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Electric Operating Revenues
 12 Months Ended
Dec. 31, 2020
Revenue from Contract with Customer [Abstract]  
Electric Operating Revenues Electric Operating Revenues
Revenue Recognition

Electric operating revenues are recorded in the period of energy delivery, which includes estimated amounts for service rendered but unbilled at the end of each accounting period. The determination of the energy sales billed to individual customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each month, amounts of energy delivered to customers since the date of the last meter reading and the corresponding unbilled revenue are
estimated. Unbilled electric revenue is estimated based on daily generation volumes, estimated customer usage by class, line losses, historical trends and experience, applicable customer rates or by using AMS data where available. Amounts billed are generally due within the next month. The Company does not incur incremental costs to obtain contracts for its energy services.

PNM’s wholesale electricity sales are recorded as electric operating revenues and wholesale electricity purchases are recorded as costs of energy sold. Derivative contracts that are subject to unplanned netting are recorded net in earnings. A “book-out” is the planned or unplanned netting of off-setting purchase and sale transactions. A book-out is a transmission mechanism to reduce congestion on the transmission system or administrative burden. For accounting purposes, a book-out is the recording of net revenues upon the settlement of a derivative contract.

Unrealized gains and losses on derivative contracts that are not designated for hedge accounting are classified as economic hedges. Economic hedges are defined as derivative instruments, including long-term power and fuel supply agreements, used to hedge generation assets and purchased power costs. Changes in the fair value of economic hedges are reflected in results of operations, with changes related to economic hedges on sales included in operating revenues and changes related to economic hedges on purchases included in cost of energy sold. See Note 9.

The Company adopted ASU 2014-09 – Revenue from Contracts with Customers (Topic 606) as of January 1, 2018, its required effective date, using the modified retrospective method of adoption. The adoption of ASU 2014-09 did not result in changes to the nature, amount, and timing of the Company’s existing revenue recognition processes or information technology infrastructure. Therefore, the adoption of ASU 2014-09 had no effect on the amount of revenue recorded in 2018 compared to the amount that would have been recorded under prior GAAP, no effect on total electric operating revenues or any other caption within the Company’s financial statements, and no cumulative effect adjustment was recorded. Additional disclosures to further disaggregate 2020, 2019 and 2018 revenues are presented below.

The Company adopted ASU 2018-18 – Collaborative Arrangements (Topic 808) in 2019, ahead of its required effective date, using the retrospective method of adoption. The Company has collaborative arrangements related to its interest in SJGS, Four Corners, PVNGS, and Luna. The Company has determined that during the years ended December 31, 2020, 2019, and 2018 none of the joint owners in its collaborative arrangements were customers under Topic 606. Therefore, the adoption of this standard did not impact the financial statements. The Company will continue to evaluate transactions between collaborative arrangement participants in future periods under the requirements of the new standard.

PNM and TNMP recognize revenue as they satisfy performance obligations, which typically occurs as the customer or end-user consumes the electric service provided. Electric services are typically for a bundle of services that are distinct and transferred to the end-user in one performance obligation measured by KWh or KW. Electric operating revenues are recorded in the period of energy delivery, including estimated unbilled amounts. The Company has elected to exclude all sales and similar taxes from revenue.

Revenue from contracts with customers is recorded based upon the total authorized tariff price at the time electric service is rendered, including amounts billed under arrangements qualifying as an Alternative Revenue Program (“ARP”). ARP arrangements are agreements between PNM or TNMP and its regulator that allow PNM or TNMP to adjust future rates in response to past activities or completed events, if certain criteria are met. ARP revenues are required to be reported separately from contracts with customers. ARP revenues in a given period include the recognition of “originating” ARP revenues (i.e. when the regulator-specific conditions are met) in the period, offset by the reversal of ARP revenues when billed to customers.

Sources of Revenue

Additional information about the nature of revenues is provided below. Additional information about matters affecting PNM’s and TNMP’s regulated revenues is provided in Note 17.
Revenue from Contracts with Customers

PNM

NMPRC Regulated Retail Electric Service – PNM provides electric generation, transmission, and distribution service to its rate-regulated customers in New Mexico. PNM’s retail electric service territory covers a large area of north central New Mexico, including the cities of Albuquerque, Rio Rancho, and Santa Fe, and certain areas of southern New Mexico. Customer rates for retail electric service are set by the NMPRC and revenue is recognized as energy is delivered to the customer. PNM invoices customers on a monthly basis for electric service and generally collects billed amounts within one month.

Transmission Service to Third Parties – PNM owns transmission lines that are interconnected with other utilities in New Mexico, Texas, Arizona, Colorado, and Utah. Transmission customers receive service for the transmission of energy owned by the customer utilizing PNM’s transmission facilities. Customers generally receive transmission services, which are regulated by FERC, from PNM through PNM’s Open Access Transmission Tariff (“OATT”) or a specific contract. Customers are billed based on capacity and energy components on a monthly basis.

Miscellaneous – Beginning on January 1, 2018, PNM acquired a 65 MW interest in SJGS Unit 4, which is held as merchant plant as ordered by the NMPRC (Note 16). PNM sells power from 36 MW of this capacity to a third party at a fixed price that is recorded as revenue from contracts with customers. PNM is obligated to deliver power under this arrangement only when SJGS Unit 4 is operating. Other market sales from this 65 MW interest are recorded in other electric operating revenues.

TNMP

PUCT Regulated Retail Electric Service – TNMP provides transmission and distribution services in Texas under the provisions of TECA and the Texas Public Utility Regulatory Act. TNMP is subject to traditional cost-of-service regulation with respect to rates and service under the jurisdiction of the PUCT and certain municipalities. TNMP’s transmission and distribution activities are solely within ERCOT and not subject to traditional rate regulation by FERC. TNMP provides transmission and distribution services at regulated rates to various REPs that, in turn, provide retail electric service to consumers within TNMP’s service territory. Revenue is recognized as energy is delivered to the consumer. TNMP invoices REPs on a monthly basis and is generally paid within a month.

Transmission Cost of Service (“TCOS”) – TNMP is a transmission service provider that is allowed to recover its TCOS through a network transmission rate that is approved by the PUCT. TCOS customers are other utilities that receive service for the transmission of energy owned by the customer utilizing TNMP’s transmission facilities.

Alternative Revenue Programs

The Company defers certain costs and records certain liabilities pursuant to the rate actions of the NMPRC, PUCT, and FERC. ARP revenues, which are discussed above, include recovery or refund provisions under PNM’s renewable energy rider and true-ups to PNM’s formula transmission rates; TNMP’s AMS surcharge, transmission cost recovery factor, and the impacts of the PUCT’s January 25, 2018 order regarding the change in the federal corporate income tax rate; and the energy efficiency incentive bonus at both PNM and TNMP. Regulatory assets and liabilities are recognized for the difference between ARP revenues and amounts billed under those programs. Regulatory assets and liabilities are amortized into earnings as amounts are billed. As discussed in Note 17, TNMP’s 2018 Rate Case integrated AMS costs into base rates beginning January 1, 2019. These costs are being amortized into earnings as alternative revenues over a period of five years.

Other Electric Operating Revenues

Other electric operating revenues consist primarily of PNM’s sales for resale meeting the definition of a derivative. Derivatives are not considered revenue from contracts with customers. PNM engages in activities meeting the definition of derivatives to optimize its existing jurisdictional assets and long-term power agreements through spot market, hour-ahead, day-ahead, week-ahead, month-ahead, and other sales of excess generation not required to fulfill retail load and contractual commitments.
Disaggregation of Revenues

A disaggregation of revenues from contracts with customers by the type of customer is presented in the table below. The table also reflects ARP revenues and other revenues.
PNMTNMPPNMR Consolidated
Year Ended December 31, 2020(In thousands)
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential$482,852 $158,066 $640,918 
Commercial392,257 118,243 510,500 
Industrial90,845 27,367 118,212 
Public authority23,126 5,853 28,979 
Economy energy service15,911 — 15,911 
Transmission59,856 78,374 138,230 
Miscellaneous13,311 3,738 17,049 
Total revenues from contracts with customers
1,078,158 391,641 1,469,799 
Alternative revenue programs(3,531)(8,463)(11,994)
Other electric operating revenues65,207 — 65,207 
Total Electric Operating Revenues
$1,139,834 $383,178 $1,523,012 
Year Ended December 31, 2019
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential$427,883 $150,742 $578,625 
Commercial396,987 116,953 513,940 
Industrial69,601 22,405 92,006 
Public authority20,322 5,694 26,016 
Economy energy service25,757 — 25,757 
Transmission57,214 66,948 124,162 
Miscellaneous13,134 3,568 16,702 
Total revenues from contracts with customers
1,010,898 366,310 1,377,208 
Alternative revenue programs1,987 (2,529)(542)
Other electric operating revenues80,937 — 80,937 
Total Electric Operating Revenues
$1,093,822 $363,781 $1,457,603 
Year Ended December 31, 2018
Electric Operating Revenues:
Contracts with customers:
Retail electric revenue
Residential$433,009 $130,288 $563,297 
Commercial408,333 111,261 519,594 
Industrial61,119 17,317 78,436 
Public authority21,688 5,609 27,297 
Economy energy service26,764 — 26,764 
Transmission54,280 66,991 121,271 
Miscellaneous14,098 8,983 23,081 
Total revenues from contracts with customers
1,019,291 340,449 1,359,740 
Alternative revenue programs(2,443)4,199 1,756 
Other electric operating revenues75,117 — 75,117 
Total Electric Operating Revenues
$1,091,965 $344,648 $1,436,613 
Contract Balances

Performance obligations related to contracts with customers are typically satisfied when the energy is delivered and the customer or end-user utilizes the energy. Accounts receivable from customers represent amounts billed, including amounts under ARP programs. For PNM, accounts receivable reflected on the Consolidated Balance Sheets, net of allowance for credit losses, includes $86.2 million and $59.3 million at December 31, 2020 and 2019 resulting from contracts with customers. All of TNMP’s accounts receivable results from contracts with customers. On January 1, 2020, the Company adopted Accounting Standards Update 2016-13 – Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. As a result of the adoption of the new standard and economic conditions resulting from the COVID-19 pandemic, PNM updated its allowance for accounts receivable balances and recorded incremental credit losses of $7.2 million in the year ended December 31, 2020. The NMPRC issued an order authorizing all public utilities to create a regulatory asset to defer incremental costs related to COVID-19, including increases in uncollectible accounts. See additional discussion of ASU 2016-13 in Note 9 and the related regulatory treatment in Note 17.

Contract assets are an entity’s right to consideration in exchange for goods or services that the entity has transferred to a customer when that right is conditioned on something other than the passage of time (for example, the entity’s future performance). The Company has no contract assets as of December 31, 2020. Contract liabilities arise when consideration is received in advance from a customer before satisfying the performance obligations. Therefore, revenue is deferred and not recognized until the obligation is satisfied. Under its OATT, PNM accepts upfront consideration for capacity reservations requested by transmission customers, which requires PNM to defer the customer’s transmission capacity rights for a specific period of time. PNM recognizes the revenue of these capacity reservations over the period it defers the customer’s capacity rights. Other utilities pay PNM and TNMP in advance for the joint-use of their utility poles. These revenues are recognized over the period of time specified in the joint-use contract, typically for one calendar year. Deferred revenues on these arrangements are recorded as contract liabilities. PNMR’s, PNM’s, and TNMP’s contract liabilities and related revenues are insignificant for all periods presented. The Company has no other arrangements with remaining performance obligations to which a portion of the transaction price would be required to be allocated.