XML 58 R32.htm IDEA: XBRL DOCUMENT
v3.22.1

Regulatory and Rate Matters | 3 Months Ended
--- | ---
Mar. 31, 2022
Regulated Operations [Abstract] |
Regulatory and Rate Matters | Regulatory and Rate Matters The Company is involved in various regulatory matters, some of which contain contingencies that are subject to the same uncertainties as those described in Note 11. Additional information concerning regulatory and rate matters is contained in Note 17 of the Notes to Consolidated Financial Statements in the 2021 Annual Reports on Form 10-K. PNMR Merger Regulatory Proceedings On October 20, 2020, PNMR, Avangrid and Merger Sub entered into the Merger Agreement pursuant to which Merger Sub will merge with and into PNMR, with PNMR surviving the Merger as a wholly-owned subsidiary of Avangrid. Among other conditions, consummation of the Merger is subject to receipt of all required regulatory approvals. Five federal agencies and the PUCT have completed their reviews and approved the Merger, leaving the NMPRC as the only remaining approval necessary for the Merger. The original application before the NMPRC was filed in November 2020. For additional information on the Merger regulatory proceedings see Note 17. PNM Renewable Energy Portfolio Standard As discussed in Note 11, the ETA, enacted on June 14, 2019, amends the REA including removal of diversity requirements and certain customer caps and exemptions relating to the application of the RPS under the REA. The REA provides for streamlined proceedings for approval of utilities’ renewable energy procurement plans, assures that utilities recover costs incurred consistent with approved procurement plans, and requires the NMPRC to establish a RCT for the procurement of renewable resources to prevent excessive costs being added to rates. The ETA sets a RCT of $60 per MWh using an average annual levelized resource cost basis. PNM makes renewable procurements consistent with the NMPRC approved plans and recovers certain renewable procurement costs from customers through the renewable energy rider billed on a KWh basis. Included in PNM’s approved procurement plans are the following renewable energy resources: •158 MW of PNM-owned solar-PV facilities •A PPA through 2044 for the output of New Mexico Wind, having a current aggregate capacity of 200 MW, and a PPA through 2035 for the output of Red Mesa Wind, having an aggregate capacity of 102 MW •A PPA through 2040 for 140 MW of output from La Joya Wind II •A PPA through 2042 for the output of the Lightning Dock Geothermal facility with a current capacity of 11 MW •Solar distributed generation, aggregating 211.8 MW at March 31, 2022, owned by customers or third parties from whom PNM purchases any net excess output and RECs The NMPRC has authorized PNM to recover certain renewable procurement costs through a rate rider billed on a per KWh basis. In its 2022 renewable energy procurement plan, which became effective on January 1, 2022, PNM proposed to collect $66.9 million for the year. PNM recorded revenues from the rider of $14.5 million and $15.9 million in the three months ended March 31, 2022 and 2021. Under the renewable rider, if PNM’s earned rate of return on jurisdictional equity in a calendar year, adjusted for items not representative of normal operations, exceeds the NMPRC-approved rate by 0.5%, PNM is required to refund the excess to customers during May through December of the following year. PNM did not exceed such limitation in 2021. The NMPRC currently has an open inquiry docket into the continued use of renewable riders by New Mexico utilities. PNM is unable to predict the outcome of the NMPRC's inquiry. Energy Efficiency and Load Management Program Costs and Incentives/Disincentives The New Mexico Efficient Use of Energy Act (“EUEA”) requires public utilities to achieve specified levels of energy savings and to obtain NMPRC approval to implement energy efficiency and load management programs. The EUEA requires the NMPRC to remove utility disincentives to implementing energy efficiency and load management programs and to provide incentives for such programs. The NMPRC has adopted a rule to implement this Act. PNM’s costs to implement approved programs and incentives are recovered through a rate rider. During the 2019 New Mexico legislative session, the EUEA was amended to, among other things, include a decoupling mechanism for disincentives, preclude a reduction to a utility’s ROE based on approval of disincentive or incentive mechanisms, establish energy savings targets for the period 2021 through 2025, and require that annual program funding be 3% to 5% of an electric utility's annual customer bills excluding gross receipt taxes, franchise and right-of-way access fees, provided that a customer's annual cost not exceed seventy-five thousand dollars. On April 15, 2021, PNM filed its 2020 Energy Efficiency Annual Report which reconciles the actual 2020 profit incentive collections with the profit incentive authorized by the NMPRC resulting in an additional $0.8 million incentive collected during the remainder of 2021. The additional incentive was authorized for 2020 because annual energy savings for the year exceeded 87 GWh, and was the maximum level of profit incentive allowed under the approved mechanism. PNM began collecting the additional incentive effective May 27, 2021. On April 15, 2022, PNM filed an Advice Notice which reconciles the actual 2021 energy efficiency profit incentive collections with the profit incentive authorized by the NMPRC resulting in an additional $0.3 million incentive to be collected through the energy efficiency rider during the remainder of 2022. The additional incentive was authorized for 2021 because annual energy savings for the year exceeded 94 GWh. PNM will begin collecting the incentive effective May 31, 2022, unless suspended by the NMPRC. On April 15, 2020, PNM filed an application for energy efficiency and load management programs to be offered in 2021, 2022, and 2023. The proposed program portfolio consists of twelve programs with a total annual budget of $31.4 million in 2021, $31.0 million in 2022, and $29.6 million in 2023. The application also sought approval of an annual base incentive of 7.1% of the portfolio budget if PNM were to achieve energy savings of at least 80 GWh in a year. The proposed incentive, as modified in rebuttal testimony, would increase if PNM is able to achieve savings greater than 94 GWh in a year. On September 17, 2020, the hearing examiner in the case issued a recommended decision recommending that PNM's proposed energy efficiency and load management program be approved. On October 28, 2020, the NMPRC issued an order adopting the recommended decision in its entirety. 2020 Decoupling Petition As discussed above, the legislature amended the EUEA to, among other things, include a decoupling mechanism for disincentives. On May 28, 2020, PNM filed a petition for approval of a rate adjustment mechanism that would decouple the rates of its residential and small power rate classes. Decoupling is a rate design principle that severs the link between the recovery of fixed costs of the utility through volumetric charges. PNM proposed to record the difference between the annual revenue per customer derived from the cost of service approved in the NM 2015 Rate Case and the annual revenue per customer actually recovered from the rate classes beginning on January 1, 2021. If approved, PNM would collect the difference from customers if the revenue per customer from the NM 2015 Rate Case exceeds the actual revenue recovered, or return the difference to customers if the actual revenue per customer recovered exceeds the revenue per customer from the NM 2015 Rate Case. On July 13, 2020, NEE, ABCWUA, the City of Albuquerque, and Bernalillo County filed motions to dismiss the petition on the grounds that approving PNM’s proposed rate adjustment mechanism outside of a general rate case would result in retroactive ratemaking and piecemeal ratemaking. The motions to dismiss also allege that PNM’s proposed rate adjustment mechanism is inconsistent with the EUEA. Responses to the motions to dismiss were filed on August 7, 2020. On September 16, 2020, ABCWUA, Bernalillo County, CCAE, the City of Albuquerque, NEE, NMAG, NMPRC Staff ("Staff"), and WRA filed testimony. CCAE and WRA supported PNM's petition, but recommended that the rate adjustment mechanism not take effect until new rates are approved in PNM's next general rate case. The other parties filing testimony opposed PNM's petition. On October 2, 2020, PNM requested an order to vacate the public hearing, scheduled to begin October 13, 2020, and staying the proceeding until the NMPRC decides whether to entertain a petition to issue a declaratory order resolving the issues raised in the motions to dismiss. On October 7, 2020, the hearing examiner approved PNM's request to stay the proceeding and vacate the public hearing and required PNM to file a petition for declaratory order by October 30, 2020. On October 30, 2020, PNM filed a petition for declaratory order asking the NMPRC to issue an order finding that full revenue decoupling is authorized by the EUEA. On November 4, 2020, ABCWUA and Bernalillo County jointly filed a competing petition asking the NMPRC to issue a declaratory order on the EUEA’s requirements related to disincentives. On November 24, 2020, the NMAG requested that the NMPRC deny both petitions for declaratory orders and instead address disincentives under the EUEA in a rulemaking. On March 17, 2021, the NMPRC issued an order granting the petitions for declaratory order, commencing a declaratory order proceeding to address the petitions, denying the NMAG’s request to initiate a rulemaking, and appointing a hearing examiner to preside over the declaratory order proceeding. Initial briefs were filed on June 7, 2021 and response briefs were filed on June 28, 2021. Oral arguments were made on July 15, 2021. On January 14, 2022, the hearing examiner issued a recommended decision recommending the NMPRC find that the EUEA does not mandate the NMPRC to authorize or approve a full decoupling mechanism, defining full decoupling as limited to energy efficiency and load management measures and programs. The recommended decision also states that a utility may request approval of a rate adjustment mechanism to remove regulatory disincentives to energy efficiency and load management measures and programs through a stand-alone petition, as part of the utility’s triennial energy efficiency application or a general rate case and that PNM is not otherwise precluded from petitioning for a rate adjustment mechanism prior to its next general rate case. Finally, the recommended decision stated that the EUEA does not permit the NMPRC to reduce a utility’s ROE based on approval of a disincentive removal mechanism founded on removing regulatory disincentives to energy efficiency and load management measures and programs. The recommended decision does not specifically prohibit a downward adjustment to a utility’s capital structure, based on approval of a disincentive removal mechanism. On April 27, 2022, the NMPRC issued an order adopting the recommended decision in its entirety. PNM cannot predict the outcome of this matter. Integrated Resource Plans NMPRC rules require that investor-owned utilities file an IRP every three years. The IRP is required to cover a 20-year planning period and contain an action plan covering the first four years of that period. 2020 IRP NMPRC rules required PNM to file its 2020 IRP in July 2020. On March 16, 2020, PNM filed a motion to extend the deadline to file its 2020 IRP to six months after the NMPRC issues a final order approving a replacement resource portfolio and closes the docket in the bifurcated SJGS Abandonment Application and replacement resource proceedings. On April 8, 2020, the NMPRC approved PNM's motion to extend the deadline to file its 2020 IRP as requested. On January 29, 2021, PNM filed its 2020 IRP addressing the 20-year planning period, from 2020 through 2040. The plan focuses on a carbon-free electricity portfolio by 2040 that would eliminate coal at the end of 2024. This includes replacing the power from San Juan with a mix of approved carbon-free resources and the plan to exit Four Corners at the end of 2024. The plan highlights the need for additional investments in a diverse set of resources, including renewables to supply carbon-free power, energy storage to balance supply and demand, and efficiency and other demand-side resources to mitigate load growth. On May 24, 2021, the hearing examiner issued a procedural schedule and required PNM, upon request, to provide modeling data and assumptions to parties within two weeks. Additionally, PNM was required upon request, to run modeling or provide reasonable access to PNM virtual machines at PNM's expense. The alternative modeling deadline concluded on August 30, 2021 and Staff's recommendation was filed on November 12, 2021. The recommendation found that PNM has met the requirements of the IRP rule, but not the requirements of the NM 2016 Rate Case. On April 6, 2022, the NMPRC issued an order requiring PNM to update its 2020 IRP and to identify material events, including the SJGS extension and replacement resource delays, and the related impact to its plan. On April 27, 2022, PNM responded to the NMPRC order, as required. PNM cannot predict the outcome of this matter. Abandonment Applications made under the ETA As discussed in Note 11, the ETA sets a statewide standard that requires investor-owned electric utilities to have specified percentages of their electric-generating portfolios be from renewable and zero-carbon generating resources. The ETA also provides for a transition from fossil-fuel generation resources to renewable and other carbon-free resources through certain provisions relating to the abandonment of coal-fired generating facilities. These provisions include the use of energy transition bonds, which are designed to be highly rated bonds that can be issued to finance certain costs of abandoning coal-fired facilities that are retired prior to January 1, 2023, for facilities operated by a “qualifying utility,” or prior to January 1, 2032, for facilities that are not operated by the qualifying utility. SJGS Abandonment Application On July 1, 2019, PNM filed a Consolidated Application for the Abandonment and Replacement of SJGS and Related Securitized Financing Pursuant to the ETA (the “SJGS Abandonment Application”). The SJGS Abandonment Application sought NMPRC approval to retire PNM’s share of SJGS after the existing coal supply and participation agreements end in June 2022, for approval of replacement resources, and for the issuance of energy transition bonds. PNM's application proposed several replacement resource scenarios. The SJGS Abandonment Application also included a request to issue approximately $361 million of energy transition bonds (the “Securitized Bonds”). PNM’s request for the issuance of Securitized Bonds included approximately $283 million of forecasted undepreciated investments in SJGS at June 30, 2022, an estimated $28.6 million for plant decommissioning and coal mine reclamation costs, approximately $9.6 million in upfront financing costs, and approximately $20.0 million for job training and severance costs for affected employees. Proceeds from the Securitization Bonds would also be used to fund approximately $19.8 million for economic development in the four corners area. On July 10, 2019, the NMPRC issued an order requiring the SJGS Abandonment Application be considered in two proceedings: one addressing SJGS abandonment and related financing, and the other addressing replacement resources. The NMPRC indicated that PNM's July 1, 2019 filing is responsive to the January 30, 2019 order. Hearings on the abandonment and securitized financing proceedings were held in December 2019 and hearings on replacement resources were held in January 2020. On February 21, 2020, the hearing examiners issued two recommended decisions recommending approval of PNM’s proposed abandonment of SJGS, subject to approval of replacement resources, and approval of PNM’s proposed financing order to issue Securitized Bonds. The hearing examiners recommended that PNM be authorized to abandon SJGS by June 30, 2022, and to record regulatory assets for certain other abandonment costs that are not specifically addressed under the provisions of the ETA to preserve its ability to recover the costs in a future general rate case. The hearing examiners recommended that this authority only extend to the deferral of the costs and it not be an approval of any ratemaking treatment. The hearing examiners also recommended PNM be authorized to issue Securitized Bonds of up to $361 million and establish a rate rider to collect non-bypassable customer charges for repayment of the bonds and be subject to bi-annual adjustments (the "Energy Transition Charge"). The hearing examiners recommended an interim rate rider adjustment upon the start date of the Energy Transition Charge to provide immediate credits to customers for the full value of PNM’s revenue requirement related to SJGS until those reductions are reflected in base rates. In addition, the hearing examiners recommended PNM be granted authority to establish regulatory assets to recover costs that PNM will pay prior to the issuance of the Securitized Bonds, including costs associated with the bond issuances as well as for severances, job training, economic development, and workforce training. On April 1, 2020, the NMPRC unanimously approved the hearing examiners' recommended decisions regarding the abandonment of SJGS and the related securitized financing under the ETA. On April 10, 2020, CFRE and NEE filed a notice of appeal with the NM Supreme Court of the NMPRC's approval of PNM's request to issue securitized financing under the ETA. The NM Supreme Court granted motions to intervene filed by PNM, WRA, CCAE, and the Sierra Club. On May 8, 2020, CFRE and NEE filed a joint statement of issues with the NM Supreme Court which asserted that the NMPRC improperly applied the ETA and that the ETA violates the New Mexico Constitution. On August 17, 2020, the appellants filed a Brief in Chief and on October 5, 2020, PNM, WRA, CCAE, and Sierra Club filed Answer Briefs. On January 10, 2022, the NM Supreme Court issued its decision rejecting CFRE’s and NEE’s constitutional challenges to the ETA and affirmed the NMPRC final order. In March 2020, PNMR and PNM recorded obligations of $9.4 million and $8.1 million for estimated severances, $8.9 million for obligations to fund severances and other costs of WSJ LLC employees, and to fund $19.8 million to state agencies for economic development and workforce training upon the issuance of the Securitized Bonds. The total amount recorded for these estimates of $36.9 million and $36.0 million is reflected in other current liabilities and as a corresponding deferred regulatory asset on PNMR's and PNM's Condensed Consolidated Balance Sheets at December 31, 2021. In the three months ended March 31, 2022, PNM paid $8.9 million for obligations to fund severances and other costs of WSJ LLC employees. PNM revised its estimates in the first quarter reflecting other current liabilities of $27.7 million and $26.8 million and deferred regulatory assets of $36.8 million and $35.9 million on PNMR's and PNM's Condensed Consolidated Balance Sheets at March 31, 2022. These estimates may continue to be adjusted in future periods as the Company refines its expectations. On June 24, 2020, the hearing examiners issued a recommended decision on PNM's request for approval of replacement resources that addressed the entire portfolio of replacement resources, which superseded a previous partial recommended decision issued on March 27, 2020. The hearing examiners concluded that the ultimate selection of a portfolio of replacement resources involves policy considerations that are the province of the NMPRC and stated that they did not intend to make that decision for the NMPRC. On July 29, 2020, the NMPRC issued an order approving resource selection criteria identified in the ETA that would include PPAs for 650 MW of solar and 300 MW of battery storage. The order also granted in part PNM’s request for an extension of time for PNM to file the application to implement the replacement resource portfolio. PNM had 60 days from the date of the order to file an application in a separate docket seeking approval of the proposed final executed contracts, for any replacement resources not in evidence that had been approved by the NMPRC. On September 28, 2020, PNM filed its application for approval of the final executed contracts for the replacement resources. In addition, PNM provided updated cost estimates of $8.1 million for the SJGS replacement resources, based on the NMPRC authorization to create regulatory assets granted in the abandonment order, which it plans to seek recovery of in a future general rate case. On November 13, 2020, the hearing examiner issued a recommended decision recommending approval of a 200 MW solar PPA combined with a 100 MW battery storage agreement and the 100 MW solar PPA combined with a 30 MW battery storage agreement. On December 2, 2020, the NMPRC issued an order adopting the recommended decision in its entirety. Throughout 2021 and continuing into 2022, PNM provided notices of delays and status updates to the NMPRC for the approved SJGS replacement resource projects. All four project developers have notified PNM that completion of the projects will be delayed and no longer available for the 2022 summer peak and some may also not be available for the 2023 summer peak. The delays in the SJGS replacement resources, coupled with the abandonment of SJGS Units 1 and 4 present a risk that PNM will not have sufficient operational resources to meet the 2022 summer peak demand and reliably serve its customers unless PNM is able to place additional generation resources in service. In the second half of 2021, PNM entered into three agreements to purchase power from third parties to minimize potential impacts to customers; the purchase of 85 MW, unit contingent from Four Corners for June through September of 2022; the purchase of 150 MW, firm power in June and September 2022; and the purchase of 40 MW, unit contingent from PVNGS Unit 3 for the full year of 2022. After considering these additional contracts, PNM projected a system reserve margin ranging from 0.9% to (3.4%) during the 2022 summer peak. As a result, on February 17, 2022, PNM filed a Notice and Request for Modification to or Variance from Abandonment Date for SJGS Unit 4 with the NMPRC. The filing provided notice that PNM had obtained agreement from the SJGS owners and WSJ LLC to extend operation of SJGS Unit 4 until September 30, 2022. SJGS Unit 4 will provide 327 MW of capacity and improve PNM’s projected system reserve margin to a range from 17.4% to 9.8%. On February 23, 2022, the NMPRC issued an order finding that PNM did not require NMPRC approval to extend operation of SJGS Unit 4 for an additional three-month period. The NMPRC’s order states that issues regarding the prudence or reasonableness of the decisions made, actions taken by PNM, and recoverability of costs related to the continued operation of SJGS Unit 4, including fuel costs collected through PNM’s FPPAC, shall be subject to review in a future proceeding. On February 25, 2022, the amended San Juan Project Participation Agreement was filed with FERC. On March 18, 2022, PNM filed its Compliance Notice updating its January 26, 2022 Compliance Notice indicating that 65 MW of SJGS Unit 4 owned as a deregulated merchant resource will be available to PNM retail operations on a system contingent basis, which increases PNM's projected system reserve margin to a range from 20.7% to 12.5% during the 2022 summer peak. On March 24, 2022, FERC accepted the amended SJGS participation agreement. Given the non-normal geological condition impeding longwall progress in the San Juan Mine, PNM does not know whether reduced levels of coal inventory may continue to impact full load operations through the remainder of the CSA and the projected system reserve margin for the 2022 summer peak. See Note 11. On February 28, 2022, WRA and CCAE filed a Joint Motion for Order to Show Cause and Enforce Financing Order and Supporting Brief, which requests that the NMPRC order PNM to show cause why its rates should not be reduced at the time SJGS is abandoned, and to otherwise enforce the NMPRC’s April 1, 2020 final order. On March 14, 2022, PNM filed its response to the Joint Motion to Show Cause refuting the movants' claims that the ETA and April 1, 2020 Financing Order require energy transition bonds be issued at the time of abandonment and that rates be reduced upon abandonment as not being legally supportable. The movants filed joint replies on March 24, 2022. In response, on March 30, 2022, the NMPRC issued an Order appointing hearing examiners to conduct a hearing, if necessary, and to issue a recommended decision to address the issues raised by the motion. The Order also states that the hearing examiners should endeavor to issue a recommended decision with sufficient time for consideration of exceptions and for the NMPRC to be able to take action prior to June 30, 2022. The hearing examiners issued a procedural order which required PNM to file testimony on April 20, 2022 and scheduled a hearing to begin on May 23, 2022. PNM cannot predict the outcome of this matter. Additional information concerning the SJGS Abandonment Application is contained in Note 17 of the Notes to Consolidated Financial Statements in the 2021 Annual Reports on Form 10-K. Four Corners Abandonment Application On November 1, 2020, PNM entered into the Four Corners Purchase and Sale Agreement with NTEC, pursuant to which PNM will sell its 13% ownership interest (other than certain transmission assets) in Four Corners to NTEC. The sale is contingent upon NMPRC approval and expected to close by the end of 2024. In connection with the sale, PNM would make payments of $75.0 million to NTEC for relief from its obligations under the coal supply agreement for Four Corners after December 31, 2024. Pursuant to the Four Corners Purchase and Sale Agreement, PNM will retain its current plant decommissioning and coal mine reclamation obligations. PNM made an initial payment to NTEC of $15.0 million in November 2020, subject to refund with interest upon termination of the Four Corners Purchase and Sale Agreement prior to closing. Under the terms of the Four Corners Purchase and Sale Agreement, upon receipt of the NMPRC approval, PNM would make a final payment of $60.0 million. The initial $15.0 million payment was recorded in other deferred charges on the Condensed Consolidated Balance Sheet as of March 31, 2022 and December 31, 2021. On January 8, 2021, PNM filed the Four Corners Abandonment Application, which sought NMPRC approval to exit PNM’s share of Four Corners as of December 31, 2024, and issuance of approximately $300 million of energy transition bonds as provided by the ETA. PNM’s request for the issuance of Securitized Bonds included approximately $272 million of forecasted undepreciated investments in Four Corners at December 31, 2024, an estimated $4.6 million for plant decommissioning costs, an estimated $7.3 million in upfront financing costs, and an estimated $16.5 million in economic development. PNM intends to submit a separate application for NMPRC approval of a replacement resource portfolio following NMPRC action on this application. On March 15, 2021, PNM filed an amended application and supplemental testimony for the approval of the abandonment and transfer of Four Corners and issuance of a financing order pursuant to the ETA and a motion to withdraw the January 8, 2021 Four Corners Application. The amended application and supplemental testimony provided additional information to support PNM's request to abandon its interest in Four Corners and transfer that interest to NTEC, and also provided additional detail explaining how the proposed sale and abandonment provides a net public benefit. A hearing began August 31, 2021, briefs were filed October 1, 2021 and response briefs were filed October 13, 2021. On November 12, 2021, the hearing examiner issued a recommended decision recommending approval of the Four Corners Abandonment Application and the corresponding request for issuance of securitized financing. On December 15, 2021, the NMPRC issued a final order rejecting the hearing examiners recommended decision and denying approval of the Four Corners Abandonment Application and the corresponding request for issuance of securitized financing. In its order, the NMPRC concluded that PNM needed to conduct a review of the actual replacement resource portfolio and determined that the record was insufficient to determine the prudence of PNM’s investments in Four Corners. On December 22, 2021, PNM filed a Notice of Appeal with the NM Supreme Court of the NMPRC decision to deny the application. On January 21, 2022, PNM filed a statement of issues outlining the arguments for appeal asserting, among other things, that the NMPRC misinterpreted and improperly applied the ETA in concluding that the NMPRC needed to review the actual replacement resource portfolio before authorizing abandonment and that the NMPRC improperly deferred the issue of prudence with respect to certain of PNM’s investments in Four Corners, where other parties were given the opportunity to present evidence and failed to demonstrate PNM was imprudent in its decisions. On March 24, 2022, PNM filed its Brief in Chief and answer briefs are due from the NMPRC on May 9, 2022. GAAP requires a loss be recognized when it is probable that a loss has been incurred and the amount of loss can be reasonably estimated. As of March 31, 2022, PNM evaluated the NMPRC order in the Four Corners Abandonment Application and determined it was reasonably possible that PNM would be successful in recovery of its undepreciated investment in a future proceeding. Therefore, no loss has been recorded. The financial impact of an early exit of Four Corners and the NMPRC approval process are influenced by many factors outside of PNM’s control, including the overall political and economic conditions of New Mexico. See additional discussion of the ETA in Note 11. PNM cannot predict the outcome of these matters. PVNGS Leased Interest Abandonment Application On April 2, 2021, PNM filed an application with the NMPRC requesting approval for the decertification and abandonment of 114 MW of leased PVNGS capacity, sale and transfer of related assets, and approval to procure new resources ("PVNGS Leased Interest Abandonment Application"). As discussed in Note 13, PNM currently controls leased capacity in PVNGS Unit 1 and Unit 2 under five separate leases ("Leased Interest") that were approved and certificated by the predecessor agency to the NMPRC in the 1980s. Four of the five leases for 104 MW of Leased Interest terminate on January 15, 2023, while the remaining lease for 10 MW of Leased Interest terminates on January 15, 2024. Associated with the Leased Interest are certain PNM-owned assets and nuclear fuel that are necessary for the ongoing operation and maintenance of the Leased Interest and integration of the Leased Interest generation to the transmission network. PNM has determined that there will be net benefits to its customers to return the Leased Interest to the lessors in conformity with the leases, sell and transfer the related PNM-owned assets, and to replace the Leased Interest with new resources. In the application PNM requested NMPRC authorization to decertify and abandon its Leased Interest and to create regulatory assets for the associated remaining undepreciated investments with consideration of cost recovery of the undepreciated investments in a future rate case. PNM also sought NMPRC approval to sell and transfer the PNM-owned assets and nuclear fuel supply associated with the Leased Interest to SRP, which will be acquiring the Leased Interest from the lessors upon termination of the existing leases. In addition, PNM sought NMPRC approval for a 150 MW solar PPA combined with a 40 MW battery storage agreement, and a stand-alone 100 MW battery storage agreement to replace the Leased Interest. To ensure system reliability and load needs are met in 2023, when a majority of the leases expire, PNM also requested NMPRC approval for a 300 MW solar PPA combined with a 150 MW battery storage agreement. PNM's application sought a six-month regulatory time frame. On April 21, 2021, the NMPRC issued an order assigning a hearing examiner and stated PNM's request to abandon the Leased Interest does not have any statutory or rule time limitation and the six-month limit in which the NMPRC must issue an order regarding the request for approvals of the solar PPAs and battery storage agreements does not begin until after the NMPRC acts on the abandonment request. The NMPRC's April 21, 2021 order also stated that issues reserved to a separate proceeding in the NM 2015 Rate Case regarding the decision to permanently disallow recovery of certain future decommissioning costs related to PVNGS Units 1 and 2 shall be addressed in this case and PNM shall file testimony addressing the issue. On June 14, 2021 and June 25, 2021, PNM filed supplemental testimony responding to questions provided by the hearing examiner. On June 28, 2021, NEE and CCAE jointly filed a motion to dismiss a portion of the application claiming that since PNM's request to abandon the Leased Interest was filed after PNM had already provided irrevocable notice it would not acquire the Leased Interest, abandonment is no longer required. On July 28, 2021, the hearing examiner issued a recommended decision on NEE's and CCAE's joint motion to dismiss, recommending dismissal of PNM's requests for approval to abandon and decertify the Leased Interest; dismissal of PNM's request for approval to sell and transfer the related assets; and dismissal of PNM's request to create regulatory assets for the associated remaining undepreciated investments, but did not preclude PNM seeking recovery of the costs in a general rate case in which the test year period includes the time period in which PNM incurs such costs. The hearing examiner's recommended decision further provides that PNM's request for replacement and system reliability resources and the decision to permanently disallow recovery of certain future decommissioning costs related to PVNGS Units 1 and 2 should remain within the scope of this case. On August 25, 2021, the NMPRC issued an order granting portions of the July 28, 2021 recommended decision that were not contested related to dismissal of PNM's request for approval to abandon and decertify the Leased Interest and dismissal of PNM's request for approval to sell and transfer the related assets. In addition, the order bifurcated the issue of approval for the two PPAs and three battery storage agreements into a separate docket so it may proceed expeditiously. On September 8, 2021 the NMPRC issued an order on the remaining issues in the recommended decision. The order found that PNM's request for a regulatory asset to record costs associated with obtaining an abandonment order should be dismissed. However, the requests for regulatory assets associated with the remaining undepreciated investments should be addressed at an evidentiary hearing. On September 20, 2021, ABCWUA, Bernalillo County, NEE and the NMAG filed a joint motion to reconsider the September 8, 2021 NMPRC order. Also, on September 20, 2021, PNM filed a motion for rehearing of the September 8, 2021 order stating that certain requirements of the order would lead to compromising PNM's First Amendment rights. On October 6, 2021, the NMPRC issued an order granting the motions for reconsideration and vacated the September 8, 2021 order, without specifically addressing issues raised in the motions. The hearing on the two PPAs and three battery storage agreements was held on November 12 and 15, 2021 and December 3, 2021 and post-hearing briefing was completed on January 18, 2022. On February 14, 2022, the hearing examiner issued a recommended decision recommending the NMPRC approve the 150 MW solar PPA combined with a 40 MW battery storage agreement, the stand-alone 100 MW battery storage agreement, and the 300 MW solar PPA combined with a 150 MW battery storage agreement. On February 16, 2022, the NMPRC adopted an order approving the recommended decision. On April 15, 2022, PNM made a compliance filing with the NMPRC in which it updated the NMPRC on the status of the PPAs and the battery storage agreements listed above. It has been determined that the projects will not be in commercial operation in time for the 2023 summer peak. PNM is conferring with project developers and is unable to predict the outcome of this matter. In addition to approval by the NMPRC, PNM and SRP received NRC approval for the transfer of the associated possessory licenses at the end of the term of each of the respective leases. PNM cannot predict the outcome of this matter. COVID-19 Regulatory Matters In March 2020, PNM and other utilities voluntarily implemented a temporary suspension of disconnections and late payment fees for non-payment of utility bills in response to the impacts of COVID-19. On March 18, 2020, the NMPRC conducted an emergency open meeting for the purpose of adopting emergency amendments to its rules governing service to residential customers. The NMPRC’s emergency order was applicable during the duration of the Governor of New Mexico's emergency executive order and allowed for the closure of payment centers, prohibited the discontinuance of a residential customer’s service for non-payment, and suspended the expiration of medical certificates for certain customers. On April 27, 2020, PNM, El Paso Electric Company, New Mexico Gas Company, and Southwestern Public Service Company filed a joint motion with the NMPRC requesting authorization to track costs resulting from each utility's response to the COVID-19 outbreak. The utilities proposed these incremental costs and uncollected customer accounts receivable resulting from COVID-19 during the period March 11, 2020 through December 31, 2020, be recorded as a regulatory asset. On June 24, 2020, the NMPRC issued an order authorizing all public utilities regulated by the NMPRC to create a regulatory asset to defer incremental costs related to COVID-19, including increases to bad debt expense incurred during the period beginning March 11, 2020 through the termination of the Governor of New Mexico’s emergency executive order. The NMPRC order requires public utilities creating regulatory assets to pursue all federal, state, or other subsidies available, to record a regulatory liability for all offsetting cost savings resulting from the COVID-19 pandemic, and allows PNM to request recovery in future ratemaking proceedings. As a result, PNM had deferred costs related to COVID-19 of $6.8 million and $6.9 million in regulatory assets on the Condensed Consolidated Balance Sheet at March 31, 2022 and December 31, 2021. In addition, PNM has costs savings related to COVID-19 of $0.9 million in regulatory liabilities on the Condensed Consolidated Balance Sheet at both March 31, 2022 and December 31, 2021. Although PNM still intends to seek recovery for the increase in bad debt expense resulting from COVID-19 through a regulatory asset in a future general rate case proceeding, it no longer intends to seek recovery of other incremental costs related to the pandemic. On February 3, 2021, the NMPRC issued an order finding that the temporary mandatory moratorium on disconnections of residential utility customers would be in effect from the date of the order for 100 days, which ended May 14, 2021. At the end of the moratorium, the 90-day transition period began, which continued the temporary moratorium on disconnections to provide the utilities additional time to assist residential customers with arrearages to enter into installment agreements. On July 14, 2021, the NMPRC issued an order clarifying previous orders that the mandatory requirements of the NMPRC's previous order prohibiting residential disconnects should be voluntarily complied with by investor-owned utilities until August 12, 2021. PNM began disconnections at the end of the transition period. Transportation Electrification Program On December 18, 2020, in compliance with New Mexico Statute, PNM filed its PNM 2022-2023 TEP for approval with the NMPRC. PNM’s requested TEP included a budget of approximately $8.4 million with flexibility of 25%. As proposed, up to 25% of the program budget will be dedicated to low and moderate income customers and is based on a model with no company ownership of charging facilities. PNM’s proposed TEP provides incentives through rebates to both residential and non-residential customers towards the purchase of chargers and/or behind-the-meter infrastructure. PNM’s TEP includes a request for a modified rate to add an electric vehicle pilot with a time-of-use option, a new non-residential electric vehicle time-of-use rate pilot without demand charges and implementation of a new rider to collect the actual costs of the TEP. PNM’s application requested NMPRC approval by the end of August 2021 and authority to file a new TEP by the end of June 2023. On August 30, 2021, the hearing examiner issued a recommended decision approving, among other things, PNM's budget flexibility proposal, PNM's proposed pilot time-of-use rate and PNM's TEP Rider. On November 10, 2021, the NMPRC issued a final order approving PNM's TEP. The Community Solar Act On June 18, 2021, Senate Bill 84, known as the Community Solar Act, became effective. The Community Solar Act establishes a program that allows for the development of community solar facilities and provides customers of a qualifying utility with the option of accessing solar energy produced by a community solar facility in accordance with the Community Solar Act. The NMPRC is charged with administering the Community Solar Act program, establishing a total maximum capacity of 200 MW community solar (applicable until November 2024) facilities and allocating proportionally to the New Mexico electric investor-owned utilities and participating cooperatives. As required under the Community Solar Act, the NMPRC opened a docket on May 12, 2021 to adopt rules to establish a community solar program no later than April 1, 2022. On June 15, 2021, the NMPRC issued an order which required utilities provide a notice to all future applicants and to any likely applicants that, until the effective date of the NMPRC's rules in this area the NMPRC's existing interconnection rules and manual remain in place until amended or replaced by the NMPRC, and further, that a place in a utility's applicant queue for interconnection does not and will not provide any advantage for selection as a community solar project. PNM has provided the required notices. On October 27, 2021, the NMPRC adopted an order issuing a NOPR starting the formal process for adoption of rules pursuant to the Community Solar Act. On March 30, 2022, the NMPRC issued an Order that adopted a rule on the administration of the Community Solar Act program. The rule requires utilities to file proposed community solar tariffs with the NMPRC within 60 days from the publication of the rule. San Juan Generating Station Unit 1 Outage On June 30, 2021, a cooling tower used for SJGS Unit 1 failed resulting in a unit outage. SJGS Unit 1 was brought back online on July 25, 2021. PNM anticipates the damages to the facility will be reimbursed under an existing property insurance policy that covers SJGS, subject to a deductible of $2.0 million. PNM’s share of the deductible is $1.0 million, reflecting PNM’s 50% ownership interest in SJGS Unit 1. On July 14, 2021, the NMPRC issued an order opening a formal docket and inquiry into the cooling tower incident. PNM has responded to a number of NMPRC questions in the inquiry, including questions about the cause of the cooling tower failure, cost and progress of the cleanup and remediation, whether customers experienced loss of service, how PNM provided power during the outage, safety practices and procedures at SJGS, and the history of inspections on the cooling towers. PNM cannot predict the outcome of this matter. Formula Transmission Rates PNM charges wholesale electric transmission service customers using a formula rate mechanism pursuant to which wholesale transmission service rates are calculated annually in accordance with an approved formula. The formula reflects a ROE of 10% and includes updating cost of service components, including investment in plant and operating expenses, based on information contained in PNM’s annual financial report filed with FERC, as well as including projected large transmission capital projects to be placed into service in the following year. The projections included are subject to true-up in the following year formula rate. Certain items, including changes to return on equity and depreciation rates, require a separate filing to be made with FERC before being included in the formula rate. On April 21, 2022, FERC instituted a show cause proceeding under Section 206 of the Federal Power Act to investigate the justness and reasonableness of PNM's transmission formula rate protocols. The Order directs PNM, within 60 days to revise its formula rate protocols to provide interested parties the information necessary to understand and evaluate the implementation of the formula rate for both the correctness of inputs and calculations, and the reasonableness and prudence of the costs to be recovered in the formula rate or show cause why it should not be required to do so. PNM is unable to predict the outcome of this matter. Unexecuted Transmission Service Agreements (TSAs) with Leeward Renewable Energy On March 12, 2021, PNM filed four unexecuted TSAs with FERC totaling 145 MW with Leeward. The unexecuted TSAs provide long-term firm, point-to-point transmission service on PNM’s transmission system. The unexecuted TSAs are based on the pro-forma transmission service agreements with certain non-conforming provisions under Attachment A of PNM’s OATT and include PNM’s OATT rate. PNM is filing the unexecuted TSAs at the request of Leeward because the parties have been unable to reach an agreement on the terms and conditions for transmission service. In particular, Leeward believes the rate under the unexecuted TSAs should be an incremental rate while PNM believes the appropriate rate is its OATT rate. On April 2, 2021, Leeward and Pattern Wind separately protested PNM’s March 12, 2021 filing of four unexecuted TSAs with Leeward. The parties are requesting that FERC direct PNM to apply the same rate to the unexecuted TSAs as the incremental rate assessed to the Western Spirit transmission facilities, inclusive of Leeward’s network upgrades and requested service, or, in the alternative, initiate hearing and settlement judge procedures to address the unjust and unreasonable application of the FERC’s “higher of” policy. On April 19, 2021, PNM filed a motion for leave to answer and contested the arguments made by Leeward and Pattern Wind. In its response, PNM stated that it disagrees with the parties' pricing scheme because doing so would not recognize all the transmission facilities necessary to provide Leeward service, does not hold PNM's other transmission customers harmless, and is inconsistent with FERC pricing policy and precedent. PNM further explained that the proposal to include its FERC approved embedded rate in the unexecuted TSAs is just and reasonable and should be accepted by FERC. On May 11, 2021, FERC issued an order accepting PNM's four unexecuted TSAs. In the order, FERC stated that it agreed with PNM's pricing scheme and agreed that PNM's proposal to use the OATT rate will ensure that the benefit of Leeward's addition to the system will be spread among other existing system users, rather than simply transferred to Pattern Wind. On June 10, 2021, Pattern Wind and Leeward both filed a request for rehearing of the FERC Order. On September 10, 2021, Leeward filed a petition in the United States District Court for the District of Columbia for review of FERC's order accepting PNM's four unexecuted TSAs. On November 15, 2021, FERC issued an order denying the rehearing. On December 3, 2021, Leeward filed an Unopposed Motion for Voluntary Dismissal with the United States District Court for the District of Columbia of its petition for review, which was granted on March 22, 2022. This matter is now concluded. FERC Compliance PNM is conducting a comprehensive internal review of its filings with FERC regarding the potential timely filing of certain agreements that contained deviations from PNM’s standard form of service agreement in its OATT and assessing any applicable FERC waivers or refund requirements. Upon completion of the comprehensive review, PNM identified service agreements containing provisions that do not conform to the standard form of agreement on file with FERC. On March 18 and March 21, 2022, PNM filed applications with FERC requesting acceptance of certain agreements as well as rejection of other non-conforming service agreements and further requesting that FERC not assess time-value refunds on the accepted agreements. No parties commented or intervened on PNM's application and FERC action must be taken by May 17 and May 20, 2022. PNM is unable to predict the outcome of this matter. TNMP Transmission Cost of Service Rates TNMP can update its TCOS rates twice per year to reflect changes in its invested capital although updates are not allowed while a general rate case is in process. Updated rates reflect the addition and retirement of transmission facilities, including appropriate depreciation, federal income tax and other associated taxes, and the approved rate of return on such facilities. The following sets forth TNMP’s recent interim transmission cost rate increases:
Effective Date |  | Approved Increase in Rate Base |  | Annual Increase in Revenue
|  | (In millions)
March 12, 2021 |  | $ | 112.6 |  |  | $ | 14.1 |
September 20, 2021 |  | $ | 41.2 |  |  | $ | 6.3 |
March 25, 2022 |  | $ | 95.6 |  |  | $ | 14.2 |
Periodic Distribution Rate Adjustment PUCT rules permit interim rate adjustments to reflect changes in investments in distribution assets. Distribution utilities may file for a periodic rate adjustment between April 1 and April 8 of each year as long as the electric utility is not earning more than its authorized rate of return using weather-normalized data. Utilities are limited to four periodic interim distribution rate adjustments between general rate cases. On April 5, 2021, TNMP filed its 2021 DCOS that requested an increase in TNMP annual distribution revenue requirement of $14.0 million based on an increase in rate base of $104.5 million. On July 1, 2021, TNMP reached a unanimous settlement agreement with parties that would authorize TNMP to collect an increase in annual distribution revenues of $13.5 million beginning in September 2021. The ALJ issued an order on July 9, 2021 approving interim rates effective September 1, 2021 that the PUCT approved on September 23, 2021. On April 5, 2022, TNMP filed its 2022 DCOS that requested an increase in TNMP annual distribution revenue requirement of $9.7 million based on an increase in rate base of $100.7 million. Energy Efficiency TNMP recovers the costs of its energy efficiency programs through an energy efficiency cost recovery factor (“EECRF”), which includes projected program costs, under and over collected costs from prior years, rate case expenses, and performance bonuses (if programs exceed mandated savings goals). TNMP’s 2020 EECRF filing requested recovery of $5.9 million, including a performance bonus of $1.0 million, and became effective on March 1, 2021. TNMP's 2021 EECRF filing requested recovery of $7.2 million, including a performance bonus of $2.3 million, and became effective March 1, 2022. COVID-19 Electricity Relief Program On March 26, 2020, the PUCT issued an order establishing an electricity relief program for electric utilities, REPs, and customers impacted by COVID-19. The program allowed providers to implement a rider to collect unpaid residential retail customer bills and to ensure these customers continued to have electric service. In addition, the program provided transmission and distribution providers access to zero-interest loans from ERCOT. Collectively, ERCOT’s loans could not exceed $15 million. The program had a term of six months unless extended by the PUCT. In a separate order, the PUCT authorized electric utilities to establish a regulatory asset for costs related to COVID-19. These costs included but were not limited to costs related to unpaid accounts. TNMP filed its rider on March 30, 2020. The rider was effective immediately and established a charge of $0.33 per MWh in accordance with the PUCT's order. Final collections under the rider exceeded unpaid residential retail customer bills and were presented net as a regulatory liability of $0.1 million on the Condensed Consolidated Balance Sheet as of December 31, 2020. In 2021, TNMP refunded the net regulatory liability through its transmission cost recovery factor. Other COVID-19 related costs of $0.2 million and zero were recorded as a regulatory asset on the Condensed Consolidated Balance Sheet as of March 31, 2022 and December 31, 2021. On August 27, 2020, the PUCT issued an order determining that new enrollments in the program should end on August 31, 2020 and benefits under the program should end on September 30, 2020 to allow eligible customers a minimum of one month of benefits from the program. All requests for reimbursement were made by November 30, 2020. On December 4, 2020, TNMP filed to end collections under the tariff. Final collections under the rider were made on December 11, 2020. On January 14, 2021, TNMP made a final compliance filing for the electricity relief program. AMS Reconciliation On July 14, 2021, TNMP filed a request with the PUCT to consider and approve its final reconciliation of the costs spent on the deployment of AMS from April 1, 2018 through December 31, 2018 of $9.0 million and approve appropriate carrying charges until full collection. On September 13, 2021, the PUCT Staff filed a recommendation for approval of TNMP's application for substantially all costs from April 1, 2018 through December 31, 2018. On February 10, 2022, the PUCT approved substantially all costs included in TNMP's AMS reconciliation application. TNMP will seek recovery of these costs and associated carrying charges in a future general rate proceeding.

X
- Definition Regulatory And Rate Matters [Text Block] + References No definition available. + Details
Name: | pnm_RegulatoryAndRateMattersTextBlock
Namespace Prefix: | pnm_
Data Type: | dtr-types:textBlockItemType
Balance Type: | na
Period Type: | duration

X
- References No definition available. + Details
Name: | us-gaap_RegulatedOperationsAbstract
Namespace Prefix: | us-gaap_
Data Type: | xbrli:stringItemType
Balance Type: | na
Period Type: | duration