Exhibit 13.01
Consolidated Selected Financial Data
Southwest Gas Holdings, Inc.
Year Ended December 31,
(Thousands of dollars, except per share amounts)20202019201820172016
Operating revenues$3,298,873 $3,119,917 $2,880,013 $2,548,792 $2,460,490 
Operating expenses (1)2,875,869 2,748,106 2,522,580 2,205,668 2,145,016 
Operating income (1)$423,004 $371,811 $357,433 $343,124 $315,474 
Net income attributable to Southwest Gas Holdings, Inc.
$232,324 $213,936 $182,277 $193,841 $152,041 
Total assets (2)$8,735,853 $8,170,048 $7,357,729 $6,237,066 $5,581,126 
Capitalization:
Total equity$2,674,953 $2,505,914 $2,251,590 $1,812,403 $1,661,273 
Redeemable noncontrolling interest165,716 84,542 81,831 — 22,590 
Long-term debt, excluding current maturities
2,732,200 2,300,482 2,107,258 1,798,576 1,549,983 
$5,572,869 $4,890,938 $4,440,679 $3,610,979 $3,233,846 
Current maturities of long-term debt$40,433 $163,512 $33,060 $25,346 $50,101 
Common stock data:
Common equity percentage of capitalization48.0 %51.2 %50.7 %50.2 %51.4 %
Return on average common equity9.0 %9.0 %9.3 %11.2 %9.3 %
Basic earnings per share$4.15 $3.94 $3.69 $4.04 $3.20 
Diluted earnings per share$4.14 $3.94 $3.68 $4.04 $3.18 
Dividends declared per share$2.28 $2.18 $2.08 $1.98 $1.80 
Payout ratio55 %55 %56 %49 %56 %
Book value per share $46.77 $45.56 $42.63 $37.74 $35.03 
Market value per share $60.75 $75.97 $76.50 $80.48 $76.62 
Market value to book value per share
130 %167 %180 %213 %219 %
Common shares outstanding (000)
57,193 55,007 53,026 48,090 47,482 
Number of common stockholders
11,765 12,094 12,541 13,077 13,619 
(1)Periods prior to 2018 depict revised Operating expenses and Operating income for the reclassification of non-service cost components of net periodic benefit costs in both the Company’s and Southwest’s Consolidated Statements of Income due to the adoption of ASU 2017-07. Net income overall was not impacted.
(2)In 2019, the Company adopted FASB Topic 842 resulting in the addition of right-of-use (“ROU”) assets in the Company’s Consolidated Balance Sheet. Refer to Note 2 - Utility Plant and Leases in the notes to the consolidated financial statements in this Annual Report to Stockholders.


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Natural Gas Operations
Year Ended December 31,
(Thousands of dollars)20202019201820172016
Operating revenue$1,350,585 $1,368,939 $1,357,728 $1,302,308 $1,321,412 
Net cost of gas sold342,837 385,164 419,388 355,045 397,121 
Operating margin1,007,748 983,775 938,340 947,263 924,291 
Expenses
Operations and maintenance (1)406,382 422,174 404,813 391,321 381,964 
Depreciation and amortization235,295 215,620 191,816 201,922 233,463 
Taxes other than income taxes63,460 62,328 59,898 57,946 52,376 
Operating income (1)$302,611 $283,653 $281,813 $296,074 $256,488 
Contribution to consolidated net income
$159,118 $163,171 $138,842 $156,818 $119,423 
Total assets$7,256,636 $6,798,746 $6,141,584 $5,482,669 $5,001,756 
Net utility plant$6,176,081 $5,685,197 $5,093,238 $4,523,650 $4,131,971 
Construction expenditures and property additions
$692,216 $778,748 $682,869 $560,448 $457,120 
Cash flow, net from:
Operating activities$424,061 $367,794 $382,502 $309,216 $507,224 
Investing activities(677,412)(759,842)(669,392)(557,384)(446,238)
Financing activities253,932 400,575 280,906 267,090 (63,339)
Net change in cash$581 $8,527 $(5,984)$18,922 $(2,353)
Total throughput (thousands of therms):
Residential800,680 818,390 697,011 674,271 684,626 
Small commercial293,164 333,221 305,342 297,677 294,525 
Large commercial91,242 99,326 92,548 92,561 90,949 
Industrial/Other53,154 42,551 37,753 33,816 30,275 
Transportation983,275 1,007,989 1,050,551 974,407 970,561 
Total throughput
2,221,515 2,301,477 2,183,205 2,072,732 2,070,936 
Weighted average cost of gas purchased ($/therm)
$0.28 $0.36 $0.31 $0.44 $0.37 
Customers at year end2,123,000 2,081,000 2,047,000 2,015,000 1,984,000 
Employees at year end2,272 2,295 2,312 2,285 2,247 
Customer to employee ratio935 907 886 882 883 
Degree days – actual1,767 1,917 1,531 1,478 1,613 
Degree days – ten-year average1,676 1,701 1,694 1,733 1,771 
(1)    Periods prior to 2018 depict revised Operations and maintenance expense and Operating income for the reclassification of non-service cost components of net periodic benefit costs in Southwest’s Consolidated Statements of Income due to the adoption of ASU 2017-07. Net income overall was not impacted.
    

 




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Management’s Discussion and Analysis of Financial Condition and Results of Operations
About Southwest Gas Holdings, Inc.
Southwest Gas Holdings, Inc. is a holding company that owns all of the shares of common stock of Southwest Gas Corporation (“Southwest” or the “natural gas operations” segment), and all of the shares of common stock of Centuri Group, Inc. (“Centuri” or the “utility infrastructure services” segment). Southwest Gas Holdings, Inc. and its subsidiaries are collectively referred to as the “Company.”
Southwest is engaged in the business of purchasing, distributing, and transporting natural gas for customers in portions of Arizona, Nevada, and California. Southwest is the largest distributor of natural gas in Arizona, selling and transporting natural gas in most of central and southern Arizona, including the Phoenix and Tucson metropolitan areas. Southwest is also the largest distributor of natural gas in Nevada, serving the majority of southern Nevada, including the Las Vegas metropolitan area, and portions of northern Nevada. In addition, Southwest distributes and transports natural gas for customers in portions of California, including the Lake Tahoe area and the high desert and mountain areas in San Bernardino County.
As of December 31, 2020, Southwest had 2,123,000 residential, commercial, industrial, and other natural gas customers, of which 1,132,000 customers were located in Arizona, 790,000 in Nevada, and 201,000 in California. First-time meter sets were approximately 37,000 in 2020 compared to 35,000 in 2019. The remaining increase in active customer accounts compared to the December 31, 2019 total of 2,081,000 was primarily due to a management-initiated moratorium on disconnections as a result of the COVID-19 pandemic. As utility service is an essential service to the residents in the states in which Southwest operates, it implemented the moratorium in March 2020 and also ceased charging late fees until further notice. The duration of our moratorium is currently uncertain. Residential and commercial customers represented over 99% of the total customer base. During 2020, 52% of operating margin (gas operating revenues less the net cost of gas sold) was earned in Arizona, 36% in Nevada, and 12% in California. During this same period, Southwest earned 85% of its operating margin from residential and small commercial customers, 3% from other sales customers, and 12% from transportation customers. While these general patterns are expected to remain materially consistent for the foreseeable future, the continuing COVID-19 environment could impact these statistics and associated patterns in the short term.
Southwest recognizes operating revenues from the distribution and transportation of natural gas (and related services) to customers. Operating margin is a financial measure defined by management as gas operating revenues less the net cost of gas sold. However, operating margin is not specifically defined in accounting principles generally accepted in the United States (“U.S. GAAP”). Thus, operating margin is considered a non-GAAP measure. Management uses this financial measure because natural gas operating revenues include the net cost of gas sold, which is a tracked cost that is passed through to customers without markup under purchased gas adjustment (“PGA”) mechanisms. Fluctuations in the net cost of gas sold impact revenues on a dollar-for-dollar basis, but do not impact operating margin or operating income. Therefore, management believes operating margin provides investors and other interested parties with useful and relevant information to analyze Southwest’s financial performance in a rate-regulated environment. The principal factors affecting changes in operating margin are general rate relief (including impacts of infrastructure trackers) and customer growth. Commission decisions on the amount and timing of such relief may impact our earnings, such as with the recently concluded Arizona general rate case, whereby hearings were deferred amidst the current pandemic, resulting in both a decision and new rate establishment occurring later than originally expected. Refer to the Summary Operating Results table for a reconciliation of revenues to operating margin, and Rates and Regulatory Proceedings in this Management’s Discussion and Analysis, for details of various rate proceedings.
The demand for natural gas is seasonal, with greater demand in the colder winter months and decreased demand in the warmer summer months. All of Southwest’s service territories have decoupled rate structures (alternative revenue programs), which are designed to eliminate the direct link between volumetric sales and revenue, thereby mitigating the impacts of weather variability and conservation on operating margin, allowing Southwest to pursue energy efficiency initiatives.
Centuri is a comprehensive utility infrastructure services enterprise dedicated to delivering a diverse array of solutions to North America’s gas and electric providers. Centuri derives revenue primarily from installation, replacement, repair, and maintenance of energy distribution systems. Centuri operates in 55 primary locations across 40 states and provinces in the United States (“U.S.”) and Canada. Centuri operates in the U.S. primarily as NPL, Neuco, and Linetec, and in Canada, primarily as NPL Canada.
Utility infrastructure services activity can be impacted by changes in infrastructure replacement programs of utilities, weather, and local and federal regulation (including tax rates and incentives). Utilities continue to implement or modify system integrity management programs to enhance safety pursuant to federal and state mandates. These programs have resulted in multi-year utility system replacement programs throughout the U.S. Generally, Centuri revenues are lowest during the first quarter of the year due to less favorable winter weather working conditions. Revenues typically improve as more favorable weather conditions occur during the summer and fall months. In cases of severe weather, such as following a regional storm, Centuri may be engaged to perform restoration activities related to above-ground utility infrastructure. In certain circumstances, such as


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with large bid contracts (especially those of a longer duration), or unit-price contracts with revenue caps, results may be impacted by differences between costs incurred and those anticipated when the work was originally bid. Work awarded, or failing to be awarded, by individual large customers can impact operating results.
COVID-19 Pandemic
In March 2020, the World Health Organization categorized the novel coronavirus (“COVID-19”) as a pandemic, and it was declared a national emergency in the U.S. The outbreak resulted in government officials implementing stringent measures to help control the spread of the virus, including quarantines, “shelter in place” and “stay at home” orders, travel restrictions, business curtailments, school closures, and other measures. In addition, governments and central banks in several parts of the world enacted fiscal and monetary stimulus measures to mitigate financial impacts of COVID-19 on individuals and businesses.
Our utility operations, as essential services, have been ongoing during this time and Southwest continues to provide services to meet the demand of its customers. Consistent with federal and state guidelines and protocols, Southwest has continued to operate across its territories. Similarly, the majority of Centuri’s largest clients issued essential service letters to Centuri businesses in keeping with the federal definition of “essential” set out by the Department of Homeland Security. This allowed Centuri to similarly continue nearly all operations from the outset of the pandemic in the U.S., and demand has not significantly diminished. For the duration of the pandemic, the ability to work may be impacted by individuals contracting or being exposed to COVID-19, governmental requirements to postpone certain non-essential services in some of the Company’s jurisdictions, or by management-imposed restrictions for safety precautions; to date, these factors have not had a significant impact on the Company’s ability to maintain operations. Employees at many offices (including corporate headquarters) continue to work from home on a temporary basis and travel restrictions largely continue. Both segments initially implemented business continuity plans, including the deployment of technology to conduct administrative and critical functions remotely, where possible, and employees and management teams have effectively communicated and responded quickly to changes. To date, there has not been a significant disruption in the Company’s supply chains, transportation network, or ability to serve customers.
As an essential service provider, Southwest implemented several important measures with regard to its customers. As noted above, it initiated a moratorium on natural gas disconnections for non-payment; it is working with customers who are experiencing financial hardship through flexible payment arrangements; it is coordinating with certain governmental and nonprofit entities for customer payment assistance; and it also ceased charging late fees until further notice. Management has increased the allowance for uncollectibles; however, neither this nor other measures associated with the moratorium have had a material impact on our financial position overall. See Note 4 - Receivables and Related Allowances. In the utility infrastructure services segment, a limited number of Centuri customers delayed some projects, notably during the second quarter of 2020, and primarily in response to local governmental restrictions. Project delays, whether due to governmental restrictions or reassessments of timing by Centuri’s customers, resulted in temporary reductions of workforce crews, primarily during that quarter. Some crew reductions are ongoing in specific areas and the associated revenue impacts have not been significant. Management continues to monitor the dynamic nature of these circumstances, the full future impacts of which are not currently known, such as the impact from business curtailments, weak market conditions, or governmental restrictions, including any restrictions which could limit the fulfillment by Centuri of its contractual obligations.
The Company has incurred additional expenses in connection with its response to these conditions, including costs of disinfecting work locations and equipment, costs related to enabling employees to support customers while working remotely, and impacts on earnings and cash flows from the moratorium on customer disconnection and late fee assessment. These additional costs were not material to the Company’s 2020 results overall, and were mitigated by reduced travel and in-person training costs; important training and business meetings were held virtually, rather than in person. Appropriate access to cash exists and certain of Southwest’s regulatory commissions implemented measures to further mitigate impacts of these conditions on Southwest. See Rates and Regulatory Proceedings for additional detail.
The extent to which COVID-19 may adversely impact the Company’s business depends on future developments, including the timing of the full resumption of commerce across our service territories, the magnitude of further spread of the virus, impacts of these conditions on our customers, the state of the North American economy, the availability and distribution of effective treatments and vaccines, and other unmitigated effects of the virus. Management does not currently expect the impact of these conditions to be material to the Company’s liquidity or financial position; however, continued uncertainty of economic and operational impacts means management cannot predict whether related financial impacts in future periods will be any different from impacts reflected for the period ended December 31, 2020. In anticipation of a redeployment of employees to their normal work locations, management has created a multi-phase reintegration plan to safeguard the well-being of our teams, including hygiene, sanitization, and social distancing practices, as well as the use of personal protective equipment for employees and visitors. Management will continue to monitor developments affecting employees, customers, and operations, and take additional steps as necessary to address impacts from the pandemic. Events and changes in circumstances arising after December 31, 2020, including those resulting from the impacts of COVID-19, will be reflected in management’s estimates for future periods.


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Executive Summary
The items discussed in this Executive Summary are intended to provide an overview of the results of the Company’s operations and are covered in greater detail in later sections of management’s discussion and analysis. As reflected in the table below, the natural gas operations segment accounted for an average of 73% of consolidated net income over the past three years.
Summary Operating Results
Year ended December 31,
(In thousands, except per share amounts)202020192018
Contribution to net income
Natural gas operations$159,118 $163,171 $138,842 
Utility infrastructure services74,862 52,404 44,977 
Corporate and administrative(1,656)(1,639)(1,542)
Net income $232,324 $213,936 $182,277 
Weighted average common shares55,998 54,245 49,419 
Basic earnings per share
Consolidated$4.15 $3.94 $3.69 
Natural Gas Operations
Reconciliation of Revenue to Operating Margin (Non-GAAP measure)
Gas operating revenues$1,350,585 $1,368,939 $1,357,728 
Less: Net cost of gas sold342,837 385,164 419,388 
Operating margin$1,007,748 $983,775 $938,340 
2020 Overview
Southwest Gas Holdings highlights include the following:
•Record net income of $232 million
•Record earnings per share of $4.15

Natural gas operations highlights include the following:
•37,000 first-time meters sets (1.8% growth rate) occurred over the past 12 months
•Operating margin increased $24 million, or 2.4% between 2020 and 2019
•Operations and maintenance expense decreased $16 million
•Issued $450 million in 2.2% 10-year Notes (a record low fixed rate for Southwest)
•Nevada general rate case finalized with rate relief effective October 2020
•Arizona general rate case finalized with rate relief effective January 2021
•California general rate case agreement reached, with margin tracking until rate effective date

Utility infrastructure services highlights include the following:
•Record revenues of $1.9 billion in 2020, an increase of $197 million, or 11%, compared to 2019
•Emergency restoration services provided $82 million of revenue in 2020 compared to $13 million in 2019
•Record net income of $74.9 million in 2020




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Results of Natural Gas Operations
Year Ended December 31,
(Thousands of dollars)202020192018
Gas operating revenues$1,350,585 $1,368,939 $1,357,728 
Net cost of gas sold342,837 385,164 419,388 
Operating margin1,007,748 983,775 938,340 
Operations and maintenance expense406,382 422,174 404,813 
Depreciation and amortization235,295 215,620 191,816 
Taxes other than income taxes63,460 62,328 59,898 
Operating income302,611 283,653 281,813 
Other income (deductions)(6,590)9,517 (17,240)
Net interest deductions101,148 95,026 81,740 
Income before income taxes194,873 198,144 182,833 
Income tax expense 35,755 34,973 43,991 
Contribution to consolidated net income $159,118 $163,171 $138,842 
2020 vs. 2019
Contribution to consolidated net income from natural gas operations decreased $4 million between 2020 and 2019. The decrease was primarily due to an increase in Depreciation and amortization and Net interest deductions and a decline in Other income (deductions), offset by higher operating margin and a decrease in Operations and maintenance expense.
Operating margin increased $24 million between years. Customer growth provided $14 million as 37,000 first-time meter sets were added in 2020, and combined rate relief, primarily in Nevada and California, provided $7 million of incremental operating margin during the current year. Additionally, an increase in regulatory asset recoveries (offset in amortization expense below) contributed to the increase. The prior-year included an approximate $5 million reduction in margin resulting from a one-time adjustment to reflect the impacts of U.S. tax reform on the Arizona decoupling mechanism. The remaining decrease includes the impacts from a temporary moratorium on late fees and connection/re-connection charges during the COVID-19 pandemic.
Operations and maintenance expense decreased $16 million, or 4%, between 2020 and 2019 primarily due to lower travel and in-person training costs due to the current COVID-19 environment, lower legal claims, as well as management cost saving initiatives. These were partially offset by incremental expenditures for pipeline damage prevention programs associated with a growing infrastructure and customer base.
Depreciation and amortization expense increased $19.7 million, or 9%, between years primarily due to a $668 million, or 9%, increase in average gas plant in service for the current year. The increase in gas plant was attributable to pipeline capacity reinforcement work, franchise requirements, scheduled and accelerated pipe replacement activities, and new infrastructure. Amortization related to regulatory account recoveries, as referenced above, increased $1.4 million between years.
Other income decreased $16 million between 2020 and 2019. The current year reflects a $9.2 million increase in COLI policy cash surrender values and recognized death benefits, while 2019 reflected a $17.4 million increase. Non-service-related components of employee pension and postretirement benefit cost, included in this category, increased $5 million between years. Additionally, lower interest earned on regulatory balances contributed to the decrease between years.
Net interest deductions increased $6.1 million between 2020 and 2019, primarily due to interest associated with the issuance of $300 million of Senior Notes in May 2019 and $450 million of Senior Notes in June 2020, offset by a reduction in outstanding borrowings under the credit facility.
Income tax expense in both 2020 and 2019 reflects the fact that COLI results are recognized without tax consequence and therefore, impact the effective tax rate.


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2019 vs. 2018
The contribution to consolidated net income from natural gas operations increased $24 million between 2019 and 2018. The increase was primarily due to higher operating margin and an improvement in Other income (deductions), as well as lower Income tax expense. The increase was offset by increases in Operations and maintenance expense, Depreciation and amortization, and Net interest deductions.
Operating margin increased $45 million between 2018 and 2019. Customer growth provided $11 million, and combined rate relief, primarily in Nevada and California, provided $12 million of incremental operating margin. The remaining increase primarily resulted from the net recovery of regulatory program balances (with a $12.2 million partial offsetting impact in amortization expense), in addition to margin from customers outside the decoupling mechanisms and other miscellaneous revenues. The net increase in regulatory program recoveries included California public purpose and cap and trade programs (net of climate credits returned), as well as recoveries from Nevada renewable energy and infrastructure replacement programs, offset by the return of amounts for conservation and energy efficiency programs.
Operations and maintenance expense increased $17 million, or 4%, between 2019 and 2018 primarily due to general cost increases and higher legal claims experience. Higher expenditures for pipeline integrity management and damage prevention programs, as well as incremental information technology costs also contributed to the increase.
Depreciation and amortization expense increased $23.8 million, or 12%, between years. Amortization related to regulatory account recoveries, as noted above, increased $12.2 million between 2018 and 2019. Depreciation and amortization of gas plant increased $11.6 million primarily due to a $586 million, or 9%, increase in average gas plant in service in 2019 as compared to 2018. The increase in gas plant was attributable to pipeline capacity reinforcement work, franchise requirements, scheduled and accelerated pipe replacement activities, and new infrastructure.
Taxes other than income taxes increased $2 million, or 4%, between 2019 and 2018 primarily due to higher property taxes associated with net plant additions, and due to the Nevada Commerce Tax, as well as California franchise taxes.
Other income (deductions) improved $27 million between 2019 and 2018, primarily due to a $17.4 million increase in COLI policy cash surrender values and recognized death benefits during 2019, as compared to a $3.2 million COLI-related loss in 2018. The cash surrender values of these policies fluctuated based on the value of the underlying investments, which increased substantially during 2019, similar to the broader stock market during the same year. Additionally, non-service-related components of employee pension and postretirement benefit cost, included in this category, decreased $6 million between 2018 and 2019.
Net interest deductions increased $13.3 million between 2019 and 2018, primarily due to higher interest from the issuance of $300 million of Senior Notes in May 2019. Higher interest rates and average outstanding balances under Southwest’s credit facility and increased carrying costs on PGA balances in Arizona also contributed to the increase between comparative periods.
The reduction in income taxes and effective tax rates between 2019 and 2018 was partially due to lower state income taxes (due to apportionment changes) and $2.3 million in amortization of excess deferred income taxes during 2019, resulting from recent U.S. tax reform. The significant amount of COLI earnings in 2019 (noted above), which are recognized without tax consequence, also favorably impacted the effective rate during the same year.




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Results of Utility Infrastructure Services
Year Ended December 31,
(Thousands of dollars)202020192018
Utility infrastructure services revenues$1,948,288 $1,750,978 $1,522,285 
Operating expenses:
Utility infrastructure services expenses1,729,429 1,573,227 1,387,689 
Depreciation and amortization96,732 87,617 57,396 
Operating income122,127 90,134 77,200 
Other income (deductions)(207)466 (238)
Net interest deductions9,269 14,086 14,190 
Income before income taxes112,651 76,514 62,772 
Income tax expense31,128 21,399 18,420 
Net income 81,523 55,115 44,352 
Net income (loss) attributable to noncontrolling interest6,661 2,711 (625)
Contribution to consolidated net income attributable to Centuri$74,862 $52,404 $44,977 
2020 vs. 2019
Contribution to consolidated net income from utility infrastructure services increased $22.5 million in 2020 compared to 2019. Results were positively impacted by emergency restoration services performed by Linetec and increased volume under certain blanket and bid contracts, both in the U.S. and Canada.
Utility infrastructure services revenues increased $197.3 million, or 11%, primarily due to incremental electric infrastructure revenues of $145.3 million from expansion of work with existing customers and securing work with new customers. Included in the incremental electric infrastructure revenues during 2020 is $81.5 million from emergency restoration services performed by Linetec, following hurricane and tornado damage to customers’ above-ground utility infrastructure in and around the Gulf Coast and eastern regions of the U.S., as compared to $13.2 million in similar services during 2019. Centuri’s revenues derived from storm-related services vary from period to period due to the unpredictable nature of weather-related events. Additionally, Centuri experienced continued growth with existing gas infrastructure customers under master service and bid agreements and benefited from generally favorable weather working conditions throughout the year. Centuri achieved increases in revenues despite a temporary shut-down of certain crews, primarily in the second quarter of 2020, in response to local government requirements to postpone non-essential business services, and precautions to ensure employee safety, during the COVID-19 outbreak. Revenues from replacement work composed approximately 54% and 60% of total revenues for 2020 and 2019, respectively, as governmental safety-related programs have resulted in many utilities undertaking multi-year infrastructure replacement projects in recent years. Centuri revenues from contracts with Southwest totaled $134.9 million in 2020 and $158.7 million in 2019. Centuri accounts for services provided to Southwest at contractual prices.
Utility infrastructure services expenses increased $156.2 million, or 10%, between 2020 and 2019 largely due to incremental expenses related to electric infrastructure services of $109.3 million, including costs associated with storm restoration work, as well as costs to complete additional gas and electric infrastructure work. These costs were mitigated by increased productivity and efficiencies on electrical infrastructure projects and lower fuel costs as a percentage of revenues. Storm restoration work typically generates a higher profit margin than core infrastructure services, due to improved operating efficiencies related to equipment utilization and absorption of fixed costs. Additionally, during 2020, Centuri received $4.1 million in wage subsidies from the Canadian government associated with COVID-19 relief programs, recorded as a reduction to wage expense. Ongoing efforts to complete an industrial construction project in Canada resulted in additional costs of approximately $3 million during 2020 compared to $8 million during 2019. Included in Utility infrastructure services expenses were general and administrative (“G&A”) costs, which increased $24.4 million in 2020 when compared to 2019, due to higher payroll and operating costs associated with continued growth of the business and higher profit-based incentive compensation. Offsetting these increases were lower insurance costs from favorable claims experience under Centuri’s self-insurance programs. Gains on sale of equipment (reflected as an offset to Utility infrastructure services expenses) were approximately $1.8 million and $5.5 million in 2020 and 2019, respectively.
Depreciation and amortization expense increased $9.1 million between 2020 and 2019, primarily due to $5.8 million of incremental depreciation related to the continued growth of Linetec. Additional equipment purchased to support the growing volume of work being performed also contributed to the overall increase.
The decrease in net interest deductions was due primarily to lower incremental borrowing rates associated with outstanding borrowings under the $590 million secured revolving credit and term loan facility.


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The income tax expense increase in 2020 reflects the increased level of pre-tax earnings.
2019 vs. 2018
Contribution to consolidated net income from utility infrastructure services increased $7.4 million in 2019 compared to 2018. Results in 2019 were positively impacted by a full year of activities from Linetec and increased volume under certain blanket contracts, notably in Canada. These increases were partially offset by higher depreciation and amortization resulting from the Linetec acquisition.
Utility infrastructure services revenue increased $228.7 million, or 15%, between comparative years, primarily due to a full year of Linetec operations in 2019 ($236.1 million) compared to revenue recognized in the previous year following the November 2018 acquisition date ($14.1 million). Continued growth with customers under existing master service and bid agreements also contributed to the increase in revenue overall. Partially offsetting these increases were decreased revenues from certain non-routine projects, including customer-requested support in 2018 during an employment strike, and emergency response situations, in addition to a multi-year water pipe replacement project that expired in July 2019 and was not renewed. Revenues in 2018 also included the settlement of an earlier contract dispute related to that project ($9 million). Implementation of new regulatory requirements for operating locations within certain eastern states in the U.S. resulted in lower revenues during 2019 as Centuri worked with customers to adopt the new requirements. During the past several years, utility infrastructure services segment efforts have been focused on obtaining utility system replacement work under both blanket contracts and incremental bid projects. For both 2019 and 2018, revenues from replacement work were approximately 60% of total revenues, as governmental safety-related programs have resulted in many utilities undertaking multi-year infrastructure replacement projects in recent years. Centuri revenues from contracts with Southwest totaled $158.7 million in 2019 and $135.9 million in 2018. As noted earlier, Centuri accounts for services provided to Southwest at contractual prices.
Utility infrastructure services expenses increased $185.5 million, or 13%, between 2019 and 2018 largely due to incremental expenses related to Linetec of $172.1 million in 2019. Included in total Utility infrastructure services expenses were G&A costs, which decreased $5.6 million in 2019 when compared to 2018, due primarily to the impact of deal costs from the acquisition of Linetec during 2018 ($6.9 million), which did not recur. The 2019 period includes higher operating costs overall, associated with growth of the business. The new regulatory requirements noted above for operating locations in certain states in the eastern U.S. also resulted in productivity inefficiencies during 2019. Furthermore, efforts to complete an industrial construction project in Canada resulted in additional costs of approximately $8 million during 2019 as a result of delays in commissioning the project. Gains on sale of equipment (reflected as an offset to Utility infrastructure services expenses) were approximately $5.5 million and $1.7 million in 2019 and 2018, respectively.
Depreciation and amortization expense increased $30.2 million between 2019 and 2018, primarily due to $25 million of incremental depreciation and amortization expenses in 2019 related to finite-lived tangible and intangible assets resulting from the Linetec acquisition. Additional equipment purchased to support the growing volume of work being performed also contributed to the overall increase.
The decrease in net interest deductions between comparative years was due primarily to lower borrowing rates in 2019 associated with outstanding amounts under the $590 million secured revolving credit and term loan facility.
Income tax expense increased $3 million between 2019 and 2018, primarily due to an increase in pre-tax earnings.
Rates and Regulatory Proceedings
Southwest is subject to the regulation of the Arizona Corporation Commission (the “ACC”), the Public Utilities Commission of Nevada (the “PUCN”), the California Public Utilities Commission (the “CPUC”), and the Federal Energy Regulatory Commission (the “FERC”).
General Rate Relief and Rate Design
Rates charged to customers vary according to customer class and rate jurisdiction and are set by the individual state and federal regulatory commissions that govern Southwest’s service territories. Southwest makes periodic filings for rate adjustments as the cost of providing service (including the cost of natural gas purchased) changes, and as additional investments in new or replacement pipeline and related facilities are made. Rates are intended to provide for recovery of all commission-approved costs and a reasonable return on investment. The mix of fixed and variable components in rates assigned to various customer classes (rate design) can significantly impact the operating margin actually realized by Southwest. Management has worked with its regulatory commissions in designing rate structures that strive to provide affordable and reliable service to its customers while mitigating volatility in prices to customers and stabilizing returns to investors. Such rate structures were in place in all of Southwest’s operating areas during all periods for which results of natural gas operations are disclosed above.



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Arizona Jurisdiction
Arizona General Rate Case. On May 1, 2019, Southwest filed a general rate case application requesting to increase revenue by approximately $57 million to update the cost of service to reflect recent U.S. tax reform changes, including the return of excess deferred income taxes to customers, and to reflect capital investments of approximately $670 million, including certain post-test year additions, such as the southern Arizona LNG facility discussed below. The application also included a proposed 10.3% return on equity (“ROE”) relative to a capital structure of 51.1% equity. Southwest updated its request to reflect the actual amortization of excess accumulated deferred income taxes (“EADIT”) resulting from recent U.S. tax reform (the amortization is determined based on a prescribed methodology, which was known after the Company’s 2018 federal income tax return was filed in 2019), and to include additional post-test year plant in the amount of $124.5 million associated with its COYL and VSP programs, discussed further below. The amendment overall increased the deficiency by $36 million, to $93 million, which was further updated to $90.6 million based on certain aspects of its cost of service, including a revised proposed ROE of 10.15%. The request and amendments thereto included the retention of a fully decoupled rate design, other previously approved regulatory mechanisms, and a new infrastructure tracking mechanism for specific plastic pipe, in addition to a proposal for a renewable natural gas (“RNG”) program for the purchase of RNG for customers as part of its PGA mechanism. The original hearing date was postponed due to the COVID-19 pandemic and was convened in June and July of 2020. Prior to the start of the hearing, Southwest entered into a stipulation with the parties to the case, agreeing to continue the COYL program; to establish a Tax Expense Adjustor Mechanism to track annual changes in the amortization of EADIT, as well as any future changes in the federal tax rate; to include a 10-year amortization of EADIT associated with deemed “unprotected” plant; and to incorporate various tariff proposals. EADIT associated with “protected” plant relates to timing differences from using accelerated depreciation for tax purposes and another method for book purposes, and unprotected amounts relate to all other timing differences.
The Administrative Law Judge released his Recommended Opinion and Order (“ROO”) in November and the commission ultimately voted in December 2020 to approve an amended ROO, with new rates becoming effective in January 2021. The decision resulted in an overall revenue increase of $36.8 million; the continuation of full revenue decoupling; and continuation of the COYL program. An ROE of 9.1% was approved with a capital structure comprised of 48.9% long-term debt and 51.1% common equity. The overall increase reflects the final ROE and the inclusion of six months (as compared to eleven months originally contemplated by the ROO) of post-test year plant additions, including additions related to the LNG facility, COYL, and VSP. See additional discussion related to these programs below. The continuation of the property tax tracker was also supported in the final decision, as well as approval of a new income tax tracking mechanism (“Tax Expense Adjustor Mechanism”). While the RNG proposal was not approved as part of the final decision in the case, the commission agreed to conduct a workshop to further explore the role of RNG in Arizona.
Delivery Charge Adjustment. The annual Delivery Charge Adjustment (“DCA”) is filed each April, which along with other reporting requirements, contemplates a rate to recover the over- or under-collected margin tracker amounts based on the balance at the end of the preceding calendar year. In the process to address the 2019 activity, in April 2020, Southwest filed a request to adjust the existing rate to consider the 14-month period of January 1, 2019 through February 29, 2020, proposing a rate of $0.00655 per therm based on an ending balance of approximately $3.5 million. Although the commission staff concurred with Southwest’s proposed rate, the ACC ultimately elected to reduce the rate to zero in an effort to provide some measure of customer relief in light of current issues related to the COVID-19 pandemic, and at the time of both the April filing and the ACC decision, the balance was a liability (in an over-recovered status). Activity through the remainder of 2020 resulted in a slight under-collected balance at December 31, 2020, which is expected to be addressed in Southwest’s next annual filing.
Tax Reform. In February 2018, the ACC directed all Arizona utilities to address tax savings from the enactment of U.S. tax reform beginning January 1, 2018, through one of various means. In April 2018, Southwest filed an application with the ACC, requesting approval for a tax refund process or, in the alternative, the authority to file a general rate case to reflect the impacts of tax reform. Ultimately, Southwest was instructed to refund customers $20 million annually, as compared to rate levels established in the previously concluded general rate case. The per-therm surcredit customer refunds continued until the end of 2020, after which, rates associated with the most recent general rate case became effective, reflecting the effects of tax reform. Differences between the $20 million annually expected to be returned during the years 2018 - 2020, and actual amounts returned on a per-therm basis, resulted in an over-returned asset balance of $2.6 million as of December 31, 2020. The remaining balance is expected to be resolved through the Tax Expense Adjustor Mechanism implemented as part of the recent general rate case decision.
Liquefied Natural Gas (“LNG”) Facility. In 2014, Southwest sought ACC preapproval to construct, operate, and maintain a 233,000 dekatherm LNG facility in southern Arizona. This facility is intended to enhance service reliability and flexibility related to natural gas deliveries in the southern Arizona area by providing a local storage option, and to be connected directly to Southwest’s distribution system. Southwest was ultimately granted approval for construction and deferral of costs not to exceed $80 million. The facility was placed in service in December 2019 at a capital expenditure cost of approximately $75.3 million


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(including land acquisition costs). The capital costs and the operating expenses associated with plant operation were approved and considered as part of Southwest’s recently resolved general rate case. Due to the timing of the operating costs incurred (following the in-service date), rates to recover the associated regulatory asset balance will be part of the next Arizona general rate case application.
Customer-Owned Yard Line (“COYL”) Program. Southwest received approval, in connection with its 2010 Arizona general rate case, to implement a program to conduct leak surveys, and if leaks were present, to replace and relocate service lines and meters for Arizona customers whose meters were set off from the customer’s home, representing a non-traditional configuration. In 2014, the ACC approved a “Phase II” of the COYL program, which included the replacement of non-leaking COYLs. The surcharge is designed to collect the annual revenue requirement as the program progresses. In the filing made in February 2019, Southwest requested to increase its surcharge to recover a revenue requirement of $6.7 million (an increase of $3.2 million) associated with $26.6 million in capital projects completed in 2018. The ACC ultimately issued an order in October 2019 authorizing Southwest to retain the existing annual surcharge in place, indicating it would review the program as part of the general rate case. Southwest also proposed to have the ACC review an estimated $21.1 million of 2019 COYL capital projects, and if authorized, to also render a decision regarding cost recovery as part of the rate case. Parties to the rate case stipulated to continue the COYL program and recommended recovery of this plant as part of Southwest’s filed post-test year plant adjustment, with inclusion of related amounts in base rates. Further consideration in the rate case decision limited the post-test year plant adjustment (inclusive of COYL plant) to six months, and limited future COYL activity to the replacement of leaking COYLs, or in cases when other replacement activity is taking place in the vicinity. A filing in the first quarter of 2021 will be made, proposing the recovery of the additional revenue requirement associated with the 2019 and 2020 cost of service activity and 2019 plant, which was placed in service following the six-month post-test year period includible in the concluded rate case.
Vintage Steel Pipe Program (“VSP”). Southwest received approval, in connection with its 2016 Arizona general rate case, to implement a VSP replacement program, due to having a substantial amount of pre-1970s vintage steel pipe in Arizona. As part of the program, Southwest proposed to start replacing the pipe on an accelerated basis and to recover the costs through an annual surcharge filing. Surcharges related thereto have been customarily designed to be revised annually as the program progressed, in order to collect the annual revenue requirement associated with the related capital expenditures. In the most recent VSP filing, in February 2019, Southwest requested to increase its surcharge revenue by $9.5 million (to $11.9 million) associated with the replacement of approximately $100 million in 2018 VSP capital projects. The ACC issued an order in October 2019 authorizing Southwest to retain the existing annual surcharge, and indicated it would review the program as part of the general rate case. Southwest also proposed to have the ACC review an estimated $103.4 million of 2019 VSP capital projects, and if authorized, to also render a decision regarding cost recovery as part of the rate case. The resolution of Southwest’s rate case allowed the inclusion of post-test year plant (inclusive of VSP) placed in service during the six months following the test year. However, the commission ultimately decided to discontinue the accelerated VSP program at this time. A filing in the first quarter of 2021 will be made, proposing the recovery of the additional revenue requirement associated with the 2019 and 2020 cost of service activity and 2019 and 2020 plant, which was placed in service following the six month post-test year period includible in the concluded rate case.
Customer Data Modernization Initiative. Southwest has embarked on an initiative to replace its customer service system and gas transaction systems, each of which is utilized to support all Southwest service territories. Combined, these undertakings are referred to as the Customer Data Modernization Initiative (the “CDMI”). In March 2019, Southwest filed an application with the ACC seeking an accounting order which, if approved, would have authorized Southwest to track and defer all costs associated with the CDMI to mitigate adverse financial implications associated with this multi-year initiative. The total cost for the CDMI was estimated at $174 million, approximately $96 million of which would be allocable to the Arizona rate jurisdiction. The project is expected to be moved to production in 2021. A hearing in this matter was held in June 2020, with a legal briefing completed in mid-September. A separate ROO from that associated with the general rate case was issued in February 2021, which did not support the implementation of an accounting order to track and defer such costs. The parties have an opportunity to file exceptions to the associated ROO, which are expected to be considered at a commission meeting in late March 2021.
California Jurisdiction
California General Rate Case. Southwest’s existing rates became effective June 2014 and included a Post-Test Year (“PTY”) Ratemaking Mechanism, which allowed for attrition increases of 2.75% annually for 2015 through 2018, after which time new rates from a subsequent rate case cycle would have been expected to be in effect. In December 2016, Southwest filed to modify the earlier (2014) general rate case decision to extend the rate case cycle by two years, and received CPUC approval in June 2017, including extension of the annual 2.75% PTY attrition adjustments for 2019 and 2020.
In August 2019, Southwest filed the previously deferred general rate case, based on a test year of 2021, seeking authority to increase rates in its California rate jurisdictions. The proposed combined revenue increase of $12.8 million was net of a


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$10.9 million revenue reduction associated with changes from U.S. tax reform, which included the amortization of $9.8 million (approximately $2 million annually over five years) associated with the difference in authorized income tax expense and actual incurred income tax expense for years 2019 and 2020, which when returned will impact cash flows, but would not be expected to have an impact on earnings. Southwest has been tracking those amounts, as directed, and reserving them for return to customers. The overall revenue request also included $1.6 million of EADIT proposed to be returned to customers each year until the amount is reset as part of a future rate case. Southwest’s proposal included an ROE of 10.5%, relative to a 53% equity ratio; continuation of annual post-test year margin adjustments of 2.75%; implementation of various safety-related programs, including a targeted pipe replacement program and a meter protection program (with a combination of measures, such as snow sheds, excess flow valves, upgraded meter set piping and upgraded Encoder Receiver Transmitter protocol); as well as an expansion of the school COYL replacement program. Southwest reached an agreement in principle with the Public Advocate’s Office for settlement of the pending general rate case.
The agreement in principle includes a $6.4 million total combined revenue increase with a 10% ROE, relative to a 52% equity ratio. Approximately $4 million of the original proposed increase of $12.8 million is associated with a North Lake Tahoe project that will not be completed by the beginning of 2021; consequently, the parties agreed to remove it from the base rate increase and instead to provide for the recovery of the cost of the project through a future surcharge. The agreement also maintains Southwest’s existing 2.75% annual attrition adjustments, the continuation of the pension balancing account, and a proposed increase in the residential basic service charge from the existing $5.00 to $5.75 per month. The parties also agreed to a cumulative total of $119 million in capital projects over the five-year rate cycle to implement proposed risk-informed decision-making proposals, consisting of the school COYL replacement, meter protection, and pipe replacement programs. Southwest is authorized to implement a surcharge annually to recover the revenue requirement associated with these programs. The agreement in principle was filed in early August 2020, and originally expected to be considered for approval in late 2020, with new rates effective in January 2021. However, the proposed decision from the Administrative Law Judge is still pending. In light of the administrative delay, Southwest was granted authority to establish a general rate case memorandum account to track the margin/revenue shortfall related to the delay in rate relief. Final resolution of the general rate case is expected in the first quarter of 2021.
Attrition Filing. In November 2019, Southwest made its latest annual PTY attrition filing, requesting annual revenue increases of $2.06 million in southern California, $556,000 in northern California, and $278,000 for South Lake Tahoe. This filing was approved in December 2019 and rates were made effective in January 2020. At the same time, rates were also updated to recover the regulatory asset associated with the revenue decoupling mechanism, or margin tracker. Since Southwest’s general rate case test year is 2021, there is no attrition increase for 2021; however, the PTY attrition increases are included in the rate case agreement and expected to continue in 2022.
Greenhouse Gas (“GHG”) Compliance. California Assembly Bill Number 32 and regulations promulgated by the California Air Resources Board, require Southwest, as a covered entity, to comply with applicable requirements associated with California GHG emissions reporting and the California Cap and Trade Program. The CPUC issued a decision in 2018 adopting an allocation methodology to distribute the net revenues or costs. Southwest began amortizing its then existing net cost balance over a 12-month period with recovery rates effective July 2018 for all applicable rate schedules. In addition, for years 2019-2020, the decision adopted an allocation methodology to distribute the revenue proceeds through a California Climate Credit to active residential customers in April of each year, following initial required credits in October 2018. Amounts distributed in April 2019 and 2020 were comparable. GHG compliance costs recovered through rates have no impact on earnings.
Renewable Natural Gas. In February 2019, Southwest filed an application that, among other things, sought to formally allow the inclusion of renewable natural gas (or biomethane) as a potential component of Southwest’s gas supply portfolio through the Biomethane Gas Program (“BGP”). This proposal is designed to further the goals of the California Global Warming Solutions Act of 2006, the California Low Carbon Fuel Standard, Senate Bills 1383 and 1440, as well as current or future legislative or regulatory efforts to reduce greenhouse gas emissions. Implementation of the BGP addresses cost recovery as part of Southwest’s existing Gas Cost Incentive Mechanism related to the purchase or sale of biomethane. The CPUC issued a final decision approving the proposal in March 2020.
Customer Data Modernization Initiative. In April 2019, Southwest filed an application with the CPUC seeking authority to establish a two-way, interest bearing balancing account to record costs associated with the CDMI to mitigate adverse financial impacts associated with this multi-year project. Approximately $19 million of the estimated $174 million total for the CDMI would be allocable to the California rate jurisdiction. Southwest filed a separate request to establish a memorandum account while the CPUC considered its application request to establish the two-way balancing account. Effective October 2019, the CPUC granted Southwest’s memorandum account request, which would allow Southwest to track costs, including operations and maintenance costs and capital-related costs, such as depreciation, taxes, and return associated with California’s portion of the CDMI. The balance tracked in the memorandum account would be transferred to the two-way balancing account, if


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approved. In January 2020, Southwest and the Public Advocates Office reached a settlement agreement to adopt Southwest’s Application for Authority to Implement the CDMI. The CPUC issued a final decision approving the settlement agreement as filed in July 2020. A rate to begin recovering the balance accumulated through June 30 was established and made effective September 1, 2020. This rate was further updated in January 2021 and will be updated annually thereafter each January.
Emergency Relief Program Related to COVID-19. On March 25, 2020, Southwest filed an Advice Letter to establish a memorandum account to track costs related to customer protections under Emergency Relief regulations implemented in California in 2019 in the event of a state or federal declared emergency or disaster. The CPUC passed an emergency resolution on April 16, 2020 authorizing and directing utilities to implement customer protections and to establish memorandum accounts to track the financial impacts of complying with the resolution. On May 1, 2020, Southwest filed an Advice Letter to establish a COVID-19 Pandemic Protections Memorandum Account (“CPPMA”) to record all incremental costs and lost revenues incurred by Southwest associated with its implementation of the COVID-19 customer protections as outlined in the CPUC resolution. The customer protections were retroactively applied to March 4, 2020, the date Governor Gavin Newsom declared a state of emergency related to COVID-19. The CPPMA is effective March 4, 2020 through June 30, 2021. These customer protections focus on flexible payment plan options, additional protections for income-qualified customers, as well as the suspension of disconnections for non-payment and the waiver of deposit and late fee requirements. Tracked amounts will be considered by the CPUC for future recovery.
Nevada Jurisdiction
Nevada General Rate Case. Southwest filed a general rate case application with the PUCN in February 2020, which requested a statewide overall general rate increase of approximately $38.3 million. The request sought an ROE of 10% relative to a proposed capital structure of 50% equity and continuation of the General Revenues Adjustment (“GRA”) mechanism (full revenue decoupling). The request also proposed the recovery of previously excluded costs attributable to several software applications. In June 2020, Southwest submitted its certification filing to update certain balances through May 31, 2020, which increased its overall proposed rate increase to $38.5 million. Commission staff and the Bureau of Consumer Protection each filed testimony in July, recommending an overall increase of approximately $21.6 million and approximately $20 million, respectively. A hearing in this matter was held in August 2020, with the Commission issuing its final order on September 25, 2020, which provided for an authorized combined revenue increase of approximately $23 million for northern and southern Nevada and continuation of the existing authorized 9.25% ROE, with a capital structure of 49.26% equity and 50.74% debt. Southwest’s existing GRA (discussed further below) was authorized to continue without modification. Full cost recovery of the unamortized balance of excluded software projects from the previous general rate case was authorized in this case, along with the inclusion of all proposed Gas Infrastructure Replacement (“GIR”) and Mesquite Expansion projects in rate base, and full recovery of test year and certification period operations and maintenance expenses associated with the CDMI project. Rates became effective in October 2020.
The previous general rate case decision, in December 2018, authorized an ROE of 9.25% relative to Southwest’s proposed capital structure of 49.66% equity applicable to both southern and northern Nevada. Rates from this earlier proceeding originally became effective in January 2019. As part of that proceeding, management filed a request for reconsideration of several rate case issues during the same month of effective rates; however, the PUCN ultimately granted no further rate relief. A modified final decision, following certain technical clarifications to calculations of the decision, resulted in a final revenue increase of $9.2 million in southern Nevada and a revenue decrease in northern Nevada of $2.1 million. The modified rates became effective in March 2019. Management decided to seek judicial review of the PUCN’s rate order, which was considered in January 2020. The District Court Judge deferred to the PUCN’s original findings. In March 2020, Southwest filed an appeal with the Nevada Supreme Court, which remains active; the resolution will likely take 12-24 months from the appeal date.
General Revenues Adjustment (“GRA”). The continuation of the GRA was affirmed as part of Southwest’s recently concluded general rate case, effective October 2020. Southwest makes Annual Rate Adjustment (“ARA”) filings to update rates to recover or return amounts associated with various regulatory mechanisms, including the GRA. In June 2019, Southwest made its annual filing, which provided for a decrease of approximately $8 million for an over-collected balance in southern Nevada and an increase of approximately $2 million in northern Nevada. The proposed changes were approved, with rates effective January 2020. In May 2020, Southwest made its most recent ARA filing, which proposed an annualized margin decrease of $5.3 million in southern Nevada and an increase of $1.6 million in northern Nevada. The ARA filing was resolved through a settlement of the parties, in which the proposed changes associated with the GRA were approved, effective January 2021. While there is no impact to net income overall from adjustments to recovery rates associated with the related regulatory balances, operating cash flows are impacted by such changes.
Infrastructure Replacement Mechanism. In 2014, the PUCN approved final rules for the GIR mechanism, which defers and recovers certain costs associated with accelerated replacement of qualifying infrastructure that would not otherwise currently provide incremental revenues. Associated with the replacement of various types of pipe infrastructure under the mechanism


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(Early Vintage Plastic Pipe, COYL, and VSP), the related regulations provide Southwest with the opportunity to file a GIR “Advance Application” annually, generally in May, to seek preapproval of qualifying replacement projects.
Furthermore, a GIR rate application is generally filed each October to reset the GIR recovery surcharge rate related to previously approved and completed projects, with new rates typically becoming effective each January. On October 1, 2019, Southwest filed a rate application to reset the recovery surcharge to include cumulative deferrals through August 31, 2019. This surcharge rate became effective in February 2020, designed to result in a reduction in annual revenue of approximately $5.3 million in southern Nevada and no incremental revenue in northern Nevada. On September 30, 2020, Southwest filed its latest rate application to reset the recovery surcharge to include cumulative deferrals through August 31, 2020. The surcharge rate is expected to result in a reduction in annual revenue of approximately $11.8 million, effective in January 2021.
Conservation and Energy Efficiency. The PUCN allows deferral (and later recovery) of approved conservation and energy efficiency costs, recovery rates for which are adjusted in association with ARA filings. In its June 2019 ARA filing, Southwest proposed annualized margin increases of $3.2 million and $880,000 in southern and northern Nevada, respectively. However, Southwest entered into a stipulation and agreement to modify these amounts to $6.2 million and $1.1 million in southern and northern Nevada, respectively, which reflected the recovery of a related but separate program balance to be rolled into customer rates with the same effective date. The modification was approved, and rates became effective January 2020. In its May 2020 ARA filing, Southwest proposed annualized margin decreases of $313,000 and $55,000 for southern and northern Nevada, respectively, which were approved and became effective January 2021.
Expansion and Economic Development Legislation. In January 2016, final regulations were approved by the PUCN associated with legislation (“SB 151”) previously introduced and signed into law in Nevada. The legislation authorized natural gas utilities to expand their infrastructure to provide service to unserved and underserved areas in Nevada.
In November 2017, Southwest filed for preapproval of a project to extend service to Mesquite, Nevada, in accordance with the SB 151 regulations. Ultimately, the PUCN issued an order approving Southwest’s proposal for the expansion. The order approved a capital investment of approximately $28 million and the construction of approximately 37 miles of distribution pipeline (including the approach main). The annual revenue requirement associated with the project is $2.8 million. A volumetric rate, applicable to all southern Nevada customers (including new customers in Mesquite), was implemented in October 2019 to recover the cost. Southwest’s May 2020 ARA filing, which proposed an annualized margin increase of $185,000, reflects the cumulative deferred revenue requirement associated with the Mesquite facilities that were placed in service through April 30, 2020. During 2020, Southwest continued serving certain customers in Mesquite from an approved “virtual” pipeline network, providing temporary natural gas supply using portions of the approved distribution system and compressed natural gas. Construction of the tap site, approach main, as well as distribution mains was completed and placed in service in December 2020.
In June 2019, Southwest filed for preapproval to construct the infrastructure necessary to expand natural gas service to Spring Creek, Nevada, and to implement a cost recovery methodology to timely recover the associated revenue requirement consistent with the SB 151 regulations. Expansion to the Spring Creek area near Elko, Nevada consists of a high-pressure approach main and associated regulator stations, an interior backbone, and the extension of the distribution system from the interior backbone system. The total capital investment is estimated to be $61.9 million. A stipulation in this matter was reached with the parties and approved by the PUCN in December 2019, which largely accepted Southwest’s proposal with modifications reflected in the rate recovery allocations split amongst northern Nevada, Elko, and Spring Creek expansion customers. Construction of the initial phase of the expansion began in the third quarter of 2020, and service commenced to the first Spring Creek customers in December 2020.
Customer Data Modernization Initiative. In March 2019, Southwest filed a request seeking authority to establish a regulatory asset to defer the revenue requirement related to the CDMI to mitigate the financial attrition associated with this multi-year project. Approximately $59 million of the estimated $174 million cost of the CDMI would be allocable to the Nevada rate jurisdictions. A hearing on this matter was held in August 2019 and the PUCN issued its decision in September 2019, denying Southwest’s request for regulatory asset treatment, finding a general rate case the most appropriate avenue to address such costs. In response to the PUCN’s decision, Southwest filed a Petition for Reconsideration in October 2019, which was denied. As part of Southwest’s recently concluded general rate case, Southwest was authorized to include CDMI operations and maintenance costs since the beginning of the test year as part of its revenue requirement in the case.
Regulatory Asset Related to COVID-19. The PUCN issued an order directing utilities within the state to establish regulatory asset accounts to track the financial impacts associated with maintaining service for customers affected by COVID-19, including those whose service would have been otherwise terminated/disconnected, effective March 12, 2020, the date that Governor Steve Sisolak declared a state of emergency related to COVID-19. These costs will be considered by the PUCN for future recovery.


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FERC Jurisdiction
General Rate Case. Paiute Pipeline Company (“Paiute”), a wholly owned subsidiary of Southwest, filed a general rate case with the FERC in May 2019. The filing fulfilled an obligation from the settlement agreement reached in the 2014 Paiute general rate case. In January 2020, Paiute reached an agreement in principle with the FERC Staff and intervenors to settle its most recent general rate case. In addition to continuing the term-differentiated rate structures with its shippers, the agreement requires Paiute’s three largest transportation customers and all of its storage customers to extend their service agreements to have primary terms of at least five years. The settlement resulted in a revenue reduction of approximately $700,000 and is based on a 9.90% pre-tax rate of return. Also, as part of this agreement, Paiute agreed not to file a rate case prior to January 1, 2022, but no later than May 31, 2025.
In January 2020, Paiute requested, and was granted, the authority to place the settlement rates into effect on an interim basis, effective February 2020. On March 30, 2020, Paiute filed the proposed settlement agreement with the FERC for review and approval. On July 6, 2020, the FERC issued a letter order approving the settlement, and the order became final on August 5, 2020.
PGA Filings
The rate schedules in all of Southwest’s service territories contain provisions that permit adjustments to rates as the cost of purchased gas changes. These deferred energy provisions and purchased gas adjustment clauses are collectively referred to as “PGA” clauses. Differences between gas costs recovered from customers and amounts paid for gas by Southwest result in over- or under-collections. As of December 31, 2020, over-collections in Arizona and both southern and northern Nevada resulted in a liability of approximately $54.6 million and under-collections in California resulted in an asset of $2.1 million on the Company’s and Southwest’s Consolidated Balance Sheets.
The following table presents Southwest’s outstanding PGA balances receivable/(payable) at the end of its two most recent fiscal years:
December 31,
(Thousands of dollars)20202019
Arizona$(3,901)$(59,259)
Northern Nevada(8,601)11,894 
Southern Nevada(42,134)32,518 
California2,053 (1,496)
$(52,583)$(16,343)
Arizona PGA Filings. In Arizona, Southwest calculates the change in the gas cost component of customer rates monthly (to allow for timely refunds to/recoveries from customers), utilizing a rolling twelve-month average. During 2020, the Gas Cost Balancing Account continued providing a surcredit in order to refund the over-collected balance throughout the year.
California Gas Cost Filings. In California, a monthly gas cost adjustment based on forecasted monthly prices is utilized. Monthly adjustments modeled in this fashion provide the timeliest recovery of gas costs in any Southwest jurisdiction.
Nevada ARA Application. In November 2019, Southwest filed to adjust its quarterly Deferred Energy Account Adjustment rate, which is based upon a twelve-month rolling average, in addition to requesting adjusted Base Tariff Energy rates, both of which were approved effective January 2020. These new rates are intended to address the outstanding balances over a twelve-month period.
Gas Price Volatility and Mitigation
To mitigate price volatility to its customers, Southwest has periodically entered into fixed-price term contracts and swaps under its collective volatility mitigation programs for a portion (up to 25% in the California jurisdiction and in the Arizona jurisdiction through October 2020) of its annual normal weather supply needs. For the 2020/2021 heating season, contracts contained in the fixed-price portion of the supply portfolio ranged from approximately $2.37 to approximately $2.97 per dekatherm. In consultation with its regulators, for periods beyond October 2020, Southwest currently does not plan to make any fixed-price term purchases broadly for the Arizona jurisdiction nor enter into swap agreements, nor does it do so for its Nevada territories; however, Southwest will continue to enter into fixed-price purchases for the California jurisdiction. Southwest’s natural gas purchases, not covered by fixed-price contracts, are under variable-price contracts with firm quantities, or on the spot market. The contract price for these contracts is either determined at the beginning of each month to reflect the published first-of-month index price, or at market prices based on a published daily price index. In each case, the index price is not published or known until the purchase period begins. See also Derivatives in Note 1 - Background, Organization, and Summary of Significant Accounting Policies.


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In mid-February 2021, the central U.S. (from south Texas to North Dakota and the eastern Rocky Mountains) experienced extreme cold temperatures, which increased natural gas demand and caused temporary shortages due to wellhead freeze-off. These conditions caused daily natural gas prices to reach unprecedented levels. During this time, Southwest secured natural gas supplies, albeit at substantially higher prices, and was able to maintain service to its customers. The incremental costs for these natural gas supplies (estimated at $200 million to $300 million) are expected to be funded using existing cash on hand and short-term borrowings, including current credit facilities. It is anticipated that these incremental gas costs will be recoverable from customers through the PGA mechanisms in each jurisdiction.
Pipeline Safety Regulation
In October 2019, the Pipeline and Hazardous Materials Safety Administration (“PHMSA”) issued final rules that amend the federal pipeline safety regulations applicable to gas transmission pipelines (effective July 2020) and revise PHMSA’s authority to issue emergency orders (effective December 2019). These rules cover, among other requirements, procedures related to reconfirming maximum allowable operating pressure of gas transmission pipelines in certain circumstances, the introduction of moderate consequence areas (“MCAs”), expansion of pipeline integrity assessments including work in MCAs, requirements for gathering additional material information on in-service transmission pipelines, and the authority of PHMSA to issue emergency orders to address imminent hazards caused by unsafe conditions or practices. These rules may require Southwest to incur additional costs of compliance.
Southwest continues to monitor changing pipeline safety legislation and participates, to the extent possible, in providing public comments and working with industry associations, such as the American Gas Association, in shaping regulatory language associated with these new mandates and reporting requirements. Additionally, Southwest works with its state and federal commissions to develop customer rates that are responsive to incremental costs of compliance. However, due to the timing of when rates are implemented in response to new requirements, and as additional rules are developed, compliance requirements could impact expenses and the timing and amount of capital expenditures.
Capital Resources and Liquidity
Over the past three years, cash on hand and cash flows from operations have provided a substantial portion of cash used in investing activities (primarily construction expenditures and property additions). In recent years, Southwest has accelerated pipe replacement activities to fortify system integrity and reliability, notably in association with gas infrastructure replacement programs. This accelerated activity has necessitated the issuance of both debt and equity securities to supplement cash flows from operations. The Company’s capitalization strategy is to maintain an appropriate balance of equity and debt to preserve investment-grade credit ratings, which help minimize interest costs.
Cash Flows
Southwest Gas Holdings, Inc.:
Operating Cash Flows. Cash flows provided by consolidated operating activities increased $126 million between 2020 and 2019. The increase in operating cash flows primarily resulted from collections of amounts under PGA mechanisms ($36 million, compared to a return of $58 million in the prior year), an increase in recoveries ($11 million) related to the Arizona decoupling mechanism balance, as well as an increase in net income (and giving effect to depreciation and amortization). These impacts were partially offset by a $50 million supplemental contribution for pension funding made in January 2020 (included in Changes in other liabilities and deferred credits in the Consolidated Statement of Cash Flows of both the Company and Southwest). Other changes in operating cash flows resulted from changes in working capital components overall.
Investing Cash Flows. Cash used in consolidated investing activities decreased $150 million in 2020 as compared to 2019. The change was primarily due to a decrease in capital expenditures in both business segments. The prior-year included $47.6 million in outlays for the remittance of purchase consideration previously held back in association with the 2018 Linetec acquisition.
Financing Cash Flows. Net cash provided by consolidated financing activities decreased $206 million in 2020 as compared to 2019. The change was primarily due to a reduction in borrowings and outstanding amounts under the Company’s credit facility and Southwest’s long-term portion of its credit facility. Part of the net proceeds from the issuance of $450 million of 2.20% notes in June 2020 by Southwest was used to pay down its credit facility and redeem $125 million of 4.45% notes in September 2020. In the prior year, Southwest also used a portion of the net proceeds from the $300 million in notes issued in May 2019 to reduce amounts then outstanding under its credit facility and commercial paper program. Other changes include the combined impacts of repayment and borrowings by Centuri under its secured revolving credit and term loan facility, offset by $70 million in equipment loan proceeds. Additionally, the Company issued $18 million more in common stock under the Equity Shelf Program in 2019 compared to 2020. Dividend payments increased in 2020 as compared to 2019 as a result of an increase in the quarterly dividend rate and an increase in the number of shares outstanding. See Note 7 - Common Stock and Note 8 - Debt.


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The Company received approximately $128 million in stock proceeds during 2020 under its Equity Shelf Program and issued approximately 172,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan, from which it raised approximately $11 million.
Southwest Gas Corporation:
Operating Cash Flows. Cash flows provided by operating activities increased $56 million between 2020 and 2019. The increase in operating cash flows was attributable to collections of deferred purchased gas costs and recoveries related to the Arizona decoupling mechanism, as well as other working capital components overall, partially offset by the supplemental contribution for pension funding in 2020, described earlier.
Investing Cash Flows. Cash used in investing activities decreased $82 million in 2020 as compared to 2019, primarily due to the decrease in construction expenditures.
Financing Cash Flows. Net cash provided by financing activities decreased $147 million in 2020 as compared to 2019. The decrease was primarily due to the combined effects of the repayment of previously accumulated outstanding balances under Southwest’s credit facility and the redemption of the $125 million in maturing notes after receiving proceeds upon issuance of the $450 million notes in the current period, compared to the $300 million in notes issued, and repayment activity associated with the credit facility and commercial paper program, in the prior period. See Note 8 - Debt. In addition, capital contributed from, and dividends paid to, the parent holding company were greater during 2020 as compared to 2019.
The capital requirements and resources of the Company generally are determined independently for the natural gas operations and utility infrastructure services segments. Each business activity is generally responsible for securing its own financing sources. However, the holding company may raise funds through stock issuance or other external financing sources in support of each business segment, as discussed above and in Note 7 - Common Stock.
2020 Construction Expenditures
During the three-year period ended December 31, 2020, total gas plant in service increased from $6.6 billion to $8.4 billion, or at an average annual rate of 8%. Replacement, new business, and reinforcement work was a substantial portion of the plant increase. Customer growth impacted expenditures as Southwest set approximately 105,000 meters during the three-year period, which is reflected in new business.
During 2020, construction expenditures for the natural gas operations segment were $692 million. The majority of these expenditures represented costs associated with scheduled and accelerated replacement of existing transmission, distribution, and general plant to fortify system integrity and reliability. Cash flows from operating activities of Southwest were $424 million and provided approximately 53% of construction expenditures and dividend requirements of the natural gas operations segment. Other funding was provided by cash on hand, external financing activities (including the $450 million notes issued in June 2020), capital contributed by Southwest Gas Holdings, Inc., and, as needed, the existing credit facility.
2020 Financing Activity
Net proceeds under the Equity Shelf Program for 2020 were $128 million, comprised of an aggregate of 1,917,512 shares of Southwest Gas Holdings, Inc. common stock, sold in the open market at a weighted average price of $67.39 per share, net of $1.3 million in agent commissions. These net proceeds, in addition to another $50 million for working capital purposes, were contributed to Southwest by the holding company. As of December 31, 2020, the Company had up to $46 million of common stock available for sale under the this program. See Note 7 - Common Stock for more information.
Gas Segment Three-Year Construction Expenditures, Debt Maturities, and Financing
Management estimates natural gas segment construction expenditures during the three-year period ending December 31, 2023 will be approximately $2.1 billion. Of this amount, approximately $700 million is expected to be incurred in 2021. Southwest plans to continue to request regulatory support to undertake projects, or to accelerate projects as necessary, for the improvement of system flexibility and reliability, or to expand, where relevant, to unserved or underserved areas. Southwest may expand existing, or initiate new, programs. Significant replacement activities are expected to continue well beyond the next few years. During the three-year period, cash flows from operating activities of Southwest are expected to provide approximately 50% of the funding for gas operations total construction expenditures and dividend requirements. From a debt maturity standpoint, Southwest has $250 million 3.875% notes and $25 million 7.78% medium-term notes due in 2022. Any additional cash requirements, including construction-related and any paydown or refinancing of debt, are expected to be provided by existing credit facilities, equity contributions from the Company, and/or other external financing sources. The timing, types, and amounts of any additional external financings will be dependent on a number of factors, including the cost of gas purchases, conditions in the capital markets, timing and amounts of rate relief, timing and amounts of surcharge collections from, or amounts returned to, customers related to other regulatory mechanisms, as well as growth levels in Southwest’s service areas


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and earnings. External financings could include the issuance of debt securities, bank and other short-term borrowings, and other forms of financing.
Liquidity
Several general factors (some of which are out of the control of the Company) that could significantly affect liquidity in future years include: variability of natural gas prices, changes in the ratemaking policies of regulatory commissions, regulatory lag, customer growth in the natural gas segment’s service territories, the ability to access and obtain capital from external sources, interest rates, changes in income tax laws, pension funding requirements, inflation, and the level of earnings. Natural gas prices and related gas cost recovery rates, as well as plant investment, have historically had the most significant impact on liquidity.
On an interim basis, Southwest defers over- or under-collections of gas costs to PGA balancing accounts. In addition, Southwest uses this mechanism to either refund amounts over-collected or recoup amounts under-collected as compared to the price paid for natural gas during the period since the last PGA rate change went into effect. At December 31, 2020, the combined balance in the PGA accounts totaled an over-collection of $52.6 million. See PGA Filings for more information.
Southwest Gas Holdings, Inc. has a credit facility with a borrowing capacity of $100 million; in April 2020, the existing credit facility was amended to extend the maturity date to April 2025, while maintaining the borrowing capacity at $100 million. This facility is intended for short-term financing needs. The maximum amount outstanding during 2020 occurred during the first quarter and was $67 million. At December 31, 2020, $50 million was outstanding under this facility.
Southwest has a credit facility with a borrowing capacity of $400 million; in April 2020, Southwest amended the credit facility agreement which extended the maturity date to April 2025. The revolving borrowing capacity under the amended credit facility agreement remains at $400 million following that amendment. Southwest designates $150 million of the facility for long-term borrowing needs and the remaining $250 million for working capital purposes. The maximum amount outstanding during 2020 occurred during the first quarter and was $344 million ($150 million outstanding on the long-term portion of the credit facility, including $50 million under the commercial paper program, in addition to $194 million outstanding on the short-term portion). As of December 31, 2020, $150 million was outstanding on the long-term portion of the credit facility (including $50 million under the commercial paper program), and $57 million was outstanding on the short-term portion. The maximum amount outstanding on the long-term portion of the credit facility (including the commercial paper program) during each of the first, second, third, and fourth quarters of 2020, respectively, was $150 million, $150 million, $64 million and $150 million; the maximum outstanding balance on the short-term portion for each of the first, second, and fourth quarters was $194 million, $161 million, and $57 million, respectively, with none outstanding in the third quarter. The credit facility has been used as necessary to meet liquidity requirements, including temporarily financing under-collected PGA balances, meeting the refund needs of over-collected balances, or temporarily funding capital expenditures.
Southwest has a $50 million commercial paper program as noted above. Any issuance under the commercial paper program is supported by the revolving credit facility and, therefore, does not represent additional borrowing capacity. Any borrowing under the commercial paper program is designated as long-term debt. Interest rates for the commercial paper program are calculated at the then current commercial paper rate. At December 31, 2020, $50 million was outstanding on the commercial paper program.
In June 2020, Southwest issued $450 million aggregate principal amount of 2.20% Senior Notes with a maturity date in June 2030. See Note 8 - Debt for more information.
In May 2019, the Company filed with the SEC an automatic shelf registration statement for the offer and sale of up to $300 million of common stock from time to time in at-the-market offerings under the prospectus included therein in accordance with the Sales Agency Agreement, dated May 8, 2019, between the Company and BNY Mellon Capital Markets, LLC (the Equity Shelf Program discussed above). The Company issued $254 million under this multi-year program for the life-to-date period ended December 31, 2020. Net proceeds from the sales of shares of common stock under the Equity Shelf Program are intended for general corporate purposes, including the acquisition of property for the construction, completion, extension or improvement of pipeline systems and facilities located in and around the communities served by Southwest. See Note 7 - Common Stock.
Centuri has a senior secured revolving credit and term loan facility with an initial borrowing capacity of $590 million. The line of credit portion comprises $325 million; associated amounts borrowed and repaid are available to be reborrowed. The term loan facility portion has a limit of approximately $265 million. The $590 million credit and term loan facility expires in November 2023. It is secured by substantially all of Centuri’s assets except those explicitly excluded under the terms of the agreement (including owned real estate and certain certificated vehicles). Centuri assets securing the facility at December 31, 2020 totaled $1.4 billion. At December 31, 2020, $227 million was outstanding (after repayments) on the term facility. The maximum amount outstanding on the credit facility during 2020 was $312 million, which occurred in the second quarter, at which point $235 million was outstanding on the term loan facility. As of December 31, 2020, there was $27 million


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outstanding and approximately $266 million, net of outstanding letters of credit, available to be borrowed on the Centuri secured revolving credit facility.
Interest rates for the amended credit facilities of the holding company and Southwest are calculated at either LIBOR or an “alternate base rate,” plus, in each case, an applicable margin determined based on each entities’ respective senior unsecured long-term debt rating. Upon the occurrence of certain events providing for a transition away from LIBOR, or if LIBOR is no longer a widely recognized benchmark rate, each entity may amend their respective credit facility with a replacement rate as set forth in the amended credit facility agreement. It is currently anticipated that LIBOR may be discontinued as a benchmark or reference rate after 2021. As of December 31, 2020, $50 million of borrowings outstanding for the holding company under its credit facility, $157 million of Southwest’s outstanding borrowings under its credit facility (other than from its commercial paper program), and $145 million of Centuri’s outstanding borrowings under its credit facility have interest rates with reference to LIBOR and maturity dates that extend beyond 2021. The outstanding amounts reflect approximately 6% of Southwest’s total debt and 12% of total debt (including current maturities) for the Company overall. In order to mitigate the impact of the discontinuation on the Company’s financial condition and results of operations, Southwest and Centuri will continue to monitor developments with respect to alternative rates and work with lenders to determine the appropriate alternative reference rate for variable rate indebtedness. However, at this time the Company and Southwest can provide no assurances as to the impact a LIBOR discontinuation will have on their financial condition or results of operations. Any alternative rate may be less predictable or less attractive than LIBOR. See Reference Rate Reform (ASU 2020-04) discussion under the recently issued accounting pronouncements that will be effective after 2021 in Note 1 - Background, Organization, Summary of Significant Accounting Policies.
Credit Ratings
Credit ratings apply to debt securities such as bonds, notes, and other debt instruments and do not apply to equity securities such as common stock. Borrowing costs and the ability to raise funds are directly impacted by the credit ratings of the Company. Credit ratings issued by nationally recognized ratings agencies (Moody’s Investors Service, Inc. (“Moody’s”), Standard & Poor’s Ratings Services (“Standard & Poor’s”), and Fitch Ratings (“Fitch”)) provide a method for determining the creditworthiness of an issuer. Credit ratings are important because long-term debt constitutes a significant portion of total capitalization. These credit ratings are a factor considered by lenders when determining the cost of current and future debt for both Southwest and Southwest Gas Holdings, Inc. (i.e., generally the better the rating, the lower the cost to borrow funds). The current unsecured long-term debt ratings of both companies are all considered investment grade.
    Moody's (1)  Standard & Poor's (2)  Fitch (3)
Southwest Gas Holdings, Inc.:      
Issuer rating  Baa2  BBB+  BBB+
Outlook  Stable  Stable  Stable
Last reaffirmed  January 2021  September 2020  June 2020
Southwest Gas Corporation:      
Senior unsecured long-term debt  Baa1  A-  A
Outlook  Stable  Stable  Stable
Last reaffirmed  January 2021  September 2020  June 2020
(1)Moody’s debt ratings range from Aaa (highest rating possible) to C (lowest quality, usually in default). A numerical modifier of 1 (high end of the category) through 3 (low end of the category) is included with the rating to indicate the approximate rank of a company within the range. The Moody’s outlook of “stable” was updated and the ratings were lowered in January 2021 for both Southwest and the Company, reflected herein. Moody’s cited regulatory lag, the impacts of tax reform, and borrowings to fund capital expenditures as the primary drivers.
(2)Standard & Poor’s (“S&P”) debt ratings range from AAA (highest rating possible) to D (obligation is in default). The ratings from ‘AA’ to ‘CCC’ may be modified by the addition of a plus “+” or minus “-” sign to show relative standing within the major rating categories.
(3)Fitch debt ratings range from AAA (highest credit quality) to D (defaulted debt obligation). The modifiers “+” or “-” may be appended to a rating to denote relative status within major rating categories.
A credit rating, including the foregoing, is not a recommendation to buy, sell, or hold a debt security, but is intended to provide an estimation of the relative level of credit risk of debt securities, and is subject to change or withdrawal at any time by the rating agency. Numerous factors, including many that are not within management’s control, are considered by the ratings agencies in connection with the assigning of credit ratings.
None of Southwest’s debt instruments have credit triggers or other clauses that result in default if these bond ratings are lowered by rating agencies. Interest and fees on certain debt instruments are subject to adjustment depending on Southwest’s bond ratings. Certain debt instruments are subject to a leverage ratio cap and the 6.1% Notes due 2041 are also subject to a


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minimum net worth requirement. At December 31, 2020, Southwest was in compliance with all of its covenants. Under the most restrictive of the financial covenants, approximately $2.7 billion in additional debt could be issued and the leverage ratio requirement would still be met. At least $1.7 billion of cushion in equity relating to the minimum net worth requirement exists at December 31, 2020. No specific limitations as to dividends exist under the collective covenants. None of the debt instruments contain material adverse change clauses.
At December 31, 2020, Southwest Gas Holdings, Inc. was also in compliance with all of its credit facility covenants. Interest and fees on the credit facility are subject to adjustment depending on its credit ratings. The credit facility is subject to a leverage ratio cap. No specific limitations as to dividends exist under the collective covenants. The credit facility does not contain a material adverse change clause.
Certain Centuri debt instruments have leverage ratio caps and fixed charge ratio coverage requirements. At December 31, 2020, Centuri was in compliance with all of its covenants. Under the most restrictive of the covenants, Centuri could issue over $318 million in additional debt and meet the leverage ratio requirement. Centuri has at least $115 million of cushion relating to the minimum fixed charge ratio coverage requirement. Centuri’s revolving credit and term loan facility is secured by underlying assets of the utility infrastructure services segment. Centuri also has restrictions on how much it could give to the Company in cash dividends, which is limited to 60% of its rolling twelve-month consolidated net income.
Bonus Depreciation
In 2017, with the enactment of U.S. tax reform, the bonus depreciation deduction percentage changed from 50% to 100% for “qualified property” placed in service after September 27, 2017 and before 2023. The bonus depreciation tax deduction phases out starting in 2023, by 20% for each of the five following years. Qualified property excludes public utility property. The Company estimates bonus depreciation will defer the payment of approximately $26 million (none of which relates to utility operations) of federal income taxes for 2021.
Inflation
Inflation can impact results of operations for Southwest and Centuri. Labor, employee benefits, natural gas, professional services, and construction costs are the categories most significantly impacted by inflation. Changes to the cost of gas are generally recovered through PGA mechanisms and do not significantly impact net earnings. Labor, employee benefits, and professional services are components of the cost of service, and gas infrastructure costs are the primary component of utility rate base. In order to recover increased costs, and earn a fair return on rate base, general rate cases are filed by Southwest, when deemed necessary, for review and approval by regulatory authorities. Regulatory lag, that is, the time between the date increased costs are incurred and the time such increases are recovered through the ratemaking process, can impact earnings. See Rates and Regulatory Proceedings for a discussion of recent rate case proceedings.
Off-Balance Sheet Arrangements
All debt is recorded on the balance sheet. Long-term operating and finance leases are described in Note 2 - Utility Plant and Leases and included in the Contractual Obligations table below.
Contractual Obligations
The table below summarizes the Company’s contractual obligations at December 31, 2020:
 Payments due by period
(Millions of dollars)Total20212022-20232024-2025Thereafter
Contractual obligations:
Long-term debt, including current maturities$2,773 $40 $540 $170 $2,023 
Short-term debt107 107 — — — 
Interest on long-term debt1,357 92 161 150 954 
Pipeline capacity/storage434 84 108 62 180 
Gas purchase obligations98 84 10 2 2 
Leases108 14 25 19 50 
Other commitments50 33 16 1 — 
Total$4,927 $454 $860 $404 $3,209 
In the table above, operating leases represent multi-year obligations for buildings, land, equipment and vehicles. Other commitments include obligations relating to the CDMI, as described in Rates and Regulatory Proceedings. Gas purchase obligations include fixed-price and variable-rate gas purchase contracts. Variable-rate contracts reflect minimum contractual obligations with estimation in pricing based on market price information. Actual future variable-rate purchase commitments


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may vary depending on market prices at the time of delivery and these values may change significantly from their estimated amounts. Certain other variable-rate contracts allow for variability in quantities for which associated demand charges are included in the Gas purchase obligations line above, based on the maximum daily quantities available under the contracts. Excluded from the table are renewable natural gas purchase obligations in which the commencement dates are not specifically determinable and the volumes and contract prices are inestimable until certain contract provisions are met.
Southwest has pipeline capacity/storage contracts for firm transportation service, both on a short- and long-term basis, with several companies for all of its service territories, some with terms extending to 2044. Southwest also has interruptible contracts in place that allow additional capacity to be acquired should an unforeseen need arise. Costs associated with these pipeline capacity contracts are a component of the cost of gas sold and are recovered from customers primarily through the PGA mechanisms. Included in the pipeline capacity payments shown in the above table, are payments associated with storage that Southwest has contracted for in southern California.
Debt-related obligations in the table above consist of scheduled principal and interest payments over the life of the debt. Interest rates in effect at December 31, 2020 on variable rate long-term debt were assumed to remain in effect in the future periods disclosed in the table. Interest on long-term debt includes future interest payments of $1.3 billion for Southwest and $15 million for Centuri.
Pension:  Estimated funding for pension and other postretirement benefits during calendar year 2021 is $105 million (including a supplemental discretionary contribution of $50 million) and is not included in the table above. As changes to the discount rate have a significant impact on the pension obligation and estimated future costs, and as the discount rate at the end of 2020 was at a low not experienced in many decades, Southwest elected to make a discretionary supplemental contribution to the pension plan of $50 million in January 2021. This additional contribution was made to mitigate the expected increase in pension costs and provide for additional returns on the increased level of plan assets available for benefits. Funding amounts for years beyond 2021 are not currently known.
Recently Issued Accounting Standards Updates
The FASB routinely issues Accounting Standards Updates. See Note 1 - Background, Organization, and Summary of Significant Accounting Policies for more information regarding these Accounting Standards Updates and their potential impact on the Company’s and Southwest’s financial position, results of operations, and disclosures.
Application of Critical Accounting Policies
A critical accounting policy is one that is very important to the portrayal of the financial condition and results of a company, and requires the most difficult, subjective, or complex judgments of management. The need to make estimates about the effect of items that are uncertain is what makes these judgments difficult, subjective, and/or complex. Management makes subjective judgments about the accounting and regulatory treatment of many items and bases its estimates on historical experience and on various other assumptions that it believes to be reasonable under the circumstances, the results of which form the basis for making judgments. These estimates may change as new events occur, as more experience is acquired, as additional information is obtained, and as the operating environment changes. While management may make many estimates and judgments, many would not be materially altered, or provide a material impact to the financial statements taken as a whole, if different estimates, or means of estimation were employed. The following are accounting policies that are deemed critical to the financial statements. For more information regarding significant accounting policies, see notes to the consolidated financial statements.
Regulatory Accounting
Natural gas operations are subject to the regulation of the ACC, the PUCN, the CPUC, and the FERC. The accounting policies of the Company and Southwest conform to U.S. GAAP applicable to rate-regulated entities and reflect the effects of the ratemaking process. As such, the Company and Southwest are allowed to defer, as regulatory assets, costs that otherwise would be expensed, if it is probable that future recovery from customers will occur. Companies are also permitted to recognize, as regulatory assets, amounts associated with various revenue decoupling mechanisms, as long as the requirements of alternative revenue programs permitted under U.S. GAAP continue to be met. Management reviews the regulatory assets to assess their ultimate recoverability within the approved regulatory guidelines. If rate recovery is no longer probable, due to competition or the actions of regulators, write-off of the related regulatory asset (which would be recognized as current-period expense) is required. Regulatory liabilities are recorded if it is probable that revenues will be reduced for amounts that will be refunded to customers through the ratemaking process. The timing and inclusion of costs in rates is often delayed (regulatory lag) and results in a reduction of current-period earnings. Refer to Note 5 - Regulatory Assets and Liabilities.
Accrued Utility Revenues
Revenues related to the sale and/or delivery of natural gas are generally recorded when natural gas is delivered to customers. However, the determination of natural gas sales to individual customers is based on the reading of their meters, which is


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performed on a systematic basis throughout the month. At the end of each month, operating margin associated with natural gas service that has been provided but not yet billed is accrued. This accrued utility revenue is estimated each month based primarily on applicable rates, number of customers, rate structure, analyses reflecting significant historical trends, seasonality, and experience. The interplay of these assumptions can impact the variability of the accrued utility revenue estimates. All Southwest rate jurisdictions have decoupled rate structures, limiting variability due to extreme weather conditions.
Accounting for Income Taxes
The Company is subject to income taxes in the U.S. and Canada. Income tax calculations require estimates due to known future tax rate changes, book to tax differences, and uncertainty with respect to regulatory treatment of certain property items. The asset and liability method of accounting is utilized for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Regulatory tax assets and liabilities are recorded to the extent management believes they will be recoverable from, or refunded to, customers in future rates. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. Management regularly assesses financial statement tax provisions to identify any change in the regulatory treatment or tax-related estimates, assumptions, or enacted tax rates that could have a material impact on cash flows, financial position, and/or results of operations.
Accounting for Pensions and Other Postretirement Benefits
Southwest has a noncontributory qualified retirement plan with defined benefits covering substantially all employees. In addition, there is a separate unfunded supplemental retirement plan which is limited to officers. Pension obligations and costs for these plans are affected by the amount and timing of cash contributions to the plans, the return on plan assets, discount rates, and by employee demographics, including age, compensation, and length of service. Changes made to the provisions of the plans may also impact current and future pension costs. Actuarial formulas are used in the determination of pension obligations and costs and are affected by actual plan experience and assumptions about future experience. Key actuarial assumptions include the expected return on plan assets, the discount rate used in determining the projected benefit obligation and pension costs, and the assumed rate of increase in employee compensation. Relatively small changes in these assumptions (particularly the discount rate) may significantly affect pension obligations and costs for these plans. For example, a change of 0.25% in the discount rate assumption would change the pension plan projected benefit obligation by approximately $57 million and future pension expense by $6 million. A change of 0.25% in the employee compensation assumption would change the pension obligation by approximately $15 million and expense by $3 million. A 0.25% change in the expected asset return assumption would change pension expense by approximately $3 million (but has no impact on the pension obligation).
At December 31, 2020, the discount rate was 2.75%, a decrease from the 3.50% rate used at December 31, 2019. The methodology utilized to determine the discount rate was consistent with prior years. The weighted-average rate of compensation escalation decreased to 3.00% at December 31, 2020 compared to the 3.25% rate used at December 31, 2019. The asset return assumption of 6.50% to be used for 2021 expense was reduced from the 6.75% rate utilized for 2020. Pension costs for 2021 are estimated to increase approximately $600,000 as compared to that experienced in 2020. Future years’ expense level movements (up or down) will continue to be greatly influenced by long-term interest rates, asset returns, and funding levels.
Goodwill
Goodwill is assessed for impairment annually as of October, or more frequently, if events or changes in circumstances indicate an impairment may have occurred before that time. As permitted under accounting guidance on testing goodwill for impairment, we perform either a qualitative assessment or a quantitative assessment of each of our reporting units based on management’s judgment. Adjustment of values would only occur if conditions of impairment were deemed to be permanent. With respect to our qualitative assessments, we consider events and circumstances specific to us, such as macroeconomic conditions, industry and market considerations, cost factors, and overall financial performance, when evaluating whether it is more likely than not that the fair values of our reporting units are less than their respective carrying amounts. The assumptions we use in our analysis are subject to uncertainty, and declines in the future performance of our reporting units and changing business conditions could result in the recognition of impairment charges, which could be significant. The Company’s reporting units are the same as its segments (natural gas operations and utility infrastructure services) for purposes of impairment evaluation. Almost all of the goodwill on the Company’s consolidated balance sheet pertains to the utility infrastructure services segment.
Business Combinations
In accordance with U.S. GAAP, the assets acquired and liabilities assumed in an acquired business are recorded at their estimated fair values on the date of acquisition. The amount of goodwill initially recognized in a business combination is based on the excess of the purchase price of the acquired company over the fair value of the other assets acquired and liabilities


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assumed. The determination of these fair values requires management to make significant estimates and assumptions. For example, assumptions with respect to the timing and amount of future revenues and expenses associated with an asset are used to determine its fair value, but the actual timing and amount may differ materially, resulting in impairment of the asset’s recorded value. In some cases, the Company engages independent third-party valuation firms to assist in determining the fair values of acquired assets and liabilities assumed. Critical estimates in valuing certain intangible assets include, but are not limited to, future expected cash flows of the acquired business, trademarks, customer relationships, technology obsolescence, and discount rates. In addition, uncertain tax positions and tax-related valuation allowances assumed in connection with a business combination are initially estimated at the acquisition date. These items are reevaluated quarterly, based upon facts and circumstances that existed at the acquisition date with any adjustments to the preliminary estimates being recorded to goodwill, provided that the Company is within the twelve-month measurement period allowed by authoritative guidance. Subsequent to the measurement period or the final determination of the estimated value of the tax allowance or contingency, whichever comes first, changes to these uncertain tax positions and tax-related valuation allowances will affect the provision for income taxes in the Consolidated Statements of Income, and could have a material impact on the Company’s results of operations and financial position.
Certifications
The SEC requires the filing of certifications of the Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”) of registrants regarding reporting accuracy, disclosure controls and procedures, and internal control over financial reporting as exhibits to periodic filings. The CEO and CFO certifications for the period ended December 31, 2020 are included as exhibits to the 2020 Annual Report on Form 10-K filed with the SEC.
Forward-Looking Statements
This annual report contains contains statements which constitute “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 (“Reform Act”). All statements other than statements of historical fact included or incorporated by reference in this annual report are forward-looking statements, including, without limitation, statements regarding the Company’s plans, objectives, goals, intentions, projections, strategies, future events or performance, negotiations, and underlying assumptions. The words “may,” “if,” “will,” “should,” “could,” “expect,” “plan,” “anticipate,” “believe,” “estimate,” “predict,” “project,” “continue,” “forecast,” “intend,” “endeavor,” “promote,” “seek,” and similar words and expressions are generally used and intended to identify forward-looking statements. For example, statements regarding operating margin patterns, customer growth, the composition of our customer base, price volatility including that experienced related to gas prices in early 2021, seasonal patterns, payment of debt, the Company’s COLI strategy, replacement market and new construction market, impacts from the novel Coronavirus (COVID-19), including on our employees, customers, supply chain, transportation network, our financial position, revenue, earnings, cash flows, debt covenants, operations, regulatory recovery, work deployment or resumption and related uncertainties stemming from this pandemic, expected impacts of valuation adjustments associated with any redeemable noncontrolling interest, the impacts of U.S. tax reform including disposition in regulatory proceedings, including future proceedings, and bonus depreciation tax deductions, the impact of recent PHMSA rulemaking, the amounts and timing for completion of estimated future construction expenditures and other projects, plans to pursue infrastructure programs or programs under SB151 legislation, forecasted operating cash flows and results of operations, net earnings impacts or recovery of costs from gas infrastructure replacement and COYL programs and surcharges, including from pending proceedings, funding sources of cash requirements, amounts generally expected to be reflected in future period revenues from regulatory rate proceedings including amounts requested or preliminarily settled from recent and ongoing general rate cases, the outcome of judicial review of the previous Nevada rate case, rates and surcharges, PGA administration and recovery, and other rate adjustments, sufficiency of working capital and current credit facilities, bank lending practices, the Company’s views regarding its liquidity position, ability to raise funds and receive external financing capacity and the intent and ability to issue various financing instruments and stock under the Equity Shelf Program or otherwise, future dividend increases and the Board’s current target dividend payout ratio, pension and postretirement benefits, certain impacts of tax acts, the effect of any other rate changes or regulatory proceedings, contract or construction change order negotiations, impacts of accounting standard updates, statements regarding future gas prices, gas purchase contracts and derivative financial instruments, recoverability of regulatory assets, the impact of certain legal proceedings, and the timing and results of future rate hearings, the final resolution for recovery of the CDMI in all jurisdictions, and statements regarding pending procedures or approvals are forward-looking statements. All forward-looking statements are intended to be subject to the safe harbor protection provided by the Reform Act.


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A number of important factors affecting the business and financial results of the Company could cause actual results to differ materially from those stated in the forward-looking statements. These factors include, but are not limited to, customer growth rates, conditions in the housing market, the impacts of COVID-19 including that which may result from a sustained restriction on commerce by government officials or otherwise, including impacts on employment in our territories, the health impacts to our customers and employees due to the persistence of the virus, the ability to collect on customer accounts due to the current or an extended moratorium on late fees or service disconnection, the ability to obtain regulatory recovery of all costs and financial impacts resulting from this pandemic, the ability of the infrastructure services business to resume work with all customers and the impact of a delay or termination of work as a result thereof, the impacts of future restrictions placed on our business by government regulation or otherwise (such as self-imposed restrictions for the safety of employees and customers), including related to personal distancing, investment in personal protective equipment and other protocols, the impact of a resurgence of the virus following the resumption of commerce in our territories, and decisions of Centuri customers as to whether to pursue capital projects due to economic impacts resulting from the pandemic or otherwise, the ability to recover costs through the PGA mechanisms or other regulatory assets, the effects of regulation/deregulation, governmental or regulatory policy regarding pipeline safety, natural gas or alternative energy, the regulatory support for ongoing infrastructure programs or expansions, the timing and amount of rate relief, the timing and methods determined by regulators to refund amounts to customers resulting from U.S. tax reform, changes in rate design, variability in volume of gas or transportation service sold to customers, changes in gas procurement practices, changes in capital requirements and funding, the impact of credit rating actions and conditions in the capital markets on financing costs, the impact of variable rate indebtedness associated with a discontinuance of LIBOR including in relation to amounts of indebtedness then outstanding, changes in construction expenditures and financing, changes in operations and maintenance expenses, effects of pension expense forecasts, accounting changes and regulatory treatment related thereto, currently unresolved and future liability claims, changes in pipeline capacity for the transportation of gas and related costs, results of Centuri bid work, the impact of weather on Centuri’s operations, future acquisition-related costs, impacts of changes in value of any redeemable noncontrolling interest if at other than fair value, Centuri utility infrastructure expenses, differences between actual and originally expected outcomes of Centuri bid or other fixed-price construction agreements, outcomes from contract and change order negotiations, ability to successfully procure new work, impacts from work awarded or failing to be awarded from significant customers, the mix of work awarded, the amount of work awarded to Centuri following the lifting of work stoppages or reduction, the result of productivity inefficiencies from regulatory requirements or otherwise, delays in commissioning individual projects, acquisitions, and management’s plans related thereto, competition, our ability to raise capital in external financings, our ability to continue to remain within the ratios and other limits subject to our debt covenants, and ongoing evaluations in regard to goodwill and other intangible assets. In addition, the Company can provide no assurance that its discussions regarding certain trends relating to its financing and operating expenses will continue or cease to continue in future periods. For additional information on the risks associated with the Company’s business, see Item 1A. Risk Factors and Item 7A. Quantitative and Qualitative Disclosures About Market Risk in this Annual Report on Form 10-K for the year ended December 31, 2020.
All forward-looking statements in this annual report are made as of the date hereof, based on information available to the Company and Southwest as of the date hereof, and the Company and Southwest assume no obligation to update or revise any of their forward-looking statements even if experience or future changes show that the indicated results or events will not be realized. We caution you to not rely unduly on any forward-looking statement(s).
Common Stock Price and Dividend Information
The principal market on which the common stock of the Company is traded is the New York Stock Exchange and the ticker symbol of the stock is “SWX.” At February 16, 2021, there were 11,690 holders of record of common stock, and the market price of the common stock was $62.36.
Dividends are payable on the Company’s common stock at the discretion of the Board of Directors (the “Board”). In setting the dividend rate, the Board considers, among other factors, current and expected future earnings levels, our ongoing capital expenditure plans and expected external funding needs, our payout ratio, and our ability to maintain credit ratings and liquidity. The quarterly common stock dividend declared was 52.0 cents per share throughout 2018, 54.5 cents per share throughout 2019, and 57.0 cents per share throughout 2020. The Company has paid dividends on its common stock since 1956 and has increased that dividend each year since 2007. In February 2021, the Board elected to increase the quarterly dividend from $0.570 to $0.595 per share, representing a 4.4% increase, effective with the June 2021 payment. The Board currently targets a payout ratio of 55% to 65% of consolidated earnings per share.



24

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Thousands of dollars, except par value)
December 31,
20202019
ASSETS
Utility plant:
Gas plant$8,384,000 $7,813,221 
Less: accumulated depreciation(2,419,348)(2,313,050)
Construction work in progress211,429 185,026 
Net utility plant 6,176,081 5,685,197 
Other property and investments 834,245 784,173 
Current assets:
Cash and cash equivalents83,352 49,539 
Accounts receivable, net of allowances 522,172 474,097 
Accrued utility revenue 82,400 79,100 
Income taxes receivable, net10,884 31,751 
Deferred purchased gas costs 2,053 44,412 
Prepaid and other current assets 170,152 180,957 
Total current assets871,013 859,856 
Noncurrent assets:
Goodwill 345,184 343,023 
Deferred income taxes 455 856 
Deferred charges and other assets 508,875 496,943 
Total noncurrent assets854,514 840,822 
Total assets$8,735,853 $8,170,048 
 
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock, $1 par (authorized – 120,000,000 shares; issued and outstanding – 57,192,925 and 55,007,433 shares)
$58,823 $56,637 
Additional paid-in capital1,609,155 1,466,937 
Accumulated other comprehensive loss, net (61,003)(56,732)
Retained earnings1,067,978 1,039,072 
Total Southwest Gas Holdings, Inc. equity2,674,953 2,505,914 
Redeemable noncontrolling interest 165,716 84,542 
Long-term debt, less current maturities 2,732,200 2,300,482 
Total capitalization5,572,869 4,890,938 
Commitments and contingencies (Note 10)
Current liabilities:
Current maturities of long-term debt 40,433 163,512 
Short-term debt 107,000 211,000 
Accounts payable231,301 238,921 
Customer deposits67,920 69,165 
Income taxes payable, net12,556 2,069 
Accrued general taxes48,640 48,160 
Accrued interest20,536 21,329 
Deferred purchased gas costs 54,636 60,755 
Other current liabilities 328,945 264,950 
Total current liabilities911,967 1,079,861 
Deferred income taxes and other credits:
Deferred income taxes and investment tax credits, net 647,453 599,840 
Accumulated removal costs 404,000 395,000 
Other deferred credits and other long-term liabilities 1,199,564 1,204,409 
Total deferred income taxes and other credits2,251,017 2,199,249 
Total capitalization and liabilities$8,735,853 $8,170,048 
The accompanying notes are an integral part of these statements.


25

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(In thousands, except per share amounts)
 
Year Ended December 31,
202020192018
Operating revenues:
Gas operating revenues$1,350,585 $1,368,939 $1,357,728 
Utility infrastructure services revenues1,948,288 1,750,978 1,522,285 
Total operating revenues3,298,873 3,119,917 2,880,013 
Operating expenses:
Net cost of gas sold342,837 385,164 419,388 
Operations and maintenance408,116 424,150 406,393 
Depreciation and amortization332,027 303,237 249,212 
Taxes other than income taxes63,460 62,328 59,898 
Utility infrastructure services expenses1,729,429 1,573,227 1,387,689 
Total operating expenses2,875,869 2,748,106 2,522,580 
Operating income423,004 371,811 357,433 
Other income and (expenses):
Net interest deductions (111,477)(109,226)(96,671)
Other income (deductions)(6,789)10,085 (17,426)
Total other income and (expenses)(118,266)(99,141)(114,097)
Income before income taxes304,738 272,670 243,336 
Income tax expense 65,753 56,023 61,684 
Net income238,985 216,647 181,652 
Net income (loss) attributable to noncontrolling interest6,661 2,711 (625)
Net income attributable to Southwest Gas Holdings, Inc.$232,324 $213,936 $182,277 
Earnings per share:
Basic $4.15 $3.94 $3.69 
Diluted $4.14 $3.94 $3.68 
Weighted average shares:
Basic 55,998 54,245 49,419 
Diluted 56,076 54,312 49,476 
The accompanying notes are an integral part of these statements.



26

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Thousands of dollars)
 
Year Ended December 31,
202020192018
Net income$238,985 $216,647 $181,652 
Other comprehensive income (loss), net of tax
Defined benefit pension plans:
Net actuarial loss(43,730)(54,026)(15,524)
Amortization of prior service cost878 966 1,015 
Amortization of net actuarial loss28,751 17,766 25,549 
Prior service cost— (1,426)— 
Regulatory adjustment5,650 28,077 (6,257)
Net defined benefit pension plans(8,451)(8,643)4,783 
Forward-starting interest rate swaps (“FSIRS”):
Amounts reclassified into net income2,467 2,541 2,541 
Net forward-starting interest rate swaps2,467 2,541 2,541 
Foreign currency translation adjustments1,713 2,038 (3,010)
Total other comprehensive income (loss), net of tax(4,271)(4,064)4,314 
Comprehensive income234,714 212,583 185,966 
Comprehensive income (loss) attributable to noncontrolling interest6,661 2,711 (625)
Comprehensive income attributable to Southwest Gas Holdings, Inc.$228,053 $209,872 $186,591 
The accompanying notes are an integral part of these statements.



27

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Thousands of dollars)
Year Ended December 31,
202020192018
CASH FLOW FROM OPERATING ACTIVITIES:
Net income $238,985 $216,647 $181,652 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization332,027 303,237 249,212 
Deferred income taxes50,717 54,162 51,041 
Changes in current assets and liabilities:
Accounts receivable, net of allowances(48,772)(54,245)(15,862)
Accrued utility revenue(3,300)(1,900)1,000 
Deferred purchased gas costs36,239 (58,491)82,574 
Accounts payable(7,694)(1,865)11,778 
Accrued taxes15,171 5,243 (11,955)
Other current assets and liabilities107,427 74,137 (54,073)
Gains on sale of equipment(1,848)(5,473)(1,703)
Changes in undistributed stock compensation7,114 6,896 6,111 
Equity AFUDC(4,724)(4,161)(3,627)
Changes in deferred charges and other assets(32,591)(21,051)(5,738)
Changes in other liabilities and deferred credits(62,671)(12,764)38,446 
Net cash provided by operating activities626,080 500,372 528,856 
CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions(825,105)(938,148)(765,914)
Acquisition of businesses, net of cash acquired— (47,638)(251,373)
Changes in customer advances14,033 19,001 13,463 
Other 9,003 15,153 4,341 
Net cash used in investing activities(802,069)(951,632)(999,483)
CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net139,245 157,946 354,402 
Dividends paid(125,504)(116,127)(100,240)
Issuance of long-term debt, net662,377 531,596 565,172 
Retirement of long-term debt(356,406)(213,789)(237,758)
Change in short-term debt(104,000)59,000 (62,500)
Withholding remittance – share-based compensation(2,736)(1,858)(3,110)
Other(3,402)(1,488)(3,392)
Net cash provided by financing activities209,574 415,280 512,574 
Effects of currency translation on cash and cash equivalents228 158 (208)
Change in cash and cash equivalents33,813 (35,822)41,739 
Cash and cash equivalents at beginning of period49,539 85,361 43,622 
Cash and cash equivalents at end of period$83,352 $49,539 $85,361 
SUPPLEMENTAL INFORMATION:
Interest paid, net of amounts capitalized$105,182 $102,258 $86,562 
Income taxes paid (received), net$(10,951)$2,752 $1,221 
 The accompanying notes are an integral part of these statements.


28

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF EQUITY
(In thousands, except per share amounts)
 
Year Ended December 31,
202020192018
Common stock shares
Beginning balances55,007 53,026 48,090 
Common stock issuances2,186 1,981 4,936 
Ending balances57,193 55,007 53,026 
Common stock amount
Beginning balances$56,637 $54,656 $49,720 
Common stock issuances2,186 1,981 4,936 
Ending balances58,823 56,637 54,656 
Additional paid-in capital
Beginning balances1,466,937 1,305,769 955,332 
Common stock issuances142,218 161,620 353,147 
Change in ownership of noncontrolling interest— (452)(2,710)
Ending balances1,609,155 1,466,937 1,305,769 
Accumulated other comprehensive loss
Beginning balances(56,732)(52,668)(47,682)
Foreign currency exchange translation adjustment1,713 2,038 (3,010)
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax(8,451)(8,643)4,783 
FSIRS amounts reclassified to net income, net of tax2,467 2,541 2,541 
Reclassification of excess deferred taxes— — (9,300)
Ending balances(61,003)(56,732)(52,668)
Retained earnings
Beginning balances1,039,072 944,285 857,398 
Net income232,324 213,936 182,277 
Redemption value adjustments(74,513)— — 
Dividends declared(128,905)(119,149)(104,690)
Reclassification of excess deferred taxes— — 9,300 
Ending balances1,067,978 1,039,072 944,285 
Total Southwest Gas Holdings, Inc. equity ending balances2,674,953 2,505,914 2,252,042 
Noncontrolling interest
Beginning balances— (452)(2,365)
Net loss— — (797)
Change in ownership of noncontrolling interest— 452 2,710 
Ending balances— — (452)
Total equity ending balances$2,674,953 $2,505,914 $2,251,590 
Dividends declared per common share$2.28 $2.18 $2.08 
The accompanying notes are an integral part of these statements.


29

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Thousands of dollars)
December 31,
20202019
ASSETS
Utility plant:
Gas plant$8,384,000 $7,813,221 
Less: accumulated depreciation(2,419,348)(2,313,050)
Construction work in progress211,429 185,026 
Net utility plant 6,176,081 5,685,197 
Other property and investments 143,611 133,787 
Current assets:
Cash and cash equivalents41,070 40,489 
Accounts receivable, net of allowance 146,861 150,793 
Accrued utility revenue 82,400 79,100 
Income taxes receivable, net11,155 25,901 
Deferred purchased gas costs 2,053 44,412 
Prepaid and other current assets 152,748 165,639 
Total current assets436,287 506,334 
Noncurrent assets:
Goodwill 10,095 10,095 
Deferred charges and other assets 490,562 463,333 
Total noncurrent assets500,657 473,428 
Total assets$7,256,636 $6,798,746 
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock $49,112 $49,112 
   Additional paid-in capital1,410,345 1,229,083 
Accumulated other comprehensive loss, net (61,135)(55,151)
Retained earnings835,146 782,108 
Total equity2,233,468 2,005,152 
Long-term debt, less current maturities 2,438,206 1,991,333 
Total capitalization4,671,674 3,996,485 
Commitments and contingencies (Note 10)
Current liabilities:
Current maturities of long-term debt— 125,000 
Short-term debt 57,000 194,000 
Accounts payable161,646 149,368 
Customer deposits67,920 69,165 
Accrued general taxes48,640 48,160 
Accrued interest20,495 21,256 
Deferred purchased gas costs 54,636 60,755 
Payable to parent142 844 
Other current liabilities 146,046 126,573 
Total current liabilities556,525 795,121 
Deferred income taxes and other credits:
Deferred income taxes and investment tax credits, net 581,100 539,050 
Accumulated removal costs404,000 395,000 
Other deferred credits and other long-term liabilities 1,043,337 1,073,090 
Total deferred income taxes and other credits2,028,437 2,007,140 
Total capitalization and liabilities$7,256,636 $6,798,746 
The accompanying notes are an integral part of these statements.


30

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(Thousands of dollars)
 
Year Ended December 31,
202020192018
Gas operating revenues$1,350,585 $1,368,939 $1,357,728 
Operating expenses:
Net cost of gas sold342,837 385,164 419,388 
Operations and maintenance406,382 422,174 404,813 
Depreciation and amortization235,295 215,620 191,816 
Taxes other than income taxes63,460 62,328 59,898 
Total operating expenses1,047,974 1,085,286 1,075,915 
Operating income302,611 283,653 281,813 
Other income and (expenses):
Net interest deductions (101,148)(95,026)(81,740)
Other income (deductions)(6,590)9,517 (17,240)
Total other income and (expenses)(107,738)(85,509)(98,980)
Income before income taxes194,873 198,144 182,833 
Income tax expense35,755 34,973 43,991 
Net income$159,118 $163,171 $138,842 
The accompanying notes are an integral part of these statements.



31

 SOUTHWEST GAS CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Thousands of dollars)
 
Year Ended December 31,
202020192018
Net income $159,118 $163,171 $138,842 
Other comprehensive income (loss), net of tax
Defined benefit pension plans:
Net actuarial loss(43,730)(54,026)(15,524)
Amortization of prior service cost878 966 1,015 
Amortization of net actuarial loss28,751 17,766 25,549 
Prior service cost— (1,426)— 
Regulatory adjustment5,650 28,077 (6,257)
Net defined benefit pension plans(8,451)(8,643)4,783 
Forward-starting interest rate swaps (“FSIRS”):
Amounts reclassified into net income 2,467 2,541 2,541 
Net forward-starting interest rate swaps2,467 2,541 2,541 
Total other comprehensive income (loss), net of tax (5,984)(6,102)7,324 
Comprehensive income $153,134 $157,069 $146,166 
The accompanying notes are an integral part of these statements.
 



32

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Thousands of dollars)
 
Year Ended December 31,
202020192018
CASH FLOW FROM OPERATING ACTIVITIES:
Net income $159,118 $163,171 $138,842 
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization235,295 215,620 191,816 
Deferred income taxes44,997 33,681 42,999 
Changes in current assets and liabilities:
Accounts receivable, net of allowances3,933 (10,737)(20,309)
Accrued utility revenue(3,300)(1,900)1,000 
Deferred purchased gas costs36,239 (58,491)82,574 
Accounts payable9,618 (27,473)23,408 
Accrued taxes(1,527)8,895 (18,732)
Other current assets and liabilities48,545 89,171 (91,444)
Changes in undistributed stock compensation5,294 5,146 5,355 
Equity AFUDC(4,724)(4,161)(3,627)
Changes in deferred charges and other assets(44,291)(31,767)(7,049)
Changes in other liabilities and deferred credits(65,136)(13,361)37,669 
Net cash provided by operating activities424,061 367,794 382,502 
CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions(692,216)(778,748)(682,869)
Changes in customer advances14,033 19,001 13,463 
Other 771 (95)14 
Net cash used in investing activities(677,412)(759,842)(669,392)
CASH FLOW FROM FINANCING ACTIVITIES:
Contributions from parent177,922 159,936 113,549 
Dividends paid(104,500)(95,900)(87,000)
Issuance of long-term debt, net446,508 297,222 297,495 
Retirement of long-term debt(125,000)— — 
Change in short-term debt(137,000)42,000 (39,000)
Withholding remittance – share-based compensation(2,736)(1,858)(3,110)
Other(1,262)(825)(1,028)
Net cash provided by financing activities253,932 400,575 280,906 
Change in cash and cash equivalents581 8,527 (5,984)
Cash and cash equivalents at beginning of period40,489 31,962 37,946 
Cash and cash equivalents at end of period$41,070 $40,489 $31,962 
SUPPLEMENTAL INFORMATION:
Interest paid, net of amounts capitalized$96,726 $88,658 $73,805 
Income taxes paid (received), net$(19,603)$678 $(5,856)
The accompanying notes are an integral part of these statements.


33

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF EQUITY
(In thousands)
 
Year Ended December 31,
202020192018
Common stock shares
Beginning and ending balances47,482 47,482 47,482 
Common stock amount
Beginning and ending balances$49,112 $49,112 $49,112 
Additional paid-in capital
Beginning balances1,229,083 1,065,242 948,767 
Share-based compensation3,340 3,905 2,926 
Contributions from Southwest Gas Holdings, Inc.177,922 159,936 113,549 
Ending balances1,410,345 1,229,083 1,065,242 
Accumulated other comprehensive loss
Beginning balances(55,151)(49,049)(47,073)
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax
(8,451)(8,643)4,783 
FSIRS amounts reclassified to net income, net of tax2,467 2,541 2,541 
Reclassification of excess deferred taxes— — (9,300)
Ending balances(61,135)(55,151)(49,049)
Retained earnings
Beginning balances782,108 717,155 659,193 
Net income 159,118 163,171 138,842 
Share-based compensation(780)(618)(680)
Dividends declared to Southwest Gas Holdings, Inc.(105,300)(97,600)(89,500)
Reclassification of excess deferred taxes— — 9,300 
Ending balances835,146 782,108 717,155 
Total Southwest Gas Corporation equity ending balances$2,233,468 $2,005,152 $1,782,460 
The accompanying notes are an integral part of these statements.



34

Note 1 - Background, Organization, and Summary of Significant Accounting Policies
Nature of Operations. This is a combined annual report of Southwest Gas Holdings, Inc. and its subsidiaries (the “Company”) and Southwest Gas Corporation and its subsidiaries (“Southwest” or the “natural gas operations” segment). The notes to the consolidated financial statements apply to both entities. Southwest Gas Holdings, Inc., a Delaware corporation, is a holding company, owning all of the shares of common stock of Southwest and all of the shares of common stock of Centuri Group, Inc. (“Centuri” or the “utility infrastructure services” segment).
Southwest is engaged in the business of purchasing, distributing, and transporting natural gas for customers in portions of Arizona, Nevada, and California. Public utility rates, practices, facilities, and service territories of Southwest are subject to regulatory oversight. The timing and amount of rate relief can materially impact results of operations. Natural gas purchases and the timing of related recoveries can materially impact liquidity. Results for the natural gas operations segment are higher during winter periods due to the seasonality incorporated in its regulatory rate structures.
Centuri is a comprehensive utility infrastructure services enterprise dedicated to delivering a diverse array of solutions to North America’s gas and electric providers. Centuri derives revenue primarily from installation, replacement, repair, and maintenance of energy distribution systems. Centuri operations are generally conducted under the business names of NPL Construction Co. (“NPL”), NPL Canada Ltd. (“NPL Canada”), New England Utility Constructors, Inc. (“Neuco”), and Linetec Services, LLC (“Linetec”). Utility infrastructure services activity is seasonal in many of Centuri’s operating areas. Peak periods are the summer and fall months in colder climate areas, such as the northeastern and midwestern United States (“U.S.”) and in Canada. In warmer climate areas, such as the southwestern and southeastern U.S., utility infrastructure services activity continues year round.
Basis of Presentation. The Company follows accounting principles generally accepted in the United States (“U.S. GAAP”) in accounting for all of its businesses. Unless specified otherwise, all amounts are in U.S. dollars. Accounting for natural gas utility operations conforms with U.S. GAAP as applied to rate-regulated companies and as prescribed by federal agencies and commissions of the various states in which the utility operates. The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Consolidation. The accompanying financial statements are presented on a consolidated basis for Southwest Gas Holdings, Inc. and all subsidiaries and Southwest Gas Corporation and all subsidiaries as of December 31, 2020 (except those accounted for using the equity method as discussed below). All significant intercompany balances and transactions have been eliminated with the exception of transactions between Southwest and Centuri in accordance with accounting treatment for rate-regulated entities.
Centuri, through its subsidiaries, holds a 50% interest in W.S. Nicholls Western Construction Ltd. (“Western”), a Canadian infrastructure services company that is a variable interest entity. Centuri determined that it is not the primary beneficiary of the entity due to a shared-power structure; therefore, Centuri does not consolidate the entity and has recorded its investment, and results related thereto, using the equity method. The investment in Western, related earnings, and dividends received from Western in 2020 and 2019 were not significant. Centuri’s maximum exposure to loss as a result of its involvement with Western was estimated at $12.2 million as of December 31, 2020.
Fair Value Measurements. Certain assets and liabilities are reported at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date.
U.S. GAAP states that a fair value measurement should be based on the assumptions that market participants would use in pricing the asset or liability and establishes a fair value hierarchy that ranks the inputs used to measure fair value by their reliability. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to fair values derived from unobservable inputs (Level 3 measurements). Financial assets and liabilities are categorized in their entirety based on the lowest level of input that is significant to the fair value measurement. The three levels of the fair value hierarchy are as follows:
Level 1 – quoted prices (unadjusted) in active markets for identical assets or liabilities that a company has the ability to access at the measurement date.
Level 2 – inputs other than quoted prices included within Level 1 that are observable for similar assets or liabilities, either directly or indirectly.


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Level 3 – unobservable inputs for the asset or liability. Unobservable inputs are used to measure fair value to the extent that observable inputs are not available, thereby allowing for situations in which there is little, if any, market activity for the asset or liability at the measurement date.
The Company primarily used quoted market prices and other observable market pricing information in valuing cash and cash equivalents, derivatives, long-term debt outstanding, and assets of the qualified pension plan and the postretirement benefits other than pensions required to be recorded and/or disclosed at fair value. The Company uses prices and inputs that are current as of the measurement date, and recognizes transfers between levels at either the actual date of an event or a change in circumstance that caused the transfer.
Net Utility Plant. Net utility plant includes gas plant at original cost, less the accumulated provision for depreciation and amortization, plus any unamortized balance of acquisition adjustments. Original cost generally includes contracted services, material, payroll, and related costs such as taxes and certain benefits, general and administrative expenses, and an allowance for funds used during construction, less contributions in aid of construction. See also Depreciation and Amortization below.
Other Property and Investments. Other property and investments on Southwest’s and the Company’s Consolidated Balance Sheets includes:
December 31,
(Thousands of dollars)20202019
Southwest Gas Corporation:
Net cash surrender value of COLI policies$140,874 $132,072 
Other property2,737 1,715 
Total Southwest Gas Corporation143,611 133,787 
Centuri property, equipment, and intangibles1,089,414 983,905 
Centuri accumulated provision for depreciation and amortization(422,741)(352,333)
Other property23,961 18,814 
Total Southwest Gas Holdings, Inc.$834,245 $784,173 
Included in the table above are the net cash surrender values of company-owned life insurance (“COLI”) policies. These life insurance policies on members of management and other key employees are used by Southwest to indemnify itself against the loss of talent, expertise, and knowledge, as well as to provide indirect funding for certain nonqualified benefit plans.
Intangible Assets. Intangible assets (other than goodwill) are amortized using the straight-line method to reflect the pattern of economic benefits consumed over the estimated periods benefited. The recoverability of intangible assets is evaluated when events or circumstances indicate that a revision of estimated useful lives is warranted or that an intangible asset may be impaired. Non-utility intangible assets are associated with utility infrastructure services businesses previously acquired. All have finite lives. These intangible assets are included in Other property and investments on the Company’s Consolidated Balance Sheets. Centuri’s intangible assets, not including goodwill, at December 31, 2020 and 2019, respectively, were as follows:
December 31, 2020
(Thousands of dollars)
Gross Carrying
Amount
Accumulated
Amortization
Net Carrying
Amount
Customer relationships$154,757 $(29,237)$125,520 
Trade names and trademarks23,618 (8,954)14,664 
Customer contracts backlog270 (270)— 
Noncompete agreements1,931 (1,931)— 
Total$180,576 $(40,392)$140,184 
December 31, 2019
Customer relationships$154,186 $(20,735)$133,451 
Trade names and trademarks23,353 (6,754)16,599 
Customer contracts backlog270 (252)18 
Noncompete agreements2,045 (1,602)443 
Total$179,854 $(29,343)$150,511 


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Amortization expense for the acquired intangible assets listed above for the years ended December 31, 2020, 2019, and 2018 was $10.8 million, $10.7 million, and $7.6 million, respectively.
The estimated future amortization of the intangible assets for the next five years and thereafter is as follows:
(Thousands of dollars)
2021$10,343 
202210,255 
202310,255 
202410,255 
202510,211 
Thereafter88,865 
Total$140,184 
See Note 2 - Utility Plant and Leases for additional information regarding natural gas operations intangible assets.
Cash and Cash Equivalents. For purposes of reporting consolidated cash flows, cash and cash equivalents include cash on hand and financial instruments with original maturities of three months or less. Such investments are carried at cost, which approximates market value. Cash and cash equivalents for Southwest and the Company also include money market fund investments totaling approximately $40,000 for both entities at December 31, 2020, and $23.5 million and $26.7 million, for each, respectively, at December 31, 2019, which fall within Level 2 of the fair value hierarchy, due to the asset valuation methods used by money market funds.
Typical non-cash investing activities for Southwest include customer advances applied as contributions toward utility construction activity and capital expenditures that were not paid as of year end that are included in accounts payable. Amounts related to such activities were not significant for the periods presented herein. Also, see Note 2 - Utility Plant and Leases for information related to right-of-use (“ROU”) assets obtained in exchange for lease liabilities, which are non-cash investing and financing activities. ROU assets and lease liabilities are also subject to non-cash impacts as a result of other factors, such as lease terminations and modifications.
Income Taxes. The asset and liability method of accounting is utilized for the recognition of income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are anticipated to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the period that includes the enactment date. For regulatory and financial reporting purposes, investment tax credits (“ITC”) related to gas utility operations are deferred and amortized over the life of related fixed assets. As of December 31, 2020, the Company had cumulative book earnings of approximately $47 million in its foreign jurisdiction. Management previously asserted and continues to assert that all the earnings of Centuri’s Canadian subsidiaries will be permanently reinvested in Canada. As a result, no U.S. deferred income taxes have been recorded related to cumulative foreign earnings.
The Financial Accounting Standards Board (the “FASB”) issued guidance to allow an accounting policy election of either (i) treating taxes attributable to future taxable income related to Global Intangible Low-Taxed Income (“GILTI”) as a current period expense when incurred or (ii) recognizing deferred taxes for temporary differences expected to reverse as GILTI in future years. The Company has elected to treat GILTI as a current period cost when incurred and has considered the estimated 2020 GILTI impact, which was immaterial, in its 2020 tax expense.
Deferred Purchased Gas Costs. The various regulatory commissions have established procedures to enable Southwest to adjust its billing rates for changes in the cost of natural gas purchased. The difference between the current cost of gas purchased and the cost of gas recovered in billed rates is deferred. Generally, these deferred amounts are recovered or refunded within one year.
In mid-February 2021, the central U.S. (from south Texas to North Dakota and the eastern Rocky Mountains) experienced extreme cold temperatures, which increased natural gas demand and caused temporary shortages due to wellhead freeze-off. These conditions caused daily natural gas prices to reach unprecedented levels. During this time, Southwest secured natural gas supplies, albeit at substantially higher prices, and was able to maintain service to its customers. The incremental costs for these natural gas supplies (estimated at $200 million to $300 million) are expected to be funded using existing cash on hand and short-term borrowings, including current credit facilities. It is anticipated that these incremental gas costs will be recoverable from customers through the purchased gas adjustment (“PGA”) mechanisms in each jurisdiction.


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Prepaid and other current assets. Prepaid and other current assets for Southwest and the Company include, among other things, gas pipe materials and operating supplies of $50 million in 2020 and $57 million in 2019 (carried at weighted average cost), as well as $1 million in 2020 and $33 million in 2019 related to a regulatory asset associated with the Arizona decoupling mechanism (an alternative revenue program).
Goodwill. As required by U.S. GAAP, goodwill is assessed for impairment annually, or more frequently, if circumstances indicate impairment to the carrying value of goodwill may have occurred. The goodwill impairment analysis was conducted as of October 1st using a qualitative assessment, as permitted by U.S. GAAP. Management of the Company and Southwest considered its reporting units and segments and determined that its segments and reporting units remain consistent between periods presented below, and that no change was necessary with regard to the level at which goodwill is assessed for impairment. The Company and Southwest determined that it is not more likely than not that the fair value of the reporting units was less than their carrying amounts in either 2020 or 2019. Thus, no impairment was recorded in either year. Goodwill on Southwest’s and the Company’s Consolidated Balance Sheets includes:
(Thousands of dollars)Natural Gas Operations
Utility
Infrastructure
Services
Total
Company
Balance, December 31, 2018$10,095 $348,950 $359,045 
Measurement-period adjustments - Linetec acquisition— (21,172)(21,172)
Foreign currency translation adjustment— 5,150 5,150 
Balance, December 31, 201910,095 332,928 343,023 
Foreign currency translation adjustment— 2,161 2,161 
Balance, December 31, 2020$10,095 $335,089 $345,184 
Other Current Liabilities. Management recognizes in its balance sheets various liabilities that are expected to be settled through future cash payment within the next twelve months, including certain regulatory liabilities (refer to Note 5 - Regulatory Assets and Liabilities), customary accrued expenses for employee compensation and benefits, and declared but unpaid dividends. Other current liabilities for the Company includes $32.6 million and $30 million of dividends declared as of December 31, 2020 and 2019, respectively.
Accumulated Removal Costs. Approved regulatory practices allow Southwest to include in depreciation expense a component intended to recover removal costs associated with utility plant retirements. In accordance with the Securities and Exchange Commission (“SEC”) position on presentation of these amounts, management reclassifies estimated removal costs from Accumulated depreciation to Accumulated removal costs within the liabilities section of the Consolidated Balance Sheets. Management regularly updates the estimated accumulated removal costs as amounts fluctuate between periods depending on the level of replacement work performed, the estimated cost of removal in rates, and the actual cost of removal experienced.
Gas Operating Revenues. Southwest recognizes revenue when it satisfies its performance by transferring gas to the customer. Natural gas is delivered and “consumed” by the customer simultaneously. Revenues are recorded when customers are billed. Customer billings are substantially based on monthly meter reads and include certain other charges assessed monthly, and are calculated in accordance with applicable tariffs and state and local laws, regulations, and related agreements. An estimate of the margin associated with natural gas service provided, but not yet billed, to residential and commercial customers from the latest meter read date to the end of the reporting period is also recognized as accrued utility revenue. Revenues also include the net impacts of margin tracker/decoupling accruals based on criteria in U.S. GAAP for rate-regulated entities associated with alternative revenue programs. All of Southwest’s service territories have decoupled rate structures, which are designed to eliminate the direct link between volumetric sales and revenue, thereby mitigating the impacts of unusual weather variability and conservation on margin. See Note 3 - Revenue.
Utility Infrastructure Services Revenues. The majority of Centuri contracts are performed under unit-price contracts. Generally, these contracts state prices per unit of installation. Typical installations are accomplished in a few weeks or less. Revenues are recorded as installations are completed. Revenues are recorded for long-term fixed-price contracts in a pattern that reflects the transfer of control of promised goods and services to the customer over time. The amount of revenue recognized on fixed-price contracts is based on costs expended to date relative to anticipated final contract costs. Changes in job performance, job conditions, and final contract settlements are factors that influence management’s assessment of total contract value and the total estimated costs to complete those contracts. Revisions in estimates of costs and earnings during the course of work are reflected in the accounting period in which the facts requiring revision become known. If a loss on a contract becomes known or is anticipated, the entire amount of the estimated ultimate loss is recognized at that time in the financial statements. Some unit-price contracts contain caps that if encroached, trigger revenue and loss recognition similar to a fixed-price contract model. See Note 3 - Revenue.


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Utility Infrastructure Services Expenses. Centuri’s utility infrastructure services expenses in the Consolidated Statements of Income includes payroll expenses, office and equipment rental costs, subcontractor expenses, training, job-related materials, gains and losses on equipment sales, and professional fees.
Net Cost of Gas Sold. Components of net cost of gas sold include natural gas commodity costs (fixed-price and variable-rate), pipeline capacity/transportation costs, and actual settled costs of natural gas derivative instruments, where relevant. Also included are the net impacts of PGA deferrals and recoveries, which by their inclusion, result in net cost of gas sold overall that is comparable to amounts included in billed gas operating revenues. Differences between amounts incurred with suppliers, transmission pipelines, etc. and amounts already included in customer rates, are temporarily deferred in PGA accounts pending inclusion in customer rates.
Operations and Maintenance Expense. Operations and maintenance expense includes Southwest’s operating and maintenance costs associated with serving utility customers and maintaining its distribution and transmission systems, uncollectible expense, administrative and general salaries and expense, employee benefits expense excluding relevant non-service cost components, and legal expense (including injuries and damages).
Depreciation and Amortization. Utility plant depreciation is computed on the straight-line remaining life method at composite rates considered sufficient to amortize costs over estimated service lives, including components which compensate for removal costs (net of salvage value), and retirements, as approved by the appropriate regulatory agency. When plant is retired from service, the original cost of plant, including cost of removal, less salvage, is charged to the accumulated provision for depreciation. See also discussion regarding Accumulated Removal Costs above. Other regulatory assets, including acquisition adjustments, are amortized when appropriate, over time periods authorized by regulators. Non-utility and utility infrastructure services-related property and equipment are depreciated on a straight-line method based on the estimated useful lives of the related assets. Costs and gains related to refunding utility debt and debt issuance expenses are deferred and amortized over the weighted-average lives of the new issues and become a component of interest expense.
Allowance for Funds Used During Construction (“AFUDC”). AFUDC represents the cost of both debt and equity funds used to finance utility construction. AFUDC is capitalized as part of the cost of utility plant. The debt portion of AFUDC is reported in the Company’s and Southwest’s Consolidated Statements of Income as an offset to Net interest deductions and the equity portion is reported as Other income. Utility plant construction costs, including AFUDC, are recovered in authorized rates through depreciation when completed projects are placed into operation, and general rate relief is requested and granted. AFUDC, disaggregated by type, included in the Company’s and Southwest’s Consolidated Statements of Income are presented in the table below:
(Thousands of dollars)202020192018
AFUDC:
Debt portion$3,202 $4,558 $3,264 
Equity portion4,724 4,161 3,627 
AFUDC capitalized as part of utility plant$7,926 $8,719 $6,891 
AFUDC rate5.51 %5.36 %5.85 %


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Other Income (Deductions). The following table provides the composition of significant items included in Other income (deductions) on the Consolidated Statements of Income: 
(Thousands of dollars)202020192018
Southwest Gas Corporation – natural gas operations segment:
Change in COLI policies$9,200 $17,400 $(3,200)
Interest income4,015 6,356 6,020 
Equity AFUDC4,724 4,161 3,627 
Other components of net periodic benefit cost(20,022)(15,059)(21,059)
Miscellaneous income and (expense)(4,507)(3,341)(2,628)
Southwest Gas Corporation – total other income (deductions)(6,590)9,517 (17,240)
Utility infrastructure services segment:
Interest income— — 88 
Foreign transaction gain (loss)(16)546 (222)
Equity in earnings of unconsolidated investment – Western80 439 531 
Miscellaneous income and (expense)(271)(519)(635)
Centuri – total other income (deductions)(207)466 (238)
Corporate and administrative8 102 52 
Consolidated Southwest Gas Holdings, Inc. - total other income (deductions)
$(6,789)$10,085 $(17,426)
Included in the table above is the change in COLI policies (including net death benefits recognized). Current tax regulations provide for tax-free treatment of life insurance (death benefit) proceeds. Therefore, changes in the cash surrender value components of COLI policies, as they progress towards the ultimate death benefits, are also recorded without tax consequences.
Derivatives. In managing its natural gas supply portfolios, Southwest has historically entered into fixed- and variable-price contracts, which qualify as derivatives. Additionally, Southwest has utilized fixed-for-floating swap contracts (“Swaps”) to supplement its fixed-price contracts. The fixed-price contracts, firm commitments to purchase a fixed amount of gas in the future at a fixed price, qualify for the normal purchases and normal sales exception that is allowed for contracts that are probable of delivery in the normal course of business, and are exempt from fair value reporting. The variable-price contracts qualify as derivative instruments; however, because the contract price is the prevailing price at the future transaction date, no fair value adjustment is required. In consultation with its regulators, management does not currently anticipate entering into new Swaps in the near term and the recently remaining Swaps matured in October 2020. Southwest does not utilize derivative financial instruments for speculative purposes, nor does it have trading operations.
Previously, Southwest entered into two forward-starting interest rate swaps (“FSIRS”). One of the FSIRS became fully amortized in the third quarter of 2020, with one FSIRS remaining to be amortized through 2022. The settled position for the remaining FSIRS is immaterial and will continue to be amortized from Accumulated other comprehensive income (loss) into interest expense.
Foreign Currency Translation. Foreign currency-denominated assets and liabilities of consolidated subsidiaries are translated into U.S. dollars at exchange rates existing at the respective balance sheet dates. Translation adjustments resulting from fluctuations in exchange rates are recorded as a separate component of accumulated other comprehensive income within stockholders’ equity. Results of operations of foreign subsidiaries are translated using the monthly weighted-average exchange rates during the respective periods. Gains and losses resulting from foreign currency transactions are included in Other income and (expenses) of the Company. Gains and losses resulting from intercompany foreign currency transactions that are of a long-term investment nature are reported in Other comprehensive income, if applicable.



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Earnings Per Share. Basic earnings per share (“EPS”) in each period of this report were calculated by dividing net income attributable to Southwest Gas Holdings, Inc. by the weighted-average number of shares during those periods. Diluted EPS includes additional weighted-average common stock equivalents (performance shares and restricted stock units). Unless otherwise noted, the term “Earnings Per Share” refers to Basic EPS. A reconciliation of the denominator used in Basic and Diluted EPS calculations is shown in the following table:
(In thousands)202020192018
Weighted average basic shares55,998 54,245 49,419 
Effect of dilutive securities:
Management Incentive Plan shares— 12 25 
Restricted stock units (1)78 55 32 
Weighted average diluted shares56,076 54,312 49,476 
(1) The number of securities granted for 2020, 2019, and 2018 includes 69,000, 46,000, and 23,000 performance shares, respectively, the total of which was derived by assuming that target performance will be achieved during the relevant performance period.
Redeemable Noncontrolling Interest. In connection with acquisition of Linetec in November 2018, the previous owner retained a 20% equity interest, the reduction of which is subject to certain rights based on the passage of time or upon the occurrence of certain triggering events. See Note 15 - Redeemable Noncontrolling Interest.
Recent Accounting Standards Updates.    
Accounting pronouncements adopted in 2020:
In June 2016, the FASB issued ASU 2016-13 “Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The update requires the measurement of all expected credit losses for financial assets held at the reporting date based on historical experience, current conditions, and reasonable and supportable forecasts. The Company and Southwest adopted the update in the first quarter of 2020, and concluded the impact was not material to the consolidated financial statements of the Company or Southwest. See Note 4 - Receivables and Related Allowances.
In January 2017, the FASB issued ASU 2017-04 “Intangibles – Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” Under the update, an entity will apply a one-step quantitative test as opposed to a two-step test as previously required, and record the amount of goodwill impairment as the excess of a reporting unit's carrying amount over its fair value, not to exceed the total amount of goodwill allocated to the reporting unit. The new guidance does not amend the optional qualitative assessment of goodwill impairment. The Company and Southwest adopted the update in the first quarter of 2020.
In August 2018, the FASB issued ASU 2018-14 “Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans.” This update removes disclosures that are no longer considered cost-beneficial, clarifies the specific requirements of disclosures, and adds disclosure requirements identified as relevant. The update applies to all employers that sponsor defined benefit pension or other postretirement plans. The Company and Southwest modified their disclosures to conform to the requirements, where applicable. See Note 11 - Pension and Other Postretirement Benefits.
In August 2018, the FASB issued ASU 2018-15 “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract.” The update generally aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement (that is a service contract) with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software, with the exception that such costs are to be included in the same line item in the balance sheet that a prepayment of the fees associated with the arrangement would be presented. Once capitalized, the update also requires the entity to expense the amount capitalized over the term of the hosting arrangement, including reasonably certain renewal periods. The Company and Southwest adopted the update in the first quarter of 2020 using the prospective transition method, which did not result in a material impact to the Company’s or Southwest’s consolidated financial statements.
Recently issued accounting pronouncements that will be effective in 2021:
In December 2019, the FASB issued ASU 2019-12 “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes.” The update simplifies the accounting for income taxes by removing certain exceptions to the general principles, as well as improving consistent application in Topic 740 by clarifying and amending existing guidance. The update is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020. Management does not believe the update will have a material impact on the Company’s and Southwest’s consolidated financial statements and disclosures.



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Recently issued accounting pronouncements that will be effective after 2021:
In March 2020, the FASB issued ASU 2020-04 “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting.” The update provides optional guidance for a limited time to ease the potential burden in accounting for, or recognizing the effects of, reference rate reform on financial reporting, including when modifying a contract (during the eligibility period covered by the update to the topic) to replace a reference rate affected by reference rate reform. The update applies only to contracts and hedging relationships that reference the London Interbank Offered Rate (“LIBOR”) or another reference rate expected to be discontinued due to reference rate reform. The guidance was eligible to be applied upon issuance on March 12, 2020, and can generally be applied through December 31, 2022. Management will monitor the impacts this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures, and will reflect such appropriately, in the event that the optional guidance is elected. See also LIBOR discussion in Note 8 - Debt.
In August 2020, the FASB issued ASU 2020-06 “Debt—Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging— Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity.” The update, amongst other amendments, improves the guidance related to the disclosures and earnings per share for convertible instruments and contracts in an entity’s own equity. The update is effective for fiscal years beginning after December 15, 2021, including interim periods within those fiscal years; early adoption is permitted. Management is evaluating the impacts this update might have on the Company’s consolidated financial statements and disclosures.
Subsequent Events. Management monitors events occurring after the balance sheet date and prior to the issuance of the financial statements to determine the impacts, if any, of events on the financial statements to be issued or disclosures to be made, and has reflected them where appropriate.



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Note 2 - Utility Plant and Leases
Net Utility Plant
Net utility plant as of December 31, 2020 and 2019 was as follows:
December 31,
(Thousands of dollars)20202019
Gas plant:
Storage$101,203 $100,908 
Transmission400,657 391,864 
Distribution7,078,656 6,581,043 
General515,879 467,274 
Software and software-related intangibles270,883 256,299 
Other16,722 15,833 
8,384,000 7,813,221 
Less: accumulated depreciation and amortization(2,419,348)(2,313,050)
Construction work in progress211,429 185,026 
Net utility plant$6,176,081 $5,685,197 
Utility plant depreciation is computed on the straight-line remaining life method at composite rates considered sufficient to amortize costs over estimated service lives, including components which are intended to compensate for removal costs (net of salvage value), and retirements, based on the processes of regulatory proceedings and related regulatory commission approvals and/or mandates. In 2020, 2019, and 2018, annual utility depreciation and amortization expense averaged 2.7% of the original cost of depreciable and amortizable property. Transmission and Distribution plant are associated with the core natural gas delivery infrastructure, and combined, constitute the majority of gas plant. Annual utility depreciation expense averaged approximately 2.3% of the original cost of depreciable transmission and distribution plant during the period 2018 through 2020.
Depreciation and amortization expense on gas plant, including intangibles, was as follows:
(Thousands of dollars)202020192018
Depreciation and amortization expense$215,636 $197,358 $185,719 
Included in the figures above is amortization of utility intangibles of $13.7 million, $13.2 million, and $13.6 million for the years ended December 31, 2020, 2019, and 2018, respectively. The amounts above exclude regulatory asset and liability amortization.
Leases
Southwest and Centuri determine if an arrangement is a lease at inception. ROU assets represent the right to use an underlying asset for the lease term; lease liabilities represent obligations to make lease payments arising from the lease. Operating lease ROU assets and lease liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. When Southwest’s and Centuri’s leases do not provide an implicit interest rate, an incremental borrowing rate based on information available at commencement is used in determining the present value of lease payments; an implicit rate, if readily determinable, is used. Lease terms utilized in the computations may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised. When lease agreements include non-lease components, they are included with the lease component and accounted for as a single component, for all asset classes.
Southwest’s leases are comprised primarily of operating leases of buildings, land, and equipment. Southwest has no finance leases and no significant short-term leases. Southwest’s leases have a remaining term of up to six years, some of which include optional renewal periods. Southwest is currently not a lessor in any significant lease arrangements.


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Centuri has operating and finance leases for corporate and field offices, construction equipment, and transportation vehicles. Centuri is currently not a lessor in any significant lease arrangements. Centuri’s leases have remaining lease terms of up to 18 years. Some of these include options to extend the leases, generally for optional terms of up to 5 years, and some include options to terminate the leases within 1 year. Centuri’s equipment leases may include variable payment terms in addition to the fixed lease payments if machinery is used in excess of the standard work periods. These variable payments are not probable of occurring under the current operating environment and have not been included in consideration of lease payments. Due to the seasonality of Centuri’s business, expense for short-term leases will fluctuate throughout the year with higher expense incurred during the warmer months. As of December 31, 2020, Centuri executed lease agreements that had not yet commenced. These lease agreements primarily relate to real estate leases that have terms ranging from January 2021 through May 2025. Total future lease payments over the lease terms are approximately $1 million.
The components of lease expense were as follows:
(Thousands of dollars)20202019
Southwest:
Operating lease cost
$1,251 $1,531 
Centuri:
Operating lease cost
$14,294 $12,235 
Finance lease cost:
Amortization of ROU assets
$140 $137 
Interest on lease liabilities
37 34 
Total finance lease cost
177 171 
Short-term lease cost
19,806 16,217 
Total lease cost - Southwest Gas Holdings, Inc.$35,528 $30,154 
Supplemental cash flow information related to leases for the years ended December 31, 2020 and 2019 was as follows:
2020
(Thousands of dollars)SouthwestCenturiTotal
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases$766 $12,889 $13,655 
Operating cash flows from finance leases— 36 36 
Financing cash flows from finance leases— 199 199 
ROU assets obtained in exchange for lease obligations:
Operating leases$1,547 $19,372 $20,919 
Finance leases— 361 361 
2019
(Thousands of dollars)SouthwestCenturiTotal
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases$1,278 $11,166 $12,444 
Operating cash flows from finance leases— 3333 
Financing cash flows from finance leases— 212212 
ROU assets obtained in exchange for lease obligations:
Operating leases$862 $23,825 $24,687 
Finance leases— 13,839 13,839 


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Supplemental information related to leases, including location in the Consolidated Balance Sheets, is as follows:
(Thousands of dollars)December 31,
20202019
Southwest:
Operating leases:
Net utility plant
$2,195 $1,443 
Other current liabilities
$656 $723 
Other deferred credits and other long-term liabilities
1,586 730 
Total operating lease liabilities$2,242 $1,453 
Weighted average remaining lease term (in years)4.242.88
Weighted average discount rate4.49 %3.18 %
Centuri:
Operating leases:
Other property and investments
$81,010 $78,954 
Other current liabilities
$10,032 $8,851 
Other deferred credits and other long-term liabilities
75,247 73,323 
Total operating lease liabilities$85,279 $82,174 
Finance leases:
Other property and investments
$752 $14,264 
Other current liabilities
$202 $13,769 
Other deferred credits and other long-term liabilities
490 355 
Total finance lease liabilities$692 $14,124 
Weighted average remaining lease term (in years)
Operating leases
10.0810.25
Finance leases
2.122.13
Weighted average discount rate
Operating leases
4.05 %4.03 %
Finance leases
5.55 %6.10 %
With regard to the finance lease balance as of December 31, 2020, there exist lease provisions for purchase options that meet the “reasonably certain” threshold related to exercise of such options. These amounts were not included in the calculations of the weighted average remaining lease term and discount rate for finance leases above.


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The following are schedules of maturities of lease liabilities as of December 31, 2020:
(Thousands of dollars)Operating Leases
Southwest:
2021$735 
2022543 
2023426 
2024404 
2025330 
Thereafter36 
Total lease payments
2,474 
Less imputed interest232 
Total
$2,242 
(Thousands of dollars)Operating LeasesFinance Leases
Centuri:
2021$13,144 $235 
202212,153 241 
202310,864 275 
20249,904 1 
20258,051 — 
Thereafter50,605 — 
Total lease payments
104,721 752 
Less imputed interest19,442 60 
Total
$85,279 $692 
Note 3 - Revenue
The following information about the Company’s revenues is presented by segment. Southwest encompasses the natural gas operations segment and Centuri encompasses the utility infrastructure services segment.
Natural Gas Operations Segment:
Southwest recognizes revenue when it satisfies its performance by transferring gas to the customer. Revenues also include the net impacts of margin tracker/decoupling accruals based on criteria in U.S. GAAP for rate-regulated entities associated with alternative revenue programs. Revenues from customer arrangements and from alternative revenue programs are described below.
Southwest acts as an agent for state and local taxing authorities in the collection and remittance of a variety of taxes, including sales and use taxes and surcharges. These taxes are not included in Gas operating revenues. Management uses the net classification method to report taxes collected from customers to be remitted to governmental authorities.
Southwest generally offers two types of services to its customers: tariff sales and transportation–only service. Tariff sales encompass sales to many types of customers (primarily residential) under various rate schedules, subject to cost-of-service ratemaking, which is based on the rate-regulation of state commissions and the Federal Energy Regulatory Commission (the “FERC”). Southwest provides both the commodity and the related distribution service to nearly all of its approximate 2 million customers, and only several hundred customers (who are eligible to secure their own gas) subscribe to transportation-only service. Also, only a few hundred customers have contracts with stated periods. Natural gas is delivered and consumed by the customer simultaneously. The provision of service is represented by the turn of the meter dial and is the primary representation of the satisfaction of performance obligations of Southwest. The amount billable via regulated rates (both volumetric and fixed monthly rates as part of rate design) corresponds to the value to the customer, and management believes that the amount billable (amount Southwest has the right to invoice) is appropriate to utilize for purposes of recognizing revenue. Estimated amounts remaining unbilled since the last meter read date are restricted from being billed due only to the passage of time and therefore are also recognized for service provided through the balance sheet date. While natural gas service is typically recurring, there is generally not a contract term for utility service. Therefore, the contract term is not generally viewed to extend beyond the service provided to date, and customers can generally terminate service at will.


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Transportation-only service is also governed by tariff rate provisions. Transportation-only service is generally only available to very large customers under requirements of Southwest’s various tariffs. With this service, customers secure their own gas supply and Southwest provides transportation services to move the customer-supplied gas to the intended location. Southwest concluded that transportation/transmission service is suitable to an “over time” recognition model. Rate structures under Southwest’s regulation for transportation customers include a combination of volumetric charges and monthly “fixed” charges (including charges commonly referred to as capacity charges, demand charges, or reservation charges) as part of the rate design of regulated jurisdictions. These types of fixed charges represent a separate performance obligation associated with standing ready over the period of the month to deliver quantities of gas, regardless of whether the customer takes delivery of any quantity of gas. The performance obligations under these circumstances are satisfied over the course of the month under an output measure of progress based on time, which correlates to the period for which the charges are eligible to be invoiced.
Under its regulation, Southwest enters into negotiated rate contracts for those customers located in proximity to another pipeline, which pose a threat of bypassing its distribution system. Southwest may also enter into similar contracts for customers otherwise able to satisfy their energy needs by means of alternative fuel to natural gas. Less than two dozen customers are party to contracts with rate components subject to negotiation. Many rate provisions and terms of service for these less common types of contracts are also subject to regulatory oversight and tariff provisions. The performance obligations for these customers are satisfied similarly to those for other customers by means of transporting/delivering natural gas to the customer. Many or most of the rate components, and structures, for these types of customers are the same as those for similar customers without negotiated rate components; and the negotiated rates are within the parameters of the tariff guidelines. Furthermore, while some of these contracts include contract periods extending over time, including multiple years, as amounts billable under the contract are based on rates in effect for the customer for service provided to date, no significant financing component is deemed to exist.
As indicated above, revenues also include the net impacts of margin tracker/decoupling accruals. All of Southwest’s service territories have decoupled rate structures (also referred to as alternative revenue programs) that are designed to eliminate the direct link between volumetric sales and revenue, thereby mitigating the impacts of unusual weather variability and conservation on margin. The primary alternative revenue programs involve permissible adjustments for differences between stated tariff benchmarks and amounts billed through revenue from contracts with customers via existing rates. Such adjustments are recognized monthly in revenue and in the associated regulatory asset/liability accounts in advance of rate adjustments intended to collect or return amounts recognized. Revenues recognized for the adjustment to the benchmarks noted are required to be presented separately from revenues from contracts with customers, and as such, are provided below and identified as related to alternative revenue programs (which excludes recoveries from customers).
Gas operating revenues on the Consolidated Statements of Income of both the Company and Southwest include revenue from contracts with customers, which is shown below disaggregated by customer type, and various categories of revenue:
 December 31,
(Thousands of dollars)202020192018
Residential$958,520 $972,788 $887,220 
Small commercial221,541 249,117 255,083 
Large commercial44,633 48,935 53,192 
Industrial/other26,242 22,074 23,489 
Transportation88,215 92,380 86,990 
Revenue from contracts with customers1,339,151 1,385,294 1,305,974 
Alternative revenue program deferrals12,140 (25,112)45,979 
Other revenues (a)(706)8,757 5,775 
Total Gas operating revenues$1,350,585 $1,368,939 $1,357,728 
(a)     Comprised of late fees, certain regulatory mechanism impacts, such as cost-of-service components in current customer rates that are expected to be returned to customers in the future, and various other revenue impacts, including $(5) million, $(4.9) million, and $(13.5) million for 2020, 2019, and 2018, respectively, related to tax reform savings reserves/adjustments. In 2020, late fees and certain other fees were reduced due to a moratorium on late fees and disconnection for nonpayment during the COVID-19 pandemic.
Utility Infrastructure Services Segment:
The majority of Centuri contracts are performed under unit-price contracts. Generally, these contracts state prices per unit of installation. Typical installations are accomplished in a few weeks or less. Revenues are recorded as installations are completed. Revenues are recorded for long-term fixed-price contracts in a pattern that reflects the transfer of control of promised goods and services to the customer over time. The amount of revenue recognized on fixed-price contracts is based on costs expended to date relative to anticipated final contract costs (a method of recognition based on inputs). Some unit-price contracts contain caps that if encroached, trigger revenue and loss recognition similar to a fixed-price contract model.


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Centuri is required to collect taxes imposed by various governmental agencies on the work performed for its customers. These taxes are not included in Utility infrastructure services revenues. Management uses the net classification method to report taxes collected from customers to be remitted to governmental authorities.
Centuri derives revenue from the installation, replacement, repair, and maintenance of energy distribution systems. Centuri has operations in the U.S. and Canada. The majority of Centuri’s revenues are related to contracts for natural gas pipeline replacement and installation work for natural gas utilities. In addition, Centuri performs certain industrial construction activities for various customers and industries. Centuri has two types of agreements with its customers: master services agreements (“MSAs”) and bid contracts. Most of Centuri’s customers supply many of their own materials in order for Centuri to complete its work under the contracts.
An MSA identifies most of the terms describing each party’s rights and obligations that will govern future work authorizations. An MSA is often effective for multiple years. A work authorization is issued by the customer to describe the location, timing, and any additional information necessary to complete the work for the customer. The combination of the MSA and the work authorization determines when a contract exists and revenue recognition may begin. Each work authorization is generally a single performance obligation as Centuri is performing a significant integration service.
A bid contract is typically a one-time agreement for a specific project that has all necessary terms defining each party’s rights and obligations. Each bid contract is evaluated for revenue recognition individually. Control of assets created under bid contracts generally passes to the customer over time. Bid contracts often have a single performance obligation as Centuri is providing a significant integration service.
Centuri’s MSA and bid contracts are characterized as either fixed-price contracts or unit-price contracts for revenue recognition purposes. The cost-to-cost input method is used to measure progress towards the satisfaction of a performance obligation for fixed-price contracts. Input methods result in the recognition of revenue based on the entity’s expended effort toward satisfaction of the performance obligation relative to the total expected effort to satisfy it in full. For unit-price contracts, an output method is used to measure progress towards satisfaction of a performance obligation (based on the completion of each unit that is required under the contract).
Actual revenues and project costs can vary, sometimes substantially, from previous estimates due to changes in a variety of factors, including unforeseen circumstances. These factors, along with other risks inherent in performing fixed-price contracts may cause actual revenues and gross profit for a project to differ from previous estimates, and could result in reduced profitability or losses on projects. Changes in these factors may result in revisions to costs and earnings, the impacts for which are recognized in the period in which the changes are identified. Once identified, these types of conditions continue to be evaluated for each project throughout the project term, and ongoing revisions in management’s estimates of contract value, cost, and profit are recognized as necessary in the period determined.
Centuri categorizes work performed under MSAs and bid contracts into three primary service types: gas construction, electrical construction, and other construction. Gas construction includes work involving previously existing gas pipelines and the installation of new pipelines or service lines. Electrical construction includes work involving installation and maintenance of transmission and distribution lines, including storm restoration services. Other construction includes all other work and can include industrial and water utility services.
Contracts can have compensation/consideration that is variable. For MSAs, variable consideration is evaluated at the customer level as the terms creating variability in pricing are included within the MSA and are not specific to a work authorization. For multi-year MSAs, variable consideration items are typically determined for each year of the contract and not for the full contract term. For bid contracts, variable consideration is evaluated at the individual contract level. The expected value method or most likely amount method is used based on the nature of the variable consideration. Types of variable consideration include liquidated damages, delay penalties, performance incentives, safety bonuses, payment discounts, and volume rebates. Centuri will typically estimate variable consideration and adjust financial information, as necessary.
Change orders involve the modification in scope, price, or both to the current contract, requiring approval by both parties. The existing terms of the contract continue to be accounted for under the current contract until such time as a change order is approved. Once approved, the change order is either treated as a separate contract or as part of the existing contract, as appropriate, under the circumstances. When the scope is agreed upon in the change order but not the price, Centuri estimates the change to the transaction price.


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The following tables display Centuri’s revenue from contracts with customers disaggregated by service type and contract type:
December 31,
(Thousands of dollars)202020192018
Service Types:
Gas infrastructure services$1,261,160 $1,238,974 $1,123,682 
Electric power infrastructure services411,826 247,717 32,629 
Other275,302 264,287 365,974 
Total Utility infrastructure services revenues$1,948,288 $1,750,978 $1,522,285 
December 31,
(Thousands of dollars)202020192018
Contract Types:
Master services agreement$1,490,009 $1,383,377 $1,102,412 
Bid contract458,279 367,601 419,873 
Total Utility infrastructure services revenues$1,948,288 $1,750,978 $1,522,285 
Unit price contracts$1,356,640 $1,380,256 $1,258,419 
Fixed price contracts157,701 112,924 117,298 
Time and materials contracts433,947 257,798 146,568 
Total Utility infrastructure services revenues$1,948,288 $1,750,978 $1,522,285 
The following table provides information about contracts receivable and revenue earned on contracts in progress in excess of billings (contract assets), both of which are included within Accounts receivable, net of allowances, and provides information about amounts billed in excess of revenue earned on contracts (contract liabilities), which are included in Other current liabilities as of December 31, 2020 and 2019 on the Company’s Consolidated Balance Sheets:
December 31,
(Thousands of dollars)20202019
Contracts receivable, net$278,316 $223,904 
Revenue earned on contracts in progress in excess of billings96,996 99,399 
Amounts billed in excess of revenue earned on contracts4,507 4,525 
The revenue earned on contracts in progress in excess of billings (contract asset) primarily relates to Centuri’s rights to consideration for work completed but not billed and/or approved at the reporting date. These contract assets are transferred to contracts receivable when the rights become unconditional. These contract assets are recoverable from Centuri’s customers based upon various measures of performance, including achievement of certain milestones, completion of specified units or completion of a contract. In addition, many of Centuri’s time and materials arrangements are billed in arrears pursuant to contract terms that are standard within the industry, resulting in contract assets and/or unbilled receivables being recorded, as revenue is recognized in advance of billings. Due to the lag in invoicing associated with contractual provisions (or other economic or market conditions that may impact a customer’s business), Centuri’s ability to bill and subsequently collect amounts due may be impacted. These changes may result in the need to record an estimated valuation allowance to adjust contract asset balances to their net realizable value.
The amounts billed in excess of revenue earned (contract liability) primarily relate to the advance consideration received from customers for which work has not yet been completed. The change in this contract liability balance from December 31, 2019 to December 31, 2020 was due to revenue recognized of $4.5 million that was included in this balance as of January 1, 2020, after which time it became earned and the balance was reduced, and to increases due to cash received, net of revenue recognized during the period related to contracts that commenced during the period.
For contracts that have an original duration of one year or less, Centuri does not consider/compute an interest component based on the time value of money. Further, because of the short duration of these contracts, the Company has not disclosed the transaction price for the remaining performance obligations as of the end of each reporting period or when the Company expects to recognize the revenue.
As of December 31, 2020, Centuri has 16 contracts with an original duration of more than one year. The aggregate amount of the transaction price allocated to the unsatisfied performance obligations of these contracts as of December 31, 2020 was $76.4 million. Centuri expects to recognize the remaining performance obligations over approximately the next two years;


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however, the timing of that recognition is largely within the control of the customer, including when the necessary equipment and materials required to complete the work will be provided by the customer.
Utility infrastructure services contracts receivable consists of the following:
December 31,
(Thousands of dollars)20202019
Billed on completed contracts and contracts in progress$273,778 $216,268 
Other receivables6,692 8,456 
Contracts receivable, gross280,470 224,724 
Allowance for doubtful accounts(2,154)(820)
Contracts receivable, net$278,316 $223,904 
Note 4 - Receivables and Related Allowances
Business activity with respect to natural gas utility operations is conducted with customers located within the three-state region of Arizona, Nevada, and California. Southwest’s accounts receivable are short-term in nature with no billing due dates customarily extending beyond one month, with customers’ credit worthiness assessed upon account creation by evaluation of other utility service and related payment history. Although Southwest seeks generally to minimize its credit risk related to utility operations by requiring security deposits from new customers, imposing late fees, and actively pursuing collection on overdue accounts, some accounts are ultimately not collected. Customer accounts are subject to collection procedures that vary by jurisdiction (late fee assessment, noticing requirements for disconnection of service, and procedures for actual disconnection and/or reestablishment of service). After disconnection of service, accounts are customarily written off approximately two months after inactivation. Dependent upon the jurisdiction, reestablishment of service requires both payment of previously unpaid balances and additional deposit requirements. Provisions for uncollectible accounts are recorded monthly based on experience, consideration of current and expected future conditions, customer and rate composition, and write-off processes. They are included in the ratemaking process as a cost of service. The Nevada jurisdictions have a regulatory mechanism associated with the gas-cost-related portion of uncollectible accounts. Such amounts are deferred and collected through a surcharge in the ratemaking process. Due to the ongoing COVID-19 pandemic, Southwest initiated a moratorium in March 2020 on disconnection of natural gas service for non-payment and also ceased charging late fees until further notice. While the moratorium continues to be in place, Southwest is actively working with customers experiencing financial hardship by means of flexible payment options and by coordinating with certain governmental and nonprofit entities for customer payment assistance. Management continues to monitor expected credit losses in light of the evolving financial impact of COVID-19. The allowance as of December 31, 2020 reflects the expected impact from the pandemic on balances as of that date, including consideration of customers’ ability to pay currently and once the moratorium is lifted.
Utility infrastructure services contracts receivable are recorded at face amounts less an allowance for doubtful accounts. Centuri’s customers are generally investment-grade gas and electric utility companies for which Centuri has historically recognized an insignificant amount of write-offs. Centuri’s trade accounts receivable balances carry standard payment terms of up to 60 days. Centuri maintains an allowance that is an estimate based on historical collection experience, current and estimated future economic and market conditions, and a review of the current status of each customer's trade accounts receivable balance. Account balances are monitored at least monthly, and are charged off against the allowance when management determines it is probable the balance will not be recovered. Centuri has not been significantly impacted, nor does it anticipate it will experience significant difficulty in collecting amounts due, given the nature of its customers, as a result of the current environment surrounding COVID-19.
The table below contains information about the gas utility customer accounts receivable balance (net of allowance) at December 31, 2020 and 2019, and the percentage of customers in each of the three states, which was consistent with the prior year.
December 31,
(Thousands of dollars)20202019
Gas utility customer accounts receivable balance $145,108 $148,173 



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The following table represents customers by state at December 31, 2020:
Percent of customers by state:
Arizona53 %
Nevada37 %
California10 %
Activity in the allowance account for uncollectibles is summarized as follows:
(Thousands of dollars)
Allowance for
Uncollectibles
Balance, December 31, 2017$2,111 
Additions charged to expense2,959 
Accounts written off, less recoveries(2,902)
Balance, December 31, 20182,168 
Additions charged to expense3,507 
Accounts written off, less recoveries(3,580)
Balance, December 31, 20192,095 
Additions charged to expense4,693 
Accounts written off, less recoveries(2,454)
Balance, December 31, 2020$4,334 
At December 31, 2020, the utility infrastructure services segment (Centuri) had $375.3 million in combined customer accounts and contracts receivable. Both the allowance for uncollectibles and write-offs related to Centuri customers have been insignificant and are not reflected in the table above.


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Note 5 - Regulatory Assets and Liabilities
Southwest is subject to the regulation of the Arizona Corporation Commission (“ACC”), the Public Utilities Commission of Nevada (“PUCN”), the California Public Utilities Commission (“CPUC”), and the FERC. Accounting policies of Southwest conform to U.S. GAAP applicable to rate-regulated entities and reflect the effects of the ratemaking process. Accounting treatment for rate-regulated entities allows for deferral as regulatory assets, costs that otherwise would be expensed, if it is probable that future recovery from customers will occur. If rate recovery is no longer probable, due to competition or the actions of regulators, Southwest is required to write-off the related regulatory asset. Regulatory liabilities are recorded if it is probable that revenues will be reduced for amounts that will be refunded to customers through the ratemaking process. Southwest management records regulatory assets and liabilities based on decisions of the commissions noted above, including the issuance of regulatory orders and precedents established by these commissions. Southwest has generally been successful in seeking recovery of regulatory assets, and regularly files rate cases in all jurisdictions, in part to establish the basis for recovering regulatory assets reflected in accounting records.
The following table represents existing regulatory assets and liabilities:
December 31,
(Thousands of dollars)20202019
Regulatory assets:
Accrued pension and other postretirement benefit costs (1)$427,550 $420,114 
Unrealized net loss on non-trading derivatives (Swaps) (2)— 10,951 
Deferred purchased gas costs (3)2,053 44,412 
Accrued purchased gas costs (4)29,000 8,000 
Unamortized premium on reacquired debt (5)17,124 18,249 
Accrued absence time (8)15,565 14,519 
Margin, interest- and property tax-tracking (9)4,759 33,380 
Other (10)45,596 33,134 
541,647 582,759 
Regulatory liabilities:
Deferred purchased gas costs (3)(54,636)(60,755)
Accumulated removal costs(404,000)(395,000)
Unamortized gain on reacquired debt (6)(7,644)(8,181)
Regulatory excess deferred/other taxes and gross-up (7)(461,023)(455,625)
Margin, interest- and property tax-tracking (9)(17,132)(22,650)
Other (10)(3,503)(4,438)
Net regulatory liabilities$(406,291)$(363,890)
(1)Included in Deferred charges and other assets on the Consolidated Balance Sheets. Recovery period is greater than five years. (See Note 11 - Pension and Other Postretirement Benefits).
(2)Included in Prepaid and other assets on the Consolidated Balance Sheets. The actual amounts, when realized at settlement, become a component of purchased gas costs under Southwest’s PGA mechanisms. (For specific details, see Derivatives in Note 1 - Background, Organization, and Summary of Significant Accounting Policies).
(3)Balance recovered or refunded on an ongoing basis with interest.
(4)Included in Prepaid and other current assets on the Consolidated Balance Sheets. Balance recovered or refunded on an ongoing basis.
(5)Included in Deferred charges and other assets on the Consolidated Balance Sheets. Recovered over life of debt instruments.
(6)Included in Other deferred credits and other long-term liabilities on the Consolidated Balance Sheets. Amortized over life of debt instruments.
(7)Includes remeasurement/reduction of the net accumulated deferred income tax liability from U.S. tax reform. The reduction (excess accumulated deferred taxes, or “EADIT”) became a regulatory liability with tax gross-up. EADIT reduces rate base, and is expected to be returned to utility customers in accordance with IRS and regulatory requirements. Included generally, in Other deferred credits and other long-term liabilities on the Consolidated Balance Sheets, except for $15 million in 2020 which is in Other current liabilities. Amount also includes difference in current taxes required to be returned to customers and a separate $2.6 million gross-up related to contributions in aid of construction.
(8)Regulatory recovery occurs on a one-year lag basis through the labor loading process. Included in Prepaid and other current assets on the Consolidated Balance Sheets.
(9)Margin tracking/decoupling mechanisms are alternative revenue programs; revenue associated with under-collections (for the difference between authorized margin levels and amounts billed to customers through rates currently) is recognized as revenue so long as


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recovery is expected to take place within 24 months. Total category asset balances are included in Prepaid and other current assets and Deferred charges and other assets on the Consolidated Balance Sheets. Total category liability balances are included in Other current liabilities and Other deferred credits and other long-term liabilities.
(10)The following tables detail the components of Other regulatory assets and liabilities. Other regulatory assets are included in either Prepaid and other current assets or Deferred charges and other assets on the Consolidated Balance Sheets (as indicated). Recovery periods vary. Other regulatory liabilities are included in either Other current liabilities or Other deferred credits and other long-term liabilities on the Consolidated Balance Sheets (as indicated).
December 31,
(Thousands of dollars)20202019
Other Regulatory Assets:
State mandated public purpose programs (including low income and conservation programs) (a) (e)$11,527 $9,172 
Infrastructure replacement programs and similar (b) (e)7,731 8,236 
Environmental compliance programs (c) (e)5,235 5,768 
Pension tracking mechanism (b)3,075 — 
Other (d)18,028 9,958 
$45,596 $33,134 
a)Included in Prepaid and other current assets on the Consolidated Balance Sheets.
b)Included in Deferred charges and other assets on the Consolidated Balance Sheets.
c)In 2020, approximately $4.2 million of these balances included in Prepaid and other current assets and $998,000 included in Deferred charges and other assets on the Consolidated Balance Sheets. In 2019, approximately $5.0 million included in Prepaid and other current assets and $782,000 included in Deferred charges and other assets on the Consolidated Balance Sheets.
d)In 2020, $3.6 million included in Prepaid and other current assets and $14.4 million included in Deferred charges and other assets on the Consolidated Balance Sheets. In 2019, $1.6 million included in Prepaid and other current assets and $8.3 million included in Deferred charges and other assets on the Consolidated Balance Sheets.
e)Balance recovered or refunded on an ongoing basis, generally with interest.
December 31,
(Thousands of dollars)20202019
Other Regulatory Liabilities:
State mandated public purpose programs (including low income and conservation programs) (a) (c)$(834)$(308)
Environmental compliance programs (c) (d)(405)(527)
Pension tracking mechanism (b)— (2,476)
Other (b) (c)(2,264)(1,127)
$(3,503)$(4,438)
a)Included in Other current liabilities, except for $339,000 which is included in Other deferred credits and long-term liabilities on the Consolidated Balance Sheets.
b)Included in Other deferred credits and other long-term liabilities on the Consolidated Balance Sheets.
c)Balance typically recovered or refunded on an ongoing basis, generally with interest.
d)In 2020 and 2019, included in Other current liabilities on the Consolidated Balance Sheet.
Note 6 - Other Comprehensive Income and Accumulated Other Comprehensive Income ("AOCI")
The following information provides insight into amounts impacting the Company’s Other comprehensive income (loss), both before and after-tax impacts, within the Consolidated Statements of Comprehensive Income, which also impact Accumulated other comprehensive income (“AOCI”) in the Consolidated Balance Sheets and the Consolidated Statements of Equity.


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Related Tax Effects Allocated to Each Component of Other Comprehensive Income (Loss)
Year Ended December 31,
202020192018
(Thousands of dollars)
Before-
Tax
Amount
Tax (Expense) or
Benefit (1)
Net-of-
Tax
Amount
Before-
Tax
Amount
Tax
(Expense)
or
Benefit (1)
Net-of-
Tax
Amount
Before-
Tax
Amount
Tax
(Expense)
or
Benefit (1)
Net-of-
Tax
Amount
Defined benefit pension plans:
Net actuarial gain/(loss)$(57,539)$13,809 $(43,730)$(71,087)$17,061 $(54,026)$(20,426)$4,902 $(15,524)
Amortization of prior service cost1,155 (277)878 1,271 (305)966 1,335 (320)1,015 
Amortization of net actuarial (gain)/loss37,830 (9,079)28,751 23,376 (5,610)17,766 33,617 (8,068)25,549 
Prior service cost— — — (1,878)452 (1,426)— — — 
Regulatory adjustment7,435 (1,785)5,650 36,944 (8,867)28,077 (8,233)1,976 (6,257)
Pension plans other comprehensive income (loss)
(11,119)2,668 (8,451)(11,374)2,731 (8,643)6,293 (1,510)4,783 
FSIRS (designated hedging activities):
Amounts reclassified into net income3,247 (780)2,467 3,344 (803)2,541 3,345 (804)2,541 
FSIRS other comprehensive income (loss)3,247 (780)2,467 3,344 (803)2,541 3,345 (804)2,541 
Total other comprehensive income (loss) –Southwest Gas Corporation
(7,872)1,888 (5,984)(8,030)1,928 (6,102)9,638 (2,314)7,324 
Foreign currency translation adjustments:
Translation adjustments1,713 — 1,713 2,038 — 2,038 (3,010)— (3,010)
Foreign currency other comprehensive income (loss)
1,713 — 1,713 2,038 — 2,038 (3,010)— (3,010)
Total other comprehensive income (loss) – Southwest Gas Holdings, Inc.
$(6,159)$1,888 $(4,271)$(5,992)$1,928 $(4,064)$6,628 $(2,314)$4,314 
(1) Tax amounts are calculated using a 24% rate. With regard to foreign currency translation adjustments, the Company has elected to indefinitely reinvest the earnings of Centuri’s Canadian subsidiaries in Canada, thus preventing deferred taxes on such earnings. As a result of this assertion, and no repatriation of earnings anticipated, the Company is not recognizing a tax effect or presenting a tax expense or benefit for currency translation adjustments in Other comprehensive income (loss).
Approximately $1.7 million of realized losses (net of tax) related to the remaining balance of FSIRS, included in AOCI at December 31, 2020, will be reclassified into interest expense within the next twelve months as the related interest payments on long-term debt occur.


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The following table represents a rollforward of AOCI, presented on the Company’s Consolidated Balance Sheets and its Consolidated Statements of Equity:
  Defined Benefit PlansFSIRSForeign Currency Items  
(Thousands of dollars)Before-TaxTax
(Expense)
Benefit (4)		After-Tax
Before-
Tax
Tax
(Expense)
Benefit (4)		After-Tax
Before-
Tax
Tax
(Expense)
Benefit
After-TaxAOCI
Beginning Balance AOCI December 31, 2019
$(66,601)$15,985 $(50,616)$(5,966)$1,431 $(4,535)$(1,581)$— $(1,581)$(56,732)
Net actuarial gain/(loss)(57,539)13,809 (43,730)— — — — — — (43,730)
Translation adjustments— — — — — — 1,713 — 1,713 1,713 
Other comprehensive income before reclassifications
(57,539)13,809 (43,730)— — — 1,713 — 1,713 (42,017)
FSIRS amounts reclassified from AOCI (1)
— — — 3,247 (780)2,467 — — — 2,467 
Amortization of prior service cost (2)
1,155 (277)878 — — — — — — 878 
Amortization of net actuarial loss (2)
37,830 (9,079)28,751 — — — — — — 28,751 
Regulatory adjustment (3)7,435 (1,785)5,650 — — — — — 5,650 
Net current period other
comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.
(11,119)2,668 (8,451)3,247 (780)2,467 1,713 — 1,713 (4,271)
Ending Balance AOCI December 31, 2020
$(77,720)$18,653 $(59,067)$(2,719)$651 $(2,068)$132 $— $132 $(61,003)
(1)The FSIRS reclassification amounts are included in Net interest deductions on the Company’s Consolidated Statements of Income.
(2)These AOCI components are included in the computation of net periodic benefit cost (see Note 11 - Pension and Other Postretirement Benefits for additional details).
(3)The regulatory adjustment represents the portion of the activity above that is expected to be recovered through rates in the future (the related regulatory asset is included in Deferred charges and other assets on the Company’s Consolidated Balance Sheets).
(4)    Tax amounts are calculated using a 24% rate.

The following table represents a rollforward of AOCI, presented on Southwest’s Consolidated Balance Sheets:
  Defined Benefit PlansFSIRS   
(Thousands of dollars)Before-TaxTax
(Expense)
Benefit (9)		After-
Tax
Before-
Tax
Tax
(Expense)
Benefit (9)		After-
Tax		AOCI
Beginning Balance AOCI December 31, 2019$(66,601)$15,985 $(50,616)$(5,966)$1,431 $(4,535)$(55,151)
Net actuarial gain/(loss)(57,539)13,809 (43,730)— — — (43,730)
Other comprehensive loss before reclassifications
(57,539)13,809 (43,730)— — — (43,730)
FSIRS amounts reclassified from AOCI (6)— — — 3,247 (780)2,467 2,467 
Amortization of prior service cost (7)1,155 (277)878 — — — 878 
Amortization of net actuarial loss (7)37,830 (9,079)28,751 — — — 28,751 
Regulatory adjustment (8)7,435 (1,785)5,650 — — — 5,650 
Net current period other comprehensive income (loss) attributable to Southwest Gas Corporation
(11,119)2,668 (8,451)3,247 (780)2,467 (5,984)
Ending Balance AOCI December 31, 2020$(77,720)$18,653 $(59,067)$(2,719)$651 $(2,068)$(61,135)
(6)    The FSIRS reclassification amounts are included in Net interest deductions on Southwest’s Consolidated Statements of Income.
(7)    These AOCI components are included in the computation of net periodic benefit cost (see Note 11 - Pension and Other Postretirement Benefits for additional details).
(8)    The regulatory adjustment represents the portion of the activity above that is expected to be recovered through rates in the future (the related regulatory asset is included Deferred charges and other assets on Southwest’s Consolidated Balance Sheets).
(9)    Tax amounts are calculated using a 24% rate.
The following table represents amounts (before income tax impacts) included in AOCI (in the tables above), that have not yet been recognized in net periodic benefit cost:
Year Ended December 31,
(Thousands of dollars)20202019
Net actuarial loss$(502,783)$(483,074)
Prior service cost(2,487)(3,641)
Less: amount recognized in regulatory assets427,550 420,114 
Recognized in AOCI$(77,720)$(66,601)
See Note 11 - Pension and Other Postretirement Benefits for more information on the defined benefit pension plans and Note 1 - Background, Organization, and Summary of Significant Accounting Policies for more information on the FSIRS.


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Note 7 - Common Stock
Only shares of the Company’s common stock are publicly traded on the New York Stock Exchange, under the ticker symbol “SWX.” Share-based compensation related to Southwest and Centuri is based on awards to be issued in shares of Southwest Gas Holdings, Inc.
In May 2019, the Company filed with the SEC an automatic shelf registration statement on Form S-3 (File No. 333-231297), which became effective upon filing, for the offer and sale of up to $300 million of common stock from time to time in at-the-market offerings under the prospectus included therein and in accordance with the Sales Agency Agreement, dated May 2019, between the Company and BNY Mellon Capital Markets, LLC (the “Equity Shelf Program”). The following table provides the activity in the Equity Shelf Program for the three-month and life-to-date periods ended December 31, 2020:
Three Months EndedLife-To-Date Ended
December 31, 2020
Gross proceeds$46,425,623 $253,551,490 
Less: agent commissions(464,256)(2,535,515)
Net proceeds$45,961,367 $251,015,975 
Number of shares sold691,081 3,396,457
Weighted average price per share$67.18 $74.65 
As of December 31, 2020, the Company had up to $46,448,510 of common stock available for future issuance under the program. Net proceeds from the sale of shares of common stock under the Equity Shelf Programs are intended for general corporate purposes, including the acquisition of property for the construction, completion, extension, or improvement of pipeline systems and facilities located in and around the communities served by Southwest. Net proceeds during the twelve months ended December 31, 2020 were contributed to, and reflected in the records of, Southwest (as a capital contribution from Southwest Gas Holdings, Inc.).
Aside from the equity shelf registration, in December 2020, the Company and Southwest jointly filed with the SEC an automatic shelf registration statement (File No. 333-251074), or a “Universal Shelf,” which became effective upon filing and includes a prospectus detailing the Company’s ability to offer and sell, from time to time in amounts at prices and on terms that will be determined at the time of such offering, any combination of common stock, preferred stock, debt securities (which may or may not be guaranteed by one or more of its directly or indirectly wholly owned subsidiaries if indicated in the relevant prospectus supplement), guarantees of debt securities issued by Southwest, depository shares, warrants to purchase common stock, preferred stock or depository shares issued by the Company or debt securities issued by the Company or Southwest, units and rights. Additionally as part of the Universal Shelf, Southwest may offer and sell, from time to time in amounts at prices and on terms that will be determined at the time of such offering, any combination of debt securities (which may or may not be guaranteed by one or more of its directly or indirectly wholly owned subsidiaries if indicated in the relevant prospectus supplement) and guarantees of debt securities issued by the Company or by one or more of its directly or indirectly wholly owned subsidiaries if indicated in the relevant prospectus supplement.
During 2020, the Company issued approximately 96,000 shares of common stock through the Restricted Stock/Unit Plan, Omnibus Incentive Plan, and Management Incentive Plan.
Additionally during 2020, the Company issued 172,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan, raising proceeds of approximately $11 million.
As of December 31, 2020, there were 4.5 million shares of common stock registered and available for issuance under the provisions of the various stock issuance plans, which does not include the amount of common stock available that is separately disclosed with respect to the Equity Shelf Program above.
Note 8 - Debt
Long-Term Debt
Long-term debt is recognized in the Company’s and Southwest’s Consolidated Balance Sheets generally at the carrying value of the obligations outstanding. However, details surrounding the fair value and individual carrying values of instruments are discussed below and provided in the table that follows.


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The fair values of Southwest’s revolving credit facility (including commercial paper) and the variable-rate Industrial Development Revenue Bonds (“IDRBs”) approximate their carrying values. The fair values of the revolving credit facility and IDRBs are categorized as Level 1 based on the FASB’s fair value hierarchy, due to Southwest’s ability to access similar debt arrangements at measurement dates with comparable terms, including variable/market rates. Additionally, the borrowings by Southwest under the revolving credit facility are generally repaid quickly, and the IDRBs have interest rates that reset frequently.
The fair values of Southwest’s debentures (which include senior and medium-term notes) were determined utilizing a market-based valuation approach, where fair values are determined based on evaluated pricing data, such as broker quotes and yields for similar securities adjusted for observable differences. Significant inputs used in the valuation generally include benchmark yield curves, credit ratings, and issuer spreads. The external credit rating, coupon rate, and maturity of each security are considered in the valuation, as applicable. The fair values of debentures are categorized as Level 2 in the hierarchy. 
The Centuri secured revolving credit and term loan facility and Centuri’s other debt obligations (not actively traded) are categorized as Level 3. Because Centuri’s debt is not publicly traded, fair values for the secured revolving credit and term loan facility and its other debt obligations were based on a conventional discounted cash flow methodology and utilizing current market pricing yield curves, across Centuri’s debt maturity spectrum, of other industrial bonds with an assumed credit rating comparable to the Company’s.
Carrying amounts of long-term debt and related estimated fair values as of December 31, 2020 and 2019 are disclosed in the following table. The fair value hierarchy is described in Note 1 - Background, Organization, and Summary of Significant Accounting Policies.


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December 31,
  20202019
  
Carrying
Amount
Fair
Value
Carrying
Amount
Fair
Value
(Thousands of dollars)    
Southwest Gas Corporation:
Debentures:
Notes, 4.45%, due 2020
$— $— $125,000 $126,673 
Notes, 6.1%, due 2041
125,000 174,858 125,000 162,666 
Notes, 3.875%, due 2022
250,000 258,825 250,000 258,550 
Notes, 4.875%, due 2043
250,000 317,190 250,000 291,928 
Notes, 3.8%, due 2046
300,000 347,046 300,000 308,307 
Notes, 3.7%, due 2028
300,000 344,553 300,000 320,685 
Notes, 4.15%, due 2049
300,000 370,278 300,000 330,138 
Notes, 2.2%, due 2030
450,000 474,552 — — 
8% Series, due 2026
75,000 99,723 75,000 96,905 
Medium-term notes, 7.78% series, due 2022
25,000 26,663 25,000 27,500 
Medium-term notes, 7.92% series, due 2027
25,000 33,802 25,000 32,543 
Medium-term notes, 6.76% series, due 2027
7,500 9,613 7,500 9,156 
Unamortized discount and debt issuance costs(17,822)(14,450)
2,089,678 1,768,050 
Revolving credit facility and commercial paper150,000 150,000 150,000 150,000 
Industrial development revenue bonds:
Tax-exempt Series A, due 202850,000 50,000 50,000 50,000 
2003 Series A, due 203850,000 50,000 50,000 50,000 
2008 Series A, due 203850,000 50,000 50,000 50,000 
2009 Series A, due 203950,000 50,000 50,000 50,000 
Unamortized discount and debt issuance costs(1,472)(1,717)
198,528 198,283 
Less: current maturities— (125,000)
Long-term debt, less current maturities – Southwest Gas Corporation
$2,438,206 $1,991,333 
Centuri:
Centuri term loan facility$226,648 230,824 $244,812 252,182 
Unamortized debt issuance costs(820)(1,101)
225,828 243,711 
Centuri secured revolving credit facility26,626 26,645 60,021 60,057 
Centuri other debt obligations81,973 84,246 43,929 44,787 
Less: current maturities(40,433)(38,512)
Long-term debt, less current maturities – Centuri$293,994 $309,149 
Consolidated Southwest Gas Holdings, Inc.:
Southwest Gas Corporation long-term debt$2,438,206 $2,116,333 
Centuri long-term debt334,427 347,661 
Less: current maturities(40,433)(163,512)
Long-term debt, less current maturities – Southwest Gas Holdings, Inc.
$2,732,200 $2,300,482 


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Southwest has a $400 million credit facility, for which it has designated $150 million of associated capacity as long-term debt and the remaining $250 million for working capital purposes. Interest rates for the credit facility are calculated at either LIBOR or an “alternate base rate,” plus in each case an applicable margin that is determined based on Southwest’s senior unsecured debt rating. At December 31, 2020, $150 million was outstanding on the long-term portion (including $50 million under the commercial paper program discussed below). The effective interest rate on the long-term portion of the credit facility was 0.92% at December 31, 2020. Borrowings under the credit facility ranged from none at various times throughout 2020 to a high of $344 million during the first quarter of 2020.
On April 10, 2020, Southwest amended its credit facility agreement; total borrowing capacity under the amended agreement remains at $400 million. The amended agreement extended the maturity date from March 2022 to April 2025. Under the amended agreement, the applicable margin ranges from 0.750% to 1.500% for loans bearing interest with reference to LIBOR and from 0.000% to 0.500% for loans bearing interest with reference to an alternate base rate. At December 31, 2020, the applicable margin is 1% for loans bearing interest with reference to LIBOR and 0% for loans bearing interest with reference to the alternative base rate. Upon the occurrence of certain events providing for a transition away from LIBOR, or if LIBOR is no longer a widely recognized benchmark rate, Southwest may further amend the credit facility with a replacement rate as set forth in the amended agreement. Southwest is also required to pay a commitment fee on the unfunded portion of the commitments based on its senior unsecured long-term debt rating. The commitment fee on the unfunded portion of the commitments ranges from 0.075% to 0.200% per annum, and was not significant for the year ended December 31, 2020. The amended agreement contains certain representations and warranties and affirmative and negative covenants similar to those contained in the previous agreement. In addition, the amended agreement contains a financial covenant requiring Southwest to maintain a ratio of funded debt to total capitalization not to exceed 0.70 to 1.00 as of the end of any quarter of any fiscal year.
Southwest has a $50 million commercial paper program. Issuances under the commercial paper program are supported by Southwest’s current revolving credit facility and, therefore, do not represent additional borrowing capacity. Borrowings under the commercial paper program are designated as long-term debt. Interest rates for the program are calculated at the then current commercial paper rate. At December 31, 2020, as noted above, $50 million of borrowings were outstanding under the commercial paper program.
In June 2020, Southwest issued $450 million aggregate principal amount of 2.20% Senior Notes at a discount of 0.126%. The notes will mature in June 2030. A portion of the net proceeds was used to reduce borrowings under Southwest’s credit facility and to redeem the 4.45% $125 million notes due in December 2020, which were redeemed in September 2020 after Southwest provided advance notice to the holders of its intention to redeem the notes in full at a redemption price of 100% plus accrued and unpaid interest.
Centuri has a $590 million senior secured revolving credit and term loan facility, scheduled to expire in November 2023. The capacity of the line of credit portion of the facility is $325 million; related amounts borrowed and repaid are available to be re-borrowed. The term loan portion of the facility has a limit of approximately $265 million; amounts borrowed and repaid under this portion of the facility are not able to be re-borrowed. It is secured by substantially all of Centuri’s assets except those explicitly excluded under the terms of the agreement (including owned real estate and certain certificated vehicles). Centuri’s assets securing the facility at December 31, 2020 totaled $1.4 billion. At December 31, 2020, $253 million in borrowings were outstanding under Centuri’s combined facility. During 2020, Centuri also received proceeds of $70 million in equipment loans.
Interest rates for Centuri’s $590 million secured revolving credit and term loan facility are calculated at LIBOR, the Canadian Dealer Offered Rate (“CDOR”), or an alternate base rate or Canadian base rate, plus in each case an applicable margin that is determined based on Centuri’s consolidated leverage ratio. The applicable margin ranges from 0.875% to 2.25% for loans bearing interest with reference to LIBOR or CDOR and from 0.00% to 1.25% for loans bearing interest with reference to the alternate base rate or Canadian base rate. Centuri is also required to pay a commitment fee on the unfunded portion of the commitments based on their consolidated leverage ratio. The commitment fee ranges from 0.125% to 0.35% per annum. Borrowings under the secured revolving credit portion of the facility ranged from a low of $27 million during the fourth quarter of 2020 to a high of $77 million during the third quarter of 2020.
All amounts outstanding are considered long-term borrowings. The effective interest rate on the secured revolving credit and term loan facility was 1.3% at December 31, 2020.
It is currently anticipated that LIBOR may be discontinued as a benchmark or reference rate after 2021. As of December 31, 2020, $50 million of outstanding borrowings for the holding company under its credit facility (see Short-term Debt below), $157 million of Southwest’s outstanding borrowings under its credit facility (other than from its commercial paper program), and $145 million of Centuri’s outstanding borrowings under its combined facility have interest rates with reference to LIBOR and maturity dates that extend beyond 2021. The outstanding amounts reflect approximately 6% of Southwest’s total debt and 12% of total debt (including current maturities) for the Company overall. Southwest and Southwest Gas Holdings, Inc., in accordance with the April 2020 amendments to their respective facilities, may make further amendments with replacement rates


59

if LIBOR is discontinued. However, replacement rates are not currently determinable. In order to mitigate the impact of the discontinuance on the Company’s and Southwest’s financial condition and results of operations, management will continue to monitor developments and work with lenders to determine the appropriate replacement/alternative reference rate for variable rate debt. At this time the Company and Southwest can provide no assurances as to the impact a LIBOR discontinuance will have on their financial condition or results of operations. Any alternative rate may be less predictable or less attractive than LIBOR.
The effective interest rates on Southwest’s variable-rate IDRBs are included in the table below:
December 31,
20202019
2003 Series A0.80 %2.51 %
2008 Series A0.83 %2.46 %
2009 Series A0.76 %2.37 %
Tax-exempt Series A0.87 %2.32 %
In Nevada, interest fluctuations due to changing interest rates on Southwest’s 2003 Series A, 2008 Series A, and 2009 Series A variable-rate IDRBs are tracked and recovered from customers through a variable interest expense recovery mechanism.
None of Southwest’s debt instruments have credit triggers or other clauses that result in default if bond ratings are lowered by rating agencies. Interest and fees on certain debt instruments are subject to adjustment depending on Southwest’s bond ratings. Certain debt instruments are subject to a leverage ratio cap and the 6.1% Notes due 2041 are also subject to a minimum net worth requirement. At December 31, 2020, Southwest was in compliance with all of its covenants. Under the most restrictive of the financial covenants, approximately $2.7 billion in additional debt could be issued while still meeting the leverage ratio requirement. Relating to the minimum net worth requirement, as of December 31, 2020, there is at least $1.7 billion of cushion in equity. No specific dividend restrictions exist under the collective covenants. None of the debt instruments contain material adverse change clauses.
Certain Centuri debt instruments have leverage ratio caps and fixed charge ratio coverage requirements. At December 31, 2020, Centuri was in compliance with all of its covenants. Under the most restrictive of the covenants, Centuri could issue over $318 million in additional debt and meet the leverage ratio requirement. Centuri has at least $115 million of cushion relating to the minimum fixed charge ratio coverage requirement. Centuri’s covenants limit its ability to provide cash dividends to Southwest Gas Holdings, Inc., its parent. The dividend restriction is equal to a maximum of 60% of its rolling twelve-month consolidated net income.
Estimated maturities of long-term debt for the next five years are:
(Thousands of dollars)SouthwestCenturiTotal
2021$— $40,433 $40,433 
2022275,000 45,433 320,433 
2023— 219,638 219,638 
2024— 11,284 11,284 
2025150,000 9,076 159,076 
Short-Term Debt
Southwest Gas Holdings, Inc. has a $100 million credit facility that is primarily used for short-term financing needs. Interest rates for this facility are calculated at either LIBOR or the “alternate base rate,” plus in each case an applicable margin that is determined based on the Company’s senior unsecured debt rating. Borrowings under the credit facility ranged from a low of $17 million during the first quarter of 2020 to a high of $67 million during the first quarter of 2020. There was $50 million and $17 million outstanding under this facility with a weighted average interest rate of 1.225% and 2.749% at December 31, 2020 and 2019, respectively.
Similar to Southwest amending its credit facility agreement, on April 10, 2020, Southwest Gas Holdings, Inc. also amended its existing credit facility, extending the maturity date to April 2025. The revolving borrowing capacity under the amended agreement remained at $100 million, the same as before the amendment. Interest rate benchmarks (LIBOR or an alternative) as well as related ranges, including with regard to the applicable margin, largely mirror those included in Southwest’s amended facility agreement noted above, determined in this case based on Southwest Gas Holdings, Inc.’s senior unsecured long-term debt rating. At December 31, 2020, the applicable margin is 1.125% for loans bearing interest with reference to LIBOR and 0.125% for loans bearing interest with reference to the alternative base rate. Similar to the Southwest facility amendment, upon the occurrence of certain events providing for a transition away from LIBOR, or if LIBOR is no longer a widely recognized


60

benchmark rate, Southwest Gas Holdings, Inc. may amend its credit facility agreement with a replacement rate, as set forth in the amended agreement. The commitment fee rates, terms, and covenants, noted above for Southwest are also applicable to Southwest Gas Holdings, Inc. in its amended credit facility, including the noted ratio of funded debt to total capitalization as of the end of any quarter of any fiscal year. The commitment fee under this credit facility was not significant for the year ended December 31, 2020.
At December 31, 2020, Southwest Holdings, Inc. was in compliance with all of its credit facility covenants. Interest and fees on the credit facility are subject to adjustment depending on its bond ratings. The credit facility is subject to a leverage ratio cap. No specific dividend restrictions exist under the collective covenants. The credit facility does not contain a material adverse change clause.
As indicated above, under Southwest’s $400 million credit facility, of which $250 million has been designated by management for working capital purposes. Southwest had $57 million and $194 million of short-term borrowings outstanding with weighted average interest rates of 1.10% and 2.61%, at December 31, 2020 and 2019, respectively.
Note 9 - Share-Based Compensation
At December 31, 2020, the following share-based compensation plans existed at the Company: an omnibus incentive plan and a restricted stock/unit plan. All share grants in 2020, including time-lapse restricted stock units and performance shares, occurred under the omnibus incentive plan. The table below shows total share-based plan compensation expense which was recognized in the Consolidated Statements of Income:
Year Ended December 31,
(Thousands of dollars)202020192018
Share-based compensation plan expense, net of related tax benefits$4,816 $5,154 $4,644 
Share-based compensation plan related tax benefits1,521 1,627 1,467 
Omnibus Incentive Plan
The omnibus incentive plan is used to promote the long-term growth and profitability of the Company by providing directors, employees, and certain other individuals with incentives to increase stockholder value and otherwise contribute to the success of the Company. In addition, the plan enables the Company to attract, retain, and reward the best available persons for positions of responsibility. The omnibus incentive plan provides for the grant of stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, and other equity-based and cash awards. Employees, directors, and consultants who provide services to the Company or any subsidiary may be eligible under this plan. For grants under the omnibus incentive plan, directors continue to immediately vest in the shares upon grant but are provided the option to defer receipt of equity compensation until they leave the Board of Directors.
Performance-based incentive opportunities under the omnibus plan were granted to all officers of Southwest in the form of performance shares and are based, depending on the officer, on consolidated earnings per share, utility net income, and utility return on equity, with an adjustment based on relative total shareholder return, in each case, measured over a three-year performance period. Southwest recorded $2.8 million, $2.3 million, and $2.1 million of estimated compensation expense associated with these shares during 2020, 2019, and 2018, respectively.
Restricted Stock/Unit Plan
Restricted stock/units under the restricted stock/unit plan were granted to attract, motivate, retain, and reward key employees of the Company with an incentive to attain high levels of individual performance and improved financial performance. As noted above, grants of restricted stock during 2020 occurred under the omnibus incentive plan. The restricted stock/units vest 40% at the end of year one and 30% at the end of years two and three and are issued annually as common stock in accordance with the percentage vested. The restricted stock/unit plan was also established to attract, motivate, and retain experienced and knowledgeable independent directors. Vesting for grants of restricted stock/units to directors occurred immediately upon grant. The issuance of common stock for directors occurs when their service on the Board ends. No new grants are made under the legacy restricted stock/unit plan as all future incentive compensation, including restricted stock, is granted under programs of the omnibus incentive plan, which subject to advance election, provides that issuance to directors may occur upon grant. With regard to management, grants of time-lapse restricted stock under the omnibus plan vest based on the same percentages indicated above under the legacy program.



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Management Incentive Plan
Under the management incentive plan, awards were historically granted to encourage key employees of the Company to remain as employees and to achieve short-term and long-term performance goals. Plan participants were eligible to receive a cash bonus (i.e., short-term incentive) and a portion in shares (i.e., long-term incentive). The share grants vested three years after grant and were then issued as common stock. No new share grants are made under the management incentive plan as all future incentive share compensation is granted under the omnibus incentive plan. The remaining shares vesting under the management incentive plan were issued during the first quarter of 2020.
The following table summarizes the activity of the management incentive plan shares and restricted stock/units as of December 31, 2020:
(thousands of shares)
Management
Incentive
Plan Shares
Weighted-
average grant date fair value
Restricted
Stock/
Units (1)
Weighted-
average grant date fair value
Nonvested/unissued at December 31, 2019
29 $79.16 365 $60.94 
Granted— — 129 76.85 
Dividends— 8 
Forfeited or expired— — — — 
Vested and issued (2)(29)79.16 (101)71.06 
Nonvested/unissued at December 31, 2020
— $— 401 $62.23 
(1)The number of performance shares includes 77,400 granted and 35,500 vested and issued, which was derived by assuming that target performance will be achieved during the relevant performance period.
(2)Includes shares for retiree payouts and those converted for taxes.
The weighted average grant date fair value of all restricted stock/units granted in 2019 and 2018 was $81.75 and $69.16, respectively.
As of December 31, 2020, total compensation cost related to all nonvested restricted stock/units not yet recognized is $4.5 million, which is expected to be recognized over a weighted average period of 1.7 years.
Note 10 - Commitments and Contingencies
The Company and Southwest are defendants in miscellaneous legal proceedings. The Company and Southwest are also parties to various regulatory proceedings. The ultimate dispositions of these proceedings are not presently determinable; however, it is the opinion of management that no litigation or regulatory proceeding to which the Company and Southwest are currently subject will have a material adverse impact on their financial position, results of operations, or cash flows.
Southwest maintains liability insurance for various risks associated with the operation of its natural gas pipelines and facilities. In connection with these liability insurance policies, Southwest is responsible for an initial deductible or self-insured retention amount per incident, after which the insurance carriers would be responsible for amounts up to the policy limits. For the policy year August 2020 to July 2021, these liability insurance policies require Southwest to be responsible for the first $1 million (self-insured retention) of each incident plus the first $4 million in aggregate claims above its self-insured retention in the policy year.
Centuri maintains liability insurance for various risks associated with its operations. In connection with these liability insurance policies, Centuri is responsible for an initial deductible or self-insured retention amount per occurrence, after which the insurance carriers would be responsible for amounts up to the policy limits. For the policy year May 2020 to April 2021, Centuri is responsible for the first $750,000 (self-insured retention) per occurrence under these liability insurance policies.
Through an assessment process, the Company and Southwest may determine that certain costs are likely to be incurred in the future related to specific legal matters. In these circumstances and in accordance with accounting policies, the Company and Southwest will make an accrual, as necessary.
Note 11 - Pension and Other Postretirement Benefits
Southwest Gas Corporation
Employees’ Investment Plan
An Employees’ Investment Plan (“EIP”) is offered to eligible employees of Southwest through deduction of a percentage of base compensation, subject to IRS limitations. The EIP provides for purchases of various mutual fund investments and Company common stock. One-half of amounts deferred by employees are matched, up to a maximum matching contribution of 3.5% of an employee’s annual compensation. There are no employer matching contributions for officer deferrals into the EIP.


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Contributions to the plan by Southwest were $5.9 million, $5.7 million, and $5.5 million for 2020, 2019, and 2018, respectively.
Deferred Compensation Plan
A deferred compensation plan is offered to all officers of Southwest and a separate deferred compensation plan is offered to members of the Company’s Board of Directors. The plans provide the opportunity to defer up to 100% of annual cash compensation. One-half of amounts deferred by officers are matched, up to a maximum matching contribution of 3.5% of an officer’s annual base salary. Upon retirement, payments of compensation deferred, plus interest, are made in equal monthly installments over 10, 15, or 20 years, as elected by the participant. Directors have an additional option to receive such payments over a five-year period. Deferred compensation earns interest at a rate determined each January. The interest rate equals 150% of Moody’s Seasoned Corporate Bond Rate Index.
Pension and Postretirement Plans
A noncontributory qualified retirement plan with defined benefits covering substantially all Southwest employees is available, in addition to a separate unfunded supplemental executive retirement plan (“SERP”), which is limited to Southwest’s officers. Postretirement benefits other than pensions (“PBOP”) are provided to qualified retirees for health care, dental, and life insurance benefits.
The overfunded or underfunded positions of defined benefit postretirement plans, including pension plans, are recognized in the Consolidated Balance Sheets. Any actuarial gains and losses, prior service costs, and transition assets or obligations are recognized in Accumulated other comprehensive income under Stockholders’ equity, net of tax, until they are amortized as a component of net periodic benefit cost.
A regulatory asset has been established for the portion of the total amounts otherwise chargeable to Accumulated other comprehensive income that are expected to be recovered through rates in future periods. Changes in actuarial gains and losses and prior service costs pertaining to the regulatory asset will be recognized as an adjustment to the regulatory asset account as these amounts are amortized and recognized as components of net periodic pension costs each year.
The qualified retirement plan invests the majority of its plan assets in common collective trusts, which include a well-diversified portfolio of domestic and international equity securities and fixed income securities, and which are managed by a professional investment manager appointed by Southwest. The investment manager has full discretionary authority to direct the investment of plan assets held in trust within the specific guidelines prescribed by Southwest through the plan’s investment policy statement. In 2016, Southwest adopted a liability driven investment (“LDI”) strategy for part of the portfolio, a form of investing designed to better match the movement in pension plan assets with the impact of interest rate changes and inflation assumption changes on the pension plan liability. The implementation of the LDI strategy will be phased in over time by using a glide path. The glide path is designed to increase the allocation of the plan’s assets to fixed income securities, as the funded status of the plan increases, in order to more closely match the duration of the plan assets to that of the plan liability. Pension plan assets are held in a Master Trust. The pension plan funding policy is in compliance with the federal government’s funding requirements.
Pension costs for these plans are affected by the amount and timing of cash contributions to the plans, the return on plan assets, discount rates, and by employee demographics, including age, compensation, and length of service. Changes made to the provisions of the plans may also impact current and future pension costs. Actuarial formulas are used in the determination of pension costs and are affected by actual plan experience and assumptions about future experience. Key actuarial assumptions include the expected return on plan assets, the discount rate used in determining the projected benefit obligation and pension costs, and the assumed rate of increase in employee compensation. Relatively small changes in these assumptions, particularly the discount rate, may significantly affect pension costs and plan obligations for the qualified retirement plan. In determining the discount rate, management matches the plan’s projected cash flows to a spot-rate yield curve based on highly rated corporate bonds. Changes to the discount rate from year-to-year, if any, are generally made in increments of 25 basis points.
Due to an historically low interest rate environment, there was a 75 basis points decrease in the discount rate between years, as reflected below. This decrease in the discount rate was the most significant contributor to the actuarial loss for the qualified retirement plan, SERP, and PBOP benefit obligations as of December 31, 2020. The methodology utilized to determine the discount rate was consistent with prior years. The weighted-average rate of compensation increase was lowered from the prior year by 25 basis points. The asset return assumption (which impacts the following year’s expense) was also lowered by 25 basis points. The rates are presented in the table below:


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December 31,
20202019
Discount rate2.75 %3.50 %
Weighted-average rate of compensation increase3.00 %3.25 %
Asset return assumption6.50 %6.75 %
Future years’ expense level movements (up or down) will continue to be greatly influenced by long-term interest rates, asset returns, and funding levels.
The following table sets forth the retirement plan, SERP, and PBOP funded statuses and amounts recognized on the Consolidated Balance Sheets and Consolidated Statements of Income.
Year Ended December 31,
  20202019
(Thousands of dollars)
Qualified
Retirement Plan
SERPPBOP
Qualified
Retirement Plan
SERPPBOP
Change in benefit obligations:
Benefit obligation for service rendered to date at beginning of year (PBO/PBO/APBO)
$1,329,577 $47,397 $76,111 $1,116,014 $40,603 $69,956 
Service cost34,299 389 1,581 25,864 266 1,276 
Interest cost45,555 1,604 2,582 49,006 1,760 3,046 
Plan amendments— — — — — 1,878 
Actuarial loss (gain)145,440 7,240 6,547 192,416 7,974 3,156 
Benefits paid(55,632)(2,999)(4,616)(53,723)(3,206)(3,201)
Benefit obligation at end of year (PBO/PBO/APBO)
1,499,239 53,631 82,205 1,329,577 47,397 76,111 
Change in plan assets:
Market value of plan assets at beginning of year
974,993 — 52,838 790,614 — 47,341 
Actual return on plan assets165,072 — 5,320 186,102 — 9,757 
Employer contributions102,000 2,999 — 52,000 3,206 — 
Benefits paid(55,632)(2,999)(5,872)(53,723)(3,206)(4,260)
Market value of plan assets at end of year
1,186,433 — 52,286 974,993 — 52,838 
Funded status at year end$(312,806)$(53,631)$(29,919)$(354,584)$(47,397)$(23,273)
Weighted-average assumptions (benefit obligation):
Discount rate2.75 %2.75 %2.75 %3.50 %3.50 %3.50 %
Weighted-average rate of compensation increase
3.00 %3.00 %N/A 3.25 %3.25 %N/A
Estimated funding for the plans above during calendar year 2021 is approximately $105 million, of which $102 million pertains to the retirement plan, and which includes a supplemental discretionary contribution of $50 million in January 2021, similar to the supplemental discretionary contribution made in January 2020. Management monitors plan assets and liabilities and may, at its discretion, increase plan funding levels above the minimum in order to achieve a desired funded status and avoid or minimize potential benefit restrictions. As a result of the impact of the historically low discount rates at December 31, 2020 and December 31, 2019, Southwest made the discretionary supplemental contributions, which are intended to mitigate the impacts on the funded status and the increase in pension costs in both years, through the ability to provide returns on the increased level of plan investments.
The accumulated benefit obligation for the retirement plan and the SERP is presented below:
December 31,
(Thousands of dollars)20202019
Retirement plan$1,367,179 $1,219,989 
SERP50,471 46,067 


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Benefits expected to be paid for pension, SERP, and PBOP over the next 10 years are as follows:
(Millions of dollars)202120222023202420252026-2030
Pension$58.0 $60.0 $61.0 $62.0 $63.0 $339.0 
SERP3.2 3.2 3.2 3.2 3.1 15.1 
PBOP4.9 5.0 4.9 4.9 4.9 24.0 
No assurance can be made that actual funding and benefits paid will match these estimates.
For PBOP measurement purposes, the per capita cost of the covered health care benefits medical rate trend assumption is 6.0%, declining to 4.5%. Specific contributions are made for health care benefits of employees who retire after 1988, but Southwest pays all covered health care costs for employees who retired prior to 1989. The medical trend rate assumption noted above applies to the benefit obligations of pre-1989 retirees only.
The service cost component of net periodic benefit costs included in the table below is part of an overhead loading process associated with the cost of labor. The overhead process ultimately results in allocation of that portion of overall net periodic benefit costs to the same accounts to which productive labor is charged. As a result, service costs become components of various accounts, primarily Operations and maintenance expense, Net utility plant, and Deferred charges and other assets for both the Company and Southwest. The non-service cost components of net periodic benefit cost are reflected in Other income (deductions) on the Consolidated Statements of Income of each entity, based on accounting guidance for the presentation of such costs.
Components of net periodic benefit cost:
Qualified Retirement PlanSERPPBOP
(Thousands of dollars)202020192018202020192018202020192018
Service cost$34,299 $25,864 $28,555 $389 $266 $245 $1,581 $1,276 $1,473 
Interest cost45,555 49,006 44,174 1,604 1,760 1,658 2,582 3,046 2,748 
Expected return on plan assets(65,296)(60,244)(58,755)— — — (3,408)(3,156)(3,718)
Amortization of prior service cost
— — — — — — 1,155 1,271 1,335 
Amortization of net actuarial loss
36,025 22,356 32,115 1,805 1,020 1,502 — — — 
Net periodic benefit cost$50,583 $36,982 $46,089 $3,798 $3,046 $3,405 $1,910 $2,437 $1,838 
Weighted-average assumptions (net benefit cost)
Discount rate3.50 %4.50 %3.75 %3.50 %4.50 %3.75 %3.50 %4.50 %3.75 %
Expected return on plan assets6.75 %7.00 %7.00 %N/A N/AN/A6.75 %7.00 %7.00 %
Weighted-average rate of compensation increase
3.25 %3.25 %3.25 %3.25 %3.25 %3.25 %N/A N/AN/A


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Other Changes in Plan Assets and Benefit Obligations Recognized in Net Periodic Benefit Cost and Other Comprehensive Income
Year Ended December 31,
 202020192018
  (Thousands of dollars)Total
Qualified
Retirement
Plan
SERPPBOPTotal
Qualified
Retirement
Plan
SERPPBOPTotal
Qualified
Retirement
Plan
SERPPBOP
Net actuarial loss (gain) (a)
$57,539 $45,665 $7,240 $4,634 $71,087 $66,557 $7,975 $(3,445)$20,426 $23,607 $(3,940)$759 
Amortization of prior service cost (b)
(1,155)— — (1,155)(1,271)— — (1,271)(1,335)— — (1,335)
Amortization of net
actuarial loss (b)
(37,830)(36,025)(1,805)— (23,376)(22,356)(1,020)— (33,617)(32,115)(1,502)— 
Prior service cost
— — — — 1,878 — — 1,878 — — — — 
Regulatory adjustment
(7,435)(3,956)— (3,479)(36,944)(39,782)— 2,838 8,233 7,657 — 576 
Recognized in other comprehensive (income) loss
11,119 5,684 5,435 — 11,374 4,419 6,955 — (6,293)(851)(5,442)— 
Net periodic benefit costs recognized in net income
56,291 50,583 3,798 1,910 42,465 36,982 3,046 2,437 51,332 46,089 3,405 1,838 
Total of amount recognized in net periodic benefit cost and other comprehensive (income) loss
$67,410 $56,267 $9,233 $1,910 $53,839 $41,401 $10,001 $2,437 $45,039 $45,238 $(2,037)$1,838 
The table above discloses the net gain or loss and prior service cost recognized in Other comprehensive income, separated into (a) amounts initially recognized in Other comprehensive income, and (b) amounts subsequently recognized as adjustments to Other comprehensive income as those amounts are amortized as components of net periodic benefit cost. See also Note 6 - Other Comprehensive Income and Accumulated Other Comprehensive Income ("AOCI").


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The following table sets forth, by level within the three-level fair value hierarchy, the fair values of the assets of the qualified pension plan and the PBOP as of December 31, 2020 and 2019. The SERP has no assets.
December 31,
  20202019
(Thousands of dollars)
Qualified
Retirement
Plan
PBOPTotal
Qualified
Retirement
Plan
PBOPTotal
Assets at fair value:
Level 1 – Quoted prices in active markets for identical financial assets
Mutual funds$— $30,358 $30,358 $— $29,188 $29,188 
Total Level 1 Assets (1)— 30,358 30,358 — 29,188 29,188 
Level 2 – Significant other observable inputs
Private commingled equity funds (2)
Global324,084 5,878 329,962 266,908 6,338 273,246 
International141,290 2,563 143,853 117,086 2,780 119,866 
U.S. equity securities223,374 4,051 227,425 184,642 4,386 189,028 
Emerging markets76,679 1,391 78,070 62,943 1,494 64,437 
Private commingled fixed income funds (3)412,230 7,476 419,706 335,138 7,959 343,097 
Pooled funds and mutual funds5,990 565 6,555 5,359 689 6,048 
Government fixed income and mortgage backed securities201 4 205 181 4 185 
Total Level 2 assets (4)1,183,848 21,928 1,205,776 972,257 23,650 995,907 
Total Plan assets at fair value1,183,848 52,286 1,236,134 972,257 52,838 1,025,095 
Insurance company general account contracts (5)2,585 — 2,585 2,736 — 2,736 
Total Plan assets$1,186,433 $52,286 $1,238,719 $974,993 $52,838 $1,027,831 
(1)The Mutual funds category above is a balanced fund that invests in a diversified portfolio of common stocks, preferred stocks, and fixed-income securities. Under normal circumstances the balanced fund will hold no more than 75%, and no less than 25%, of its total assets in equity securities. The fund seeks regular income, conservation of principal, and an opportunity for long-term growth of principal and income.
(2)The private commingled equity funds include common collective trusts that invest in a diversified portfolio of securities regularly traded on securities exchanges. These funds are shown in the above table at net asset value (“NAV”), which is the value of securities in the fund less the amount of any liabilities outstanding. Strategies employed by the funds include investment in:
▪Global equities, including domestic equities
▪International developed countries equities
▪Domestic equities
▪Emerging markets equities
Shares in the private commingled equity funds may be redeemed given one business day notice. While they are private equity funds and reported at NAV, due to the short redemption notice period, the lack of redemption fees, the fact that the underlying investments are exchange-traded, and that substantial liabilities do not exist subject to the NAV calculation, these investments are viewed as indirectly observable (Level 2) in the fair value hierarchy and are therefore not excluded from the body of the fair value table as a reconciling item.
The global fund provides diversified exposure to global equity markets. The fund seeks to provide long-term capital growth by investing primarily in securities listed on the major developed equity markets of the U.S., Europe, and Asia, as well as within those listed on emerging country equity markets on a tactical basis.
The international fund invests in international financial markets, primarily those of developed economies in Europe and the Pacific Basin. The fund invests primarily in equity securities issued by foreign corporations, but may invest in other securities perceived as offering attractive investment return opportunities.
The domestic equities securities funds include a large and medium capitalization fund and a small capitalization fund. The large and medium capitalization fund is designed to track the performance of the large and medium capitalization companies contained in the index, which represents approximately 90% of the market capitalization of the U.S. stock market. The small capitalization fund is designed to provide maximum long-term appreciation through investments that are well diversified by industry.
The emerging markets fund was developed to invest in emerging market equities worldwide. The purposes of the fund’s operations, “emerging market countries,” include every country in the world except the developed markets of the U.S., Canada, Japan, Australia, New Zealand, Hong Kong, and Singapore, and most countries located in Western Europe. Fund investments are made directly in each country or, where direct investment is inefficient or prohibited, through appropriate financial instruments or participation in commingled funds.
(3)The private commingled fixed income funds consist primarily of fixed income debt securities issued by the U.S. Treasury, government agencies, and fixed income debt securities issued by corporations. The fixed income fund investments may include the use of


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high yield, international fixed income securities and other instruments, including derivatives, to ensure prudent diversification over a broad spectrum of investments. The changes in the value of the fixed income funds are intended to offset the changes in the pension plan liabilities due to changes in the discount rate.
These funds are shown in the above table at NAV. Investments in the private commingled fixed equity funds may be redeemed given one business day notice. While they are private fixed income funds and reported at NAV, due to the short redemption notice period, the lack of redemption fees, the fact that the underlying investments are exchange-traded, and that substantial liabilities do not exist subject to the NAV calculation, these investments are viewed as indirectly observable (Level 2), and are also not excluded from the body of the fair value table as a reconciling item.
(4)With the exception of items (2) and (3), which are discussed above, the Level 2 assets consist mainly of pooled funds and mutual funds. These funds are collective short-term funds that invest in Treasury bills and money market funds and are used as a temporary cash repository.
(5)The insurance company general account contracts are annuity insurance contracts used to pay the pensions of employees who retired prior to 1989. The balance of the account disclosed in the above table is the contract value, which is the result of deposits, withdrawals, and interest credits.
Centuri
Defined Contribution Plans
Centuri offers defined contribution plans under Section 401(k) of the Internal Revenue Code to its eligible employees, regardless of whether they are covered under collective-bargaining agreements. Eligibility requirements vary, as does timing of participation, matching, vesting, and profit-sharing features of the plans. Contributions by Centuri to these plans for the years ended December 31, 2020, 2019, and 2018 were $9 million, $8 million, and $7 million, respectively.
Deferred Compensation Plan
Centuri sponsors a nonqualified deferred compensation plan that is offered to a select group of management and highly-compensated employees. The plan allows participants to defer up to 80% of base salary and provides a match of 100% of contributions up to 5% of a participant’s salary. The plan also allows Centuri, at its election, to credit participant accounts with discretionary contributions. Participants are 100% vested in salary deferrals, contributions, and all earnings. Participant accounts include a return based on the performance of the underlying investment options selected. Payments from the plan are designated at each annual enrollment period based on specified triggering events and are payable by lump sum or on an annual installment basis.
Multiemployer Pension Plans
Centuri makes defined contributions to several multiemployer defined benefit pension plans under the terms of collective bargaining agreements (“CBAs”) with various unions representing certain employees. Contribution rates are generally specified in the CBAs and are made to the plans on a “pay-as-you-go” basis. Such contributions correspond to the number of union employees and the particular plans in which they participate, and vary depending upon the location, number of ongoing projects, and the need for union resources in connection with those projects.
The risks of participating in multiemployer plans are different from single-employer plans, including: (i) assets contributed to the multiemployer plan by one employer may be used to provide benefits to employees of other participating employers; (ii) if a participating employer stops contributing to the multiemployer plan, the unfunded obligations of the plan may become the obligation of the remaining participating employers; and (iii) if a participating employer chooses to stop participating in these multiemployer plans, the employer may be required to pay those plans an amount based on the underfunded status of the plan.
The Pension Protection Act of 2006 requires special funding and operational rules for multiemployer plans in the U.S., including classification of the plans (based on multiple factors, including the funded status of the plan), the most severe of which is “critical.” Depending upon the classification, plans may be required to adopt measures to improve their funded status through a funding improvement or rehabilitation plan, which may require additional contributions from employers (in the form of a surcharge on benefit contributions) and/or modification of retiree benefits. The amount of additional funds, if any, that Centuri may be obligated to contribute to these plans in the future cannot be estimated due to the uncertainty regarding future levels of work that may require the utilization of union employees covered by these plans, as well as uncertainty as to the future contribution levels and possible surcharges on contributions that may apply to these plans at that time.
Centuri contributed $44.3 million, $41.3 million, and $38.2 million collectively to the plans for the years ended December 31, 2020, 2019, and 2018, respectively. Substantially all of the contributions made by Centuri during these years were to U.S. plans that were not classified as critical, and for which no special surcharges were assessed. Only three plans were classified as critical and required special surcharges; however, the contributions overall related to these plans in all periods were insignificant.


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Note 12 - Income Taxes
Southwest Gas Holdings, Inc.:
The following is a summary of income before taxes and noncontrolling interest for domestic and foreign operations:
Year ended December 31,
(Thousands of dollars)202020192018
U.S.$282,489 $261,525 $235,120 
Foreign22,249 11,145 8,216 
Total income before income taxes$304,738 $272,670 $243,336 
Income tax expense (benefit) consists of the following:
Year Ended December 31,
(Thousands of dollars)202020192018
Current:
Federal$6,287 $622 $(13,476)
State8,617 (1,510)(3,219)
Foreign4,666 5,013 2,563 
19,570 4,125 (14,132)
Deferred:
Federal44,547 45,593 67,784 
State414 8,212 8,901 
Foreign1,222 (1,907)(869)
46,183 51,898 75,816 
Total income tax expense$65,753 $56,023 $61,684 
Deferred income tax expense (benefit) consists of the following significant components:
Year Ended December 31,
(Thousands of dollars)202020192018
Deferred federal and state:
Property-related items$50,504 $60,449 $94,899 
Purchased gas cost adjustments(5,726)3,834 (3,507)
Employee benefits459 7,680 (7,334)
Regulatory adjustments(9,885)(11,962)2,412 
Deferred payroll taxes(9,055)— — 
Alternative minimum tax4,409 441 849 
All other deferred15,529 (8,298)(10,890)
Total deferred federal and state46,235 52,144 76,429 
Deferred ITC, net(52)(246)(613)
Total deferred income tax expense$46,183 $51,898 $75,816 
References above and below to Deferred payroll taxes relate to the employer portion of Social Security tax, for which deferment of remittance was permissible under the Coronavirus Aid, Relief, and Economic Security (“CARES”) Act.


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A reconciliation of the U.S. federal statutory rate to the consolidated effective tax rate (and the sources of these differences and the effect of each) are summarized as follows:
Year Ended December 31,
202020192018
U.S. federal statutory income tax rate21.0 %21.0 %21.0 %
Net state taxes3.0 2.1 2.9 
Tax credits(0.5)(0.3)(0.3)
Company-owned life insurance(0.8)(1.5)0.1 
Amortization of excess deferred taxes(0.8)(0.9)— 
All other differences(0.3)0.1 1.6 
Consolidated effective income tax rate21.6 %20.5 %25.3 %
Deferred tax assets and liabilities consist of the following:
December 31,
(Thousands of dollars)20202019
Deferred tax assets:
Deferred income taxes for future amortization of ITC and excess deferred taxes$104,314 $105,077 
Employee benefits39,907 37,439 
Alternative minimum tax credit— 4,409 
Federal net operating losses4,118 7,467 
Deferred payroll taxes9,055 — 
Lease-related item20,890 21,226 
Other14,350 21,536 
Valuation allowance(22)(25)
192,612 197,129 
Deferred tax liabilities:
Property-related items, including accelerated depreciation785,734 732,798 
Regulatory balancing accounts4,205 9,931 
Debt-related costs2,585 2,818 
Intangibles13,511 10,611 
Lease-related item19,789 20,386 
Other13,786 19,569 
839,610 796,113 
Net noncurrent deferred tax liabilities$646,998 $598,984 
Net noncurrent deferred tax liabilities above at December 31, 2020 and 2019 are reflected net of $455,000 and $856,000 of noncurrent deferred tax assets associated with the Company’s Canadian operations, which are shown separately on the Company’s Consolidated Balance Sheets.


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A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:
December 31,
(Thousands of dollars)20202019
Unrecognized tax benefits at beginning of year$1,056 $971 
Gross increases – tax positions in prior period641 85 
Gross decreases – tax positions in prior period— — 
Gross increases – current period tax positions231 — 
Gross decreases – current period tax positions— — 
Settlements— — 
Lapse in statute of limitations— — 
Unrecognized tax benefits at end of year$1,928 $1,056 
Southwest Gas Corporation:
The following is a summary of income before taxes:
Year ended December 31,
(Thousands of dollars)202020192018
Total income before income taxes$194,873 $198,144 $182,833 
 Income tax expense (benefit) consists of the following:
Year Ended December 31,
(Thousands of dollars)202020192018
Current:
Federal$(4,678)$4,109 $(17,584)
State(179)250 (6,783)
(4,857)4,359 (24,367)
Deferred:
Federal38,561 29,543 58,136 
State2,051 1,071 10,222 
40,612 30,614 68,358 
Total income tax expense$35,755 $34,973 $43,991 
Deferred income tax expense (benefit) consists of the following significant components:
Year Ended December 31,
(Thousands of dollars)202020192018
Deferred federal and state:
Property-related items$36,029 $34,398 $67,576 
Purchased gas cost adjustments(5,726)3,834 (3,507)
Employee benefits11,437 6,493 2,156 
Regulatory adjustments(9,885)(11,962)2,412 
Deferred payroll taxes(1,810)— — 
Alternative minimum tax4,409 441 849 
All other deferred6,210 (2,344)(515)
Total deferred federal and state40,664 30,860 68,971 
Deferred ITC, net(52)(246)(613)
Total deferred income tax expense$40,612 $30,614 $68,358 



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A reconciliation of the U.S. federal statutory rate to the consolidated effective tax rate (and the sources of these differences and the effect of each) are summarized as follows:
Year Ended December 31,
202020192018
U.S. federal statutory income tax rate21.0 %21.0 %21.0 %
Net state taxes1.7 0.7 2.1 
Tax credits(0.7)(0.4)(0.4)
Company-owned life insurance(1.0)(1.9)0.3 
Amortization of excess deferred taxes(1.3)(1.2)— 
All other differences(1.4)(0.5)1.1 
Effective income tax rate18.3 %17.7 %24.1 %
Deferred tax assets and liabilities consist of the following:
December 31,
(Thousands of dollars)20202019
Deferred tax assets:
Deferred income taxes for future amortization of ITC and excess deferred taxes$104,314 $105,077 
Employee benefits4,806 13,574 
Alternative minimum tax credit— 4,409 
Deferred payroll taxes1,810 — 
Other7,790 12,193 
Valuation allowance(22)(25)
118,698 135,228 
Deferred tax liabilities:
Property-related items, including accelerated depreciation680,294 644,046 
Regulatory balancing accounts4,205 9,931 
Debt-related costs2,585 2,818 
Other12,714 17,483 
699,798 674,278 
Net deferred tax liabilities$581,100 $539,050 
A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:
December 31,
(Thousands of dollars)20202019
Unrecognized tax benefits at beginning of year$1,056 $971 
Gross increases – tax positions in prior period506 85 
Gross decreases – tax positions in prior period— — 
Gross increases – current period tax positions231 — 
Gross decreases – current period tax positions— — 
Settlements— — 
Lapse in statute of limitations— — 
Unrecognized tax benefits at end of year$1,793 $1,056 
In assessing whether uncertain tax positions should be recognized in its financial statements, management first determines whether it is more-likely-than-not that a tax position will be sustained upon examination, including resolution of any related appeals or litigation processes, based on the technical merits of the position. In evaluations of whether a tax position has met the more-likely-than-not recognition threshold, management presumes that the position will be examined by the appropriate taxing authority that would have full knowledge of all relevant information. For tax positions that meet the more-likely-than-not recognition threshold, management measures the amount of benefit recognized in the financial statements at the largest amount of benefit that is greater than 50% likely of being realized upon ultimate settlement. Unrecognized tax benefits are recognized in the first financial reporting period in which information becomes available indicating that such benefits will more-likely-than-not be realized. For each reporting period, management applies a consistent methodology to measure unrecognized tax benefits, and all unrecognized tax benefits are reviewed periodically and adjusted as circumstances warrant. Measurement of unrecognized tax benefits is based on management’s assessment of all relevant information, including prior audit experience,


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the status of audits, conclusions of tax audits, lapsing of applicable statutes of limitation, identification of new issues, and any administrative guidance or developments.
At December 31, 2020, the total amount of unrecognized tax benefits that, if recognized, would impact the effective tax rate was $1.9 million for the Company and $1.8 million for Southwest. No significant increases or decreases in unrecognized tax benefits are expected within the next 12 months.
The Company and Southwest recognize interest expense and income and penalties related to income tax matters in income tax expense. There was $523,000 of tax-related interest income for 2020, and none in 2019 or 2018.
The Company’s regulated operations accounting for income taxes is impacted by the FASB’s ASC 980 – Regulated Operations. Reductions in accumulated deferred income tax balances due to the reduction in the corporate income tax rates to 21% under the provisions of the Tax Cuts and Jobs Act (the “TCJA”), enacted in December 2017, may continue to result in a refund of excess deferred taxes to customers, generally through reductions in future rates. The TCJA included provisions that stipulate how these excess deferred taxes may be passed back to customers for certain accelerated tax depreciation benefits. Potential refunds of other deferred taxes will be determined in conjunction with appropriate regulatory commissions. Southwest began refunding excess deferred taxes to Nevada customers starting in January 2019 and to Arizona customers in January 2021. Refunding to California customers will begin with the effective date of new rates for the most recent general rate case. Paiute began refunding excess deferred taxes to its customers starting in December 2019. The December 31, 2020 Consolidated Balance Sheets of Southwest and the Company reflect the impact of the TCJA and the remaining unamortized balance of the regulatory liability (including a gross-up), barring further changes to income tax rates. See also Note 5 - Regulatory Assets and Liabilities.
The Company and its subsidiaries file a consolidated federal income tax return in the U.S. and in various states, as well as separate returns in Canada. With few exceptions, the Company is no longer subject to U.S. federal, state and local, or Canadian income tax examinations for years before 2016.
The Company and each of its subsidiaries, including Southwest, participate in a tax sharing agreement to establish the method for allocating tax benefits and losses among members of the consolidated group. The consolidated federal income tax is apportioned among the subsidiaries using a separate return method.
At December 31, 2020, the Company has no U.S. federal net operating loss carryforward. The Company also has no general business credit carryforwards. The Company has a net capital loss carryforward of $97,000, which will begin to expire in 2021. At December 31, 2020, the Company has an income tax net operating loss carryforward related to Canadian operations of $12.7 million, which begins to expire in 2034. At December 31, 2020, the Company has $50.9 million of state net operating loss carryforwards, with a tax effect (net of federal benefit) of $3.2 million. Depending on the jurisdiction in which the state net operating loss was generated, the carryforwards will begin to expire in 2025.
Management intends to continue to permanently reinvest any future foreign earnings in Canada.
Note 13 - Segment Information
The Company’s operating segments are determined based on the nature of their activities. The natural gas operations segment is engaged in the business of purchasing, distributing, and transporting natural gas. Revenues are generated from the distribution and transportation of natural gas. The utility infrastructure services segment is primarily engaged in the business of providing utility companies with trenching and installation, replacement, and maintenance services for energy distribution systems. Although our utility infrastructure services operations are geographically dispersed, they are aggregated and reported as a single segment as each reporting unit has similar economic characteristics. Over 99% of the total Company’s long-lived assets are in the U.S.
The accounting policies of the reported segments are the same as those described within Note 1 - Background, Organization, and Summary of Significant Accounting Policies. Centuri accounts for the services provided to Southwest at contractual prices at contract inception. Accounts receivable for these services, which are not eliminated during consolidation, are presented in the table below:
December 31,
(Thousands of dollars)20202019
Accounts receivable for Centuri services
$13,956 $15,235 


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The following table presents the amount of revenues for both segments by geographic area:
December 31,
(Thousands of dollars)202020192018
Revenues (a)
United States$3,057,041 $2,893,201 $2,664,670 
Canada241,832 226,716 215,343 
Total$3,298,873 $3,119,917 $2,880,013 
(a)Revenues are attributed to countries based on the location of customers.
The Company has two reportable segments: natural gas operations and utility infrastructure services. Southwest has a single reportable segment that is referred to herein as the natural gas operations segment of the Company. In order to reconcile to net income as disclosed in the Consolidated Statements of Income, an Other column is included associated with impacts of corporate and administrative activities related to Southwest Gas Holdings, Inc. The financial information pertaining to the natural gas operations and utility infrastructure services segments for each of the three years in the period ended December 31, 2020 is as follows:
Year Ended December 31, 2020
(Thousands of dollars)
Natural Gas
Operations
Utility Infrastructure ServicesOtherTotal
Revenues from external customers$1,350,585 $1,813,429 $— $3,164,014 
Intersegment sales— 134,859 — 134,859 
Total$1,350,585 $1,948,288 $— $3,298,873 
Interest income$4,015 $— $— $4,015 
Interest expense$101,148 $9,269 $1,060 $111,477 
Depreciation and amortization$235,295 $96,732 $— $332,027 
Income tax expense$35,755 $31,128 $(1,130)$65,753 
Segment net income$159,118 $74,862 $(1,656)$232,324 
Segment assets$7,256,636 $1,475,237 $3,980 $8,735,853 
Capital expenditures$692,216 $132,889 $— $825,105 
Year Ended December 31, 2019
(Thousands of dollars)
Natural Gas
Operations
Utility Infrastructure ServicesOtherTotal
Revenues from external customers$1,368,939 $1,592,252 $— $2,961,191 
Intersegment sales— 158,726 — 158,726 
Total$1,368,939 $1,750,978 $— $3,119,917 
Interest income$6,356 $— $— $6,356 
Interest expense$95,026 $14,086 $114 $109,226 
Depreciation and amortization$215,620 $87,617 $— $303,237 
Income tax expense$34,973 $21,399 $(349)$56,023 
Segment net income$163,171 $52,404 $(1,639)$213,936 
Segment assets$6,798,746 $1,365,194 $6,108 $8,170,048 
Capital expenditures$778,748 $159,400 $— $938,148 


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Year Ended December 31, 2018
(Thousands of dollars)
Natural Gas
Operations
Utility Infrastructure ServicesOtherTotal
Revenues from external customers$1,357,728 $1,386,371 $— $2,744,099 
Intersegment sales— 135,914 — 135,914 
Total$1,357,728 $1,522,285 $— $2,880,013 
Interest income$6,020 $88 $— $6,108 
Interest expense$81,740 $14,190 $741 $96,671 
Depreciation and amortization$191,816 $57,396 $— $249,212 
Income tax expense$43,991 $18,420 $(727)$61,684 
Segment net income$138,842 $44,977 $(1,542)$182,277 
Segment assets$6,141,584 $1,215,573 $572 $7,357,729 
Capital expenditures$682,869 $83,045 $— $765,914 




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Note 14 - Quarterly Financial Data (Unaudited)
The following table presents summarized quarterly financial data for 2020 and 2019:
  Quarter Ended
  March 31June 30September 30December 31
(Thousands of dollars, except per share amounts)
2020
Southwest Gas Holdings, Inc.:
Operating revenues$836,320 $757,247 $791,226 $914,080 
Operating income 148,373 67,572 54,264 152,795 
Net income73,005 39,881 21,063 105,036 
Net income attributable to Southwest Gas Holdings, Inc.
72,542 37,965 18,273 103,544 
Basic earnings per common share (1)$1.31 $0.68 $0.32 $1.82 
Diluted earnings per common share (1)$1.31 $0.68 $0.32 $1.82 
Southwest Gas Corporation:
Operating revenues$502,827 $262,434 $210,834 $374,490 
Operating income157,815 27,101 1,625 116,070 
Net income (loss)83,599 11,942 (15,973)79,550 
2019
Southwest Gas Holdings, Inc.:
Operating revenues$833,539 $713,011 $725,230 $848,137 
Operating income140,480 54,869 38,258 138,204 
Net income95,384 22,832 6,525 91,906 
Net income attributable to Southwest Gas Holdings, Inc.
94,809 22,056 5,353 91,718 
Basic earnings per common share (1)$1.78 $0.41 $0.10 $1.67 
Diluted earnings per common share (1)$1.77 $0.41 $0.10 $1.67 
Southwest Gas Corporation:
Operating revenues$520,677 $258,711 $209,980 $379,571 
Operating income (loss)148,713 24,069 (1,807)112,678 
Net income (loss)103,389 3,369 (20,012)76,425 
(1)The sum of quarterly earnings (loss) per average common share may not equal the annual earnings (loss) per share due to the ongoing change in the weighted-average number of common shares.
The demand for natural gas is seasonal, and it is the opinion of management that comparisons of earnings for interim periods do not reliably reflect overall trends and changes in operations. Also, the timing of general rate relief can have a significant impact on earnings for interim periods.
Note 15 - Redeemable Noncontrolling Interest
In connection with the acquisition of Linetec in November 2018, the previous owner retained a 20% equity interest in Linetec, the reduction of which is subject to certain rights based on the passage of time or upon the occurrence of certain triggering events. Effective January 2022, the Company, by means of Centuri, has the right, but not the obligation, to purchase at fair value (subject to a floor) a portion of the interest held by the noncontrolling party, and in incremental amounts each year thereafter. The shares subject to the election accumulate (if earlier elections are not made) such that 100% of the interest retained by the noncontrolling party is subject to the election beginning in 2024. If the Company does not exercise its rights at each or any of the specified intervals, the noncontrolling party has the ability, but not the obligation, to exit their investment retained by requiring Centuri to purchase a similar portion of their interest up to the maximum cumulative amounts specified and at each interval discussed above. The outstanding noncontrolling interest is not subject to minimum purchase provisions and following the eligibility dates for the elections, they do not expire. The redemption price represents the greater of fair value


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of the ownership interest to be redeemed on the redemption date or a floor amount under the terms of the agreement. The Company has determined that this noncontrolling interest is a redeemable noncontrolling interest and, in accordance with SEC guidance, is classified as mezzanine equity (temporary equity) in the Company’s Consolidated Balance Sheets.
Significant changes in the value of the redeemable noncontrolling interest, above a floor established at the acquisition date, are recognized as they occur, and the carrying value is adjusted as necessary at each reporting date. The fair value is estimated using a market approach that utilizes certain financial metrics from guideline public companies of similar industry and operating characteristics. Based on the fair value model employed, the estimated redemption value of the redeemable noncontrolling interest increased by approximately $74.5 million during the year ended December 31, 2020. Adjustment to the redemption value also impacted retained earnings, as reflected in the Company’s Consolidated Statement of Equity, but did not impact net income.
The following depicts changes to the balance of the redeemable noncontrolling interest:
 
Redeemable Noncontrolling
Interest
(Thousands of dollars)
Balance, December 31, 2018$81,831 
Net income attributable to redeemable noncontrolling interest2,711 
Balance, December 31, 201984,542 
Net income attributable to redeemable noncontrolling interest6,661 
Redemption value adjustment74,513 
Balance, December 31, 2020$165,716 


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MANAGEMENT’S REPORTS ON INTERNAL CONTROL OVER FINANCIAL REPORTING
Management of Southwest Gas Holdings, Inc. is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined by Rule 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934. Under the supervision and with the participation of Southwest Gas Holdings, Inc. management, including the principal executive officer and principal financial officer, an evaluation was conducted of the effectiveness of internal control over financial reporting based on the “Internal Control – Integrated Framework” (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based upon management’s evaluation under such framework, management concluded that the internal control over financial reporting was effective as of December 31, 2020. The effectiveness of internal control over financial reporting as of December 31, 2020 has been audited by PricewaterhouseCoopers, LLP, an independent registered public accounting firm, as stated in their report which is included herein.
Management of Southwest Gas Corporation is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934. Under the supervision and with the participation of Southwest Gas Corporation management, including the principal executive officer and principal financial officer, an evaluation was conducted of the effectiveness of internal control over financial reporting based on the “Internal Control – Integrated Framework” (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based upon management’s evaluation under such framework, management concluded that Southwest Gas Corporation’s internal control over financial reporting was effective as of December 31, 2020. This annual report does not include a report of Southwest Gas Corporation’s registered public accounting firm regarding internal control over financial reporting pursuant to rules of the Securities and Exchange Commission that permit Southwest Gas Corporation to provide only this management’s report in this annual report.
February 25, 2021
 



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Report of Independent Registered Public Accounting Firm
To the Board of Directors and Stockholders of Southwest Gas Holdings, Inc.
Opinions on the Financial Statements and Internal Control over Financial Reporting
We have audited the accompanying consolidated balance sheets of Southwest Gas Holdings, Inc. and its subsidiaries (the “Company”) as of December 31, 2020 and 2019, and the related consolidated statements of income, of comprehensive income, of equity and of cash flows for each of the three years in the period ended December 31, 2020, including the related notes (collectively referred to as the “consolidated financial statements”). We also have audited the Company’s internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2020, based on criteria established in Internal Control – Integrated Framework (2013) issued by the COSO.
Basis for Opinions
The Company’s management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Reports on Internal Control Over Financial Reporting. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company’s internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.



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Critical Audit Matters
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Regulatory Assets and Liabilities
As described in Note 5 to the consolidated financial statements, the Company’s net regulatory liabilities were $406 million as of December 31, 2020. The Company is subject to the regulation of the Arizona Corporation Commission, the Public Utilities Commission of Nevada, the California Public Utilities Commission and the Federal Energy Regulatory Commission. Accounting treatment for rate-regulated entities allows for deferral of costs as regulatory assets, costs that otherwise would be expensed, if it is probable that future recovery from customers will occur. As disclosed, management reviews the regulatory assets to assess their recoverability. If rate recovery is no longer probable, due to competition or the actions of regulators, write-off of the related regulatory asset as a current period expense would be recognized. Regulatory liabilities are recorded if it is probable that revenues will be reduced for amounts that will be refunded to customers through the ratemaking process.
The principal considerations for our determination that performing procedures relating to the Company’s accounting for regulatory assets and liabilities is a critical audit matter are the significant judgment by management in the ongoing evaluation of regulatory assets and liabilities and in applying guidance contained in regulatory proceedings and other relevant evidence including the timing of recognition of regulatory assets and liabilities; this in turn led to significant auditor judgment, subjectivity and effort in performing audit procedures and evaluating audit evidence relating to management’s judgments about the probability of recovery of regulatory assets and refund of regulatory liabilities.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s assessment of regulatory proceedings, including the probability of recovery of regulatory assets, refund of regulatory liabilities, and disclosure impacts. These procedures also included, among others, obtaining the Company’s correspondence with regulators, evaluating the reasonableness of management’s assessment regarding the probability of recovery of regulatory assets and refund of regulatory liabilities based on the status of regulatory proceedings and evaluating the related accounting and disclosure implications.
/s/PricewaterhouseCoopers LLP
Las Vegas, Nevada
February 25, 2021
We have served as the Company’s or its predecessor’s auditor since 2002.
 


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Report of Independent Registered Public Accounting Firm
To the Board of Directors and Stockholder of Southwest Gas Corporation
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Southwest Gas Corporation and its subsidiaries (the “Company”) as of December 31, 2020 and 2019, and the related consolidated statements of income, of comprehensive income, of equity and of cash flows for each of the three years in the period ended December 31, 2020, including the related notes (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2020 and 2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2020 in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits of these consolidated financial statements in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.
Regulatory Assets and Liabilities
As described in Note 5 to the consolidated financial statements, the Company’s net regulatory liabilities were $406 million as of December 31, 2020. The Company is subject to the regulation of the Arizona Corporation Commission, the Public Utilities Commission of Nevada, the California Public Utilities Commission and the Federal Energy Regulatory Commission. Accounting treatment for rate-regulated entities allows for deferral of costs as regulatory assets, costs that otherwise would be expensed, if it is probable that future recovery from customers will occur. As disclosed, management reviews the regulatory assets to assess their recoverability. If rate recovery is no longer probable, due to competition or the actions of regulators, write-off of the related regulatory asset as a current period expense would be recognized. Regulatory liabilities are recorded if it is probable that revenues will be reduced for amounts that will be refunded to customers through the ratemaking process.
The principal considerations for our determination that performing procedures relating to the Company’s accounting for regulatory assets and liabilities is a critical audit matter are the significant judgment by management in the ongoing evaluation of regulatory assets and liabilities and in applying guidance contained in regulatory proceedings and other relevant evidence including the timing of recognition of regulatory assets and liabilities; this in turn led to significant auditor judgment, subjectivity and effort in performing audit procedures and evaluating audit evidence relating to management’s judgments about the probability of recovery of regulatory assets and refund of regulatory liabilities.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to


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management’s assessment of regulatory proceedings, including the probability of recovery of regulatory assets, refund of regulatory liabilities, and disclosure impacts. These procedures also included, among others, obtaining the Company’s correspondence with regulators, evaluating the reasonableness of management’s assessment regarding the probability of recovery of regulatory assets and refund of regulatory liabilities based on the status of regulatory proceedings and evaluating the related accounting and disclosure implications.
/s/PricewaterhouseCoopers LLP
Las Vegas, Nevada
February 25, 2021
We have served as the Company’s auditor since 2002.
 



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