1,915 |
Total Current Regulatory Liabilities (6) | $ | 39 |  |  | $ | 6 |  |  | $ | 33 |
Total Non-Current Regulatory Liabilities | $ | 3,208 |  |  | $ | 1,025 |  |  | $ | 1,882 |
(1)Pension and postretirement-related regulatory assets balances are actuarially valued annually. (2)Represents the following: (a) CenterPoint Energy’s allowed equity return on post in-service carrying cost generally associated with investments in Indiana; (b) Houston Electric’s allowed equity return on TEEEF costs and storm restoration costs; and (c) CERC’s allowed equity return on post in-service carrying cost associated with certain distribution facilities replacements expenditures in Texas. (3)Represents the following: (a) CenterPoint Energy’s allowed equity return on post in-service carrying cost generally associated with investments in Indiana; (b) Houston Electric’s allowed equity return on certain storm restoration balances and (c) CERC’s allowed equity return on post in-service carrying cost associated with certain distribution facilities replacements expenditures in Texas. (4)Represents the following: (a) CenterPoint Energy’s allowed equity return on post in-service carrying cost generally associated with investments in Indiana; (b) Houston Electric’s allowed equity return on its true-up balance of stranded costs, other changes and related interest resulting from the formerly integrated electric utilities prior to Texas deregulation to be recovered in rates through 2024 and certain storm restoration balances; and (c) CERC’s allowed equity return on post in-service carrying cost associated with certain distribution facilities replacements expenditures in Texas. (5)Of the $1.5 billion, $368 million and $741 million currently being recovered in customer rates related to CenterPoint Energy, Houston Electric and CERC, respectively, $463 million, $305 million and $158 million is earning a return, respectively. The weighted average recovery period of regulatory assets currently being recovered in base rates, not earning a return, which totals $424 million, $63 million and $328 million for CenterPoint Energy, Houston Electric and CERC, respectively, is 11 years, 27 years and 7 years, respectively. Regulatory assets not earning a return with perpetual or undeterminable lives have been excluded from the weighted average recovery period calculation. (6)Current regulatory liabilities are included in Other current liabilities in each of the Registrants’ respective Consolidated Balance Sheets. The table below reflects the amount of allowed equity return recognized by each Registrant in its Statements of Consolidated Income for the periods presented:
| Year Ended December 31,
| 2024 |  | 2023 |  | 2022
| CenterPoint Energy |  | Houston Electric |  | CERC |  | CenterPoint Energy |  | Houston Electric |  | CERC |  | CenterPoint Energy |  | Houston Electric |  | CERC
| (in millions)
Allowed equity return recognized | $ | 23 |  |  | $ | 20 |  |  | $ | 2 |  |  | $ | 41 |  |  | $ | 38 |  |  | $ | 2 |  |  | $ | 45 |  |  | $ | 42 |  |  | $ | 2 |
February 2021 Winter Storm Event In February 2021, certain of the Registrants’ jurisdictions experienced an extreme and unprecedented winter weather event that resulted in prolonged freezing temperatures, which impacted their businesses. The February 2021 Winter Storm Event impacted wholesale prices of CenterPoint Energy’s and CERC’s natural gas purchases and their ability to serve customers in their Natural Gas service territories, including due to the reduction in available natural gas capacity and impacts to CenterPoint Energy’s and CERC’s natural gas supply portfolio activities, and the effects of weather on their systems and their ability to transport natural gas, among other things. The overall natural gas market, including the markets from which CenterPoint Energy and CERC sourced a significant portion of their natural gas for their operations, experienced significant impacts caused by the February 2021 Winter Storm Event, resulting in extraordinary increases in the cost of natural gas purchased by CenterPoint Energy and CERC of approximately $2 billion. CenterPoint Energy and CERC have completed recovery of natural gas costs in Mississippi, Indiana, Louisiana and Texas, and continue to recover the natural gas cost in Minnesota. As of December 31, 2024, CenterPoint Energy and CERC had each recorded current regulatory assets of $67 million and non-current regulatory assets of $67 million associated with the February 2021 Winter Storm Event. As of December 31, 2023, CenterPoint Energy and CERC have each recorded current regulatory assets of $86 million and non-current regulatory assets of $130 million associated with the February 2021 Winter Storm Event. In Minnesota, the MPUC issued its written order on October 19, 2022 disallowing CERC’s recovery of approximately $36 million of the $409 million incurred, and CERC’s regulatory asset balance was reduced to reflect the disallowance. CERC filed a petition for reconsideration on November 8, 2022 and a written order denying the petition for reconsideration was issued on January 6, 2023. As of December 31, 2024 and 2023, as authorized by the PUCT, both CenterPoint Energy and Houston Electric had each recorded a regulatory asset of $8 million for bad debt expenses resulting from REPs’ default on their obligation to pay delivery charges to Houston Electric net of collateral. Additionally, both CenterPoint Energy and Houston Electric had each recorded a regulatory asset of $19 million and $17 million as of December 31, 2024 and 2023, respectively, and requested reimbursement of costs associated with the February 2021 Winter Storm Event in Houston Electric’s rate case, which was filed in March 2024. On January 29, 2025 Houston Electric announced that a settlement agreement was reached with certain parties to the rate case filed on March 6, 2024, including the City of Houston and other regional municipalities. Subject to PUCT review and approval, the settlement is expected to result in approximately $50 million less annual revenue and an average decrease of approximately $1 a month for residential customers based on average usage of 1,000 kWh per month. See Note 14(d) for further information regarding litigation related to the February 2021 Winter Storm Event. Texas Public Securitization The Texas Natural Gas Securitization Finance Corporation issued customer rate relief bonds in March 2023, and on March 23, 2023, CenterPoint Energy and CERC, collectively, received approximately $1.1 billion in cash proceeds from the issuance and sale of the state’s customer rate relief bonds. The proceeds from the state’s customer rate relief bonds included carrying costs incurred through August 2022. Incremental carrying costs incurred after August 2022 until the date the proceeds were received are recorded in a separate regulatory asset; the most recent CERC rate proceeding in Texas included a request for recovery of this regulatory asset and was included in the settlement agreement approved by the Railroad Commission in June 2024. As CenterPoint Energy and CERC have no future financial obligations for the repayment of the state’s customer rate relief bonds, the customer rate relief bonds are not recorded on CenterPoint Energy’s or CERC’s balance sheets. The state’s customer rate relief bonds are backed in part by customer rate relief property, including customer rate relief charges, which are non-bypassable uniform monthly volumetric charges to be paid by all existing and future sales customers as a component of each regulated utility’s gas cost, separate from their base rate. CERC only acts as a collection agent, whose duties include management, servicing and administration of a portion of the customer rate relief property which is associated with the customer rate relief charge imposed on customers of CERC under the guidance and direction from the Railroad Commission. The Texas Natural Gas Securitization Finance Corporation, and not CenterPoint Energy or CERC, is the owner of the customer rate relief property. The assets of the Texas Natural Gas Securitization Finance Corporation are not available to pay creditors of CenterPoint Energy, CERC, or their affiliates. While the customer rate relief charges will be included by CERC in their monthly billings, the billing amount is established by the Railroad Commission. CERC will remit all customer rate relief charges collected to the financing entity set up by the Railroad Commission. Therefore, the collection and servicing of customer rate relief charges have no impact on the respective Statements of Consolidated Income of CenterPoint Energy or CERC. As U.S. GAAP has no specific accounting guidance for government grants or assistance, the cash proceeds from the state’s customer rate relief bonds were accounted for as a government grant by analogy to the grant model under IAS 20—Accounting for Government Grants and Disclosures of Government Assistance. CenterPoint Energy and CERC reflect the proceeds from the grant as a deduction to natural gas costs and recognized the $1.1 billion of cash proceeds from the state’s customer rate relief bonds within Utility natural gas expense on their respective Statements of Consolidated Income in the year ended December 31, 2023, net of the recognition of natural gas cost related to relieving CenterPoint Energy and CERC’s regulatory assets related to the February 2021 Winter Storm Event in the same period. Indiana Electric Securitization of Generation Retirements (CenterPoint Energy) On January 4, 2023, the IURC issued an order in accordance with Indiana Senate Enrolled Act 386 authorizing the issuance of up to $350 million in securitization bonds to securitize qualified costs associated with the retirements of Indiana Electric’s A.B. Brown coal-fired generation facilities. Accordingly, CenterPoint Energy determined that the retirement of property, plant and equipment became probable upon the issuance of the order. No loss on abandonment was recognized in connection with issuance of the order as there was no disallowance of all or part of the cost of the abandoned property, plant and equipment. In the first quarter of 2023, upon receipt of the order, CenterPoint Energy reclassified property, plant and equipment to be recovered through securitization to a regulatory asset and such amounts continued to earn a full return until recovered through securitization. The SIGECO Securitization Subsidiary issued $341 million aggregate principal amount of the SIGECO Securitization Bonds on June 29, 2023. The SIGECO Securitization Subsidiary used a portion of the net proceeds from the issuance of the SIGECO Securitization Bonds to purchase the securitization property from SIGECO. No gain or loss was recognized. The SIGECO Securitization Bonds are secured by the securitization property, which includes the right to recover, through non-bypassable securitization charges payable by SIGECO’s retail electric customers, the qualified costs of SIGECO authorized by the IURC order. The SIGECO Securitization Subsidiary, and not SIGECO, is the owner of the securitization property, and the assets of the SIGECO Securitization Subsidiary are not available to pay the creditors of SIGECO or its affiliates, other than the SIGECO Securitization Subsidiary. SIGECO has no payment obligations with respect to the SIGECO Securitization Bonds except to remit collections of securitization charges as set forth in a servicing agreement between SIGECO and the SIGECO Securitization Subsidiary. The non-bypassable securitization charges are subject to a true-up mechanism. Houston Electric TEEEF Pursuant to legislation passed in 2021, Houston Electric entered into two leases for TEEEF (temporary generation) which are detailed in Note 19. Houston Electric initially sought recovery of the lease costs and the applicable return as of December 31, 2021 under these lease agreements of approximately $200 million in its DCRF application filed with the PUCT on April 5, 2022, and subsequently amended on July 1, 2022, to show temporary generation in a separate Rider TEEEF. A final order was issued on April 5, 2023 approving a revenue requirement of $39 million that results in full recovery of costs requested but lengthens the amortization period for the short-term lease to be collected over 82.5 months. On May 25, 2023, the PUCT issued its order on rehearing which clarified some of the findings but did not change the approval of TEEEF cost recovery. The PUCT’s decision on the first TEEEF filing is now final and non-appealable. On April 5, 2023, Houston Electric made its second TEEEF filing requesting recovery of TEEEF related costs incurred through December 31, 2022, which requested a new annual revenue requirement of approximately $188 million u sing 78 months to amortize the related deferred costs for proposed rates beginning September 2023, a net increase in TEEEF revenues of approximately $149 million. On August 28, 2023, the State Office of Administrative Hearings issued an Order setting interim rates to collect an annual revenue requirement at the filed amount. Interim rates became effective on September 1, 2023, subject to surcharge or refund if they differ from the final rates approved by the PUCT. An agreement in principle was reached which reduced the annual revenue requirement by approximately $35 million based on recovering the balance as of December 31, 2022 over a 102-month amortization period (instead of the 78-month period in the initial filing) and also allowed for revised interim rates (to incorporate the agreement in principle and the initial interim rates that have been in place since September 1, 2023). The updated interim rates were implemented on December 15, 2023 and approved by the PUCT pursuant to its order issued on February 1, 2024 when the PUCT approved the agreement in principle. The PUCT’s decision on the second TEEEF filing is final and non-appealable. On September 11, 2024, the TCA filed a complaint with the PUCT requesting that the PUCT modify its rulings with respect to its prior decisions related to the TEEEF filings made in 2022 and 2023. Specifically, TCA requested that the PUCT end cost recovery and return on investment on all the large 32 MW and 5 MW TEEEF units approved in docket 53442. On October 2, 2024, Houston Electric filed a response to the TCA complaint and requested that the complaint be dismissed due to the principles of res judicata and collateral estoppel. On October 8, 2024, TCA supplemented its complaint and on October 9, 2024, PUCT staff filed a statement of position stating that Houston Electric’s response provided a strong argument for dismissal of the complaint, but also stating that it would be prudent to have a thorough legal argument from TCA. On October 10, 2024, PUCT issued Order No. 2 finding the TCA complaint insufficient and requiring supplemental information or amendment from TCA by October 24, 2024; TCA filed supplemental information on October 24, 2024. On November 14, 2024, PUCT issued Order No. 4 denying the motion to reconsider and extending a deadline. On December 16, 2024, PUCT issued Order No. 5 granting waiver of the requirement for informal disposition and soliciting commission staff recommendation by January 16, 2025. On January 16, 2025, PUCT staff filed a supplemental recommendation recommending that the TCA has not met its requirement to first present its complaint to the City of Houston prior to presenting it to the PUCT. On January 17, 2025 the case was abated until February 28, 2025 to enable the TCA to present its complaint to the City of Houston. On December 19, 2024, Houston Electric announced a proposal to release Houston Electric’s 15 large 27 MW to 32 MW TEEEF units to the San Antonio area prior to the summer of 2025. The proposal is intended to help ERCOT address a potential energy shortfall and Load Shed risk and to provide additional electric generation capacity to support growing energy demand in the greater San Antonio region. Under the proposal, Houston Electric would not receive revenue or profit from ERCOT and would also not charge Houston-area customers for these TEEEF units for the period when they are in San Antonio serving ERCOT, which is currently expected to be for a period of up to two years. Houston Electric would anticipate receiving revenues from one or more future transactions after the period the units are utilized to temporarily serve an energy need in the San Antonio area, and would therefore plan to continue to not charge customers for these units for any future periods. The proposal has not been finalized and is subject to the negotiation of definitive documentation among the relevant parties, as well as being subject to the approval of ERCOT and other stakeholders. It is not certain that mutually agreeable definitive documentation will be entered into at all or that all approvals will be obtained. Houston Electric 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 debt returns, and determined that such regulatory assets remain probable of recovery as of December 31, 2024. Right of use 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. Houston Electric did not record any impairments on its right of use assets or regulatory asset in the years ended December 31, 2024 and 2023. See Note 19 for further information. May 2024 Storm Events Houston Electric’s service territory experienced sudden and destructive severe weather events in May 2024 that included hurricane-like winds and tornadoes. The May 2024 Storm Events caused significant damage to Houston Electric’s electric delivery system. As of December 31, 2024, Houston Electric had recorded $345 million in Property, plant and equipment and $73 million in Regulatory assets, excluding carrying costs, for such restoration costs. Based on currently available information, as of December 31, 2024, Houston Electric estimates that total costs to restore the electric delivery facilities damaged as a result of the May 2024 Storm Events will be approximately $458 million, excluding carrying costs. These preliminary estimates are subject to revision as certain restoration costs are expected to be incurred through the end of 2025. As is common with electric utilities serving coastal regions, the poles, towers, wires, street lights and pole-mounted equipment that comprise Houston Electric’s transmission and distribution system are not covered by property insurance. Houston Electric is deferring certain storm restoration costs as management believes it is probable that such costs will be recovered through the regulatory process. On November 8, 2024, Houston Electric filed an Application for Determination of System Restoration Costs with the PUCT. The application seeks a determination as to the reasonableness and necessity of approximately $502 million of costs (including estimated case processing expenses and carrying costs) incurred or expected to be incurred to restore service following the May 2024 Storm Events. On January 10, 2025, intervenors filed testimony recommending various disallowances ranging from $4.1 million to $101.9 million. On January 17, 2025, PUCT staff filed testimony recommending no adjustments to Houston Electric’s request. Houston Electric’s rebuttal testimony was filed January 21, 2025. On January 29, 2025, the parties represented to the ALJ that a settlement in principle had been reached and requested an abatement to memorialize and finalize the settlement. The case was abated and parties will file finalized settlement documents or a status update by February 26, 2025. Prior to authorizing Houston Electric to recover these costs, the PUCT must first determine the amount of reasonable and necessary system restoration costs. On January 24, 2025, Houston Electric filed a request for a Financing Order for the distribution costs included in the November 8, 2024 Application for Determination of System Restoration Costs. The ultimate recovery of the costs (or a portion thereof) is expected to be sought through the issuance and sale of non-recourse securitization bonds for distribution-related costs and the TCOS capital mechanism for transmission-related costs. However, neither the amount nor timing of the recovery is certain. See Note 12 for further information regarding a term loan facility to fund certain costs related to the May 2024 Storm Events. Hurricane Beryl On July 8, 2024, Hurricane Beryl made landfall in Texas, bringing sustained winds, storm surges and torrential rain into Houston Electric’s service territory. Hurricane Beryl caused significant damage to Houston Electric’s electric delivery system. Based on currently available information, as of December 31, 2024, Houston Electric estimates that total costs to restore the electric delivery facilities damaged as a result of Hurricane Beryl will be approximately $1.1 billion, excluding carrying costs. As of December 31, 2024, Houston Electric had recorded $654 million in Property, plant and equipment and $442 million in Regulatory assets, excluding carrying costs, for such restoration costs. Houston Electric is deferring certain storm restoration costs as management believes it is probable that such costs will be recovered through the regulatory process. Similar to the costs related to the May 2024 Storm Events, insurance coverage was not available for damages to much of our transmission and distribution assets. The ultimate recovery of the costs (or a portion thereof) relating to Hurricane Beryl is expected to be sought through the issuance and sale of non-recourse securitization bonds for distribution-related costs. However, neither the amount nor timing of the recovery is certain.

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