UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 10-Q


☒			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~March 31,~~September 30, 2021


☐			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission

File Number

Exact name of registrant as specified in its charter and
principal office address and telephone number

State of
Incorporation

I.R.S.
Employer Identification No.

001-37976

Southwest Gas Holdings, Inc.

Delaware

81-3881866

8360 S. Durango Drive

Post Office Box 98510

Las Vegas,

Nevada

89193-8510

(702)

876-7237

1-7850

Southwest Gas Corporation

California

88-0085720

8360 S. Durango Drive

Post Office Box 98510

Las Vegas,

Nevada

89193-8510

(702)

876-7237

Securities registered pursuant to Section 12(b) of the Act:

Title of each class

Trading Symbol

Name of each exchange on which registered

Southwest Gas Holdings, Inc. Common Stock, $1 Par Value

SWX

New York Stock Exchange

Preferred Stock Purchase Rights

N/A

New York Stock Exchange

Indicate by check mark whether each registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that each registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether each registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that each registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “non-accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Southwest Gas Holdings, Inc.:

Large accelerated filer

☒

Accelerated filer

☐

Non-accelerated filer

☐

Smaller reporting company

☐

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Southwest Gas Corporation:

Large accelerated filer

☐

Accelerated filer

☐

Non-accelerated filer

☒

Smaller reporting company

☐

Emerging growth company

☐

Indicate by check mark whether each registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

Indicate the number of shares outstanding of each of the issuer’s classes of common stock as of the latest practicable date.

Southwest Gas Holdings, Inc. Common Stock, $1 Par Value, ~~58,001,396~~60,385,084 shares as of ~~April 30,~~October 29, 2021.

All of the outstanding shares of common stock ($1 par value) of Southwest Gas Corporation were held by Southwest Gas Holdings, Inc. as of ~~April 30,~~October 29, 2021.

SOUTHWEST GAS CORPORATION MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION (H)(1)(a) and (b) OF FORM 10-Q AND IS THEREFORE FILING THIS REPORT WITH THE REDUCED DISCLOSURE FORMAT AS PERMITTED BY GENERAL INSTRUCTION H(2).


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

FILING FORMAT

This quarterly report on Form 10-Q is a combined report being filed by two separate registrants: Southwest Gas Holdings, Inc. and Southwest Gas Corporation. Except where the content clearly indicates otherwise, any reference in the report to “we,” “us” or “our” is to the holding company or the consolidated entity of Southwest Gas Holdings, Inc. and all of its subsidiaries, including Southwest Gas Corporation, which is a distinct registrant that is a wholly owned subsidiary of Southwest Gas Holdings, Inc. Information contained herein relating to any individual company is filed by such company on its own behalf. Each company makes representations only as to itself and makes no other representation whatsoever as to any other company.

Part I—Financial information in this Quarterly Report on Form 10-Q includes separate financial statements (i.e., balance sheets, statements of income, statements of comprehensive income, statements of cash flows, and statements of equity) for Southwest Gas Holdings, Inc. and Southwest Gas Corporation, in that order. The Notes to the Condensed Consolidated Financial Statements are presented on a combined basis for both entities. All Items other than Part I – Item 1 are combined for the reporting companies.


			2


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Thousands of dollars, except par value)

(Unaudited)


		March 31, 2021		December 31, 2020			September 30, 2021		December 31, 2020
ASSETS	ASSETS					ASSETS
Utility plant:	Utility plant:					Utility plant:
Gas plant	Gas plant	$	8,479,295	$	8,384,000	Gas plant	$	8,742,806	$	8,384,000
Less: accumulated depreciation	Less: accumulated depreciation	(2,453,924)		(2,419,348)		Less: accumulated depreciation	(2,499,488)		(2,419,348)
Construction work in progress	Construction work in progress	215,395		211,429		Construction work in progress	153,100		211,429
Net utility plant	Net utility plant	6,240,766		6,176,081		Net utility plant	6,396,418		6,176,081
Other property and investments	Other property and investments	842,672		834,245		Other property and investments	1,305,334		834,245
Current assets:	Current assets:					Current assets:
Cash and cash equivalents	Cash and cash equivalents	92,345		83,352		Cash and cash equivalents	186,690		83,352
Accounts receivable, net of allowances	Accounts receivable, net of allowances	479,184		522,172		Accounts receivable, net of allowances	692,135		522,172
Accrued utility revenue	Accrued utility revenue	50,500		82,400		Accrued utility revenue	39,700		82,400
Income taxes receivable, net	Income taxes receivable, net	6,523		10,884		Income taxes receivable, net	32,554		10,884
Deferred purchased gas costs	Deferred purchased gas costs	238,886		2,053		Deferred purchased gas costs	240,827		2,053
Prepaid and other current assets	Prepaid and other current assets	133,466		170,152		Prepaid and other current assets	200,700		170,152
Total current assets	Total current assets	1,000,904		871,013		Total current assets	1,392,606		871,013
Noncurrent assets:	Noncurrent assets:					Noncurrent assets:
Goodwill	Goodwill	346,553		345,184		Goodwill	791,902		345,184

Deferred income taxes	Deferred income taxes	563		455		Deferred income taxes	268		455
Deferred charges and other assets	Deferred charges and other assets	497,187		508,875		Deferred charges and other assets	483,107		508,875
Total noncurrent assets	Total noncurrent assets	844,303		854,514		Total noncurrent assets	1,275,277		854,514
Total assets	Total assets	$	8,928,645	$	8,735,853	Total assets	$	10,369,635	$	8,735,853
CAPITALIZATION AND LIABILITIES	CAPITALIZATION AND LIABILITIES					CAPITALIZATION AND LIABILITIES
Capitalization:	Capitalization:					Capitalization:
Common stock, $1 par (authorized - 120,000,000 shares; issued and outstanding - 57,995,563 and 57,192,925 shares)		$	59,625	$	58,823
Common stock, $1 par (authorized - 120,000,000 shares; issued and outstanding - 60,378,684 and 57,192,925 shares)						Common stock, $1 par (authorized - 120,000,000 shares; issued and outstanding - 60,378,684 and 57,192,925 shares)	$	62,009	$	58,823
Additional paid-in capital	Additional paid-in capital	1,660,108		1,609,155		Additional paid-in capital	1,823,889		1,609,155
Accumulated other comprehensive loss, net	Accumulated other comprehensive loss, net	(58,388)		(61,003)		Accumulated other comprehensive loss, net	(55,951)		(61,003)
Retained earnings	Retained earnings	1,112,377		1,067,978		Retained earnings	1,079,869		1,067,978
Total equity	Total equity	2,773,722		2,674,953		Total equity	2,909,816		2,674,953
Redeemable noncontrolling interest	Redeemable noncontrolling interest	205,286		165,716		Redeemable noncontrolling interest	183,547		165,716
Long-term debt, less current maturities	Long-term debt, less current maturities	2,696,570		2,732,200		Long-term debt, less current maturities	3,573,783		2,732,200
Total capitalization	Total capitalization	5,675,578		5,572,869		Total capitalization	6,667,146		5,572,869
Current liabilities:	Current liabilities:					Current liabilities:
Current maturities of long-term debt	Current maturities of long-term debt	67,334		40,433		Current maturities of long-term debt	297,271		40,433
Short-term debt	Short-term debt	310,000		107,000		Short-term debt	272,000		107,000
Accounts payable	Accounts payable	182,805		231,301		Accounts payable	222,959		231,301
Customer deposits	Customer deposits	67,121		67,920		Customer deposits	51,816		67,920
Income taxes payable, net	Income taxes payable, net	19,356		12,556		Income taxes payable, net	27,490		12,556
Accrued general taxes	Accrued general taxes	72,103		48,640		Accrued general taxes	60,656		48,640
Accrued interest	Accrued interest	34,571		20,536		Accrued interest	38,600		20,536
Deferred purchased gas costs	Deferred purchased gas costs	0		54,636		Deferred purchased gas costs	—		54,636
Other current liabilities	Other current liabilities	282,745		328,945		Other current liabilities	384,442		328,945
Total current liabilities	Total current liabilities	1,036,035		911,967		Total current liabilities	1,355,234		911,967
Deferred income taxes and other credits:	Deferred income taxes and other credits:					Deferred income taxes and other credits:
Deferred income taxes and investment tax credits, net	Deferred income taxes and investment tax credits, net	671,574		647,453		Deferred income taxes and investment tax credits, net	789,141		647,453
Accumulated removal costs	Accumulated removal costs	407,000		404,000		Accumulated removal costs	419,000		404,000
Other deferred credits and other long-term liabilities	Other deferred credits and other long-term liabilities	1,138,458		1,199,564		Other deferred credits and other long-term liabilities	1,139,114		1,199,564
Total deferred income taxes and other credits	Total deferred income taxes and other credits	2,217,032		2,251,017		Total deferred income taxes and other credits	2,347,255		2,251,017
Total capitalization and liabilities	Total capitalization and liabilities	$	8,928,645	$	8,735,853	Total capitalization and liabilities	$	10,369,635	$	8,735,853

The accompanying notes are an integral part of these statements.


			3


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(In thousands, except per share amounts)

(Unaudited)


		Three Months Ended March 31,				Twelve Months Ended March 31,					Three Months Ended September 30,				Nine Months Ended September 30,				Twelve Months Ended September 30,
		2021		2020			2021		2020				2021		2020		2021		2020		2021		2020
Operating revenues:	Operating revenues:											Operating revenues:
Gas operating revenues	Gas operating revenues	$	521,932	$	502,827		$	1,369,690	$	1,351,089		Gas operating revenues	$	255,848	$	210,834	$	1,070,576	$	976,095	$	1,445,066	$	1,355,666
Utility infrastructure services revenues	Utility infrastructure services revenues	363,975		333,493			1,978,770		1,771,609			Utility infrastructure services revenues	632,848		580,392		1,525,448		1,408,698		2,065,038		1,877,264
Total operating revenues	Total operating revenues	885,907		836,320			3,348,460		3,122,698			Total operating revenues	888,696		791,226		2,596,024		2,384,793		3,510,104		3,232,930
Operating expenses:	Operating expenses:											Operating expenses:
Net cost of gas sold	Net cost of gas sold	156,021		160,821			338,037		353,381			Net cost of gas sold	63,710		36,321		296,227		264,615		374,449		356,925
Operations and maintenance	Operations and maintenance	106,690		103,781			411,025		421,686			Operations and maintenance	122,927		101,764		334,450		304,964		437,602		407,924
Depreciation and amortization	Depreciation and amortization	93,442		87,653			337,816		313,351			Depreciation and amortization	91,380		80,139		267,670		245,009		354,688		324,995
Taxes other than income taxes	Taxes other than income taxes	20,687		16,378			67,769		62,500			Taxes other than income taxes	20,109		15,787		60,134		47,507		76,087		63,195
Utility infrastructure services expenses	Utility infrastructure services expenses	335,614		319,314			1,745,729		1,592,076			Utility infrastructure services expenses	567,270		502,951		1,381,524		1,252,489		1,858,464		1,671,478
Total operating expenses	Total operating expenses	712,454		687,947			2,900,376		2,742,994			Total operating expenses	865,396		736,962		2,340,005		2,114,584		3,101,290		2,824,517
Operating income	Operating income	173,453		148,373			448,084		379,704			Operating income	23,300		54,264		256,019		270,209		408,814		408,413
Other income and (expenses):	Other income and (expenses):											Other income and (expenses):
Net interest deductions	Net interest deductions	(23,964)		(28,380)			(107,061)		(111,209)			Net interest deductions	(31,298)		(28,311)		(81,201)		(83,141)		(109,537)		(111,705)
Other income (deductions)	Other income (deductions)	448		(20,770)			14,429		(17,524)			Other income (deductions)	(3,112)		1,799		(3,975)		(11,046)		282		(7,788)
Total other income and (expenses)	Total other income and (expenses)	(23,516)		(49,150)			(92,632)		(128,733)			Total other income and (expenses)	(34,410)		(26,512)		(85,176)		(94,187)		(109,255)		(119,493)
Income before income taxes		149,937		99,223			355,452		250,971
Income tax expense		31,092		26,218			70,627		56,703
Net income		118,845		73,005			284,825		194,268
Income (loss) before income taxes												Income (loss) before income taxes	(11,110)		27,752		170,843		176,022		299,559		288,920
Income tax expense (benefit)												Income tax expense (benefit)	(1,816)		6,689		34,818		42,073		58,498		63,065
Net income (loss)												Net income (loss)	(9,294)		21,063		136,025		133,949		241,061		225,855
Net income attributable to noncontrolling interest	Net income attributable to noncontrolling interest	1,552		463			7,750		2,599			Net income attributable to noncontrolling interest	2,282		2,790		5,189		5,169		6,681		5,357
Net income attributable to Southwest Gas Holdings, Inc.		$	117,293	$	72,542		$	277,075	$	191,669
Earnings per share:
Net income (loss) attributable to Southwest Gas Holdings, Inc.												Net income (loss) attributable to Southwest Gas Holdings, Inc.	$	(11,576)	$	18,273	$	130,836	$	128,780	$	234,380	$	220,498
Earnings (loss) per share:												Earnings (loss) per share:
Basic	Basic	$	2.04	$	1.31		$	4.90	$	3.50		Basic	$	(0.19)	$	0.32	$	2.23	$	2.31	$	4.03	$	3.97
Diluted	Diluted	$	2.03	$	1.31		$	4.89	$	3.50		Diluted	$	(0.19)	$	0.32	$	2.23	$	2.31	$	4.02	$	3.97
Weighted average shares:	Weighted average shares:											Weighted average shares:
Basic	Basic	57,600		55,310			56,564		54,726			Basic	59,688		56,271		58,639		55,683		58,209		55,508
Diluted	Diluted	57,679		55,363			56,649		54,792			Diluted	59,816		56,357		58,742		55,753		58,312		55,577

The accompanying notes are an integral part of these statements.


			4


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Thousands of dollars)

(Unaudited)


		Three Months Ended March 31,				Twelve Months Ended March 31,					Three Months Ended September 30,				Nine Months Ended September 30,				Twelve Months Ended September 30,
		2021		2020			2021		2020				2021		2020		2021		2020		2021		2020
Net income		$	118,845	$	73,005		$	284,825	$	194,268
Net income (loss)												Net income (loss)	$	(9,294)	$	21,063	$	136,025	$	133,949	$	241,061	$	225,855
Other comprehensive income (loss), net of tax	Other comprehensive income (loss), net of tax											Other comprehensive income (loss), net of tax
Defined benefit pension plans:	Defined benefit pension plans:											Defined benefit pension plans:
Net actuarial loss	Net actuarial loss	0		0			(43,730)		(54,026)			Net actuarial loss	—		—		—		—		(43,730)		(54,026)
Amortization of prior service cost	Amortization of prior service cost	182		220			840		945			Amortization of prior service cost	183		220		547		659		766		901
Amortization of net actuarial loss	Amortization of net actuarial loss	8,474		7,188			30,037		20,513			Amortization of net actuarial loss	8,474		7,187		25,420		21,563		32,608		26,004
Prior service cost	Prior service cost	0		0			0		(1,426)			Prior service cost	—		—		—		—		—		(1,426)
Regulatory adjustment	Regulatory adjustment	(7,277)		(6,380)			4,753		25,760			Regulatory adjustment	(7,277)		(6,380)		(21,831)		(19,140)		2,959		21,130
Net defined benefit pension plans	Net defined benefit pension plans	1,379		1,028			(8,100)		(8,234)			Net defined benefit pension plans	1,380		1,027		4,136		3,082		(7,397)		(7,417)
Forward-starting interest rate swaps (“FSIRS”):	Forward-starting interest rate swaps (“FSIRS”):											Forward-starting interest rate swaps (“FSIRS”):
Amounts reclassified into net income		413		636			2,244		2,542
Amounts reclassified into net income (loss)												Amounts reclassified into net income (loss)	413		783		1,240		2,054		1,653		2,689
Net forward-starting interest rate swaps	Net forward-starting interest rate swaps	413		636			2,244		2,542			Net forward-starting interest rate swaps	413		783		1,240		2,054		1,653		2,689
Foreign currency translation adjustments	Foreign currency translation adjustments	823		(4,005)			6,541		(2,758)			Foreign currency translation adjustments	(2,056)		1,024		(324)		(1,187)		2,576		(280)
Total other comprehensive income (loss), net of tax	Total other comprehensive income (loss), net of tax	2,615		(2,341)			685		(8,450)			Total other comprehensive income (loss), net of tax	(263)		2,834		5,052		3,949		(3,168)		(5,008)
Comprehensive income		121,460		70,664			285,510		185,818
Comprehensive income (loss)												Comprehensive income (loss)	(9,557)		23,897		141,077		137,898		237,893		220,847
Comprehensive income attributable to noncontrolling interest	Comprehensive income attributable to noncontrolling interest	1,552		463			7,750		2,599			Comprehensive income attributable to noncontrolling interest	2,282		2,790		5,189		5,169		6,681		5,357
Comprehensive income attributable to Southwest Gas Holdings, Inc.		$	119,908	$	70,201		$	277,760	$	183,219
Comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.												Comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.	$	(11,839)	$	21,107	$	135,888	$	132,729	$	231,212	$	215,490

The accompanying notes are an integral part of these statements.


			5


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of dollars)

(Unaudited)


		Three Months Ended March 31,				Twelve Months Ended March 31,					Nine Months Ended September 30,				Twelve Months Ended September 30,
		2021		2020		2021		2020			2021		2020		2021		2020
CASH FLOW FROM OPERATING ACTIVITIES:	CASH FLOW FROM OPERATING ACTIVITIES:									CASH FLOW FROM OPERATING ACTIVITIES:
Net income	Net income	$	118,845	$	73,005	$	284,825	$	194,268	Net income	$	136,025	$	133,949	$	241,061	$	225,855
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Adjustments to reconcile net income to net cash provided by operating activities:										Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	93,442		87,653		337,816		313,351		Depreciation and amortization	267,670		245,009		354,688		324,995
Deferred income taxes	Deferred income taxes	23,326		25,309		48,734		54,548		Deferred income taxes	45,374		37,752		58,339		45,815
Changes in current assets and liabilities:	Changes in current assets and liabilities:									Changes in current assets and liabilities:
Accounts receivable, net of allowances	Accounts receivable, net of allowances	42,892		45,837		(51,717)		7,154		Accounts receivable, net of allowances	(62,081)		(42,139)		(68,714)		(76,769)
Accrued utility revenue	Accrued utility revenue	31,900		31,000		(2,400)		(1,100)		Accrued utility revenue	42,700		42,600		(3,200)		(700)
Deferred purchased gas costs	Deferred purchased gas costs	(291,469)		10,155		(265,385)		19,527		Deferred purchased gas costs	(293,410)		59,899		(317,070)		38,016
Accounts payable	Accounts payable	(41,147)		(60,723)		11,882		(49,945)		Accounts payable	(51,086)		(59,031)		251		(14,817)
Accrued taxes	Accrued taxes	34,636		30,377		19,430		10,220		Accrued taxes	5,954		17,991		3,134		26,075
Other current assets and liabilities	Other current assets and liabilities	(5,255)		76,453		25,719		102,742		Other current assets and liabilities	23,289		121,185		9,531		121,274
Gains on sale of equipment	Gains on sale of equipment	(1,509)		(28)		(3,329)		(5,268)		Gains on sale of equipment	(5,365)		(581)		(6,632)		(2,897)
Changes in undistributed stock compensation	Changes in undistributed stock compensation	3,658		2,816		7,956		6,524		Changes in undistributed stock compensation	7,676		5,789		9,001		6,618
Equity AFUDC	Equity AFUDC	(981)		(1,061)		(4,644)		(4,262)		Equity AFUDC	—		(3,413)		(1,311)		(4,395)

Changes in deferred charges and other assets	Changes in deferred charges and other assets	(10,379)		6,495		(49,465)		1,772		Changes in deferred charges and other assets	(7,956)		(19,174)		(21,373)		(24,370)
Changes in other liabilities and deferred credits	Changes in other liabilities and deferred credits	(50,416)		(55,722)		(57,365)		(65,704)		Changes in other liabilities and deferred credits	(57,269)		(52,018)		(67,922)		(54,996)
Net cash provided by (used in) operating activities		(52,457)		271,566		302,057		583,827
Net cash provided by operating activities										Net cash provided by operating activities	51,521		487,818		189,783		609,704
CASH FLOW FROM INVESTING ACTIVITIES:	CASH FLOW FROM INVESTING ACTIVITIES:									CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions	Construction expenditures and property additions	(152,709)		(210,655)		(767,159)		(938,141)		Construction expenditures and property additions	(506,737)		(632,474)		(699,368)		(851,236)
Acquisition of businesses, net of cash acquired	Acquisition of businesses, net of cash acquired	0		0		0		(47,638)		Acquisition of businesses, net of cash acquired	(830,395)		(250)		(830,145)		(28,355)
Changes in customer advances	Changes in customer advances	4,286		5,434		12,885		21,357		Changes in customer advances	7,940		7,691		14,282		11,643
Other	Other	3,563		4,430		8,136		19,321		Other	14,755		6,520		17,238		8,811
Net cash used in investing activities	Net cash used in investing activities	(144,860)		(200,791)		(746,138)		(945,101)		Net cash used in investing activities	(1,314,437)		(618,513)		(1,497,993)		(859,137)
CASH FLOW FROM FINANCING ACTIVITIES:	CASH FLOW FROM FINANCING ACTIVITIES:									CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net	Issuance of common stock, net	48,990		3,148		185,087		135,215		Issuance of common stock, net	210,812		90,635		259,422		119,240
Dividends paid	Dividends paid	(32,619)		(30,006)		(128,117)		(118,531)		Dividends paid	(102,292)		(93,317)		(134,479)		(123,099)
Issuance of long-term debt, net	Issuance of long-term debt, net	10,659		99,978		573,058		601,908		Issuance of long-term debt, net	1,654,960		650,619		1,666,718		699,601
Retirement of long-term debt	Retirement of long-term debt	(21,228)		(75,168)		(302,466)		(257,797)		Retirement of long-term debt	(406,815)		(289,295)		(473,926)		(375,909)

Change in credit facility and commercial paper										Change in credit facility and commercial paper	(150,000)		(92,000)		(58,000)		(92,000)
Change in short-term debt	Change in short-term debt	203,000		(54,000)		153,000		(31,000)		Change in short-term debt	165,000		(157,000)		218,000		24,000
Withholding remittance - share-based compensation	Withholding remittance - share-based compensation	(1,242)		(2,736)		(1,242)		(2,756)		Withholding remittance - share-based compensation	(1,254)		(2,736)		(1,254)		(2,736)
Other	Other	(1,353)		(250)		(4,505)		(1,615)		Other	(4,355)		(1,596)		(6,161)		(4,090)
Net cash provided by (used in) financing activities		206,207		(59,034)		474,815		325,424
Net cash provided by financing activities										Net cash provided by financing activities	1,366,056		105,310		1,470,320		245,007
Effects of currency translation on cash and cash equivalents	Effects of currency translation on cash and cash equivalents	103		(315)		646		(222)		Effects of currency translation on cash and cash equivalents	198		(209)		635		(109)
Change in cash and cash equivalents	Change in cash and cash equivalents	8,993		11,426		31,380		(36,072)		Change in cash and cash equivalents	103,338		(25,594)		162,745		(4,535)
Cash and cash equivalents at beginning of period	Cash and cash equivalents at beginning of period	83,352		49,539		60,965		97,037		Cash and cash equivalents at beginning of period	83,352		49,539		23,945		28,480
Cash and cash equivalents at end of period	Cash and cash equivalents at end of period	$	92,345	$	60,965	$	92,345	$	60,965	Cash and cash equivalents at end of period	$	186,690	$	23,945	$	186,690	$	23,945
SUPPLEMENTAL INFORMATION:	SUPPLEMENTAL INFORMATION:									SUPPLEMENTAL INFORMATION:
Interest paid, net of amounts capitalized	Interest paid, net of amounts capitalized	$	8,303	$	13,073	$	100,412	$	99,481	Interest paid, net of amounts capitalized	$	57,128	$	63,743	$	98,567	$	103,836
Income taxes paid (received), net	Income taxes paid (received), net	$	1,651	$	(20,064)	$	10,764	$	(17,766)	Income taxes paid (received), net	$	7,665	$	(16,006)	$	12,720	$	(13,625)

The accompanying notes are an integral part of these statements.


			6


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

(In thousands, except per share amounts)

(Unaudited)


				Three Months Ended March 31,					Three Months Ended September 30,				Nine Months Ended September 30,
				2021		2020					2021		2020		2021		2020
Common stock shares	Common stock shares							Common stock shares
		Beginning balances		57,193		55,007			Beginning balances		59,088		55,910		57,193		55,007
			Common stock issuances	802		119				Common stock issuances	1,291		549		3,186		1,452
		Ending balances		57,995		55,126			Ending balances		60,379		56,459		60,379		56,459
Common stock amount	Common stock amount							Common stock amount
		Beginning balances		$	58,823	$	56,637		Beginning balances		$	60,718	$	57,540	$	58,823	$	56,637
			Common stock issuances	802		119				Common stock issuances	1,291		549		3,186		1,452
		Ending balances		59,625		56,756			Ending balances		62,009		58,089		62,009		58,089
Additional paid-in capital	Additional paid-in capital							Additional paid-in capital
		Beginning balances		1,609,155		1,466,937			Beginning balances		1,733,572		1,523,630		1,609,155		1,466,937
			Common stock issuances	50,953		3,474				Common stock issuances	90,317		36,184		214,734		92,877
		Ending balances		1,660,108		1,470,411			Ending balances		1,823,889		1,559,814		1,823,889		1,559,814
Accumulated other comprehensive loss	Accumulated other comprehensive loss							Accumulated other comprehensive loss
		Beginning balances		(61,003)		(56,732)			Beginning balances		(55,688)		(55,617)		(61,003)		(56,732)
			Foreign currency exchange translation adjustment	823		(4,005)				Foreign currency exchange translation adjustment	(2,056)		1,024		(324)		(1,187)
			Net actuarial gain arising during period, less amortization of unamortized benefit plan cost, net of tax	1,379		1,028				Net actuarial gain arising during period, less amortization of unamortized benefit plan cost, net of tax	1,380		1,027		4,136		3,082
			FSIRS amounts reclassified to net income, net of tax	413		636				FSIRS amounts reclassified to net income, net of tax	413		783		1,240		2,054
									Ending balances		(55,951)		(52,783)		(55,951)		(52,783)
		Ending balances		(58,388)		(59,073)
Retained earnings	Retained earnings							Retained earnings
		Beginning balances		1,067,978		1,039,072			Beginning balances		1,108,279		1,085,742		1,067,978		1,039,072
			Net income	117,293		72,542				Net income (loss)	(11,576)		18,273		130,836		128,780
			Dividends declared	(34,876)		(31,813)				Dividends declared	(36,098)		(32,324)		(106,303)		(96,161)
			Redemption value adjustments	(38,018)		0				Redemption value adjustments	19,264		(17,573)		(12,642)		(17,573)
		Ending balances		1,112,377		1,079,801			Ending balances		1,079,869		1,054,118		1,079,869		1,054,118
Total equity ending balances	Total equity ending balances			$	2,773,722	$	2,547,895	Total equity ending balances			$	2,909,816	$	2,619,238	$	2,909,816	$	2,619,238
Dividends declared per common share	Dividends declared per common share			$	0.595	$	0.57	Dividends declared per common share			$	0.595	$	0.57	$	1.785	$	1.71

The accompanying notes are an integral part of these statements.


			7


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Thousands of dollars)

(Unaudited)


		March 31, 2021		December 31, 2020			September 30, 2021		December 31, 2020
ASSETS	ASSETS					ASSETS
Utility plant:	Utility plant:					Utility plant:
Gas plant	Gas plant	$	8,479,295	$	8,384,000	Gas plant	$	8,742,806	$	8,384,000
Less: accumulated depreciation	Less: accumulated depreciation	(2,453,924)		(2,419,348)		Less: accumulated depreciation	(2,499,488)		(2,419,348)
Construction work in progress	Construction work in progress	215,395		211,429		Construction work in progress	153,100		211,429
Net utility plant	Net utility plant	6,240,766		6,176,081		Net utility plant	6,396,418		6,176,081
Other property and investments	Other property and investments	146,338		143,611		Other property and investments	149,926		143,611
Current assets:	Current assets:					Current assets:
Cash and cash equivalents	Cash and cash equivalents	49,795		41,070		Cash and cash equivalents	122,758		41,070
Accounts receivable, net of allowance	Accounts receivable, net of allowance	174,492		146,861		Accounts receivable, net of allowance	103,430		146,861
Accrued utility revenue	Accrued utility revenue	50,500		82,400		Accrued utility revenue	39,700		82,400
Income taxes receivable, net	Income taxes receivable, net	0		11,155		Income taxes receivable, net	17,775		11,155
Deferred purchased gas costs	Deferred purchased gas costs	238,886		2,053		Deferred purchased gas costs	240,827		2,053
Prepaid and other current assets	Prepaid and other current assets	118,397		152,748		Prepaid and other current assets	170,470		152,748
Total current assets	Total current assets	632,070		436,287		Total current assets	694,960		436,287
Noncurrent assets:	Noncurrent assets:					Noncurrent assets:
Goodwill	Goodwill	10,095		10,095		Goodwill	10,095		10,095

Deferred charges and other assets	Deferred charges and other assets	481,184		490,562		Deferred charges and other assets	461,212		490,562
Total noncurrent assets	Total noncurrent assets	491,279		500,657		Total noncurrent assets	471,307		500,657
Total assets	Total assets	$	7,510,453	$	7,256,636	Total assets	$	7,712,611	$	7,256,636
CAPITALIZATION AND LIABILITIES	CAPITALIZATION AND LIABILITIES					CAPITALIZATION AND LIABILITIES
Capitalization:	Capitalization:					Capitalization:
Common stock	Common stock	$	49,112	$	49,112	Common stock	$	49,112	$	49,112
Additional paid-in capital	Additional paid-in capital	1,458,344		1,410,345		Additional paid-in capital	1,617,796		1,410,345
Accumulated other comprehensive loss, net	Accumulated other comprehensive loss, net	(59,343)		(61,135)		Accumulated other comprehensive loss, net	(55,759)		(61,135)
Retained earnings	Retained earnings	926,011		835,146		Retained earnings	851,645		835,146
Total equity	Total equity	2,374,124		2,233,468		Total equity	2,462,794		2,233,468
Long-term debt, less current maturities	Long-term debt, less current maturities	2,413,588		2,438,206		Long-term debt, less current maturities	2,309,857		2,438,206
Total capitalization	Total capitalization	4,787,712		4,671,674		Total capitalization	4,772,651		4,671,674
Current liabilities:	Current liabilities:					Current liabilities:
Current maturities of long-term debt	Current maturities of long-term debt	25,000		0		Current maturities of long-term debt	275,000		—
Short-term debt	Short-term debt	267,000		57,000		Short-term debt	250,000		57,000
Accounts payable	Accounts payable	117,471		161,646		Accounts payable	113,810		161,646
Customer deposits	Customer deposits	67,121		67,920		Customer deposits	51,816		67,920
Income taxes payable		7,232		0

Accrued general taxes	Accrued general taxes	72,103		48,640		Accrued general taxes	60,656		48,640
Accrued interest	Accrued interest	34,532		20,495		Accrued interest	34,938		20,495
Deferred purchased gas costs	Deferred purchased gas costs	0		54,636		Deferred purchased gas costs	—		54,636
Payable to parent	Payable to parent	90		142		Payable to parent	207		142
Other current liabilities	Other current liabilities	141,167		146,046		Other current liabilities	155,490		146,046
Total current liabilities	Total current liabilities	731,716		556,525		Total current liabilities	941,917		556,525
Deferred income taxes and other credits:	Deferred income taxes and other credits:					Deferred income taxes and other credits:
Deferred income taxes and investment tax credits, net	Deferred income taxes and investment tax credits, net	596,617		581,100		Deferred income taxes and investment tax credits, net	618,597		581,100
Accumulated removal costs	Accumulated removal costs	407,000		404,000		Accumulated removal costs	419,000		404,000
Other deferred credits and other long-term liabilities	Other deferred credits and other long-term liabilities	987,408		1,043,337		Other deferred credits and other long-term liabilities	960,446		1,043,337
Total deferred income taxes and other credits	Total deferred income taxes and other credits	1,991,025		2,028,437		Total deferred income taxes and other credits	1,998,043		2,028,437
Total capitalization and liabilities	Total capitalization and liabilities	$	7,510,453	$	7,256,636	Total capitalization and liabilities	$	7,712,611	$	7,256,636

The accompanying notes are an integral part of these statements.


			8


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Thousands of dollars)

(Unaudited)


		Three Months Ended March 31,				Twelve Months Ended March 31,					Three Months Ended September 30,				Nine Months Ended September 30,				Twelve Months Ended September 30,
		2021		2020			2021		2020				2021		2020		2021		2020		2021		2020
Gas operating revenues	Gas operating revenues	$	521,932	$	502,827		$	1,369,690	$	1,351,089		Gas operating revenues	$	255,848	$	210,834	$	1,070,576	$	976,095	$	1,445,066	$	1,355,666
Operating expenses:	Operating expenses:											Operating expenses:
Net cost of gas sold	Net cost of gas sold	156,021		160,821			338,037		353,381			Net cost of gas sold	63,710		36,321		296,227		264,615		374,449		356,925
Operations and maintenance	Operations and maintenance	106,135		103,088			409,429		419,720			Operations and maintenance	119,708		101,159		328,980		303,567		431,795		406,169
Depreciation and amortization	Depreciation and amortization	68,698		64,725			239,268		222,733			Depreciation and amortization	61,359		55,942		187,688		173,865		249,118		230,158
Taxes other than income taxes	Taxes other than income taxes	20,687		16,378			67,769		62,500			Taxes other than income taxes	20,109		15,787		60,134		47,507		76,087		63,195
Total operating expenses	Total operating expenses	351,541		345,012			1,054,503		1,058,334			Total operating expenses	264,886		209,209		873,029		789,554		1,131,449		1,056,447
Operating income		170,391		157,815			315,187		292,755
Operating income (loss)												Operating income (loss)	(9,038)		1,625		197,547		186,541		313,617		299,219
Other income and (expenses):	Other income and (expenses):											Other income and (expenses):
Net interest deductions	Net interest deductions	(22,166)		(25,058)			(98,256)		(96,985)			Net interest deductions	(24,922)		(26,103)		(71,263)		(75,152)		(97,259)		(100,115)
Other income (deductions)	Other income (deductions)	550		(20,536)			14,496		(16,965)			Other income (deductions)	(4,287)		1,751		(4,902)		(10,947)		(545)		(7,615)
Total other income and (expenses)	Total other income and (expenses)	(21,616)		(45,594)			(83,760)		(113,950)			Total other income and (expenses)	(29,209)		(24,352)		(76,165)		(86,099)		(97,804)		(107,730)
Income before income taxes		148,775		112,221			231,427		178,805
Income tax expense		30,060		28,622			37,193		35,424
Net income		$	118,715	$	83,599		$	194,234	$	143,381
Income (loss) before income taxes												Income (loss) before income taxes	(38,247)		(22,727)		121,382		100,442		215,813		191,489
Income tax expense (benefit)												Income tax expense (benefit)	(10,703)		(6,754)		18,798		20,874		33,679		35,496
Net income (loss)												Net income (loss)	$	(27,544)	$	(15,973)	$	102,584	$	79,568	$	182,134	$	155,993

The accompanying notes are an integral part of these statements.


			9


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Thousands of dollars)

(Unaudited)


		Three Months Ended March 31,				Twelve Months Ended March 31,					Three Months Ended September 30,				Nine Months Ended September 30,				Twelve Months Ended September 30,
		2021		2020			2021		2020				2021		2020		2021		2020		2021		2020
Net income		$	118,715	$	83,599		$	194,234	$	143,381
Net income (loss)												Net income (loss)	$	(27,544)	$	(15,973)	$	102,584	$	79,568	$	182,134	$	155,993
Other comprehensive income (loss), net of tax	Other comprehensive income (loss), net of tax											Other comprehensive income (loss), net of tax
Defined benefit pension plans:	Defined benefit pension plans:											Defined benefit pension plans:
Net actuarial loss	Net actuarial loss	0		0			(43,730)		(54,026)			Net actuarial loss	—		—		—		—		(43,730)		(54,026)
Amortization of prior service cost	Amortization of prior service cost	182		220			840		945			Amortization of prior service cost	183		220		547		659		766		901
Prior service cost	Prior service cost	0		0			0		(1,426)			Prior service cost	—		—		—		—		—		(1,426)
Amortization of net actuarial loss	Amortization of net actuarial loss	8,474		7,188			30,037		20,513			Amortization of net actuarial loss	8,474		7,187		25,420		21,563		32,608		26,004
Regulatory adjustment	Regulatory adjustment	(7,277)		(6,380)			4,753		25,760			Regulatory adjustment	(7,277)		(6,380)		(21,831)		(19,140)		2,959		21,130
Net defined benefit pension plans	Net defined benefit pension plans	1,379		1,028			(8,100)		(8,234)			Net defined benefit pension plans	1,380		1,027		4,136		3,082		(7,397)		(7,417)
Forward-starting interest rate swaps (“FSIRS”):	Forward-starting interest rate swaps (“FSIRS”):											Forward-starting interest rate swaps (“FSIRS”):
Amounts reclassified into net income		413		636			2,244		2,542
Amounts reclassified into net income (loss)												Amounts reclassified into net income (loss)	413		783		1,240		2,054		1,653		2,689
Net forward-starting interest rate swaps	Net forward-starting interest rate swaps	413		636			2,244		2,542			Net forward-starting interest rate swaps	413		783		1,240		2,054		1,653		2,689
Total other comprehensive income (loss), net of tax	Total other comprehensive income (loss), net of tax	1,792		1,664			(5,856)		(5,692)			Total other comprehensive income (loss), net of tax	1,793		1,810		5,376		5,136		(5,744)		(4,728)
Comprehensive income		$	120,507	$	85,263		$	188,378	$	137,689
Comprehensive income (loss)												Comprehensive income (loss)	$	(25,751)	$	(14,163)	$	107,960	$	84,704	$	176,390	$	151,265

The accompanying notes are an integral part of these statements.


			10


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of dollars)

(Unaudited)


		Three Months Ended March 31,				Twelve Months Ended March 31,					Nine Months Ended September 30,				Twelve Months Ended September 30,
		2021		2020		2021		2020			2021		2020		2021		2020
CASH FLOW FROM OPERATING ACTIVITIES:	CASH FLOW FROM OPERATING ACTIVITIES:									CASH FLOW FROM OPERATING ACTIVITIES:
Net income	Net income	$	118,715	$	83,599	$	194,234	$	143,381	Net income	$	102,584	$	79,568	$	182,134	$	155,993
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Adjustments to reconcile net income to net cash provided by operating activities:										Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	Depreciation and amortization	68,698		64,725		239,268		222,733		Depreciation and amortization	187,688		173,865		249,118		230,158
Deferred income taxes	Deferred income taxes	14,952		7,707		52,242		15,118		Deferred income taxes	35,800		25,633		55,164		23,415
Changes in current assets and liabilities:	Changes in current assets and liabilities:									Changes in current assets and liabilities:
Accounts receivable, net of allowance	Accounts receivable, net of allowance	(27,631)		1,975		(25,673)		21,652		Accounts receivable, net of allowance	43,430		70,129		(22,766)		(7,135)
Accrued utility revenue	Accrued utility revenue	31,900		31,000		(2,400)		(1,100)		Accrued utility revenue	42,700		42,600		(3,200)		(700)
Deferred purchased gas costs	Deferred purchased gas costs	(291,469)		10,155		(265,385)		19,527		Deferred purchased gas costs	(293,410)		59,899		(317,070)		38,016
Accounts payable	Accounts payable	(33,076)		(41,899)		18,441		(29,798)		Accounts payable	(42,536)		(50,314)		17,396		(476)
Accrued taxes	Accrued taxes	41,851		53,335		(13,011)		33,526		Accrued taxes	5,396		15,914		(12,045)		29,228
Other current assets and liabilities	Other current assets and liabilities	41,018		99,257		(9,694)		106,803		Other current assets and liabilities	18,608		74,892		(7,739)		76,194
Changes in undistributed stock compensation	Changes in undistributed stock compensation	2,908		2,496		5,706		5,045		Changes in undistributed stock compensation	5,437		4,492		6,239		4,928
Equity AFUDC	Equity AFUDC	(981)		(1,061)		(4,644)		(4,262)		Equity AFUDC	—		(3,413)		(1,311)		(4,395)

Changes in deferred charges and other assets	Changes in deferred charges and other assets	(13,535)		3,658		(61,484)		(9,871)		Changes in deferred charges and other assets	(18,726)		(27,688)		(35,329)		(38,357)
Changes in other liabilities and deferred credits	Changes in other liabilities and deferred credits	(48,782)		(55,910)		(58,008)		(66,294)		Changes in other liabilities and deferred credits	(55,905)		(52,532)		(68,509)		(55,536)
Net cash provided by (used in) operating activities		(95,432)		259,037		69,592		456,460
Net cash provided by operating activities										Net cash provided by operating activities	31,066		413,045		42,082		451,333
CASH FLOW FROM INVESTING ACTIVITIES:	CASH FLOW FROM INVESTING ACTIVITIES:									CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions	Construction expenditures and property additions	(128,544)		(173,353)		(647,407)		(788,465)		Construction expenditures and property additions	(415,398)		(525,221)		(582,393)		(716,564)
Changes in customer advances	Changes in customer advances	4,285		5,433		12,885		21,356		Changes in customer advances	7,940		7,691		14,282		11,643
Other	Other	(121)		(31)		681		(48)		Other	65		183		653		139

Net cash used in investing activities	Net cash used in investing activities	(124,380)		(167,951)		(633,841)		(767,157)		Net cash used in investing activities	(407,393)		(517,347)		(567,458)		(704,782)
CASH FLOW FROM FINANCING ACTIVITIES:	CASH FLOW FROM FINANCING ACTIVITIES:									CASH FLOW FROM FINANCING ACTIVITIES:

Contributions from parent	Contributions from parent	45,984		50,000		173,906		187,094		Contributions from parent	202,583		131,961		248,544		165,711
Dividends paid	Dividends paid	(26,000)		(25,200)		(105,300)		(97,600)		Dividends paid	(82,000)		(77,500)		(109,000)		(102,400)
Issuance of long-term debt, net	Issuance of long-term debt, net	0		0		446,508		297,222		Issuance of long-term debt, net	297,318		446,508		297,318		446,508
Retirement of long-term debt	Retirement of long-term debt	0		0		(125,000)		0		Retirement of long-term debt	—		(125,000)		—		(125,000)

Change in credit facility and commercial paper										Change in credit facility and commercial paper	(150,000)		(92,000)		(58,000)		(92,000)
Change in short-term debt	Change in short-term debt	210,000		(97,000)		170,000		(91,000)		Change in short-term debt	193,000		(194,000)		250,000		(30,000)
Withholding remittance - share-based compensation	Withholding remittance - share-based compensation	(1,242)		(2,736)		(1,242)		(2,756)		Withholding remittance - share-based compensation	(1,254)		(2,736)		(1,254)		(2,737)
Other	Other	(205)		(115)		(1,352)		(887)		Other	(1,632)		(1,186)		(1,708)		(1,210)
Net cash provided by (used in) financing activities		228,537		(75,051)		557,520		292,073
Net cash provided by financing activities										Net cash provided by financing activities	458,015		86,047		625,900		258,872

Change in cash and cash equivalents	Change in cash and cash equivalents	8,725		16,035		(6,729)		(18,624)		Change in cash and cash equivalents	81,688		(18,255)		100,524		5,423
Cash and cash equivalents at beginning of period	Cash and cash equivalents at beginning of period	41,070		40,489		56,524		75,148		Cash and cash equivalents at beginning of period	41,070		40,489		22,234		16,811
Cash and cash equivalents at end of period	Cash and cash equivalents at end of period	$	49,795	$	56,524	$	49,795	$	56,524	Cash and cash equivalents at end of period	$	122,758	$	22,234	$	122,758	$	22,234
SUPPLEMENTAL INFORMATION:	SUPPLEMENTAL INFORMATION:									SUPPLEMENTAL INFORMATION:
Interest paid, net of amounts capitalized	Interest paid, net of amounts capitalized	$	6,952	$	10,204	$	93,474	$	87,277	Interest paid, net of amounts capitalized	$	53,220	$	57,168	$	92,778	$	94,106
Income taxes paid (received), net	Income taxes paid (received), net	$	0	$	(22,962)	$	3,359	$	700	Income taxes paid (received), net	$	—	$	(22,962)	$	3,359	$	(22,262)

The accompanying notes are an integral part of these statements.


			11


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

(In thousands)

(Unaudited)


				Three Months Ended March 31,						Three Months Ended September 30,			Nine Months Ended September 30,
				2021		2020					2021		2020		2021		2020
Common stock shares	Common stock shares							Common stock shares
		Beginning and ending balances		47,482		47,482			Beginning and ending balances		47,482		47,482		47,482		47,482
Common stock amount	Common stock amount							Common stock amount
		Beginning and ending balances		$	49,112	$	49,112		Beginning and ending balances		$	49,112	$	49,112	$	49,112	$	49,112
Additional paid-in capital	Additional paid-in capital							Additional paid-in capital
		Beginning balances		1,410,345		1,229,083			Beginning balances		1,529,419		1,329,843		1,410,345		1,229,083
			Share-based compensation	2,015		125				Share-based compensation	1,435		1,137		4,868		2,397
			Contributions from Southwest Gas Holdings, Inc.	45,984		50,000				Contributions from Southwest Gas Holdings, Inc.	86,942		32,461		202,583		131,961
		Ending balances		1,458,344		1,279,208			Ending balances		1,617,796		1,363,441		1,617,796		1,363,441
Accumulated other comprehensive loss	Accumulated other comprehensive loss							Accumulated other comprehensive loss
		Beginning balances		(61,135)		(55,151)			Beginning balances		(57,552)		(51,825)		(61,135)		(55,151)
			Net actuarial gain arising during period, less amortization of unamortized benefit plan cost, net of tax	1,379		1,028				Net actuarial gain arising during period, less amortization of unamortized benefit plan cost, net of tax	1,380		1,027		4,136		3,082
			FSIRS amounts reclassified to net income, net of tax	413		636				FSIRS amounts reclassified to net income, net of tax	413		783		1,240		2,054
		Ending balances		(59,343)		(53,487)			Ending balances		(55,759)		(50,015)		(55,759)		(50,015)
Retained earnings	Retained earnings							Retained earnings
		Beginning balances		835,146		782,108			Beginning balances		908,757		824,847		835,146		782,108
			Net income	118,715		83,599				Net income (loss)	(27,544)		(15,973)		102,584		79,568
			Share-based compensation	(350)		(364)				Share-based compensation	(168)		(139)		(685)		(641)
			Dividends declared to Southwest Gas Holdings, Inc.	(27,500)		(25,900)				Dividends declared to Southwest Gas Holdings, Inc.	(29,400)		(27,000)		(85,400)		(79,300)
		Ending balances		926,011		839,443			Ending balances		851,645		781,735		851,645		781,735
Total Southwest Gas Corporation equity ending balances	Total Southwest Gas Corporation equity ending balances			$	2,374,124	$	2,114,276	Total Southwest Gas Corporation equity ending balances			$	2,462,794	$	2,144,273	$	2,462,794	$	2,144,273

The accompanying notes are an integral part of these statements.


			12


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

Note 1 – Background, Organization, and Summary of Significant Accounting Policies

Nature of Operations. Southwest Gas Holdings, Inc. is a holding company, owning 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).

In October 2021, Southwest Gas Holdings, Inc. (the “Company”) entered into an agreement with Dominion Energy Questar Corporation, a wholly owned subsidiary of Dominion Energy, Inc., to acquire all equity interests in Dominion Energy Questar Pipeline, LLC and related entities (“Questar Pipelines”). Upon closing, Questar Pipelines will operate as part of a standalone subsidiary of the Company, and will undergo new branding at or subsequent to close. The agreement provides for consideration of $1.545 billion in cash (subject to certain adjustments) and assumption of approximately $430 million of existing long-term debt. The agreement contains certain termination rights, including a mutual termination right exercisable at any time and a unilateral termination right exercisable by either party if certain conditions have not been met by December 31, 2021 (the initial termination date), subject to an extension unilaterally exercisable by either party if certain conditions have not been met, subsequently extending the initial termination date through June 30, 2022. The completion of this transaction is subject to closing conditions, including the expiration or termination of any waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, and approval of certain aspects of the transaction by the Federal Communications Commission. The operations to be acquired would further diversify the Company’s business with an expansion of regulated interstate natural gas pipelines and underground storage services as part of the jurisdiction of the Federal Energy Regulatory Commission (the “FERC”), thereby expanding transportation services into Utah, Wyoming, and Colorado. The Company plans to initially fund this acquisition with a new 364-day term loan, followed by permanent financing. See Note 5 – Debt for more information.

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”), and Riggs Distler & Company, Inc. (“Riggs Distler”). Utility infrastructure services activity is seasonal in most 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. Centuri completed the acquisition of Drum Parent, Inc. (“Drum”), including Drum’s most significant operating subsidiary, Riggs Distler, in August 2021, thereby expanding Centuri’s electric services footprint in the Northeast and Mid-Atlantic regions of the U.S. See Note 8 - Business Acquisitions for more information.

Basis of Presentation. The condensed consolidated financial statements of Southwest Gas Holdings, Inc. and subsidiaries ~~(the “Company”)~~ and Southwest included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). The year-end condensed balance sheet data was derived from audited financial statements. Certain information and footnote disclosures normally included in financial statements prepared in accordance with U.S. generally accepted accounting principles (“U.S. GAAP”) have been condensed or omitted pursuant to such rules and regulations. No substantive change has occurred with regard to the Company’s business segments on the whole.

The preparation of the condensed consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities atas of 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. In the opinion of management, all adjustments, consisting of normal recurring items and estimates necessary for a fair depiction of results for the interim periods, have been made. In association with the novel Coronavirus (“COVID-19”) pandemic environment, utility operations, and to a large extent, utility infrastructure services, ~~have been~~were deemed “essential services.” Management has considered the impact of the pandemic and adjusted certain estimates, where relevant, ~~used~~ in the preparation of the condensed consolidated financial statements.

These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in the 2020 Annual Report to Stockholders, which is incorporated by reference into the 2020 Form 10-K.


			13


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

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.

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.


			13


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

The Company primarily used quoted market prices and other observable market pricing information in valuing cash and cash equivalents, long-term debt outstanding, and assets of the qualified pension plan and postretirement benefit plans required to be recorded and/or disclosed at fair value.

Other Property and Investments. Other property and investments on the Condensed Consolidated Balance Sheets includes:


(Thousands of dollars)	(Thousands of dollars)	March 31, 2021		December 31, 2020		(Thousands of dollars)	September 30, 2021		December 31, 2020
Southwest Gas Corporation:	Southwest Gas Corporation:					Southwest Gas Corporation:
Net cash surrender value of COLI policies	Net cash surrender value of COLI policies	$	143,618	$	140,874	Net cash surrender value of COLI policies	$	147,187	$	140,874
Other property	Other property	2,720		2,737		Other property	2,739		2,737
Total Southwest Gas Corporation	Total Southwest Gas Corporation	146,338		143,611		Total Southwest Gas Corporation	149,926		143,611
Centuri property, equipment, and intangibles	Centuri property, equipment, and intangibles	1,106,855		1,089,414		Centuri property, equipment, and intangibles	1,592,461		1,089,414
Centuri accumulated provision for depreciation and amortization	Centuri accumulated provision for depreciation and amortization	(439,126)		(422,741)		Centuri accumulated provision for depreciation and amortization	(468,206)		(422,741)
Other property and investments	Other property and investments	28,605		23,961		Other property and investments	31,153		23,961
Total Southwest Gas Holdings, Inc.	Total Southwest Gas Holdings, Inc.	$	842,672	$	834,245	Total Southwest Gas Holdings, Inc.	$	1,305,334	$	834,245

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. Balances reflect impacts of equity and fixed-income securities underlying the cash surrender values at each reporting date; however, ultimately, only the insurance proceeds are ever actually received, due to management’s intent to hold the policies to maturity.

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 of ~~Southwest and~~ the Company include $55 million of money market fund investments ~~totaling approximately $40,000 for each entity~~ at ~~March 31,~~September 30, 2021, and an insignificant amount at December 31, ~~2020, respectively, which~~2020. The money market fund investments for Southwest were insignificant at both balance sheet dates. These investments 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 include customer advances applied as contributions toward utility construction activity, and capital expenditures that were not yet paid as of period-end reporting dates, but rather were included in accounts payable. Typical activities that represent aspects of both non-cash investing and non-cash financing activities relate to right-of-use assets obtained in exchange for lease liabilities (including, at times, lease terminations and modifications). Amounts related to these collective activities were immaterial for the periods presented herein. See also Prepaid and other current assets below.

Intercompany Transactions. Centuri recognizes revenues generated from contracts with Southwest (see Note 7 – Segment Information). The accounts receivable balance, revenues, and associated profits are included in the condensed consolidated financial statements of the Company and Southwest and were not eliminated during consolidation in accordance with accounting treatment for rate-regulated entities.


			14


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

Accounts Receivable, net of allowances. Business activity with respect to natural gas utility operations is conducted with customers located within the 3-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. ~~Due to~~Southwest lifted the ~~ongoing COVID-19 pandemic, Southwest continued the~~ moratorium ~~initiated in March 2020~~ on disconnection of natural gas service for non-payment ~~but~~in Arizona and Nevada in September 2021, which was initiated (at the same time as a moratorium on late fees) in March 2020 in response to the COVID-19 pandemic. The moratorium on disconnection continues to be in place for California, and is expected to be lifted in the fourth quarter of 2021. Southwest recommenced assessing late fees on past-due balances in ~~Nevada~~Arizona and ~~Arizona~~Nevada in April 2021, ~~with~~and expects to recommence late fees in California ~~expected to recommence~~ in the ~~latter half~~fourth quarter of 2021. Southwest is actively working with customers experiencing financial hardship by means of flexible payment options. Management continues to monitor expected credit losses in light of the ~~evolving~~ impact of COVID-19. The allowance for uncollectible accounts receivable balances as of ~~March 31,~~September 30, 2021 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 on disconnections is lifted.~~those amounts that are due.

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 has not been significantly impacted, nor does it anticipate it will experience significant difficulty in collecting amounts due, as a result of the current environment surrounding COVID-19 given the nature of its customers.

Activity between periods in the allowance for ~~uncollectibles~~uncollectible accounts and the balances as of the periods presented within the Company’s and Southwest’s financial statements were not material to the condensed consolidated financial statements overall.


			14


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

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 supply issues due to wellhead freeze-offs, power outages, or other adverse operating conditions upstream of Southwest’s distribution systems. These conditions caused daily natural gas prices to reach unprecedented levels. During this time, Southwest secured natural gas supplies, albeit at substantially higher prices, maintaining service to its customers. The incremental cost for these supplies was approximately $250 million, funded using a 364-day $250 million ~~Bank Term Loan~~term loan executed in March 2021 (see Note 5 – Debt). The incremental gas costs are expected to continue to be collected from customers through the purchased gas adjustment (“PGA”) mechanisms.

Following the extreme weather event, an interstate transmission pipeline company billed Southwest, in addition to customary transmission costs, $65 million (later reduced to approximately $55 million) for pipeline imbalance charges, allegedly incurred during the period of the pipeline’s critical operation condition. However, Southwest ~~has~~ formally disputed the imbalance charges, in addition to interest on that amount, believing that no amounts were due to the pipeline. In June 2021, the interstate transmission pipeline company requested approval from the Federal Energy Regulatory Commission (the “FERC”) to waive these imbalance charges and ~~believes~~interest, affirming that they had the authority to elect the option to waive the underlying charges based on their tariff, but were seeking approval by the FERC for purposes of transparency and regulatory certainty. In August 2021, FERC approval was received. Consequently, no amounts ~~are due~~were recognized by Southwest related to the ~~pipeline. Consequently, Southwest has not recognized this charge. Pipeline transmission costs, including periodic imbalance charges, are components of~~original charge from the ~~cost of gas recovered from customers through the PGA and similar mechanisms.~~pipeline.

Prepaid and other current assets. Prepaid and other current assets includes gas pipe materials and operating supplies of ~~$47~~$55 million at ~~March 31,~~September 30, 2021 and $50 million at December 31, 2020 (carried at weighted average cost).

In the third quarter of 2021, the Company and Southwest classified certain assets associated with its previous corporate headquarters as held for sale. As a result, the Company and Southwest reclassified approximately $31 million from Net utility plant to Prepaid and other current assets on their respective Condensed Consolidated Balance Sheets during the third quarter of 2021; this was a non-cash item and therefore did not impact the Company’s or Southwest’s respective Condensed Consolidated Statements of Cash Flows.

Goodwill. Goodwill is assessed as of October 1st each year for impairment, or more frequently, if circumstances indicate an impairment to the carrying value of goodwill may have occurred. Management of the Company and Southwest considered its reporting units and segments and determined that ~~its segments and reporting units remain~~they remained consistent between periods presented below, and that no change was necessary with regard to the level at which goodwill is assessed for impairment. Since December 31, 2020, management also qualitatively assessed whether events during the first ~~three~~nine months of 2021 may have resulted in conditions whereby the carrying value of goodwill was higher than its fair value, which if the case, could be an indication of a permanent


			15


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

impairment. Through this assessment, no such condition was believed to have existed and therefore, 0no impairment was deemed to have occurred. The Riggs Distler acquisition in August 2021 (see further discussion in Note 8 - Business Acquisitions) was deemed a stock purchase for tax purposes, and as a result, only pre-acquisition goodwill that was historically tax-deductible by Riggs Distler will continue to be deductible for tax purposes by the Company. Goodwill on Southwest’s and the Company’s Condensed Consolidated Balance Sheets includes:

(Thousands of dollars) Natural Gas
Operations Utility Infrastructure
Services Total Company
December 31, 2020 $ 10,095 $ 335,089 $ 345,184
Foreign currency translation adjustment 0 1,369 1,369
March 31, 2021 $ 10,095 $ 336,458 $ 346,553


(Thousands of dollars)	Natural Gas Operations		Utility Infrastructure Services		Total Company
December 31, 2020	$	10,095	$	335,089	$	345,184
Additional goodwill from Riggs Distler acquisition	—		446,794		446,794
Foreign currency translation adjustment	—		(76)		(76)
September 30, 2021	$	10,095	$	781,807	$	791,902

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 amounts payable under regulatory mechanisms, customary accrued expenses for employee compensation and benefits, declared but unpaid dividends, and miscellaneous other accrued liabilities. Other current liabilities for the Company includes ~~$34.5~~$35.9 million and $32.6 million of dividends declared as ~~well as $37 million and $25.2 million~~ of ~~accrued property taxes, as of March 31,~~September 30, 2021 and December 31, 2020, ~~respectively.~~respectively, as well as liabilities included as part of the Riggs Distler acquisition.


			15


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

Other Income (Deductions). The following table provides the composition of significant items included in Other income (deductions) in the Condensed Consolidated Statements of Income:


		Three Months Ended March 31,				Twelve Months Ended March 31,			Three Months Ended September 30,						Nine Months Ended September 30,				Twelve Months Ended September 30,
(Thousands of dollars)	(Thousands of dollars)	2021		2020			2021			2020		(Thousands of dollars)	2021		2020		2021		2020		2021		2020
Southwest Gas Corporation - natural gas operations segment:	Southwest Gas Corporation - natural gas operations segment:											Southwest Gas Corporation - natural gas operations segment:
Change in COLI policies	Change in COLI policies	$	2,700	$	(15,500)		$	27,400		$	(5,700)	Change in COLI policies	$	—	$	4,500	$	5,800	$	1,000	$	14,000	$	7,200
Interest income	Interest income	716		1,388			3,343			6,147		Interest income	1,365		1,412		3,312		3,214		4,113		4,630
Equity AFUDC	Equity AFUDC	981		1,061			4,644			4,262		Equity AFUDC	—		1,232		—		3,413		1,311		4,395
Other components of net periodic benefit cost	Other components of net periodic benefit cost	(3,505)		(5,005)			(18,522)			(16,299)		Other components of net periodic benefit cost	(3,506)		(5,005)		(10,516)		(15,016)		(15,522)		(18,780)
Miscellaneous income and (expense)	Miscellaneous income and (expense)	(342)		(2,480)			(2,369)			(5,375)		Miscellaneous income and (expense)	(2,146)		(388)		(3,498)		(3,558)		(4,447)		(5,060)
Southwest Gas Corporation - total other income (deductions)	Southwest Gas Corporation - total other income (deductions)	550		(20,536)			14,496			(16,965)		Southwest Gas Corporation - total other income (deductions)	(4,287)		1,751		(4,902)		(10,947)		(545)		(7,615)
Utility infrastructure services segment:	Utility infrastructure services segment:											Utility infrastructure services segment:

Foreign transaction gain (loss)	Foreign transaction gain (loss)	(3)		(10)			(9)			5		Foreign transaction gain (loss)	(7)		—		(19)		(16)		(19)		(16)
Miscellaneous income and (expense)	Miscellaneous income and (expense)	(99)		(232)			(58)			(656)		Miscellaneous income and (expense)	1,182		48		946		(91)		846		(194)
Centuri - total other income (deductions)	Centuri - total other income (deductions)	(102)		(242)			(67)			(651)		Centuri - total other income (deductions)	1,175		48		927		(107)		827		(210)
Corporate and administrative	Corporate and administrative	0		8			0			92		Corporate and administrative	—		—		—		8		—		37
Consolidated Southwest Gas Holdings, Inc. - total other income (deductions)	Consolidated Southwest Gas Holdings, Inc. - total other income (deductions)	$	448	$	(20,770)		$	14,429		$	(17,524)	Consolidated Southwest Gas Holdings, Inc. - total other income (deductions)	$	(3,112)	$	1,799	$	(3,975)	$	(11,046)	$	282	$	(7,788)

Included in the table above is the change in cash surrender values of 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 values of COLI policies, as they progress towards the ultimate death benefits, are also recorded without tax consequences. Refer also to the discussion of Other Property and Investments above and ~~also~~ to Note 2 – Components of Net Periodic Benefit Cost.

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.


			16


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

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~~ ~~$38 million during the first quarter of 2021~~. Adjustment to the redemption value also impacts retained earnings, as reflected in the Company’s Condensed Consolidated Statement of Equity, but does not impact net income. The following depicts the change to the balance of the redeemable noncontrolling interest:


(Thousands of dollars):	Redeemable Noncontrolling Interest
Balance, December 31, 2020	$	165,716
Net income attributable to redeemable noncontrolling interest	~~1,552~~5,189
Redemption value adjustment	~~38,018~~12,642
Balance, ~~March 31,~~September 30, 2021	$	~~205,286~~183,547


			16


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

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:


		Three Months Ended March 31,		Twelve Months Ended March 31,			Three Months Ended September 30,			Nine Months Ended September 30,		Twelve Months Ended September 30,
(In thousands)	(In thousands)	2021	2020		2021	2020		(In thousands)	2021	2020	2021	2020	2021	2020
Weighted average basic shares	Weighted average basic shares	57,600	55,310		56,564	54,726		Weighted average basic shares	59,688	56,271	58,639	55,683	58,209	55,508
Effect of dilutive securities:	Effect of dilutive securities:							Effect of dilutive securities:
Management Incentive Plan shares	Management Incentive Plan shares	0	0		0	9		Management Incentive Plan shares	—	—	—	—	—	3
Restricted stock units (1)	Restricted stock units (1)	79	53		85	57		Restricted stock units (1)	128	86	103	70	103	66
Weighted average diluted shares	Weighted average diluted shares	57,679	55,363		56,649	54,792		Weighted average diluted shares	59,816	56,357	58,742	55,753	58,312	55,577

(1) The number of securities included ~~75,000~~115,000 and ~~50,000~~76,000 performance shares during the three months ending ~~March 31,~~September 30, 2021 and 2020, 95,000 and 63,000 performance shares during the nine months ending September 30, 2021 and 2020, and ~~76,000~~93,000 and ~~48,000~~57,000 performance shares during the twelve months ending ~~March 31,~~September 30, 2021 and 2020, respectively, the total of which was derived by assuming that target performance will be achieved during the relevant performance period.

Contingency. 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 2021 to July 2022, 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. In August 2021, a natural gas pipe was involved in an explosion that injured four individuals and damaged property. The explosion was caused by a leak in the pipe, and is under investigation. Claims are expected to be filed against Southwest. If Southwest is deemed fully or partially responsible, Southwest estimates its exposure could be as much as $5 million (the maximum noted above). As of September 30, 2021, pursuant to Accounting Standards Codification 450, Contingencies, Southwest recorded a $5 million liability related to this incident reflecting the maximum noted above; an estimate of actual loss greater than this exposure (to be covered by insurance) cannot be estimated as of the date these financial statements are issued.

Recent Accounting Standards Updates.

Accounting pronouncements adopted in 2021:

In December 2019, the Financial Accounting Standards Board (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 Company and Southwest adopted the update in the first quarter of 2021, the impact of which was not material to the condensed consolidated financial statements of the Company or Southwest.


			17


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

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 Topic 848) to replace a reference rate affected by such reform. The update applies only to contracts and hedging relationships that reference the London Interbank Offered Rate (“LIBOR”) or another 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, but to date, no further updates have occurred that would extend the optional guidance to the full tenor of LIBOR expiration dates occurring after 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. It will also monitor further FASB action, if any, in regard to the full tenor of LIBOR expiration dates. See also LIBOR discussion in Note 5 – 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 what impacts, if any, this update might have on the Company’s consolidated financial statements and disclosures.


			1718


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

Note 2 – Components of Net Periodic Benefit Cost

Southwest has a noncontributory qualified retirement plan with defined benefits covering substantially all employees and a separate unfunded supplemental retirement plan (“SERP”) which is limited to officers. Southwest also provides postretirement benefits other than pensions (“PBOP”) to its qualified retirees for health care, dental, and life insurance.

The service cost component of net periodic benefit costs included in the table below is a component of an overhead loading process associated with the cost of labor. The overhead process ultimately results in allocation of service cost 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 other components of net periodic benefit cost are reflected in Other income (deductions) on the Condensed Consolidated Statements of Income of each entity.


		Qualified Retirement Plan					Qualified Retirement Plan
		March 31,					September 30,
		Three Months				Twelve Months				Three Months						Nine Months				Twelve Months
		2021		2020				2021			2020			2021		2020		2021		2020		2021		2020
(Thousands of dollars)	(Thousands of dollars)												(Thousands of dollars)
Service cost	Service cost	$	10,290	$	8,574			$	36,015		$	27,972	Service cost	$	10,289	$	8,576	$	30,869	$	25,725	$	39,443	$	32,191
Interest cost	Interest cost	10,108		11,388				44,275			48,142		Interest cost	10,108		11,388		30,324		34,165		41,714		46,416
Expected return on plan assets	Expected return on plan assets	(18,088)		(16,324)				(67,060)			(61,507)		Expected return on plan assets	(18,088)		(16,324)		(54,264)		(48,972)		(70,588)		(64,033)
Amortization of net actuarial loss	Amortization of net actuarial loss	10,489		9,007				37,507			25,774		Amortization of net actuarial loss	10,489		9,006		31,467		27,019		40,473		32,608
Net periodic benefit cost	Net periodic benefit cost	$	12,799	$	12,645			$	50,737		$	40,381	Net periodic benefit cost	$	12,798	$	12,646	$	38,396	$	37,937	$	51,042	$	47,182

		SERP					SERP
		March 31,					September 30,
		Three Months				Twelve Months				Three Months						Nine Months				Twelve Months
		2021		2020				2021			2020			2021		2020		2021		2020		2021		2020
(Thousands of dollars)	(Thousands of dollars)												(Thousands of dollars)
Service cost	Service cost	$	131	$	98			$	422		$	298	Service cost	$	131	$	97	$	394	$	292	$	491	$	359
Interest cost	Interest cost	358		401				1,561			1,721		Interest cost	358		401		1,074		1,204		1,474		1,644
Amortization of net actuarial loss	Amortization of net actuarial loss	660		451				2,014			1,216		Amortization of net actuarial loss	661		451		1,981		1,353		2,433		1,608
Net periodic benefit cost	Net periodic benefit cost	$	1,149	$	950			$	3,997		$	3,235	Net periodic benefit cost	$	1,150	$	949	$	3,449	$	2,849	$	4,398	$	3,611

		PBOP					PBOP
		March 31,					September 30,
		Three Months				Twelve Months				Three Months						Nine Months				Twelve Months
		2021		2020				2021			2020			2021		2020		2021		2020		2021		2020
(Thousands of dollars)	(Thousands of dollars)												(Thousands of dollars)
Service cost	Service cost	$	423	$	396			$	1,608		$	1,353	Service cost	$	423	$	395	$	1,269	$	1,186	$	1,664	$	1,505
Interest cost	Interest cost	548		645				2,485			2,929		Interest cost	549		646		1,645		1,936		2,291		2,697
Expected return on plan assets	Expected return on plan assets	(810)		(852)				(3,366)			(3,219)		Expected return on plan assets	(810)		(852)		(2,430)		(2,556)		(3,282)		(3,345)
Amortization of prior service costs	Amortization of prior service costs	240		289				1,106			1,243		Amortization of prior service costs	239		289		719		867		1,007		1,185

Net periodic benefit cost	Net periodic benefit cost	$	401	$	478			$	1,833		$	2,306	Net periodic benefit cost	$	401	$	478	$	1,203	$	1,433	$	1,680	$	2,042

For new employees hired on or after January 1, 2022, the defined benefit retirement plan will be replaced with enhanced contributions to the 401(k) plan. The change is not applicable to existing employees, nor to employees hired during the remainder of 2021. Current employees will continue to be eligible to receive employer 401(k) matching contributions on one-half of amounts deferred by them, up to a maximum matching contribution of 3.5% of their eligible annual compensation. Employees hired after 2021 will be eligible for enhanced employer 401(k) contributions of 3% plus a matching contribution (dollar-for-dollar) up to 7% of eligible compensation.

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.


			1819


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

~~Note 3 – Revenue~~

Natural Gas Operations Segment:

Gas operating revenues on the Condensed 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:


		Three Months Ended March 31,				Twelve Months Ended March 31,			Three Months Ended September 30,						Nine Months Ended September 30,				Twelve Months Ended September 30,
(Thousands of dollars)	(Thousands of dollars)	2021		2020			2021			2020		(Thousands of dollars)	2021		2020		2021		2020		2021		2020
Residential	Residential	$	403,143	$	378,555		$	983,108		$	934,115	Residential	$	147,326	$	131,008	$	743,791	$	690,861	$	1,011,450	$	957,379
Small commercial	Small commercial	81,398		82,463			220,476			241,970		Small commercial	48,283		35,204		185,774		159,122		248,193		228,720
Large commercial	Large commercial	12,673		12,667			44,639			47,640		Large commercial	14,199		9,942		40,030		32,588		52,075		45,493
Industrial/other	Industrial/other	13,770		6,702			33,310			22,298		Industrial/other	9,608		5,888		30,352		19,089		37,505		25,435
Transportation	Transportation	24,536		24,406			88,345			91,884		Transportation	21,884		21,040		68,217		65,281		91,151		89,364
Revenue from contracts with customers	Revenue from contracts with customers	535,520		504,793			1,369,878			1,337,907		Revenue from contracts with customers	241,300		203,082		1,068,164		966,941		1,440,374		1,346,391
Alternative revenue program revenues (deferrals)	Alternative revenue program revenues (deferrals)	(16,373)		(3,765)			(468)			5,668		Alternative revenue program revenues (deferrals)	12,569		9,199		(5,335)		9,545		(2,740)		7,629
Other revenues (1)	Other revenues (1)	2,785		1,799			280			7,514		Other revenues (1)	1,979		(1,447)		7,747		(391)		7,432		1,646
Total Gas operating revenues	Total Gas operating revenues	$	521,932	$	502,827		$	1,369,690		$	1,351,089	Total Gas operating revenues	$	255,848	$	210,834	$	1,070,576	$	976,095	$	1,445,066	$	1,355,666

(1) Amounts include late fees and other miscellaneous revenues, and may also include the impact of certain regulatory mechanisms, such as cost-of-service components in customer rates expected to be returned to customers in future periods. ~~Late fees and certain other fees were reduced, for~~Also includes the ~~three- and twelve-month periods ended March 31, 2021, due to~~impacts of a temporary moratorium on late fees and disconnection for nonpayment during the COVID-19 pandemic.

Utility Infrastructure Services Segment:

The following tables display Centuri’s revenue, reflected as Utility infrastructure services revenues on the Condensed Consolidated Statements of Income of the Company, representing revenue from contracts with customers disaggregated by service and contract types:


		Three Months Ended March 31,				Twelve Months Ended March 31,			Three Months Ended September 30,						Nine Months Ended September 30,				Twelve Months Ended September 30,
(Thousands of dollars)	(Thousands of dollars)	2021		2020			2021			2020		(Thousands of dollars)	2021		2020		2021		2020		2021		2020
Service Types:	Service Types:											Service Types:
Gas infrastructure services	Gas infrastructure services	$	221,837	$	217,709		$	1,265,288		$	1,258,790	Gas infrastructure services	$	393,122	$	387,578	$	961,836	$	935,444	$	1,287,552	$	1,288,468
Electric power infrastructure services	Electric power infrastructure services	93,961		72,320			433,467			267,736		Electric power infrastructure services	155,456		115,386		347,061		282,992		475,895		346,432
Other	Other	48,177		43,464			280,015			245,083		Other	84,270		77,428		216,551		190,262		301,591		242,364
Total Utility infrastructure services revenues	Total Utility infrastructure services revenues	$	363,975	$	333,493		$	1,978,770		$	1,771,609	Total Utility infrastructure services revenues	$	632,848	$	580,392	$	1,525,448	$	1,408,698	$	2,065,038	$	1,877,264


		Three Months Ended March 31,				Twelve Months Ended March 31,			Three Months Ended September 30,						Nine Months Ended September 30,				Twelve Months Ended September 30,
(Thousands of dollars)	(Thousands of dollars)	2021		2020			2021			2020		(Thousands of dollars)	2021		2020		2021		2020		2021		2020
Contract Types:	Contract Types:											Contract Types:
Master services agreement	Master services agreement	$	293,680	$	263,545		$	1,520,144		$	1,411,267	Master services agreement	$	467,869	$	437,914	$	1,160,199	$	1,076,961	$	1,573,247	$	1,438,540
Bid contract	Bid contract	70,295		69,948			458,626			360,342		Bid contract	164,979		142,478		365,249		331,737		491,791		438,724
Total Utility infrastructure services revenues	Total Utility infrastructure services revenues	$	363,975	$	333,493		$	1,978,770		$	1,771,609	Total Utility infrastructure services revenues	$	632,848	$	580,392	$	1,525,448	$	1,408,698	$	2,065,038	$	1,877,264

Unit price contracts	Unit price contracts	$	234,449	$	243,136		$	1,347,953		$	1,387,706	Unit price contracts	$	406,404	$	377,284	$	1,002,779	$	985,673	$	1,373,746	$	1,359,352
Fixed price contracts	Fixed price contracts	34,594		27,545			164,750			101,931		Fixed price contracts	64,632		46,379		149,681		109,935		197,447		142,356
Time and materials contracts	Time and materials contracts	94,932		62,812			466,067			281,972		Time and materials contracts	161,812		156,729		372,988		313,090		493,845		375,556
Total Utility infrastructure services revenues	Total Utility infrastructure services revenues	$	363,975	$	333,493		$	1,978,770		$	1,771,609	Total Utility infrastructure services revenues	$	632,848	$	580,392	$	1,525,448	$	1,408,698	$	2,065,038	$	1,877,264


			1920


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

The following table provides information about contracts receivable and revenue earned on contracts in progress in excess of billings (contract ~~asset)~~assets), which are both included within Accounts receivable, net of ~~allowances, as well as~~allowances; the table also includes amounts billed in excess of revenue earned on contracts (contract ~~liability)~~liabilities), which are included in Other current liabilities as of ~~March 31,~~September 30, 2021 and December 31, 2020 on the Company’s Condensed Consolidated Balance Sheets:


(Thousands of dollars)	(Thousands of dollars)	March 31, 2021		December 31, 2020		(Thousands of dollars)	September 30, 2021		December 31, 2020
Contracts receivable, net	Contracts receivable, net	$	197,357	$	278,316	Contracts receivable, net	$	381,387	$	278,316
Revenue earned on contracts in progress in excess of billings	Revenue earned on contracts in progress in excess of billings	107,336		96,996		Revenue earned on contracts in progress in excess of billings	207,318		96,996
Amounts billed in excess of revenue earned on contracts	Amounts billed in excess of revenue earned on contracts	5,985		4,507		Amounts billed in excess of revenue earned on contracts	19,954		4,507

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 for billing at the reporting date. These contract assets are transferred to contracts receivable when the rights become unconditional. 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, 2020 to ~~March 31,~~September 30, 2021 is due to revenue recognized of approximately $4.5 million ~~$4.5 million th~~atthat was included in this item as of January 1, 2021, after which time it became earned and the balance was ~~reduced, and to~~reduced; the change also includes 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 uses the practical expedient applicable to such contracts and does not consider/compute an interest component based on the time value of money. ~~Further,~~Furthermore, because of the short duration of these contracts, Centuri 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 ~~March 31,~~September 30, 2021, Centuri had 18 c~~ontracts~~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 ~~March 31,~~September 30, 2021 was ~~$48.7 million~~.$53.8 million. Centuri expects to recognize the remaining performance ~~obligation~~sobligations over approximately the next two years; ho~~wever,~~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 are provided by the customer.

Utility infrastructure services contracts receivable consists of the following:


(Thousands of dollars)	(Thousands of dollars)	March 31, 2021		December 31, 2020		(Thousands of dollars)	September 30, 2021		December 31, 2020
Billed on completed contracts and contracts in progress	Billed on completed contracts and contracts in progress	$	193,042	$	273,778	Billed on completed contracts and contracts in progress	$	380,484	$	273,778
Other receivables	Other receivables	5,789		6,692		Other receivables	2,844		6,692
Contracts receivable, gross	Contracts receivable, gross	198,831		280,470		Contracts receivable, gross	383,328		280,470
Allowance for doubtful accounts	Allowance for doubtful accounts	(1,474)		(2,154)		Allowance for doubtful accounts	(1,941)		(2,154)
Contracts receivable, net	Contracts receivable, net	$	197,357	$	278,316	Contracts receivable, net	$	381,387	$	278,316


			2021


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

Note 4 – Common Stock

~~Only shares~~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 stock awards to be issued in shares of Southwest Gas Holdings, Inc.

On ~~May~~April 8, ~~2019,~~2021, the Company ~~filed with~~entered into a Sales Agency Agreement between the ~~SEC~~Company and BNY Mellon Capital Markets, LLC and J.P. Morgan Securities LLC (the “Equity Shelf Program”) for the offer and sale of up to $500 million of common stock from time to time in an at-the-market offering program. The shares are issued pursuant to the Company’s 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 8, 2019, between the Company and BNY Mellon Capital Markets, LLC (the “Equity Shelf Program”)333-251074). The following table provides the activity under the Equity Shelf Program for the three-month and life-to-date periods ended ~~March 31,~~September 30, 2021:


		Three Months Ended		Life-To-Date Ended			Three Months Ended		Life-To-Date Ended
		March 31, 2021					September 30, 2021
Gross proceeds	Gross proceeds	$	46,448,484	$	299,999,974	Gross proceeds	$	87,819,931	$	158,180,343
Less: agent commissions	Less: agent commissions	(464,485)		(3,000,000)		Less: agent commissions	(878,199)		(1,581,803)
Net proceeds	Net proceeds	$	45,983,999	$	296,999,974	Net proceeds	$	86,941,732	$	156,598,540
Number of shares sold	Number of shares sold	705,957		4,102,414		Number of shares sold	1,251,810		2,302,407
Weighted average price per share	Weighted average price per share	$	65.80	$	73.13	Weighted average price per share	$	70.15	$	68.70

~~During the quarter ended March 31,~~As of September 30, 2021, the Company ~~sold essentially all of the remaining~~had up to $341,819,657 in common stock available for sale under the program. Net proceeds from the sale 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.~~

~~On April 8, 2021, the Company entered into a Sales Agency Agreement between the Company and BNY Mellon Capital Markets, LLC and J.P. Morgan Securities LLC~~Southwest, as well as for the ~~offer and sale~~repayment or repurchase of ~~up to $500 million of common stock~~indebtedness (including amounts outstanding from time to time ~~in a new at-the-market offering program. The shares will be issued pursuant~~under the credit facilities, senior notes, term loan, or future credit facilities), and to ~~the Company’s automatic shelf registration statement on Form S-3 (File No. 333-251074), which became effective upon filing with the SEC on December 2, 2020.~~provide for working capital.

During the ~~three months~~quarter ended March 31, 2021, the Company sold essentially all of the remaining common stock available for sale under a previously effective equity shelf program.

During the nine months ended September 30, 2021, the Company issued approximately ~~47,000~~47,500 shares of common stock through the Restricted Stock/Unit Plan and Omnibus Incentive Plan.

Additionally, during the ~~three~~nine months ended ~~March 31,~~September 30, 2021, the Company issued ~~49,500~~130,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan, raising approximately ~~$3.1~~$8.5 million.

On October 10, 2021, the Company’s Board of Directors (the “Board”) authorized and declared a dividend of 1 preferred stock purchase right (a “Right”) for each share of common stock outstanding, $1 par value per share, of the Company to stockholders of record at the close of business on October 21, 2021. Each right entitles the registered holder to purchase from the Company one ten-thousandth (a “unit”) of a share of Series A Junior Participating Preferred Stock, no par value per share, of the Company at a purchase price of $321.70 per unit, subject to adjustment. Generally, the Rights become exercisable in the event any person or group of affiliated or associated persons acquires beneficial ownership of 10% (20% in the case of a passive institutional investor) or more of the Company’s common stock without the approval of the Board, and until such time, are inseparable from and trade with the Company’s common stock. The Rights were issued pursuant to the Rights Agreement dated October 10, 2021 (the “Rights Agreement”), between the Company and Equiniti Trust Company, as rights agent. The Rights expire at the close of business on October 9, 2022 or upon an earlier merger or other acquisition transaction involving the Company, redemption, or exchange as provided in the Rights Agreement.


			2122


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

Note 5 – Debt

Long-Term Debt

Long-term debt is recognized in the Company’s and Southwest’s Condensed Consolidated Balance Sheets generally at the carrying value of the obligations outstanding. Details surrounding the fair value, as described in Note 1 – Background, Organization, and Summary of Significant Accounting Policies, and individual carrying values of instruments are provided in the table that follows.


		March 31, 2021				December 31, 2020					September 30, 2021				December 31, 2020
		Carrying Amount		Fair Value		Carrying Amount		Fair Value			Carrying Amount		Fair Value		Carrying Amount		Fair Value
(Thousands of dollars)	(Thousands of dollars)									(Thousands of dollars)
Southwest Gas Corporation:	Southwest Gas Corporation:									Southwest Gas Corporation:
Debentures:	Debentures:									Debentures:
Notes, 6.1%, due 2041	Notes, 6.1%, due 2041	$	125,000	$	160,651	$	125,000	$	174,858	Notes, 6.1%, due 2041	$	125,000	$	167,755	$	125,000	$	174,858
Notes, 3.875%, due 2022	Notes, 3.875%, due 2022	250,000		256,693		250,000		258,825		Notes, 3.875%, due 2022	250,000		252,208		250,000		258,825
Notes, 4.875%, due 2043	Notes, 4.875%, due 2043	250,000		288,500		250,000		317,190		Notes, 4.875%, due 2043	250,000		307,385		250,000		317,190
Notes, 3.8%, due 2046	Notes, 3.8%, due 2046	300,000		306,261		300,000		347,046		Notes, 3.8%, due 2046	300,000		326,058		300,000		347,046
Notes, 3.7%, due 2028	Notes, 3.7%, due 2028	300,000		324,069		300,000		344,553		Notes, 3.7%, due 2028	300,000		331,536		300,000		344,553
Notes, 4.15%, due 2049	Notes, 4.15%, due 2049	300,000		324,183		300,000		370,278		Notes, 4.15%, due 2049	300,000		343,950		300,000		370,278
Notes, 2.2%, due 2030	Notes, 2.2%, due 2030	450,000		438,912		450,000		474,552		Notes, 2.2%, due 2030	450,000		447,287		450,000		474,552
Notes, 3.18%, due 2051										Notes, 3.18%, due 2051	300,000		291,351		—		—
8% Series, due 2026	8% Series, due 2026	75,000		95,894		75,000		99,723		8% Series, due 2026	75,000		94,752		75,000		99,723
Medium-term notes, 7.78% series, due 2022	Medium-term notes, 7.78% series, due 2022	25,000		26,201		25,000		26,663		Medium-term notes, 7.78% series, due 2022	25,000		25,513		25,000		26,663
Medium-term notes, 7.92% series, due 2027	Medium-term notes, 7.92% series, due 2027	25,000		32,138		25,000		33,802		Medium-term notes, 7.92% series, due 2027	25,000		31,936		25,000		33,802
Medium-term notes, 6.76% series, due 2027	Medium-term notes, 6.76% series, due 2027	7,500		9,127		7,500		9,613		Medium-term notes, 6.76% series, due 2027	7,500		9,116		7,500		9,613
Unamortized discount and debt issuance costs	Unamortized discount and debt issuance costs	(17,501)				(17,822)				Unamortized discount and debt issuance costs	(20,727)				(17,822)
		2,089,999				2,089,678					2,386,773				2,089,678
Revolving credit facility and commercial paper	Revolving credit facility and commercial paper	150,000		150,000		150,000		150,000		Revolving credit facility and commercial paper	—		—		150,000		150,000
Industrial development revenue bonds:	Industrial development revenue bonds:									Industrial development revenue bonds:
Variable-rate bonds:	Variable-rate bonds:									Variable-rate bonds:
Tax-exempt Series A, due 2028	Tax-exempt Series A, due 2028	50,000		50,000		50,000		50,000		Tax-exempt Series A, due 2028	50,000		50,000		50,000		50,000
2003 Series A, due 2038	2003 Series A, due 2038	50,000		50,000		50,000		50,000		2003 Series A, due 2038	50,000		50,000		50,000		50,000
2008 Series A, due 2038	2008 Series A, due 2038	50,000		50,000		50,000		50,000		2008 Series A, due 2038	50,000		50,000		50,000		50,000
2009 Series A, due 2039	2009 Series A, due 2039	50,000		50,000		50,000		50,000		2009 Series A, due 2039	50,000		50,000		50,000		50,000
Unamortized discount and debt issuance costs	Unamortized discount and debt issuance costs	(1,411)				(1,472)				Unamortized discount and debt issuance costs	(1,916)				(1,472)
		198,589				198,528					198,084				198,528
Less: current maturities	Less: current maturities	(25,000)				0				Less: current maturities	(275,000)				—
Long-term debt, less current maturities - Southwest Gas Corporation	Long-term debt, less current maturities - Southwest Gas Corporation	$	2,413,588			$	2,438,206			Long-term debt, less current maturities - Southwest Gas Corporation	$	2,309,857			$	2,438,206
Centuri:	Centuri:									Centuri:
Centuri term loan facility	Centuri term loan facility	$	222,668	$	225,269	$	226,648	$	230,824	Centuri term loan facility	$	1,145,000	$	1,146,431	$	226,648	$	230,824
Unamortized debt issuance costs	Unamortized debt issuance costs	(750)				(820)				Unamortized debt issuance costs	(25,385)				(820)
		221,918				225,828					1,119,615				225,828
Centuri secured revolving credit facility	Centuri secured revolving credit facility	26,163		26,180		26,626		26,645		Centuri secured revolving credit facility	112,236		112,348		26,626		26,645
Centuri other debt obligations	Centuri other debt obligations	77,235		78,378		81,973		84,246		Centuri other debt obligations	54,346		52,682		81,973		84,246
Less: current maturities	Less: current maturities	(42,334)				(40,433)				Less: current maturities	(22,271)				(40,433)
Long-term debt, less current maturities - Centuri	Long-term debt, less current maturities - Centuri	$	282,982			$	293,994			Long-term debt, less current maturities - Centuri	$	1,263,926			$	293,994
Consolidated Southwest Gas Holdings, Inc.:	Consolidated Southwest Gas Holdings, Inc.:									Consolidated Southwest Gas Holdings, Inc.:
Southwest Gas Corporation long-term debt	Southwest Gas Corporation long-term debt	$	2,438,588			$	2,438,206			Southwest Gas Corporation long-term debt	$	2,584,857			$	2,438,206
Centuri long-term debt	Centuri long-term debt	325,316				334,427				Centuri long-term debt	1,286,197				334,427
Less: current maturities	Less: current maturities	(67,334)				(40,433)				Less: current maturities	(297,271)				(40,433)
Long-term debt, less current maturities - Southwest Gas Holdings, Inc.	Long-term debt, less current maturities - Southwest Gas Holdings, Inc.	$	2,696,570			$	2,732,200			Long-term debt, less current maturities - Southwest Gas Holdings, Inc.	$	3,573,783			$	2,732,200


			2223


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

The fair values of Southwest's and Centuri’s revolving credit ~~facility~~facilities and Southwest’s IDRBs are categorized as Level 1 based on the FASB’s fair value hierarchy, due to ~~Southwest’s~~the ability to access similar debt arrangements at measurement dates with comparable terms, including variable/market rates. The fair values of Southwest’s debentures (which include senior and medium-term notes) and Centuri's term loan facility as of September 30, 2021 were determined utilizing a market-based valuation approach, where fair values are determined based on evaluated pricing data, and as such are categorized as Level 2 in the hierarchy. ~~Centuri's~~Prior to amending its secured revolving credit and term loan facility ~~and other debt obligations (not actively traded) are~~in the third quarter 2021 (see below), the Centuri credit facility was categorized as Level 3;3, as fair values were based on a conventional discounted cash flow methodology utilizing current market pricing yield curves.

Southwest has a $400 million credit facility that is scheduled to expire in April 2025. Southwest designates $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 ~~March 31,~~September 30, 2021, the applicable margin is 1%1.125% for loans bearing interest with reference to LIBOR and 0%0.125% for loans bearing interest with reference to the alternative base rate. At ~~March 31,~~September 30, 2021,~~$150 million was~~ no borrowings were outstanding on the long-term portion ~~(including $50 million~~(including under the commercial paper program, discussed below) of the facility ~~and $17 million of borrowings were outstanding~~or on the short-term portion of this credit facility discussed below.

Southwest has a $50 million commercial paper program. Issuances under the commercial paper program are supported by Southwest’s revolving credit facility and, therefore, do not represent additional borrowing capacity under the credit facility. 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 ~~March 31,~~September 30, 2021, as noted above, ~~$50 million~~no of borrowings were outstanding under the commercial paper program.

In August 2021, Southwest issued $300 million aggregate principal amount of 3.18% Senior Notes at a discount of 0.019%. The notes will mature in August 2051. Southwest used the net proceeds from the offering to repay the outstanding balance under its credit facility, with the remaining net proceeds used for general corporate purposes.

As referred to above, on August 27, 2021, Centuri, ~~has~~in association with the acquisition of Riggs Distler (see Note 8 - Business Acquisitions), entered into an amended and restated credit agreement. The agreement provided for a ~~$590~~$1.145 billion secured term loan facility, at a discount of 1.00%, and a $400 million ~~senior~~ secured revolving credit facility, which in addition to funding the Riggs Distler acquisition, refinanced the previous $590 million loan facility. This multi-currency facility allows the borrower to request loan advances in either Canadian dollars or U.S. dollars. Amounts borrowed and ~~term loan facility, scheduled to expire in November 2023. The capacity of~~repaid under the revolving line of credit portion of the facility ~~is $325 million; related amounts borrowed and repaid~~ are available to be re-borrowed. The obligations under the credit agreement are secured by present and future ownership interests in substantially all direct and indirect subsidiaries of Centuri, substantially all of the tangible and intangible personal property of each borrower, certain of their direct and indirect subsidiaries, and all products, profits, and proceeds of the foregoing. The term loan facility matures on August 27, 2028 and the revolving credit facility matures on August 27, 2026.

Interest rates for the term loan facility and the revolving credit facility are based on either a “base rate” or LIBOR, plus an applicable margin in either case. The term loan facility is also subject to a LIBOR floor of 0.50%. Furthermore, Centuri Canada Division Inc. may borrow under the revolving credit facility with interest rates based on either a “base rate” or the Canadian Dealer Offered Rate (“CDOR”) plus the applicable margin, at the borrower’s option. The margin for the term loan facility will be 1.50% for base rate loans and 2.50% for LIBOR loans. The margin for the revolving credit facility ranges from 0.0% to 1.25% for base rate loans and from 1.00% to 2.25% for LIBOR loans, depending on Centuri’s net leverage ratio. Upon the occurrence of certain events providing for a transition away from LIBOR, or if LIBOR is no longer a widely recognized benchmark rate, Centuri may further amend the credit agreement with a replacement rate as set forth in the amended agreement. Centuri is also required to pay a commitment fee on the unused portion of the commitments. The commitment fee ranges from 0.15% to 0.35% per annum. The credit agreement contains certain customary representations and warranties, affirmative and negative covenants and events of default. There are no financial covenants related to the term loan facility. The revolving credit facility ~~has~~requires Centuri to maintain a ~~limit~~maximum total net leverage ratio of ~~approximately $265 million. The $590 million facility is secured by substantially all of Centuri’s assets except those explicitly excluded under~~5.50 to 1.00 with a step-down to 4.75 to 1.0 on December 31, 2022, and a step-down to 4.00 to 1.00 on December 31, 2023; provided, however, Centuri may elect to increase the ~~terms of~~maximum total net leverage ratio up to 4.50 to 1.00 in connection with certain material acquisitions, with such increase being applicable for one year following such acquisition; and the agreement ~~(including owned real estate and certain certificated vehicles).~~also requires Centuri to maintain a minimum interest coverage ratio of 2.50 to 1.00. Centuri’s assets securing the facility at ~~March 31,~~September 30, 2021 totaled ~~$1.3~~$2.6 billion. At September 30, 2021, $1.257 billion~~. At March 31, 2021, $249 million~~ in ~~borrowings~~borrowings were outstanding under Centuri’s combined secured revolving credit and term loan facility.


			24


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

Short-Term Debt

Southwest Gas Holdings, Inc. has a $100 million credit facility that is scheduled to expire in April 2025 and is primarily used for short-term financing needs. There was $4322 million outstanding under this credit facility as of ~~March 31,~~September 30, 2021.

~~Under~~As indicated above, under Southwest’s $400 million credit facility, ~~Southwest had $17 million in~~no short-term borrowings were outstanding at ~~March 31,~~September 30, 2021.

In March 2021, Southwest ~~issued~~entered into a $250 million Term Loan that matures March 22, 2022. The proceeds were used to fund the increased cost of natural gas supply during the month of February 2021, caused by extreme weather conditions in the central U.S. (see Deferred Purchased Gas Costs in Note 1 – Background, Organization, and Summary of Significant Accounting Policies). Interest rates for the term loan 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 long-term debt rating. The applicable margin ranges from 0.550% to 1.000% for loans bearing interest with reference to LIBOR and 0.000% for loans bearing interest with reference to an alternate base rate. The ~~effective interest rate was 0.77% at March 31, 2021. The~~ 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.

On November 1, 2021, the Company entered into a 364-day term loan credit agreement (the “Credit Agreement”). The Credit Agreement provides for a $1.6 billion delayed-draw term loan (the “Term Loan Facility”) to fund and to pay fees, commissions, and expenses related to the Term Loan Facility and the acquisition by the Company of the equity interests in Questar Pipelines. The Term Loan Facility matures 364 days from the date of the funding of the Term Loan Facility.

The interest rate for the Term Loan Facility is based on either “base rate” or LIBOR, plus an applicable margin in either case.The applicable margin for the Term Loan Facility will be 0% to 0.50% for base rate loans and 0.75% to 1.50% for LIBOR loans, depending on the applicable pricing level in effect.Each of the interest rate spreads will increase by 0.25% at certain time intervals after the funding date. The commitment fee ranges from 0.060% to 0.175% per calendar quarter commencing January 3, 2022, depending on the applicable pricing level in effect. The pricing levels are based on the Company’s senior debt ratings. The interest rate is subject to customary benchmark replacement provisions.

The Credit Agreement contains representations and warranties, affirmative, negative, and financial covenants and events of default substantially similar to the Company’s existing credit facility. Subject to certain exceptions, after the funding date, the Company must make a mandatory prepayment from 100% of the net cash proceeds received by the Company or any of its subsidiaries from any debt offerings or equity issuances and/or 100% of the committed amount under any specified acquisition financings.

LIBOR

Certain rates established at LIBOR isare scheduled to be discontinued as a benchmark or reference rate after ~~2021.~~2021, while other LIBOR-based rates are scheduled to be discontinued after June 2023. In order to mitigate the impact of a discontinuance on the Company’s and Southwest’s financial condition and results of operations, management will 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.


			2325


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

Note 6 – Other Comprehensive Income and Accumulated Other Comprehensive Income

The following information presents the Company’s Other comprehensive income (loss), both before and after-tax impacts, within the Condensed Consolidated Statements of Comprehensive Income, which also impact Accumulated other comprehensive income (“AOCI”) in the Condensed Consolidated Balance Sheets and the Condensed Consolidated Statements of Equity.

Related Tax Effects Allocated to Each Component of Other Comprehensive Income (Loss)


		Three Months Ended March 31, 2021							Three Months Ended March 31, 2020								Three Months Ended September 30, 2021						Three Months Ended September 30, 2020
(Thousands of dollars)	(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			(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
Defined benefit pension plans:	Defined benefit pension plans:															Defined benefit pension plans:
Amortization of prior service cost	Amortization of prior service cost	$	240	$	(58)	$	182		$	289	$	(69)	$	220		Amortization of prior service cost	$	239	$	(56)	$	183	$	289	$	(69)	$	220
Amortization of net actuarial (gain)/loss	Amortization of net actuarial (gain)/loss	11,149		(2,675)		8,474			9,458		(2,270)		7,188			Amortization of net actuarial (gain)/loss	11,151		(2,677)		8,474		9,457		(2,270)		7,187
Regulatory adjustment	Regulatory adjustment	(9,575)		2,298		(7,277)			(8,395)		2,015		(6,380)			Regulatory adjustment	(9,575)		2,298		(7,277)		(8,394)		2,014		(6,380)
Pension plans other comprehensive income (loss)	Pension plans other comprehensive income (loss)	1,814		(435)		1,379			1,352		(324)		1,028			Pension plans other comprehensive income (loss)	1,815		(435)		1,380		1,352		(325)		1,027
FSIRS (designated hedging activities):	FSIRS (designated hedging activities):															FSIRS (designated hedging activities):
Amounts reclassified into net income	Amounts reclassified into net income	544		(131)		413			837		(201)		636			Amounts reclassified into net income	544		(131)		413		1,030		(247)		783
FSIRS other comprehensive income (loss)	FSIRS other comprehensive income (loss)	544		(131)		413			837		(201)		636			FSIRS other comprehensive income (loss)	544		(131)		413		1,030		(247)		783
Total other comprehensive income (loss) - Southwest Gas Corporation	Total other comprehensive income (loss) - Southwest Gas Corporation	2,358		(566)		1,792			2,189		(525)		1,664			Total other comprehensive income (loss) - Southwest Gas Corporation	2,359		(566)		1,793		2,382		(572)		1,810
Foreign currency translation adjustments:	Foreign currency translation adjustments:															Foreign currency translation adjustments:
Translation adjustments	Translation adjustments	823		0		823			(4,005)		0		(4,005)			Translation adjustments	(2,056)		—		(2,056)		1,024		—		1,024
Foreign currency other comprehensive income (loss)	Foreign currency other comprehensive income (loss)	823		0		823			(4,005)		0		(4,005)			Foreign currency other comprehensive income (loss)	(2,056)		—		(2,056)		1,024		—		1,024
Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	3,181	$	(566)	$	2,615		$	(1,816)	$	(525)	$	(2,341)		Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	303	$	(566)	$	(263)	$	3,406	$	(572)	$	2,834

								Nine Months Ended September 30, 2021							Nine Months Ended September 30, 2020

(Thousands of dollars)																(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
Defined benefit pension plans:																Defined benefit pension plans:
Amortization of prior service cost																Amortization of prior service cost	$	719	$	(172)	$	547	$	867	$	(208)	$	659
Amortization of net actuarial (gain)/loss																Amortization of net actuarial (gain)/loss	33,448		(8,028)		25,420		28,372		(6,809)		21,563
Regulatory adjustment																Regulatory adjustment	(28,725)		6,894		(21,831)		(25,184)		6,044		(19,140)
Pension plans other comprehensive income (loss)																Pension plans other comprehensive income (loss)	5,442		(1,306)		4,136		4,055		(973)		3,082
FSIRS (designated hedging activities):																FSIRS (designated hedging activities):
Amounts reclassified into net income																Amounts reclassified into net income	1,632		(392)		1,240		2,703		(649)		2,054
FSIRS other comprehensive income (loss)																FSIRS other comprehensive income (loss)	1,632		(392)		1,240		2,703		(649)		2,054
Total other comprehensive income (loss) - Southwest Gas Corporation																Total other comprehensive income (loss) - Southwest Gas Corporation	7,074		(1,698)		5,376		6,758		(1,622)		5,136
Foreign currency translation adjustments:																Foreign currency translation adjustments:
Translation adjustments																Translation adjustments	(324)		—		(324)		(1,187)		—		(1,187)
Foreign currency other comprehensive income (loss)																Foreign currency other comprehensive income (loss)	(324)		—		(324)		(1,187)		—		(1,187)
Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.																Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	6,750	$	(1,698)	$	5,052	$	5,571	$	(1,622)	$	3,949

Twelve Months Ended
March 31, 2021 Twelve Months Ended
March 31, 2020
(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
Defined benefit pension plans:
Net actuarial gain/(loss) $ (57,539) $ 13,809 $ (43,730) $ (71,087) $ 17,061 $ (54,026)
Amortization of prior service cost 1,106 (266) 840 1,243 (298) 945
Amortization of net actuarial (gain)/loss 39,521 (9,484) 30,037 26,990 (6,477) 20,513
Prior service cost 0 0 0 (1,878) 452 (1,426)
Regulatory adjustment 6,255 (1,502) 4,753 33,896 (8,136) 25,760
Pension plans other comprehensive income (loss) (10,657) 2,557 (8,100) (10,836) 2,602 (8,234)
FSIRS (designated hedging activities):
Amounts reclassified into net income 2,954 (710) 2,244 3,345 (803) 2,542
FSIRS other comprehensive income (loss) 2,954 (710) 2,244 3,345 (803) 2,542
Total other comprehensive income (loss) - Southwest Gas Corporation (7,703) 1,847 (5,856) (7,491) 1,799 (5,692)
Foreign currency translation adjustments:
Translation adjustments 6,541 0 6,541 (2,758) 0 (2,758)
Foreign currency other comprehensive income (loss) 6,541 0 6,541 (2,758) 0 (2,758)
Total other comprehensive income (loss) - Southwest Gas Holdings, Inc. $ (1,162) $ 1,847 $ 685 $ (10,249) $ 1,799 $ (8,450)


			26


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021


	Twelve Months Ended September 30, 2021						Twelve Months Ended September 30, 2020
(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
Defined benefit pension plans:
Net actuarial gain/(loss)	$	(57,539)	$	13,809	$	(43,730)	$	(71,087)	$	17,061	$	(54,026)
Amortization of prior service cost	1,007		(241)		766		1,185		(284)		901
Amortization of net actuarial (gain)/loss	42,906		(10,298)		32,608		34,216		(8,212)		26,004
Prior service cost	—		—		—		(1,878)		452		(1,426)
Regulatory adjustment	3,894		(935)		2,959		27,803		(6,673)		21,130
Pension plans other comprehensive income (loss)	(9,732)		2,335		(7,397)		(9,761)		2,344		(7,417)
FSIRS (designated hedging activities):
Amounts reclassified into net income	2,176		(523)		1,653		3,539		(850)		2,689
FSIRS other comprehensive income (loss)	2,176		(523)		1,653		3,539		(850)		2,689
Total other comprehensive income (loss) - Southwest Gas Corporation	(7,556)		1,812		(5,744)		(6,222)		1,494		(4,728)
Foreign currency translation adjustments:
Translation adjustments	2,576		—		2,576		(280)		—		(280)
Foreign currency other comprehensive income (loss)	2,576		—		2,576		(280)		—		(280)
Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	(4,980)	$	1,812	$	(3,168)	$	(6,502)	$	1,494	$	(5,008)

(1)Tax amounts are calculated using a 24% rate. The Company has elected to indefinitely reinvest, in Canada, the earnings of Centuri’s Canadian subsidiaries, ~~in Canada,~~ thus precluding 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 reported in Other comprehensive income (loss).

Approximately ~~$1.7 million~~$828,000 of realized losses (net of tax) related to the remaining balance of Southwest’s previously settled forward-starting interest rate swap (“FSIRS”), included in AOCI at ~~March 31,~~September 30, 2021, will be reclassified into interest expense within the next 126 months (the remainder of the amortization period for the balance) as the related interest payments on long-term debt occur.


			24


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

The following table represents a rollforward of AOCI, presented on the Company’s Condensed Consolidated Balance Sheets and its Condensed Consolidated Statements of Equity:


		Defined Benefit Plans						FSIRS						Foreign Currency Items									Defined Benefit Plans						FSIRS						Foreign Currency Items
(Thousands of dollars)	(Thousands of dollars)	Before-Tax		Tax (Expense) Benefit (4)		After-Tax		Before-Tax		Tax (Expense) Benefit (4)		After-Tax		Before-Tax		Tax (Expense) Benefit		After-Tax		AOCI		(Thousands of dollars)	Before-Tax		Tax (Expense) Benefit (4)		After-Tax		Before-Tax		Tax (Expense) Benefit (4)		After-Tax		Before-Tax		Tax (Expense) Benefit		After-Tax		AOCI
Beginning Balance AOCI December 31, 2020	Beginning Balance AOCI December 31, 2020	$	(77,720)	$	18,653	$	(59,067)	$	(2,719)	$	651	$	(2,068)	$	132	$	—	$	132	$	(61,003)	Beginning Balance AOCI December 31, 2020	$	(77,720)	$	18,653	$	(59,067)	$	(2,719)	$	651	$	(2,068)	$	132	$	—	$	132	$	(61,003)
Translation adjustments	Translation adjustments	—		—		—		—		—		—		823		—		823		823		Translation adjustments	—		—		—		—		—		—		(324)		—		(324)		(324)
Other comprehensive income (loss) before reclassifications	Other comprehensive income (loss) before reclassifications	—		—		—		—		—		—		823		—		823		823		Other comprehensive income (loss) before reclassifications	—		—		—		—		—		—		(324)		—		(324)		(324)
FSIRS amount reclassified from AOCI (1)	FSIRS amount reclassified from AOCI (1)	—		—		—		544		(131)		413		—		—		—		413		FSIRS amount reclassified from AOCI (1)	—		—		—		1,632		(392)		1,240		—		—		—		1,240
Amortization of prior service cost (2)	Amortization of prior service cost (2)	240		(58)		182		—		—		—		—		—		—		182		Amortization of prior service cost (2)	719		(172)		547		—		—		—		—		—		—		547
Amortization of net actuarial loss (2)	Amortization of net actuarial loss (2)	11,149		(2,675)		8,474		—		—		—		—		—		—		8,474		Amortization of net actuarial loss (2)	33,448		(8,028)		25,420		—		—		—		—		—		—		25,420
Regulatory adjustment (3)	Regulatory adjustment (3)	(9,575)		2,298		(7,277)		—		—		—		—		—		—		(7,277)		Regulatory adjustment (3)	(28,725)		6,894		(21,831)		—		—		—		—		—		—		(21,831)
Net current period other comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.	Net current period other comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.	1,814		(435)		1,379		544		(131)		413		823		—		823		2,615		Net current period other comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.	5,442		(1,306)		4,136		1,632		(392)		1,240		(324)		—		(324)		5,052
Ending Balance AOCI March 31, 2021		$	(75,906)	$	18,218	$	(57,688)	$	(2,175)	$	520	$	(1,655)	$	955	$	—	$	955	$	(58,388)
Ending Balance AOCI September 30, 2021																						Ending Balance AOCI September 30, 2021	$	(72,278)	$	17,347	$	(54,931)	$	(1,087)	$	259	$	(828)	$	(192)	$	—	$	(192)	$	(55,951)

(1)The FSIRS reclassification amount is included in Net interest deductions on the Company’s Condensed Consolidated Statements of Income.

(2)These AOCI components are included in the computation of net periodic benefit cost (see Note 2 – Components of Net Periodic Benefit Cost 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 Condensed Consolidated Balance Sheets).

(4)Tax amounts are calculated using a 24% rate.


			27


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

The following table represents a rollforward of AOCI, presented on Southwest’s Condensed Consolidated Balance Sheets:


		Defined Benefit Plans						FSIRS									Defined Benefit Plans						FSIRS
(Thousands of dollars)	(Thousands of dollars)	Before-Tax		Tax (Expense) Benefit (8)		After-Tax		Before-Tax		Tax (Expense) Benefit (8)		After-Tax		AOCI		(Thousands of dollars)	Before-Tax		Tax (Expense) Benefit (8)		After-Tax		Before-Tax		Tax (Expense) Benefit (8)		After-Tax		AOCI
Beginning Balance AOCI December 31, 2020	Beginning Balance AOCI December 31, 2020	$	(77,720)	$	18,653	$	(59,067)	$	(2,719)	$	651	$	(2,068)	$	(61,135)	Beginning Balance AOCI December 31, 2020	$	(77,720)	$	18,653	$	(59,067)	$	(2,719)	$	651	$	(2,068)	$	(61,135)
FSIRS amount reclassified from AOCI (5)	FSIRS amount reclassified from AOCI (5)	—		—		—		544		(131)		413		413		FSIRS amount reclassified from AOCI (5)	—		—		—		1,632		(392)		1,240		1,240
Amortization of prior service cost (6)	Amortization of prior service cost (6)	240		(58)		182		—		—		—		182		Amortization of prior service cost (6)	719		(172)		547		—		—		—		547
Amortization of net actuarial loss (6)	Amortization of net actuarial loss (6)	11,149		(2,675)		8,474		—		—		—		8,474		Amortization of net actuarial loss (6)	33,448		(8,028)		25,420		—		—		—		25,420
Regulatory adjustment (7)	Regulatory adjustment (7)	(9,575)		2,298		(7,277)		—		—		—		(7,277)		Regulatory adjustment (7)	(28,725)		6,894		(21,831)		—		—		—		(21,831)
Net current period other comprehensive income attributable to Southwest Gas Corporation	Net current period other comprehensive income attributable to Southwest Gas Corporation	1,814		(435)		1,379		544		(131)		413		1,792		Net current period other comprehensive income attributable to Southwest Gas Corporation	5,442		(1,306)		4,136		1,632		(392)		1,240		5,376
Ending Balance AOCI March 31, 2021		$	(75,906)	$	18,218	$	(57,688)	$	(2,175)	$	520	$	(1,655)	$	(59,343)
Ending Balance AOCI September 30, 2021																Ending Balance AOCI September 30, 2021	$	(72,278)	$	17,347	$	(54,931)	$	(1,087)	$	259	$	(828)	$	(55,759)

(5) The FSIRS reclassification amount is included in Net interest deductions on Southwest’s Condensed Consolidated Statements of Income.

(6)These AOCI components are included in the computation of net periodic benefit cost (see Note 2 – Components of Net Periodic Benefit Cost for additional details).

(7)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 Southwest’s Condensed Consolidated Balance Sheets).

(8)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:


(Thousands of dollars)	(Thousands of dollars)	March 31, 2021		December 31, 2020		(Thousands of dollars)	September 30, 2021		December 31, 2020
Net actuarial loss	Net actuarial loss	$	(491,634)	$	(502,783)	Net actuarial loss	$	(469,335)	$	(502,783)
Prior service cost	Prior service cost	(2,247)		(2,487)		Prior service cost	(1,768)		(2,487)
Less: amount recognized in regulatory assets	Less: amount recognized in regulatory assets	417,975		427,550		Less: amount recognized in regulatory assets	398,825		427,550
Recognized in AOCI	Recognized in AOCI	$	(75,906)	$	(77,720)	Recognized in AOCI	$	(72,278)	$	(77,720)


			25


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

Note 7 – Segment Information

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:

(Thousands of dollars) March 31, 2021 December 31, 2020
Centuri accounts receivable for services provided to Southwest $ 11,344 $ 13,956

The Company has 2 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.


(Thousands of dollars)	September 30, 2021		December 31, 2020
Centuri accounts receivable for services provided to Southwest	$	15,376	$	13,956

Utility infrastructure services total assets increased significantly since December 31, 2020, primarily due to Centuri’s acquisition of Riggs Distler (see Note 8 - Business Acquisitions), as follows:


(Thousands of dollars)	September 30, 2021		December 31, 2020
Centuri segment assets	$	2,671,974	$	1,475,237


			28


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

In order to reconcile (below) to net income as disclosed in the Condensed 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 is as follows:


(Thousands of dollars)	(Thousands of dollars)	Natural Gas Operations		Utility Infrastructure Services		Other		Total		(Thousands of dollars)	Natural Gas Operations		Utility Infrastructure Services		Other		Total
Three Months Ended March 31, 2021
Three Months Ended September 30, 2021										Three Months Ended September 30, 2021
Revenues from external customers	Revenues from external customers	$	521,932	$	339,772	$	—	$	861,704	Revenues from external customers	$	255,848	$	606,006	$	—	$	861,854
Intersegment revenues	Intersegment revenues	0		24,203		—		24,203		Intersegment revenues	—		26,842		—		26,842
Total	Total	$	521,932	$	363,975	$	—	$	885,907	Total	$	255,848	$	632,848	$	—	$	888,696
Segment net income (loss)	Segment net income (loss)	$	118,715	$	(859)	$	(563)	$	117,293	Segment net income (loss)	$	(27,544)	$	18,540	$	(2,572)	$	(11,576)

Three Months Ended March 31, 2020
Three Months Ended September 30, 2020										Three Months Ended September 30, 2020
Revenues from external customers	Revenues from external customers	$	502,827	$	300,291	$	—	$	803,118	Revenues from external customers	$	210,834	$	548,300	$	—	$	759,134
Intersegment revenues	Intersegment revenues	0		33,202		—		33,202		Intersegment revenues	—		32,092		—		32,092
Total	Total	$	502,827	$	333,493	$	—	$	836,320	Total	$	210,834	$	580,392	$	—	$	791,226
Segment net income (loss)	Segment net income (loss)	$	83,599	$	(10,204)	$	(853)	$	72,542	Segment net income (loss)	$	(15,973)	$	34,873	$	(627)	$	18,273

(Thousands of dollars)										(Thousands of dollars)	Natural Gas Operations		Utility Infrastructure Services		Other		Total
Nine Months Ended September 30, 2021										Nine Months Ended September 30, 2021
Revenues from external customers										Revenues from external customers	$	1,070,576	$	1,450,719	$	—	$	2,521,295
Intersegment revenues										Intersegment revenues	—		74,729		—		74,729
Total										Total	$	1,070,576	$	1,525,448	$	—	$	2,596,024
Segment net income (loss)										Segment net income (loss)	$	102,584	$	32,797	$	(4,545)	$	130,836

Nine Months Ended September 30, 2020										Nine Months Ended September 30, 2020
Revenues from external customers										Revenues from external customers	$	976,095	$	1,306,481	$	—	$	2,282,576
Intersegment revenues										Intersegment revenues	—		102,217		—		102,217
Total										Total	$	976,095	$	1,408,698	$	—	$	2,384,793
Segment net income (loss)										Segment net income (loss)	$	79,568	$	50,936	$	(1,724)	$	128,780


(Thousands of dollars)	(Thousands of dollars)	Natural Gas Operations		Utility Infrastructure Services		Other		Total		(Thousands of dollars)	Natural Gas Operations		Utility Infrastructure Services		Other		Total
Twelve Months Ended March 31, 2021
Twelve Months Ended September 30, 2021										Twelve Months Ended September 30, 2021
Revenues from external customers	Revenues from external customers	$	1,369,690	$	1,852,910	$	—	$	3,222,600	Revenues from external customers	$	1,445,066	$	1,957,667	$	—	$	3,402,733
Intersegment revenues	Intersegment revenues	0		125,860		—		125,860		Intersegment revenues	—		107,371		—		107,371
Total	Total	$	1,369,690	$	1,978,770	$	—	$	3,348,460	Total	$	1,445,066	$	2,065,038	$	—	$	3,510,104
Segment net income (loss)	Segment net income (loss)	$	194,234	$	84,207	$	(1,366)	$	277,075	Segment net income (loss)	$	182,134	$	56,723	$	(4,477)	$	234,380

Twelve Months Ended March 31, 2020
Twelve Months Ended September 30, 2020										Twelve Months Ended September 30, 2020
Revenues from external customers	Revenues from external customers	$	1,351,089	$	1,618,354	$	—	$	2,969,443	Revenues from external customers	$	1,355,666	$	1,738,430	$	—	$	3,094,096
Intersegment revenues	Intersegment revenues	0		153,255		—		153,255		Intersegment revenues	—		138,834		—		138,834
Total	Total	$	1,351,089	$	1,771,609	$	—	$	3,122,698	Total	$	1,355,666	$	1,877,264	$	—	$	3,232,930
Segment net income (loss)	Segment net income (loss)	$	143,381	$	50,231	$	(1,943)	$	191,669	Segment net income (loss)	$	155,993	$	66,615	$	(2,110)	$	220,498


			2629


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

Note 8 - Business Acquisitions

On August 27, 2021, the Company, through its subsidiaries, led principally by Centuri, completed the acquisition of a privately held regional infrastructure services business, Drum Parent, Inc. (“Drum”), for $830.4 million in cash consideration, and also assumed a long-term financing lease obligation. Drum, and its primary subsidiary Riggs Distler & Company, Inc. (“Riggs Distler”), are now wholly owned subsidiaries of the Company.

The acquisition extended the utility services operations in the northeastern region of the U.S. and provides additional opportunities for expansion of the amount of work Centuri performs for electric and gas utilities. Funding for the acquisition was provided by proceeds from Centuri’s new term loan facility, as described in Note 5 – Debt.

The Company is currently performing a detailed valuation analysis of the assets and liabilities of the acquired company, which was substantially completed during the third quarter of 2021. Certain payments were estimated as of the acquisition date and will be adjusted when paid. The necessary analysis will consider acquired intangibles (including customer relationships, trademarks, and backlog). Based on preliminary results, a substantial portion of the purchase price will be allocated to goodwill and other finite-lived intangible assets.

Assets acquired and liabilities assumed in the transaction were recorded at their acquisition date fair values. Transaction costs associated with the acquisition were expensed as incurred. The Company’s allocation of the purchase price was based on an evaluation of the appropriate fair values and represented management’s best estimate based on available data (including market data, data regarding customers of the acquired businesses, terms of acquisition-related agreements, analysis of historical and projected results, and other types of data). The analysis included consideration of types of intangibles that were acquired, including those indicated above. The gross contractual receivable is $81 million, exclusive of $12 million representing specific customer accounts that were deemed uncollectible. Of the $12 million, any amounts subsequently collected prior to December 31, 2021 would pass to the sellers. Due to the estimations made, the final purchase accounting has not yet been completed. Further refinement is expected to occur, including potential changes to income taxes, fixed assets, and intangibles.

The preliminary estimated fair values of assets acquired and liabilities assumed as of August 27, 2021, are as follows (in millions of dollars):


Cash and cash equivalents	$	1.9
Accounts receivable	69.1
Contract assets	40.1
Income taxes receivable, net	0.7
Right of use assets under operating leases	1.5
Prepaid expenses	5.2
Property and equipment	118.1
Intangible assets	335.0
Goodwill	446.8
Total assets acquired	1,018.4

Trade and other payables	46.2
Finance lease obligations	27.5
Contract liabilities	12.7
Operating lease obligations	1.5
Other liabilities	5.3
Deferred tax liabilities	94.8
Total liabilities assumed	188.0
Net assets acquired	$	830.4


			30


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

The amounts allocated to major classes of intangibles are as follows:


(Thousands of dollars)	Estimated fair Value		Estimated Weighted Average Useful Life in Years
Backlog	$	5,000	1
Trade names	60,000		15
Customer relationships	270,000		19
	$	335,000

The Company incurred and expensed acquisition costs of $14 million which were included in Utility infrastructure services expenses on the Company’s Condensed Consolidated Statement of Income. Acquisition-related costs of $13.2 million and $14 million were incurred during the three and nine months ended September 30, 2021, respectively.

The preliminary allocation of the purchase price of Drum was accounted for in accordance with applicable accounting guidance. Goodwill consists of the value associated with the assembled workforce, consolidation of operations, and the estimated economic value attributable to future opportunities related to the transaction. As the business of Drum was deemed a stock purchase for tax purposes, only pre-acquisition goodwill of $76 million that was historically tax-deductible by Riggs will continue to be deductible for tax purposes by the Company.

The following unaudited pro forma financial information reflects the consolidated results of operations of the Company assuming the acquisition had taken place on January 1, 2020. The most significant pro forma adjustments relate to: (i) reflecting approximately $30 million in transaction costs (incurred by Centuri and Riggs Distler) in the nine months ended September 30, 2020, and excluding such costs from the three and nine month periods ended September 30, 2021, and (ii) reflecting incremental interest expense related to the new loan facility of $7 million and $27 million in the three and nine month periods, respectively, ended September 30, 2021, and approximately $9 million and $24.5 million in the comparable periods in 2020. This information is preliminary in nature and subject to change based upon final purchase price adjustments. Amounts are in thousands of dollars, except per share amounts.


	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Total operating revenues	$	956,120	$	907,512	$	2,903,658	$	2,702,062
Net income (loss) attributable to Southwest Gas Holdings, Inc.	$	(8,918)	$	12,688	$	120,828	$	84,049
Basic earnings (loss) per share	$	(0.15)	$	0.23	$	2.06	$	1.51
Diluted earnings (loss) per share	$	(0.15)	$	0.23	$	2.06	$	1.51

Actual results from operations for Riggs Distler, excluding transaction costs and interest expense on acquisition related debt incurred by Centuri, included in the Consolidated Statements of Income since the date of acquisition are as follows (in thousands of dollars):


	Nine Months Ended September 30, 2021
Utility infrastructure services revenues	$	49,520
Net income attributable to Southwest Gas Holdings, Inc.	$	1,646


			31


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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.”

In October 2021, the Company entered into an agreement for the acquisition of Dominion Energy Questar Pipeline, LLC and related entities (“Questar Pipelines”), including an essential Rocky Mountain energy hub with 2,160-miles of highly contracted, FERC-regulated interstate natural gas pipelines providing transportation and underground storage services in Utah, Wyoming, and Colorado. The operations to be acquired would further diversify the Company’s business with an expansion of FERC-regulated interstate natural gas pipelines and underground storage services, thereby expanding transportation services into Utah, Wyoming, and Colorado. The Company plans to initially fund this acquisition with a new 364-day term loan, followed by permanent financing. The transaction is expected to be completed near year-end 2021. The acquisition remains subject to certain conditions and approvals, and we can provide no assurances that it will be completed within the anticipated timeline or at all. See Note 1 – Background, Organization, and Summary of Significant Accounting Policies for additional information.

On October 10, 2021, our Board of Directors (the “Board”) authorized and declared a dividend of one preferred stock purchase right for each share of common stock outstanding to stockholders of record at the close of business on October 21, 2021. See Note 4 – Common Stock.

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. Through its subsidiaries, Southwest operates two federally regulated interstate pipelines serving portions of the foregoing northern territories of Nevada and California.

As of ~~March 31,~~September 30, 2021, Southwest had ~~2,133,000~~2,147,000 residential, commercial, industrial, and other natural gas customers, of which ~~1,138,000~~1,146,000 customers were located in Arizona, ~~793,000~~799,000 in Nevada, and 202,000 in California. Over the past twelve months, first-time meter sets were approximately 37,000,, ~~compared to 36,000~~ the same as for the twelve months ended ~~March~~September 2020. ~~The remaining increase in active customer accounts compared~~In comparison to the ~~March 31,~~September 30, 2020 total of ~~2,091,000~~2,112,000 customers, there was ~~primarily due~~an offsetting decrease related to ~~a management-initiated~~management’s lifting its moratorium on ~~disconnections as a result~~disconnection of ~~the COVID-19 pandemic. As utility~~ service ~~is an essential service to the residents in the states in which~~for non-payment. Southwest ~~operates, it~~ implemented the moratorium in March 2020 and also ceased charging late ~~fees.~~fees due to the COVID-19 pandemic. Southwest recommenced assessing late fees in Nevada and Arizona in April 2021, ~~with~~and expects to recommence late fees in California ~~expected to recommence~~ in the ~~latter half~~fourth quarter of 2021. The ~~duration of our~~ moratorium on disconnections for non-payment was lifted in September 2021 for Arizona and Nevada. The moratorium continues to be in place for California, which is ~~currently uncertain.~~expected to be lifted in the fourth quarter 2021. ~~Residential~~Residential and small commercial customers represented over 99% of the total customer base. During the twelve months ended ~~March 31,~~September 30, 2021, 53% of operating margin (gas operating revenues less the net cost of gas sold) was earned in Arizona, ~~36%~~35% in Nevada, and ~~11%~~12% in California. During this same period, Southwest ~~earne~~earned d 85% of its operating margin from residential and small commercial customers, 3%4% from other sales customers, and ~~12% from~~11% from transportation customers. While these general patterns are expected to remain materially consistent for the foreseeable future, the continuing COVID-19 pandemic, as discussed further below, 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. Refer to the Summary Operating Results table below for a reconciliation of ~~revenues~~Gross margin to


			32


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

operating margin, and refer to 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 unusual weather variability and conservation on operating margin, allowing Southwest to pursue energy efficiency initiatives.


			27


~~SOUTHWEST GAS HOLDINGS, INC.~~ In June 2021, Centuri entered into an agreement for the acquisition of Drum Parent, Inc. (“Drum”) and its U.S. operations, consisting principally of the utility infrastructure services operations of Drum’s primary subsidiary, Riggs Distler, serving utility customers in the Northeast and Mid-Atlantic regions. The transaction was completed in August 2021. Information surrounding this acquisition can be found in Note 8 - Business Acquisitions.						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

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 projects throughout the U.S. Generally, Centuri revenues are lowest during the first quarter of the year due to less favorable winter weather 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 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 significantly impact operating results.

COVID-19 Pandemic

While the novel coronavirus (“COVID-19”) pandemic has been ongoing since the first quarter of 2020, management has remained focused on the impacts to local and U.S. economies, including the breadth of vaccine deployment, ~~and~~the level of ~~commerce re-opening.~~commerce/employment, as well as impacts from new virus variants on these economies. Our utility operations, as essential services, have been ongoing during this time and Southwest has continued 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, Centuri has continued 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 nonetheless be impacted by individuals contracting or being exposed to COVID-19, governmental requirements ~~to postpone the full resumption of certain non-essential services~~or restrictions 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~~some offices (including corporate headquarters) continue to work from home on a temporary ~~basis~~basis; Southwest has introduced plans for employees to begin returning to the office environment at the safest, most appropriate time, which is currently anticipated in the first quarter of 2022, while Centuri employees have resumed work in the office. At the same time, management is also focused on the need for adaptability in an environment of virus variants and ~~travel restrictions largely continue.~~governmental actions related thereto. Both segments continue to facilitate administration, communication, and all critical functions, supported by deployed ~~technology.~~technology whenever employees are working remotely. To date, there has not been a significant disruption in the Company’s supply chains, transportation network, or ability to serve customers.

As noted earlier, management ~~continues to have in place~~had a moratorium on natural gas disconnections for non-payment that was lifted in our Nevada and Arizona jurisdictions in the third quarter of 2021, with the expectation to lift the moratorium in California in the fourth quarter of 2021. Southwest continues to work with customers experiencing financial hardship through flexible payment arrangements. Management also continues to coordinate with certain governmental and nonprofit entities for customer payment assistance. 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 Accounts receivable, net of allowances in Note 1 – Background, Organization, and Summary of Significant Accounting Policies. In the utility infrastructure services segment, a limited number of Centuri customers at the outset of the pandemic delayed some projects, and crews were temporarily reduced; however, most work continued, while following appropriate government protocols. Some crew reductions are ongoing in specific areas; however, the associated revenue impacts have not been significant. Management continues to monitor these circumstances, the future impacts of which are not currently known, such as the impact from business curtailments, weak market conditions, or any restrictions that may limit the timing of fulfillment by Centuri of its contractual obligations.


			33


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

The extent to which COVID-19 may adversely impact the Company’s business depends on future developments, including the timing of full resumption of commerce across our service territories, the deployment of vaccines and population immunity, the state of local and North American economies, and impacts of these collective conditions on our customers, in addition to other unmitigated effects related to the ~~virus.~~virus and its variants. Management does not currently expect the impact of these conditions to be material to the Company’s liquidity or financial ~~position;~~position overall; however, continued uncertainty of economic and operational impacts means management cannot predict whether the related financial impact in future periods will be different from impacts reflected for the three, ~~three~~nine, and twelve months ended ~~March 31,~~September 30, 2021. In anticipation of a redeployment of employees to their normal work locations, management created a multi-phase reintegration plan to safeguard the well-being of our teams. Management will continue to monitor developments by government officials, and those affecting employees, customers, and operations, and will take additional steps as necessary to address impacts from the pandemic. Events and circumstances arising after ~~March 31,~~September 30, 2021, including those resulting from COVID-19, will be reflected in management’s estimates for future periods.

This Management’s Discussion and Analysis (“MD&A”) of Financial Condition and Results of Operations should be read in conjunction with the unaudited condensed consolidated financial statements and notes thereto included in this Quarterly Report on Form 10-Q and the audited financial statements and notes thereto, as well as MD&A, included in the 2020 Annual Report to Stockholders, which is incorporated by reference into the 2020 Form 10-K.


			28


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

Executive Summary

The items discussed in this Executive Summary are intended to provide an overview of the results of the Company’s and Southwest’s operations. As needed, certain items are covered in greater detail in later sections of MD&A. As reflected in the table below, the natural gas operations segment accounted for an ~~averag~~average of e 74%of ~~72%~~ of twelve-month-to-date consolidated net income over the past two years. Natural gas sales are seasonal, peaking during the winter months; therefore, results of operations for interim periods are not necessarily indicative of results for a full year.

Summary Operating Results


		Period Ended March 31,							Period Ended September 30,
		Three Months				Twelve Months						Three Months				Nine Months				Twelve Months
(In thousands, except per share amounts)	(In thousands, except per share amounts)	2021		2020			2021			2020			(In thousands, except per share amounts)	2021		2020		2021		2020		2021		2020
Contribution to net income	Contribution to net income												Contribution to net income
Natural gas operations	Natural gas operations	$	118,715	$	83,599		$	194,234		$	143,381		Natural gas operations	$	(27,544)	$	(15,973)	$	102,584	$	79,568	$	182,134	$	155,993
Utility infrastructure services	Utility infrastructure services	(859)		(10,204)			84,207			50,231			Utility infrastructure services	18,540		34,873		32,797		50,936		56,723		66,615
Corporate and administrative	Corporate and administrative	(563)		(853)			(1,366)			(1,943)			Corporate and administrative	(2,572)		(627)		(4,545)		(1,724)		(4,477)		(2,110)
Net income		$	117,293	$	72,542		$	277,075		$	191,669
Net income (loss)													Net income (loss)	$	(11,576)	$	18,273	$	130,836	$	128,780	$	234,380	$	220,498

Weighted average common shares	Weighted average common shares	57,600		55,310			56,564			54,726			Weighted average common shares	59,688		56,271		58,639		55,683		58,209		55,508
Basic earnings per share
Basic earnings (loss) per share													Basic earnings (loss) per share
Consolidated	Consolidated	$	2.04	$	1.31		$	4.90		$	3.50		Consolidated	$	(0.19)	$	0.32	$	2.23	$	2.31	$	4.03	$	3.97

Natural Gas Operations	Natural Gas Operations												Natural Gas Operations
Reconciliation of Revenue to Operating Margin (Non-GAAP measure)
Gas operating revenues		$	521,932	$	502,827		$	1,369,690		$	1,351,089
Less: Net cost of gas sold		156,021		160,821			338,037			353,381
Reconciliation of Gross Margin to Operating Margin (Non-GAAP measure)													Reconciliation of Gross Margin to Operating Margin (Non-GAAP measure)
Utility Gross Margin													Utility Gross Margin	$	62,681	$	57,188	$	392,190	$	354,854	$	566,065	$	524,010
Plus:													Plus:
Operations and maintenance (excluding Admin. & General) expense													Operations and maintenance (excluding Admin. & General) expense	68,098		61,383		194,471		182,761		255,434		244,573
Depreciation and amortization expense													Depreciation and amortization expense	61,359		55,942		187,688		173,865		249,118		230,158
Operating margin	Operating margin	$	365,911	$	342,006		$	1,031,653		$	997,708		Operating margin	$	192,138	$	174,513	$	774,349	$	711,480	$	1,070,617	$	998,741

~~1st~~


			34


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

3rd Quarter 2021 Overview

Natural gas operations highlights include the following:

•37,000 ~~first-time~~first-time meters s~~ets (1.8% growth rate)~~sets occurred over the past 12 months

•Operating margin increased ~~$24~~ $18 million

•C~~ompany-Owned Life Insurance (“COLI”) income was $2.7~~Issued $300 million in ~~the current quarter versus a loss of $15.5 million in the prior-year quarter~~

•~~Issued $250 million term loan due March 2022 to fund incremental gas costs~~

•~~California rate case finalized~~

3.18% 30-year Notes

Utility infrastructure services highlights include the following:

•Utility infrastructure services revenues increased ~~$30~~ $52 million, or ~~9.1%~~9%

•~~Supported customers with restoration services following winter freeze event ($9~~Completed the acquisition of Riggs Distler for $830 million ~~of incremental revenue)~~in August 2021

•~~Utility infrastructure services expenses increased $16~~$13 million ~~or 5.1%~~of acquisition costs incurred

•~~Realized $1.5~~Amended and restated credit agreement in connection with the Riggs Distler acquisition; $1.145 billion secured term loan facility and $400 million ~~in gains on sale of equipment~~secured revolving credit facility

Southwest Gas Holdings highlights include the following:

•~~Increased the quarterly dividend from $0.570~~Announced planned acquisition of Questar Pipelines for $1.545 billion in cash (subject to ~~$0.595 per share effective with the June 2021 payment~~certain adjustments) and assumption of approximately $430 million of existing long-term debt

•~~Received net proceeds of $46 million through equity shelf program issuances~~Authorized a preferred stock purchase right for each outstanding common share

•Amended and Restated Bylaws


			2935


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

Results of Natural Gas Operations

Quarterly Analysis


		Three Months Ended March 31,					Three Months Ended September 30,
(Thousands of dollars)	(Thousands of dollars)	2021		2020		(Thousands of dollars)	2021		2020
Gas operating revenues	Gas operating revenues	$	521,932	$	502,827	Gas operating revenues	$	255,848	$	210,834
Net cost of gas sold	Net cost of gas sold	156,021		160,821		Net cost of gas sold	63,710		36,321
Operating margin	Operating margin	365,911		342,006		Operating margin	192,138		174,513
Operations and maintenance expense	Operations and maintenance expense	106,135		103,088		Operations and maintenance expense	119,708		101,159
Depreciation and amortization	Depreciation and amortization	68,698		64,725		Depreciation and amortization	61,359		55,942
Taxes other than income taxes	Taxes other than income taxes	20,687		16,378		Taxes other than income taxes	20,109		15,787
Operating income		170,391		157,815
Operating income (loss)						Operating income (loss)	(9,038)		1,625
Other income (deductions)	Other income (deductions)	550		(20,536)		Other income (deductions)	(4,287)		1,751
Net interest deductions	Net interest deductions	22,166		25,058		Net interest deductions	24,922		26,103
Income before income taxes		148,775		112,221
Income tax expense		30,060		28,622
Contribution to consolidated net income		$	118,715	$	83,599
Loss before income taxes						Loss before income taxes	(38,247)		(22,727)
Income tax benefit						Income tax benefit	(10,703)		(6,754)
Contribution to consolidated results						Contribution to consolidated results	$	(27,544)	$	(15,973)

~~Improvements~~Contribution from natural gas operations ~~to consolidated net inco~~decreased $11.6 million betm~~e of $35 million occurred betwe~~ween the ~~first~~third quarters of 2021 and 2020. The ~~improvement~~decline was primarily due to ~~increases~~an increase in Operations and maintenance expense, higher Depreciation and amortization, and a decrease in Other income, offset by an increase in Operating ~~Margin and Other income.~~margin.

Operating margin increased ~~$24~~$18 million. Approximately $6$2 million of incremental margin was attributable to customer growth from 37,000 first-time meter sets during the last twelve ~~months, while rate~~months. Rate relief in Arizona, Nevada, and California added ~~$18~~$13 million of margin. ~~Offsetting these increases~~Also contributing to the increase were ~~impacts from~~late fees that were $1.5 million greater in the ~~temporary~~current quarter due to lifting the moratorium on ~~late~~such fees ~~initiated by Southwest~~ in Arizona and Nevada that had been in place since March ~~2020 ($2.6 million), in addition to lower connection/re-connection charges, as a result of the COVID-19 pandemic.~~2020. Amounts collected from and returned to ~~and collected from~~ customers associated with regulatory account balances, as well as differences in miscellaneous revenue and margin from customers outside the decoupling mechanisms, also impacted the variance between ~~periods.~~quarters.

Operations and maintenance expense increased $3$18.5 million ~~or 3%,~~ between quarters ~~primarily due to an~~reflecting a $5 million legal reserve (as described in Note 1 – Background, Organization, and Summary of Significant Accounting Policies), a $1.7 million increase in the service-related component of employee pension ~~cost~~costs, and $2.2 million of incremental temporary staffing, training, and stabilization costs associated with a new customer information system implemented in May 2021. In addition, the timing of vacation, other time-off, and miscellaneous employee benefits ~~increased~~resulted in an increase of $2.5 million when compared to the COVID-impacted third quarter of 2020. Increased expenditures for pipeline damage prevention programs, higher travel and ~~increased legal claim-related~~training costs, ~~offset by lower training~~ and ~~travel costs as a result of~~general cost increases were also recognized in the current ~~COVID-19 environment.~~quarter.

Depreciation and amortization expense increased $4$5.4 million, or 6%10%, between quarters, primarily due to a ~~$546~~$574 million, or 7%, increase in average gas plant in service compared to the corresponding quarter a year ~~ago.~~ago, including the replacement of the customer information system, which occurred in May 2021. Software/systems have shorter useful lives than pipeline assets. Amortization ofrelated to regulatory ~~program balances impacted expense~~account recoveries increased approximately $1.5 million between quarters and is also reflected as an increase in ~~both periods.~~Operating margin above. The increase in ~~gas~~ plant was attributable to pipeline capacity reinforcement w~~ork,~~work, franchise requirements, scheduled pipe replacement activities, and new infrastructure.

Taxes other than income taxes increased ~~$4.3~~$4 million between quarters primarily due to an increase in Arizona property taxes.

Other income ~~improved~~decreased ~~$21.1~~$6 million, ~~between quarters primarily due to an increase~~including a decline in income from COLI policies. The current quarter reflects ~~a $2.7 million increase~~no change in COLI policy cash surrender values, while the prior-year quarter reflected a ~~$15.5~~$4.5 million ~~decline in COLI policy cash surrender values.~~increase. These fluctuations primarily result from changes in the ~~values~~portion of ~~equity securities associated with~~ the cash surrender ~~values; changes in both quarters were~~values that are associated with equity securities, and are directionally consistent with the broader securities markets. ~~Additionally,~~Amounts associated with the allowance for funds used during construction (“AFUDC”) decreased $1.2 million in the current quarter compared to the prior year quarter due to an update to the assumptions related to the impact short-term borrowings have on AFUDC. Partially offsetting these combined impacts is a decrease in the non-service-related components of employee pension and other postretirement benefit costs ~~decreased $1.5 million~~ between ~~periods.~~quarters.

Net interest deductions decreased ~~$2.9~~$1 million i~~n the first~~in the third quarter of 2021, as compared to the prior-year quarter, primarily due

to ~~lower carrying costs on PGA balances and~~a decrease in the amortization of an interest-related regulatory balance in ~~Arizona, as well as lower interest rates associated with variable-rate debt.~~Arizona.

Income tax expense in both periods reflects that COLI results are recognized without tax consequences, and also reflects the amortization of excess accumulated deferred income tax (“EADIT”) balances.


			3036


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

Results of Natural Gas Operations

Nine-Month Analysis


	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
Gas operating revenues	$	1,070,576	$	976,095
Net cost of gas sold	296,227		264,615
Operating margin	774,349		711,480
Operations and maintenance expense	328,980		303,567
Depreciation and amortization	187,688		173,865
Taxes other than income taxes	60,134		47,507
Operating income	197,547		186,541
Other income (deductions)	(4,902)		(10,947)
Net interest deductions	71,263		75,152
Income before income taxes	121,382		100,442
Income tax expense	18,798		20,874
Contribution to consolidated net income	$	102,584	$	79,568

Contribution from natural gas operations to consolidated net income increased $23 million between the first nine months of 2021 and 2020. The increase was primarily due to an improvement in Operating margin and Other income (deductions) and a decline in Net interest deductions, offset by increases in Depreciation and amortization, Operations and maintenance expense, and Taxes other than income taxes.

Operating margin increased $62.9 million, including $10 million attributable to customer growth. Rate relief contributed an additional $46 million in operating margin. Late fees also increased (approximately $725,000), as the moratorium due to COVID was lifted and charges re-commenced, as described earlier. Residual impacts include those related to regulatory mechanisms, including recovery/return of regulatory program balances (primarily offset in amortization expense), in addition to margin from customers outside the decoupling mechanisms.

Operations and maintenance expense increased $25.4 million, or 8%, between periods, including a $5 million legal reserve in the third quarter of 2021 and a $5 million increase in the service-related component of pension cost. Other increases include expenditures for pipeline integrity management and damage prevention programs associated with a growing infrastructure and customer base, and increases in customer service-related and information technology costs.

Depreciation and amortization expense increased $13.8 million, or 8%, between periods primarily due to a $557 million, or 7%, increase in average gas plant in service between periods. The increase in plant was attributable to pipeline capacity reinforcement work, franchise requirements, scheduled pipe replacement activities, and new infrastructure, as well as the implementation of the customer information system in May 2021. Recoveries associated with regulatory program balances, as noted above, resulted in a $3 million increase in amortization expense compared to the first nine months of 2020.

Taxes other than income taxes increased $12.6 million between periods primarily due to an increase in property taxes in Arizona, and to a lesser extent, in the California and Nevada jurisdictions.

Other income (deductions) improved $6 million overall between periods. The current period reflects $5.8 million in income from the combined effects of an increase in COLI policy cash surrender values and recognized death benefits, while the prior-year period reflected $1 million in COLI-related income. The non-service cost components of employee pension and other postretirement benefit costs were $4.5 million lower between periods. Lower equity AFUDC partially offset the improvements in the current period.

Net interest deductions decreased $3.9 million between periods primarily due to amortization of an interest-related regulatory balance in Arizona.

The income tax amount in both quarters includes the amortization of Excess Accumulated Deferred Income Tax (“EADIT”) balances and the impacts of COLI cash surrender value increases, which are recognized without tax consequences.


			37


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

Results of Natural Gas Operations

Twelve-Month Analysis


		Twelve Months Ended March 31,					Twelve Months Ended September 30,
(Thousands of dollars)	(Thousands of dollars)	2021		2020		(Thousands of dollars)	2021		2020
Gas operating revenues	Gas operating revenues	$	1,369,690	$	1,351,089	Gas operating revenues	$	1,445,066	$	1,355,666
Net cost of gas sold	Net cost of gas sold	338,037		353,381		Net cost of gas sold	374,449		356,925
Operating margin	Operating margin	1,031,653		997,708		Operating margin	1,070,617		998,741
Operations and maintenance expense	Operations and maintenance expense	409,429		419,720		Operations and maintenance expense	431,795		406,169
Depreciation and amortization	Depreciation and amortization	239,268		222,733		Depreciation and amortization	249,118		230,158
Taxes other than income taxes	Taxes other than income taxes	67,769		62,500		Taxes other than income taxes	76,087		63,195
Operating income	Operating income	315,187		292,755		Operating income	313,617		299,219
Other income (deductions)	Other income (deductions)	14,496		(16,965)		Other income (deductions)	(545)		(7,615)
Net interest deductions	Net interest deductions	98,256		96,985		Net interest deductions	97,259		100,115
Income before income taxes	Income before income taxes	231,427		178,805		Income before income taxes	215,813		191,489
Income tax expense	Income tax expense	37,193		35,424		Income tax expense	33,679		35,496
Contribution to consolidated net income	Contribution to consolidated net income	$	194,234	$	143,381	Contribution to consolidated net income	$	182,134	$	155,993

Contribution to consolidated net income from natural gas ~~operatio~~nsoperations increased ~~$51~~ $26 million between the twelve-month periods ended ~~March~~September 2021 and 2020. TheThe increase waswas due primarily ~~due~~ to an increase in Operating margin and Other ~~income.~~income, offset by increases in Operations and maintenance expense, Depreciation and amortization, and Taxes other than income taxes.

Operating margin increased ~~$34~~$72 million be~~tween~~between periods. ~~Customer~~Customer growth provided ~~$15~~ $13 million, and combined rate relief provided ~~$24~~$52 million of incremental operating margin. ~~The~~Offsetting these impacts was a reduction in late fees ($817,000) due to the pandemic-period moratorium on ~~late~~these fees ~~($7.3 million)~~from March 2020 through March 2021 (resuming in Arizona and ~~lower connection/re-connection charges offset the improvements.~~Nevada in April 2021). Regulatory account balance ~~return and~~ return/recoveries impacted both periods, in addition to margin from customers outside the decoupling mechanisms.

Operations and maintenance expense ~~decreased $10.3~~increased $26 million, or 2%6%, between periods primarily due to ~~lower travel and in-person training~~higher legal-claim related costs ~~in the current COVID-19 environment and due to other cost saving initiatives by management. These were partially offset by incremental~~as noted earlier, higher levels of service-related pension costs ($7.3 million), expenditures for pipeline damage prevention programs associated with a growing infrastructure and customer base, increased customer-related and ~~by increases in~~ information technology ~~costs.~~costs, and higher reserves for customer accounts deemed uncollectible.

Depreciation and amortization expense increased ~~$16.5~~$19 million, or 7%8%, between periods primarily due to a ~~$634~~$579 million, or 8%7%, increase in average gas plant in service since the corresponding period in the prior year ~~offset by~~ and due to a ~~modest~~ $3.8 million increase~~decrease~~ in regulatory ~~amortization~~.account amortization.

Taxes other than income taxes increased ~~$5.3~~$12.9 million ~~between~~between periods primarily ~~due~~due to an increase in property taxes in Arizona, and to a lesser extent, in Southwest’s California and Nevada jurisdictions.

Other income increased ~~$31.5~~$7.1 million between the twelve-month periods of 2021 and 2020, primarily due to a current-period ~~$27.4~~$14 million increase in COLI policy cash surrender values and recognized death benefits, ~~while~~compared to the twelve months ended ~~March 31,~~September 30, 2020, which reflected a ~~$5.7~~$7.2 million ~~decline. Offsetting these amounts were lower interest earned on regulatory balances and an increase in~~ increase. The non-service ~~related~~cost components of ~~post-retirement~~employee pension and other postretirement benefit ~~cost.~~costs were $3.3 million lower between periods, which was offset by lower equity AFUDC.

Net interest deductions ~~increased $1.3~~decreased $2.9 million between periods primarily due to ~~interest associated with~~decreases in the ~~issuance of $450 million of Senior Notes in June 2020, offset by~~ amortization of an interest-related regulatory balance in ~~Arizona and a reduction in interest rates on variable-rate debt.~~Arizona.

Income tax expense in both periods reflects that COLI results are recognized without tax consequences, and also reflects the amortization of EADIT balances.


			3138


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

Results of Utility Infrastructure Services

Quarterly Analysis


		Three Months Ended March 31,					Three Months Ended September 30,
(Thousands of dollars)	(Thousands of dollars)	2021		2020		(Thousands of dollars)	2021		2020
Utility infrastructure services revenues	Utility infrastructure services revenues	$	363,975	$	333,493	Utility infrastructure services revenues	$	632,848	$	580,392
Operating expenses:	Operating expenses:					Operating expenses:
Utility infrastructure services expenses	Utility infrastructure services expenses	335,614		319,314		Utility infrastructure services expenses	567,270		502,951
Depreciation and amortization	Depreciation and amortization	24,744		22,928		Depreciation and amortization	30,021		24,197
Operating income (loss)		3,617		(8,749)
Operating income						Operating income	35,557		53,244
Other income (deductions)	Other income (deductions)	(102)		(242)		Other income (deductions)	1,175		48
Net interest deductions	Net interest deductions	1,622		2,899		Net interest deductions	6,257		2,000
Income (loss) before income taxes		1,893		(11,890)
Income tax expense (benefit)		1,200		(2,149)
Net income (loss)		693		(9,741)
Income before income taxes						Income before income taxes	30,475		51,292
Income tax expense						Income tax expense	9,653		13,629
Net income						Net income	20,822		37,663
Net income attributable to noncontrolling interest	Net income attributable to noncontrolling interest	1,552		463		Net income attributable to noncontrolling interest	2,282		2,790
Contribution to consolidated net income attributable to Centuri		$	(859)	$	(10,204)
Contribution to consolidated results attributable to Centuri						Contribution to consolidated results attributable to Centuri	$	18,540	$	34,873

Utility infrastructure services revenues increased ~~$30.5~~$52.5 million in the ~~first~~third quarter of 2021 when compared to the prior-year quarter, ~~primarily due~~including $49.5 million from Riggs Distler subsequent to ~~incremental~~the August 27, 2021 acquisition date. Revenues specific to electric infrastructure ~~revenues of $21.6 million from expansion of~~services work with existing customers and securing work with new customers. Included in the incremental electric infrastructure revenues during the first quarter of 2021 was $9 million from emergency restoration services performed by Linetec following tornados and ice storms primarily in Texas. The remaining increase in revenue was attributable to favorable weather in several areas and customer scheduling, which allowed bid projects to be completed during an otherwise seasonally slow period.

~~Utility infrastructure services expenses~~ increased ~~$16.3~~ $40.1 million in the ~~first~~third quarter of 2021 when compared to the prior-year quarter, ~~primarily due~~of which $34.1 million related to ~~costs~~Riggs Distler. Included in electric services revenues overall was $45.7 million from emergency restoration services performed by Linetec and Riggs Distler following hurricane, tornado, and other storm damage to ~~complete additional electric~~customers’ above-ground utility infrastructure in and ~~gas infrastructure work. Operating efficiencies improved due~~around the Gulf Coast and eastern regions of the U.S., compared to ~~favorable weather conditions and reduced COVID-19 restrictions from~~$48.7 million in the third quarter of the prior ~~year. Additionally, changes~~year in ~~mix of work resulted in lower subcontractor expenses as a percentage of revenues, which contributed~~regard to ~~increased operating income.~~Linetec. 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. Partially offsetting the improved revenues overall was reduced work with two significant gas infrastructure services customers during the third quarter of 2021 (totaling $17.1 million), due to timing and mix of projects under each customer’s multi-year capital spending programs.

Utility infrastructure services expenses increased $64.3 million (including $13 million of professional fees related to the acquisition of Riggs Distler) in the third quarter of 2021, compared to the prior-year quarter, and also included $42.4 million in expenses (including storm-related) recorded by Riggs Distler subsequent to the acquisition, as well as other incremental costs related to electric infrastructure services (inclusive of storm-related work) and costs necessary for the completion of additional gas infrastructure work. Higher fuel costs and equipment rental expense were also incurred due to the mix of work and in support of growth in our electric infrastructure business. Included in total Utility infrastructure services expenses were general and administrative costs, which increased ~~$3.3~~approximately $18 million ~~in 2021 compared~~between comparative periods, including $13 million of professional fees previously noted, $3 million of other administrative costs incurred by Riggs Distler subsequent to ~~2020, associated primarily with~~the acquisition, and other costs resulting from general growth ofin the business. ~~Gains~~The reduction in revenues with two large customers, as noted earlier, resulted in an unfavorable impact on ~~sale of equipment in~~profit margins during the ~~first~~third quarter of 2021, ~~(reflected as an~~due to reduced operating efficiencies from equipment and facility utilization and under-absorption of other fixed costs.

Other income increased $1.1 million between quarters attributable to proceeds from life insurance policies of $1.7 million, partially offset ~~to Utility infrastructure services expenses)~~by $700,000 of unamortized loan fees that were ~~$1.5 million.~~expensed in connection with Centuri’s debt refinancing.

Depreciation and amortization e~~xpen~~xpseense increased ~~$1.8~~$5.8 million between quarters, of which $4.7 million was recorded by Riggs Distler subsequent to the acquisition. The remaining increase was attributable to equipment and computer systems purchased to support the growing ~~business, primarily at Linetec. Depreciation expense, relative to the revenues recorded, was generally consistent between periods.~~volume of infrastructure work.

The increase in Net interest deductions ~~decreased $1.3~~of $4.3 million ~~between quarters~~ was primarily due to ~~lower~~ incremental ~~borrowing rates associated with decreased~~interest related to outstanding borrowings under Centuri’s ~~$590 million~~$1.545 billion amended and restated secured revolving credit and term loan ~~facility.~~facility in conjunction with the acquisition of Riggs Distler.

Income tax expense decreased $4 million between quarters, primarily due to reduced profitability in 2021. Certain costs related to the Riggs Distler acquisition were non-deductible for U.S. federal income tax purposes, impacting the recorded Income tax expense during the third quarter of 2021.


			3239


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

Results of Utility Infrastructure Services

Nine-Month Analysis


	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
Utility infrastructure services revenues	$	1,525,448	$	1,408,698
Operating expenses:
Utility infrastructure services expenses	1,381,524		1,252,489
Depreciation and amortization	79,982		71,144
Operating income	63,942		85,065
Other income (deductions)	927		(107)
Net interest deductions	9,511		7,138
Income before income taxes	55,358		77,820
Income tax expense	17,372		21,715
Net income	37,986		56,105
Net income attributable to noncontrolling interest	5,189		5,169
Contribution to consolidated net income attributable to Centuri	$	32,797	$	50,936

Utility infrastructure services revenues increased $116.8 million in the first nine months of 2021 when compared to the same period in the prior year primarily due to incremental electric infrastructure revenues of $64.1 million. Included in the incremental electric infrastructure revenues during the first nine months of 2021 was $57.9 million from emergency restoration services performed by Linetec and Riggs Distler following hurricane, tornado, and other storm damage to customers’ above-ground utility infrastructure in and around the Gulf Coast and eastern regions of the U.S., compared to $55.9 million in the first nine months of the prior year in regard to Linetec. The remaining increase in revenues was attributable to increased work under existing master service agreements and bid projects for gas infrastructure services in the central and eastern U.S. regions and Canada, partially offset by reduced work with two significant customers ($61.1 million) during the first nine months of 2021, due to the timing and mix of projects under each customer’s multi-year capital spending programs.

Utility infrastructure services expenses increased $129 million (including $14 million of acquisition costs) in the first nine months of 2021 as compared to the same period in 2020, primarily due to costs to complete additional electric and gas infrastructure work. Operating efficiencies during the first nine months of 2021 from favorable weather conditions were offset by higher fuel, equipment rental, payroll, and subcontractor costs caused by changes in the mix of work and continued growth in our electric infrastructure business. The significant reduction in revenues with two large customers noted above, resulted in an unfavorable impact on profit margins during the first nine months of 2021, due to reduced operating efficiencies from equipment and facility utilization and under-absorption of other fixed costs. Centuri recognized $2.5 million in wage and rent subsidies from the Canadian government amidst the COVID-19 environment during 2021, compared to $4.1 million in the prior nine-month period, in each case, recorded as a reduction in Utility infrastructure services expense. Included in total Utility infrastructure services expenses were general and administrative costs, which increased $21.9 million in 2021 compared to 2020, associated with growth of the business (including $14 million of professional fees related to the acquisition of Riggs Distler and $3 million of administrative costs incurred by Riggs Distler subsequent to the acquisition). Gains on sale of equipment (reflected as an offset to Utility infrastructure services expenses) were approximately $5.4 million and $600,000 in the nine-month periods in 2021 and 2020, respectively.

Depreciation and amortization expense increased approximately $8.8 million between periods, of which $4.7 million was recorded by Riggs Distler subsequent to the acquisition. The remaining increase was attributable to equipment and computer systems purchased to support the growing volume of infrastructure work.

The increase in Net interest deductions of $2.4 million was due to incremental interest from outstanding borrowings under Centuri’s $1.545 billion amended and restated secured revolving credit and term loan facility discussed earlier, partially offset by lower interest from lower borrowings in 2021 compared to 2020 on Centuri’s facility prior to the 2021 refinancing.

Income tax expense in 2021 was impacted by the combined effects of reduced profitability and certain non-deductible costs related to the Riggs Distler acquisition in 2021.


			40


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

Results of Utility Infrastructure Services

Twelve-Month Analysis


		Twelve Months Ended March 31,					Twelve Months Ended September 30,
(Thousands of dollars)	(Thousands of dollars)	2021		2020		(Thousands of dollars)	2021		2020
Utility infrastructure services revenues	Utility infrastructure services revenues	$	1,978,770	$	1,771,609	Utility infrastructure services revenues	$	2,065,038	$	1,877,264
Operating expenses:	Operating expenses:					Operating expenses:
Utility infrastructure services expenses	Utility infrastructure services expenses	1,745,729		1,592,076		Utility infrastructure services expenses	1,858,464		1,671,478
Depreciation and amortization	Depreciation and amortization	98,548		90,618		Depreciation and amortization	105,570		94,837
Operating income	Operating income	134,493		88,915		Operating income	101,004		110,949
Other income (deductions)	Other income (deductions)	(67)		(651)		Other income (deductions)	827		(210)
Net interest deductions	Net interest deductions	7,992		13,716		Net interest deductions	11,642		10,710
Income before income taxes	Income before income taxes	126,434		74,548		Income before income taxes	90,189		100,029
Income tax expense	Income tax expense	34,477		21,718		Income tax expense	26,785		28,057
Net income	Net income	91,957		52,830		Net income	63,404		71,972
Net income attributable to noncontrolling interest	Net income attributable to noncontrolling interest	7,750		2,599		Net income attributable to noncontrolling interest	6,681		5,357
Contribution to consolidated net income attributable to Centuri	Contribution to consolidated net income attributable to Centuri	$	84,207	$	50,231	Contribution to consolidated net income attributable to Centuri	$	56,723	$	66,615

Utility infrastructure services revenues increased ~~$207.2~~$187.8 million, or ~~12%~~10%, in the current twelve-month period compared to the corresponding period of 2020, primarily due to incremental electric infrastructure revenues of ~~$165.7~~$129.5 million from expansion of work with existing customers and securing work with new customers. Included in the incremental electric infrastructure revenues during the twelve-month period of 2021 was ~~$90.5~~$83.5 million from emergency restoration services performed by Linetec and Riggs Distler following hurricane, tornado, and other storm 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~~$55.9 million in ~~similar services during~~ the twelve-month period ~~in 2020.~~ of the prior year. Centuri’s revenues derived from storm-related services vary from period to period due to the unpredictable nature of weather-related events. The remaining increase in revenue was attributable to continued growth with existing gas infrastructure customers under master service and bid agreements.

Utility infrastructure services ~~expenses~~expenses increased ~~$153.7~~$187 million ~~between~~ (including $14 million of acquisition costs) between periods, largely due to incremental ~~expenses~~costs related to electric infrastructure work, ~~of $91.4 million,~~ including costs associated with storm restoration work overall and other costs incurred by Riggs Distler following its acquisition in August 2021, as well as costs ~~to complete~~necessary for the completion of additional gas ~~and electric~~ infrastructure work. ~~These costs were mitigated by increased productivity~~Storm restoration work typically generates a higher profit margin than core infrastructure services, due to improved operating efficiencies related to equipment utilization and ~~efficiencies in completing electrical infrastructure projects and by lower fuel costs as a percentage~~absorption of ~~revenues. Included~~fixed costs. Also included in Utility infrastructure services expenses were general and administrative costs, which increased ~~$26.1~~$30.5 million induring the twelve-month period ~~ended March~~in 2021 when compared to ~~the corresponding period ended March~~ 2020, due to $14 million in professional fees incurred related to Centuri’s acquisition of Riggs Distler, $3 million of costs incurred by Riggs Distler subsequent to the acquisition, higher payroll and operating costs associated with continued growth of the business, and higher profit-based incentive ~~compensation costs.~~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 ~~$3.3~~approximately $6.6 million and ~~$5.3~~$2.9 million for the twelve-month periods ofin 2021 and 2020, respectively.

Depreciation and amortization ~~expens~~eexpense increased ~~$7.9~~$10.7 million between the current and prior-year ~~period.~~twelve-month periods. The increase was primarily attributable to incremental costs related to electric infrastructure depreciation of $6.3 million, including $4.7 million from Riggs Distler. The remaining increase is attributable to ~~support the electric infrastructure work being performed,~~equipment and ~~to additional property and equipment purchased~~computer systems implemented to support the growing ~~business overall.~~volume of work being performed.

The increase in Net interest ~~deduction~~deductions of $932,000 w~~s decreased~~ as~~$5.7 million~~ be~~tween periods~~ primarily due to ~~lower~~ incremental ~~borrowing rates associated with decreased~~interest related to outstanding borrowings under Centuri’s ~~$590 million~~$1.545 billion amended and restated secured revolving credit and term loan ~~facility.~~

~~The income tax expense~~facility that was entered into during August 2021 in conjunction with the acquisition of Riggs Distler. This increase ~~between periods reflects~~was partially offset by lower interest associated with reduced borrowings in 2021, compared to the ~~increased level~~same period of ~~pre-tax earnings.~~2020, under Centuri’s credit facility existing prior to the 2021 refinancing.


			3341


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

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 changes (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.

Arizona Jurisdiction

Arizona General Rate Case. In May 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, incorporating the return of excess deferred income taxes to customers, and to reflect capital investments, including certain post-test year additions and the southern Arizona liquefied natural gas (“LNG”) facility. The application included a proposed 10.3% return on equity (“ROE”) relative to a capital structure of 51.1% equity. Southwest later updated its request multiple times, in order to reflect the actual amortization of ~~excess accumulated deferred income taxes (“EADIT”)~~EADIT resulting from U.S. tax reform and to include additional post-test year plant associated with its ~~customer-owned yard line~~Customer-owned Yard Line (“COYL”) and ~~vintage steel pipe~~ (“Vintage Steel Pipe (“VSP”) programs, ~~discussed further below. The amendment increased the deficiency by $36 million,~~and to ~~$93 million, which was further updated to $90.6 million based on~~reflect certain other aspects of cost of service, including a revised proposed ROE of 10.15%. The request and amendments 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 as part of its PGA mechanism. Southwest entered into a stipulation for certain aspects of the case, ~~agreeing to continue~~including continuing the COYL program; ~~to establish~~establishing 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~~including a 10-year amortization of EADIT associated with deemed “unprotected” plant; ~~and to incorporate~~addressing other aspects regarding EADIT; incorporating various tariff ~~proposals.~~proposals; and incorporating other ratemaking adjustments. 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. Following the hearing and the legal briefing process, ~~this requested amount was further~~the updated proposal reflected a request to increase rates by $80.7 ~~million to reflect agreements by the parties on the treatment of EADIT and certain other ratemaking adjustments.~~million.

A final decision was issued in December 2020, with new rates becoming effective in January 2021, resulting in an overall annual revenue increase of $36.8 million, and the continuation of both full revenue decoupling and the COYL program. The overall increase reflects the inclusion of six months (as compared to eleven months previously contemplated) of post-test year plant additions. 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 a six-month period covering certain post-test year plant additions, as well as the post-test year plant addition of the LNG facility.~~ See additional discussion related to ~~these~~the LNG facility, in addition to the COYL and VSP programs below. The continuation of the property tax tracker was supported in the final decision, as was the Tax Expense Adjustor Mechanism (noted above). While the RNG proposal was not approved as part of the decision, the ACC ~~agreed to conduct~~conducted a workshop in May 2021 to further explore the role of RNG in Arizona.

Delivery Charge Adjustment. The 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 (decoupling mechanism) amounts based on the balance at the end of the preceding calendar year. In April 2020, Southwest filed to adjust the existing rate to consider, instead, the ~~14-month period~~modest balance existing at the end 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 Commission Staff concurred with Southwest’s proposed rate,~~2020. Ultimately, the ACC ~~ultimately~~ elected to ~~reduce~~set 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~~For 2021, once again, the ~~remainder~~balance at the end of ~~2020 resulted in~~the preceding calendar year was a modest ~~under-collected~~positive balance, ~~at December 31, 2020, and~~but in an over-collected ~~balance of $9.5 million exists as of March 31, 2021.~~status by the time rates would be requested to be re-set. Therefore, the zero rate will be maintained until the next annual filing date.

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. The facility was placed in service in December 2019. The capital costs and the operating expenses associated with plant operation were considered and


			3442


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

distribution system. Southwest was ultimately granted approval for construction and deferral of costs. The facility was placed in service in December 2019. The capital costs and the operating expenses associated with plant operation were considered and approved as part of Southwest’s recently approved general rate case. ~~Due to the timing of the approximate~~Approximately $12 million in ~~operating~~ costs, incurred following the in-service date ~~a proposal to recover~~of the ~~associated~~facility and after the period considered as part of the recently concluded general rate case, were deferred in the previously authorized regulatory asset ~~balance~~and will be included for consideration in the next Arizona general rate case application.

COYL Program. Southwest originally 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. Annual surcharges ~~were~~are designed to collect the revenue requirement associated with the program. In a February 2019 filing, 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, while it reviewed the program as part of the general rate case. ~~Southwest also included an estimated $21.1 million related to the 2019 COYL capital projects as part of the rate case. Parties~~As indicated earlier, parties to the rate case stipulated to continue the COYL program and recommended recovery of ~~the~~certain plant as part of ~~Southwest’s filed~~a post-test year plant adjustment, with inclusion of related amounts in base rates. ~~Further consideration in the~~The ACC final rate case decision limited post-test year plant to six months (inclusive of COYL plant), 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 second quarter of~~May 2021 ~~will propose~~proposed the recovery of the remaining 2019 and 2020 revenue requirement associated with prior COYL program activity. The filing proposed the ~~2019 and 2020 COYL activity and plant placed in service following~~associated revenue requirement (approximately $13.7 million) be recovered over one year. In November 2021, the ~~six-month post-test year inclusion period of~~ACC approved full recovery over the ~~recently concluded~~proposed one-year timeline, with the associated rate ~~case.~~expected to be implemented during that same month.

VSP Program. ~~Southwest received approval, in connection with~~As part of a settlement agreement from its 2016 Arizona general rate case, Southwest received approval to implement a VSP replacement ~~program, due to having a substantial amount of pre-1970s vintage steel pipe in Arizona.~~program. As part of the program, Southwest proposed to begin replacing the pipe on an accelerated basis and recover the costs through an annual surcharge filing. Once implemented, surcharges to collect the annual revenue requirement associated with the capital expenditures were designed to be revised annually under the program. 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~~ACC’s October 2019 Order authorizing Southwest to retain the existing annual surcharge ~~and~~ indicated ~~it would review~~ the program would be subject to review 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 as part of the~~ rate case. As noted above, the decision in the most recent general rate case provided for a post-test year plant adjustment period of six months ~~(inclusive of~~(including for VSP). However, the ACC ultimately decided to discontinue the accelerated VSP program at this time. A filing in ~~the second quarter of~~May 2021 ~~will propose~~proposed the recovery of the otherwise unrecovered revenue requirement ~~associated~~(associated with ~~the~~years 2019 through 2022), related to VSP plant investment during 2019 and 2020, ~~VSP activity and plant placed in service following the six month post-test year inclusion period~~which was not included as part of the recently concluded rate case. The filing proposed the associated revenue requirement (approximately $60 million) be recovered over a three-year period. In November 2021, the ACC approved full recovery over the proposed three-year timeline, electing to permit the recovery rate to be implemented in March 2022.

Customer Data Modernization Initiative. Southwest embarked on an initiative to replace its customer ~~service~~information system and gas transaction systems, each to be utilized to support all Southwest service territories. Combined, these undertakings ~~are~~were referred to as the Customer Data Modernization Initiative (the “CDMI”). In March 2019, Southwest filed an application with the ACC seeking an accounting order to track and defer all costs associated with the CDMI to mitigate adverse financial implications associated with this multi-year initiative. The ~~commission~~ACC issued a decision in this matter in early April 2021 denying Southwest’s request for a regulatory asset, indicating that the requested recovery mechanism was not ~~warranted. Therefore,~~warranted, and that Southwest could, instead, seek to recover the costs ~~will be considered~~ as part of a future ~~general~~ rate ~~proceeding.~~case. The total ~~cost for the~~ CDMI ~~was~~costs were estimated at approximately $174 million, of which $96 million ~~of which~~ would be allocable to the Arizona rate jurisdiction. The customer ~~service~~information system was placed in service in May 2021.

Graham County Utilities. In April 2021, Southwest and Graham County Utilities, Inc. (“GCU”) filed a joint application with the ACC for approval to transfer assets of GCU to Southwest and extend Southwest’s Certificate of Public Convenience and Necessity to serve the associated customers. Approval of the application would provide for transfer of the natural gas system of GCU to Southwest for the purchase price of $3.5 million and the ~~gas transaction system will follow later~~addition of more than 5,000 customers. A decision is expected in the fourth quarter of 2021.

California Jurisdiction

California General Rate Case. In August 2019, Southwest filed a general rate case based on a 2021 test year, seeking authority to increase rates in its California rate jurisdictions, after being granted earlier permission to extend the rate case cycle by two years and continue its 2.75% previously approved Post-Test Year (“PTY”) attrition adjustments for 2019 and 2020. The proposed combined revenue increase of $12.8 million was net of a $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 would impact cash flows, but not expected to have an impact on earnings. Southwest tracked those amounts, as directed, and reserved them for return to customers.reform. 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. Sou~~thwest’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


			3543


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

each year until the amount is reset again later 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 general rate case,~~ which was unanimously approved by the ~~Commission~~CPUC on March 25, 2021, including 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~~ was associated with a North Lake Tahoe project that would not ultimately be completed by the beginning of 2021; consequently, the parties agreed to ~~remove it from the base rate increase and instead~~ provide for recovery of the cost of service impacts of the project through a future surcharge. The rate case decision ~~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. It also includes a cumulative ~~total of~~expenditures totaling $119 million over the five-year rate cycle to implement risk-informed proposals, consisting of the school COYL replacement, meter protection, and pipe replacement programs. Although new rates were originally anticipated to be in place by January 1, 2021, in light of an administrative delay, Southwest was granted authority to establish a general rate case memorandum account to track the ~~margin/revenue~~ impacts related to the delay in the implementation of new ~~rates. Such~~rates for purposes of later recovery. New rates were ultimately implemented April 1, 2021.

Attrition Filing. ~~Since Southwest’s~~Following the 2021 implementation of new rates approved as part of the recently concluded general rate case, ~~test year~~Southwest is ~~2021, there is no separate attrition increase for 2021; however, the~~also authorized to implement annual PTY attrition increases of 2.75% ~~will continue~~starting in ~~2022, as approved in the most recent rate case decision.~~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~~which has continued in ~~October 2018. Amounts distributed in April 2019 and 2020 were comparable.~~the current year. 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 renewable natural gas (or biomethane) as an includible component of Southwest’s gas supply portfolio through the Biomethane Gas Program (“BGP”). This proposal was 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 implications 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~~allowed 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~~was transferred to the two-way balancing account if approved. In January 2020, Southwest and the Public Advocates Office reached a settlement agreement to adopt Southwest’s Application and 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, 2020 was established and made effective September 1, 2020, ~~further~~ updated in January 2021, and ~~will~~updated further in August 2021. This rate is expected to be updated ~~annually thereafter each January.~~at least annually. As noted earlier, the customer information system, the largest of the two systems associated with the CDMI, was placed in service in May 2021.

Emergency Relief Program Related to COVID-19. In March 2020, in light of the COVID-19 pandemic, Southwest requested to establish a memorandum account to track costs as part of 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 requested 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 was originally effective March 4, 2020 through April 16, 2021, but was extended through June 30, 2021. These customer protections focus on flexible payment plan options, additional


			3644


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

related to COVID-19. The CPPMA was originally effective March 4, 2020 through April 16, 2021, but was extended through September 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. In June 2021, Southwest filed a Notice of Intent to file a general rate case, and on August 31, 2021 filed its most recent general rate case, which proposes a combined revenue increase of approximately $30.5 million. This request also proposes a return on common equity of 9.90% with a target equity ratio of 51%; a request to recover approximately $6.6 million in previously deferred late payment charges related to a regulatory asset associated with COVID-19 (as noted below); and a continuation of full-revenue decoupling with the General Revenues Adjustment (“GRA”) mechanism. The filing utilizes a May 31, 2021 test year with certification of certain adjustments through November 30, 2021. A decision is expected in the first quarter of 2022 with new rates effective April 2022.

Southwest’s previous general rate case application was filed 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).~~GRA mechanism. 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. The commissionPUCN issued its final order in September 2020, which provided for an authorized combined revenue increase of approximately $23 million for northern and southern Nevada and continuation of the ~~currently~~previously authorized 9.25% ROE, with a capital structure of 49.26% equity and 50.74% debt. Southwest’s ~~existing~~ GRA 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~~as well as full recovery of test year and certification operations and maintenance expenses associated with the ~~CDMI project.~~CDMI. Rates became effective in October 2020.

In association with ~~the previous~~an earlier Nevada rate case decision in December 2018, management requested reconsideration of several issues in the case; however, the PUCN ultimately granted no further ~~rate~~ relief. 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~~up to 24 months from the date of the appeal.

General Revenues Adjustment. ~~The~~As noted above, the continuation of the GRA was affirmed as part of Southwest’s ~~recently concluded~~previous general rate case, effective October ~~2020.~~2020, and a request to continue the GRA is included in the most recently filed general rate case request. 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. With timing changes approved in the most recent ARA, the next ARA filing will be made in November 2021 with a test year ended September 30, 2021. New rates related to that filing will be effective July 1, 2022. 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.

COYL Program. In August 2021, Southwest filed a joint petition with the Regulatory Operations Staff of the PUCN proposing a Nevada COYL replacement program to include residential COYLs, public schools, and any other COYLs that are identified to be a safety concern. The proposal contemplates capital investments of $5 million per year for five years, with $2 million allocated to northern Nevada and $3 million allocated to southern Nevada, and the establishment of a regulatory asset to track the capital- related costs. After five years, the program will be reassessed to determine if it should be continued. Southwest anticipates a decision by the end of the year.

RNG. In January 2021, Southwest filed an application seeking approval to purchase RNG for incorporation into its gas supply portfolio pursuant to Senate Bill 154 (2019). Southwest sought authority to purchase up to 3% of 2035 forecasted demands in an effort to reach the established legislative goals of 1% or more by 2025, 2% or more by 2030 and 3% or more by 2035. In October 2021, the PUCN issued an order authorizing Southwest to purchase up to 1.99% of annual forecasted demand each year between 2021 and year end 2029.

Infrastructure Replacement Mechanism. In 2014, the PUCN approved final rules for the GIR mechanism, which ~~defers~~provided for the deferral and ~~provides for~~ recovery of certain costs associated with accelerated replacement of qualifying infrastructure that would not otherwise ~~currently~~ provide incremental ~~revenues.~~revenues between general rate cases. Associated with the replacement of various types of pipe infrastructure under the mechanism (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,~~


			45


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

In cases where preapproval of projects is requested and granted, a GIR rate application is ~~generally~~separately 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 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.projects. On September 30, ~~2020,~~2021, Southwest filed its latest rate application to reset the recovery surcharge to include cumulative deferrals through August 31, ~~2020.~~2021. The updated surcharge rate is expected to result in ~~a reduction in~~an annual revenue decrease of approximately ~~$11.8~~$1.4 million in southern Nevada and ~~became effective~~an annual revenue increase of $66,000 in northern Nevada. A decision is expected in the fourth quarter 2021 with new rates anticipated January ~~2021.~~1, 2022.

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 in January 2021. In May 2021, Southwest filed its proposed Conservation and Energy Efficiency plan for the years 2022 – 2024, with a proposed annual budget amount of approximately $3 million. In October 2021, the PUCN approved the continuation of Southwest’s currently authorized commercial incentives program, residential incentives program and energy education with an annual budget of approximately $1.4 million.

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


			37


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

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~~expansion, including 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 facilities were placed in service in December 2020. A distribution loop, included in the initial estimated cost, is expected to be in service later this year.

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 was 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~~accepting 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. The expansion overall, as part of the earlier estimate, is anticipated to be completed in 2026.

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 the 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~~a decision in September 2019, denying Southwest’s request for regulatory asset treatment, finding a general rate case to be 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 approved~~its 2020 general rate case filing, Southwest was authorized to include CDMI operations and maintenance costs since the beginning of the associated test year as part of its revenue requirement in the case. The customer ~~service~~information system portion of the ~~project~~CDMI was placed in service in May 2021 and the ~~gas transaction system portion is expected to follow later~~related capital costs, as well as ongoing operations and maintenance expenses, are included in ~~2021.~~Southwest’s recent general rate case request.

Regulatory Asset Related to COVID-19. The PUCN issued an order directing utilities within the state to establish regulatory asset accounts, effective March 12, 2020, the date that Governor Steve Sisolak declared a state of emergency related to COVID-19, 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. These costs, ~~will be considered by the PUCN for future recovery.~~

~~FERC Jurisdiction~~

~~General Rate Case.~~ ~~Paiute Pipeline Company (“Paiute”), a wholly owned subsidiary of Southwest, filed a~~totaling approximately $6.6 million, are included in Southwest’s recent general rate case ~~with the FERC in May 2019. The filing fulfilled~~request and have a proposed two-year recovery period.

Proposed Carbon Offset Program. In June 2021, Southwest filed 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~~application to seek approval to offer a voluntary program to northern 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 storagesouthern Nevada customers to ~~extend their service agreements~~purchase carbon offsets in an effort 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 notprovide customers additional options 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.


			3846


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

reduce their respective GHG emissions. A request to establish a regulatory asset to track program-related costs and revenues was included as part of the application. A decision is expected in the first quarter of 2022.

FERC Jurisdiction

General Rate Case. Great Basin Gas Transmission Company (“Great Basin”), formerly Paiute Pipeline Company, 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 an earlier general rate case. In January 2020, an agreement in principle was reached with the FERC Staff and intervenors to settle the case, the results of which would not significantly impact revenues overall. The agreement required the three largest transportation customers and all storage customers to have primary terms remaining of at least five years under their agreements, provided for the continuance of term-differentiated rates generally, and included a 9.90% pre-tax rate of return. Interim rates were made effective February 2020, and in August 2020 a FERC letter order approving the settlement became final. As part of the settlement, it was agreed that a future rate case would not be filed prior to January 1, 2022, but would be filed no later than May 31, 2025.

PGA Filings

The rate schedules in all of Southwest’s service territories contain provisions that permit adjustment 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. Balances are recovered from or refunded to customers on an ongoing basis with interest. As of ~~March 31,~~September 30, 2021, under-collections in each of Southwest’s service territories resulted in an asset of ~~$238.9~~$240.8 million on the Company’s and Southwest’s Condensed Consolidated Balance Sheets. The significant change in the PGA balance was primarily due to incremental natural gas costs associated with an extreme weather event in the central U.S. in mid-February 2021. See also Deferred Purchased Gas Costs in Note 1 – Background, Organization, and Summary of Significant Accounting Policies in this quarterly report on Form 10-Q.

Filings to change rates in accordance with PGA clauses are subject to audit by state regulatory commission staffs. PGA changes impact cash flows but have no direct impact on ~~profit~~operating margin. However, gas cost deferrals and recoveries can impact comparisons between periods of individual consolidated income statement components. These include Gas operating revenues, Net cost of gas sold, Net interest deductions, and Other income (deductions).

The following table presents Southwest’s outstanding PGA balances receivable/(payable):


(Thousands of dollars)	(Thousands of dollars)	March 31, 2021		December 31, 2020		March 31, 2020		(Thousands of dollars)	September 30, 2021		December 31, 2020		September 30, 2020
Arizona	Arizona	$	194,446	$	(3,901)	$	(17,538)	Arizona	$	191,907	$	(3,901)	$	(14,674)
Northern Nevada	Northern Nevada	3,036		(8,601)		(3,154)		Northern Nevada	4,924		(8,601)		(12,724)
Southern Nevada	Southern Nevada	31,849		(42,134)		(2,585)		Southern Nevada	38,964		(42,134)		(45,506)
California	California	9,555		2,053		(3,221)		California	5,032		2,053		(3,338)
		$	238,886	$	(52,583)	$	(26,498)		$	240,827	$	(52,583)	$	(76,242)

Capital Resources and Liquidity

Historically, cash on hand and cash flows from operations have provided a substantial portion of cash used in investing activities (primarily for construction expenditures and property additions). In recent years, Southwest has undertaken significant pipe replacement activities to fortify system integrity and reliability, including on an accelerated basis in association with certain 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 endeavors to maintain an appropriate balance of equity and debt to preserve investment-grade credit ratings, which should minimize interest costs.

Cash Flows

Southwest Gas Holdings, Inc.:

Operating Cash Flows. Cash flows from consolidated operating activities decreased ~~$324~~$436 million in the first ~~three~~nine months of 2021 as compared to the same period of 2020. The decline in cash flows primarily resulted from amounts under purchased gas adjustment mechanisms, including amounts resulting from the temporary escalation in gas commodity prices during the first quarter of 2021 associated with the extreme cold temperatures in the central U.S. (see Note 1 – Background, Organization, and Summary of Significant Accounting Policies)~~, and also from~~. Other impacts include a decrease ($2545 million) in recoveries related to the Arizona decoupling mechanism balance between ~~three-month periods.~~nine-month periods, and the impact of changes in components of working capital overall.


			47


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

Investing Cash Flows. Cash used in consolidated investing activities ~~decreased~~ ~~$56~~increased $696 million in the first ~~three~~nine months of 2021 as compared to the same period of 2020. The change was primarily due to Centuri’s acquisition of Riggs Distler (see Note 8 - Business Acquisitions). The overall increase was offset by a decrease in capital expenditures in ~~both reportable segments.~~the natural gas operations segment.

Financing Cash Flows. Net cash provided by consolidated financing activities increased ~~$265 million~~$1.3 billion in the first ~~three~~nine months of 2021 as compared to the same period of 2020. The change was primarily due to Centuri, in association with the acquisition of Riggs Distler, entering into an amended and restated credit agreement. The agreement provided for a $1.145 billion secured term loan facility and a $400 million secured revolving credit facility, which in addition to ~~Southwest’s $250~~funding the Riggs Distler acquisition, refinanced the previous $590 million ~~Term Loan issued in~~loan facility. Approximately $1.26 billion was outstanding under the ~~first quarter~~combined facility as of ~~2021 to fund the increased cost of natural gas supply noted above during the extreme cold weather event.~~ September 30, 2021. Additionally, the Company issued ~~$46~~approximately $120 million more in common stock under its equity shelf ~~program~~programs in the first ~~three~~nine months of ~~2021. Other changes relate~~2021 compared to ~~borrowing and repayment activity related to the credit facilities between comparative periods in both segments, and proceeds from a $50 million equipment loan~~issuances in the ~~prior-year quarter.~~prior year, and also increased its dividend.

During the ~~three~~nine months ended ~~March 31,~~September 30, 2021, the Company also issued ~~49,500~~130,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan, raising approximately $8.5 million~~$3.1 million.~~.

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 external debt


			39


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

financing sources. However, the holding company may raise funds through stock issuances or other external financing sources. See Note 4 – Common Stock.

Southwest Gas Corporation:

Operating Cash Flows. Cash flows from operating activities decreased $~~354~~$382 million in the first ~~three~~nine months of 2021 as compared to the same period of 2020. The decline in operating cash flows was primarily attributable to the impacts related to deferred purchased gas costs and the Arizona decoupling mechanism noted ~~above.~~above, and other working capital changes.

Investing Cash Flows. Cash used in investing activities decreased ~~$44~~$110 million in the first ~~three~~nine months of 2021 as compared to the same period of 2020. The change was primarily due to a decrease in capital expenditures in ~~2021.~~2021 as compared the same period in the prior year. See also Gas Segment Construction Expenditures and Financing below.

Financing Cash Flows. Net cash provided by financing activities increased $~~304~~$372 million in the first ~~three~~nine months of 2021 as compared to the same period of 2020. The increase was primarily due to Southwest’s $250 million Term Loan issued in the first quarter of 2021 to fund the increased cost of natural gas supply ~~noted above related to~~during the extreme cold weather event. Additionally, Southwest issued $300 million in notes during the current period, compared to $450 million in notes issued in the ~~prior-year~~prior period, ~~Southwest had more repayment activity for the portion of its revolving~~and also redeemed $125 million in notes in September 2020 that were otherwise due in December 2020. Borrowings and repayments between periods under Southwest’s credit facility, ~~that is designated for working capital purposes.~~as well as and increase in dividends paid, comprised the remainder of the change. See Note 5 – Debt.

Gas Segment Construction Expenditures and Financing

During the twelve-month period ended ~~March 31,~~September 30, 2021, construction expenditures for the natural gas operations segment were ~~$647 million~~.$582 million. The majority of these expenditures represented costs associated with ~~scheduled and accelerated~~the replacement of existing transmission, distribution, and general ~~plant.~~plant (including costs to implement our customer information system).

Management estimates natural gas segment construction expenditures during the three-year period ending December 31, 2023 will be approximately ~~$2.1 billion~~.$2.1 billion. Of this amount, approximately ~~$700~~$650 million to $675 million is scheduled 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. See also Rates and Regulatory Proceedings. During the three-year period, cash flows from operating activities of Southwest are expected to provide approximately 50% of the funding for gas operations of Southwest and total construction expenditures and dividend requirements. Any additional cash requirements, including construction-related, and 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 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 and programs, as well as growth levels in Southwest’s service areas and earnings. External financings may include the issuance of debt securities, bank and other short-term borrowings, and other forms of financing.

~~In May 2019,~~


			48


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

As noted earlier, in August 2021, Southwest issued $300 million aggregate principal amount of 3.18% Senior Notes at a discount of 0.019%. The notes will mature in August 2051. Southwest used the ~~Company filed~~net proceeds from the offering to repay the outstanding balance under its credit facility, with the Securities and Exchange Commission (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 Company issued the remaining capacity ($46 million) under this equity program during the quarter ended March 31, 2021. During the twelve months ended March 31, 2021, 2,623,469 shares were issued in at-the-market offerings at an average price of $66.96 per share with gross proceeds of $175.7 million, agent commissions of $1.8 million, and net proceeds ~~of $173.9 million under this equity shelf program.~~used for general corporate purposes.

In April 2021, the Company entered into a Sales Agency Agreement between the Company and BNY Mellon Capital Markets, LLC and J.P. Morgan Securities LLC (the “Equity Shelf Program”) for the offer and sale of up to $500 million of common stock from time to time in at-the-market offerings under the related prospectus supplement filed with the ~~SEC~~Securities and Exchange Commission (the “SEC”) the same month. The Company issued $88 million under this multi-year program during the third quarter of 2021. Net proceeds from the sales of shares of common stock under ~~this equity shelf program~~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, as well as for ~~the~~ repayment or repurchase of indebtedness (including amounts outstanding from time to time under the credit facilities, senior notes, Term Loan or future credit facilities), and to provide for working capital.

In May 2019, the Company filed an earlier automatic shelf registration statement with the SEC for the offer and sale of up to $300 million of common stock from time to time in at-the-market offerings under the related prospectus and sales agency agreement. The Company issued the remaining capacity ($46 million) of this equity program during the quarter ended March 31, 2021.

During the twelve months ended September 30, 2021, 3,699,445 shares were issued in at-the-market offerings at an average price of $67.86 per share with gross proceeds of $251 million, agent commissions of $2.5 million, and net proceeds of $248.5 million under the equity shelf programs noted above. See Note 4 – Common Stock for more information.

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 most public utility property. The


			40


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

Company estimates bonus depreciation will defer the payment of approximately $20 million of federal income taxes for 2021, none of which relates to natural gas operations.

Dividend Policy

Dividends are payable on the Company’s common stock at the discretion of the ~~Board of Directors (the “Board”).~~Board. In setting the dividend rate, the Board currently targets a payout ratio of 55% to 65% of consolidated earnings per share and considers, among other factors, current and expected future earnings levels, our ongoing capital expenditure plans, ~~and~~ expected external funding needs, ~~in addition to~~and our ability to maintain strong credit ratings and liquidity. 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 $0.57 to $0.595 per share, representing a 4.4% increase, effective with the June 2021 payment.

Liquidity

Liquidity refers to the ability of an enterprise to generate sufficient amounts of cash through its operating activities and external financing to meet its cash requirements. Several factors (some of which are out of the control of the Company) that could significantly affect liquidity in the future include: variability of natural gas prices, changes in ratemaking policies of regulatory commissions, regulatory lag, customer growth in the natural gas segment, 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 ~~March 31,~~September 30, 2021, the combined balance in the PGA accounts totaled an under-collection of ~~$239~~$241 million. See PGA Filings for more information.

In March 2021, Southwest issued a $250 million Term Loan that will mature in March 22, 2022, or 364 days after issuance. The proceeds were used to fund the increased cost of natural gas supply during the month of February 2021 caused by extreme weather conditions in the central U.S.

Southwest Gas Holdings, Inc. has a credit facility with a borrowing capacity of ~~$100~~$100 million that expires in April 2025. This facility is intended for short-term financing needs. At ~~March 31,~~September 30, 2021, $4322 million was outstanding under this facility.


			49


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

Southwest has a credit facility, with a borrowing capacity of $400 million, which expires in April 2025. 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 on the long-term portion of the credit facility (including a commercial paper ~~program, as noted below)~~program) during the first ~~three~~nine months of 2021 was $150 ~~million, the same amount which was outstanding as of March 31, 2021.~~million. The maximum amount outstanding on the short-term portion of the credit facility during the first ~~quarter~~nine months of 2021 was $125 ~~million.~~million. As of ~~March 31,~~September 30, 2021, ~~$17 million was~~no borrowings were outstanding on the short-term portion of this credit facility. The credit facility can be used as necessary to meet ~~liquidity~~liquidity requirements, including temporarily financing under-collected PGA balances, or meeting the refund needs of over-collected balances. The credit facility has been adequate for Southwest’s working capital needs outside of funds raised through operations and other types of external financing. As indicated, any additional cash requirements would include the existing credit facility, equity contributions from the Company, and/or other external financing sources.

Southwest has a $50 million commercial paper program. Any issuance under the commercial paper program is supported by Southwest’s current revolving credit facility and, therefore, does not represent additional borrowing capacity. Any borrowing under the commercial paper program during 2021 will be designated as long-term debt. Interest rates for the commercial paper program are calculated at the current commercial paper rate during the borrowing term. At ~~March 31,~~September 30, 2021, there ~~was~~ ~~$50 million~~were no borrowings outstanding under this program.

In August 2021, in association with the acquisition of Riggs Distler (refer to Note 8 - Business Acquisitions), Centuri ~~has a senior secured revolving~~entered into an amended and restated credit ~~and term loan facility with borrowing capacity of $590 million~~agreement (refer to Note 5 – Debt). ~~The~~The line of credit portion comprises ~~$325~~$400 million; associated amounts borrowed and repaid are available to be re-borrowed. The term loan facility portion ~~has a limit of~~provided approximately ~~$265 million.~~$1.145 billion. The ~~$590 million credit and~~ term ~~loan~~loan facility expires ~~in November 2023. It is~~on August 27, 2028 and the revolving credit facility expires on August 27, 2026. The obligations under the credit agreement are secured by present and future ownership interests in substantially all direct and indirect subsidiaries of Centuri, substantially all of ~~Centuri’s assets except those explicitly excluded under~~ the ~~terms~~tangible and intangible personal property of each borrower, and certain of their direct and indirect subsidiaries, and all products, profits, and proceeds of the ~~agreement (including owned real estate and certain certificated vehicles).~~foregoing. Centuri assets securing the facility at ~~March 31,~~September 30, 2021 ~~totaled $1.3~~totaled $2.6 billion. TheThe maximum amount outstanding on the combined facility during the first ~~three~~nine months of 2021 was $~~249 million~~1.3 billion~~, at which point~~ ~~$223 million~~ ~~was outstanding on the term portion.~~. As of ~~March 31,~~September 30, 2021, ~~$26~~ $112 million was outstanding on the revolving credit facility, in addition to ~~the $223 million~~$1.145 billion that ~~remained~~was outstanding on the term loan portion of the facility. Also at ~~March 31,~~September 30, 2021, there was approximately ~~$267~~$235 million, net of letters of credit, available for borrowing under the line of credit.


			41


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

Interest rates for the credit facilities of the holding company, Southwest, and Centuri, and for Southwest’s Term Loan contain LIBOR-based rates. Upon the occurrence of certain events providing for a transition away from LIBOR, or ifwhen LIBOR is no longer a widely recognized benchmark rate, the holding company and Southwest each may amend their respective credit facility as set forth in ~~the~~their credit facility agreement, ~~and~~which is also in the case of Southwest’s Term Loan, in order to accommodate a replacement benchmark as set forth in the agreements. ~~LIBOR is~~Certain LIBOR-based rates are scheduled to be discontinued as a benchmark or reference rate after ~~2021.~~2021, while other LIBOR-based rates are scheduled to be discontinued after June 2023. In order to mitigate the impact of a discontinuance on the Company’s and Southwest’s financial condition and results of operations, management will monitor developments and work with lenders, where relevant, 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 Company has a Sales Agency Agreement with BNY Mellon Capital Markets, LLC and J.P. Morgan Securities LLC for the offer and sale of up to $500 million of common stock from time to time in at-the-market offerings, which is an additional source of liquidity. The Company had approximately $341.8 million available under the program as of September 30, 2021.

On October 5, 2021, the Company and Dominion Energy Questar Corporation, a wholly owned subsidiary of Dominion Energy, Inc., entered into a Purchase and Sale Agreement pursuant to which the Company would acquire the equity interests in Questar Pipelines. Pursuant to the Purchase and Sale Agreement, the purchase price is $1.545 billion in cash and the assumption of approximately $430 million in existing long-term debt. The Company has entered into an agreement for a new 364-day term loan that will provide the necessary consideration. If the acquisition closes as planned by the end of 2021, the Company expects this will be followed by permanent financing. See Note 5 – Debt.

Forward-Looking Statements

This quarterly report 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 quarterly 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


			50


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

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, seasonal patterns, payment of debt, the Company’s COLI strategy, replacement market and new construction market, our intent and ability to complete planned acquisitions and at amounts originally set out, impacts from the COVID-19 pandemic, including on our employees, customers, or otherwise, our financial position, revenue, earnings, cash flows, debt covenants, operations, regulatory recovery, work deployment or resumption and related uncertainties stemming from this pandemic or otherwise, expected impacts of valuation adjustments associated with any redeemable noncontrolling interest, the profitability of storm work, mix of work, or absorption of fixed costs by larger infrastructure services customers including Southwest, the impacts of U.S. tax reform including disposition in any regulatory proceeding and bonus depreciation tax deductions, the impact of recent PHMSA rulemaking, the amounts and timing for completion of estimated future construction expenditures, 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, funding sources of cash requirements, amounts generally expected to be reflected in future period revenues from regulatory rate proceedings including amounts requested or settled from recent and ongoing general rate cases or other regulatory proceedings, 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 existing at-the-market equity 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 pipeline imbalance charges or claims related thereto, recoverability of regulatory assets, the impact of certain legal proceedings or claims, and the timing and results of future rate hearings, including any ongoing or future general rate cases and other proceedings, and the final resolution for recovery of the ~~CDMI~~CDMI-related amounts and balances in ~~all jurisdictions,~~any jurisdiction, and statements regarding pending approvals are forward-looking statements. All forward-looking statements are intended to be subject to the safe harbor protection provided by the Reform Act.

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 continued or 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 or virus variants or efficacy of vaccines, the ability to collect on customer accounts due to the ~~current~~suspension or ~~an extended~~lifted moratorium on late fees or service disconnection in any or all jurisdictions, 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 or continue 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 or its variants following the ongoing resumption of commerce in our territories, and decisions of Centuri customers (including Southwest) as to whether to pursue capital projects due to economic impacts resulting from the pandemic or


			42


~~SOUTHWEST GAS HOLDINGS, INC.~~						~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~						~~March 31, 2021~~

otherwise, the ability to recover and timing thereof related to costs associated with the PGA mechanisms or other regulatory assets or programs, the effects of regulation/deregulation, governmental or regulatory policy regarding pipeline safety, greenhouse gas emissions, 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, levels of or changes in operations and maintenance expenses, effects of pension or other postretirement benefit expense forecasts or plan modifications, accounting changes and regulatory treatment related thereto, currently unresolved and future liability claims and disputes, 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, projections about acquired business’ earnings or those planned (including accretion within the first twelve months) and 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 and impacts from work awarded or failing to be awarded from significant customers (collectively, including from Southwest), the mix of work awarded, the amount of work awarded to Centuri following the lifting of work stoppages or


			51


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

reduction, the result of productivity inefficiencies from regulatory requirements or otherwise, delays in commissioning individual projects, acquisitions and management’s plans related thereto, the ability of management to successfully finance, close, and assimilate acquired businesses, the impact on our stock price or our credit ratings due to undertaking or failing to undertake acquisition activity or other strategic endeavors, the impact on our stock price, costs, or businesses from the stock rights program, actions or disruptions of significant shareholders, 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 or plans relating to its financing and operating expenses will continue, proceed as planned, 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 the Annual Report on Form 10-K for the year ended December 31, ~~2020.~~2020, as updated in association with the Quarterly Report on Form 10-Q for the quarter ended June 30, 2020 and in this quarterly report on Form 10-Q.

All forward-looking statements in this quarterly 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 its forward-looking statements, even if experience or future changes show that the indicated results or events will not be realized. We caution you not to unduly rely on any forward-looking statement(s).

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

See Item 7A. Quantitative and Qualitative Disclosures about Market Risk in the 2020 Annual Report on Form 10-K filed with the SEC. No material changes have occurred related to the disclosures about market risk.

ITEM 4. CONTROLS AND PROCEDURES

Management of Southwest Gas Holdings, Inc. and Southwest Gas Corporation has established disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) that are designed to provide reasonable assurance that information required to be disclosed in their respective reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms and to provide reasonable assurance that such information is accumulated and communicated to management of each company, including each respective Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosures. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and benefits of controls must be considered relative to their costs. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or management override of the control. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and may not be detected.

In August 2021, the Company, through its utility infrastructure services subsidiaries, completed the acquisition of Drum Parent, Inc. (“Drum”) and its U.S. operations consisting principally of the utility infrastructure services operations of Drum’s primary subsidiary, Riggs Distler & Company, Inc. (“Riggs Distler”), a privately held infrastructure services business. Existing assets of the acquired business represents 2% of consolidated total assets and 2% of consolidated revenues for the period ended September 30, 2021 and is not significant to the Company’s consolidated financial statements. As permitted by SEC guidance for newly acquired businesses, the Company’s management elected to exclude Riggs Distler from its evaluation of disclosure controls and procedures and management’s report on changes in internal control over financial reporting from the date of the acquisition through September 30, 2021. The Company’s management is in the process of reviewing the operations of Riggs Distler and implementing the Company’s internal control structure over the acquired operations. This review will be completed in 2022.

Based on the most recent evaluation, as of ~~March 31,~~September 30, 2021, management of Southwest Gas Holdings, Inc., and Southwest Gas Corporation, including the Chief Executive Officer and Chief Financial Officer, believes the Company’s and Southwest’s disclosure controls and procedures are effective at attaining the level of reasonable assurance noted above.

There have been no changes in the Company’s or Southwest’s internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act) during the ~~first~~third quarter of 2021 that have materially affected, or are likely to materially affect the Company’s internal control over financial reporting.

Based on the most recent evaluation, as of March 31, 2021, management of Southwest Gas Corporation, including the Chief Executive Officer and Chief Financial Officer, believes Southwest’s disclosure controls and procedures are effective at attaining the level of reasonable assurance noted above.


			4352


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

There have been no changes in Southwest’s internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act) during the first quarter of 2021 that have materially affected, or are likely to materially affect Southwest’s internal control over financial reporting.

In May 2021, the Company implemented a new customer service system, which involved replacing the legacy functionality for customer invoicing, customer service administration, and ancillary activities. The customer service system is being deployed for transactions starting in May 2021, and was not utilized in preparing the first quarter 2021 financial information. Management monitored developments related to the customer service system replacement, including working with the project team to ensure control impacts were identified and documented, in order to assist management in evaluating impacts to internal control. System integration and user acceptance testing were conducted to aid management in its evaluations. Post-implementation reviews of the system and impacted business processes are being conducted to enable management to evaluate the design and effectiveness of internal controls.

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The Company is named as a defendant in various legal proceedings. The ultimate dispositions of these proceedings are not presently determinable; however, it is the opinion of management that none of this litigation individually or in the aggregate will have a material adverse impact on the Company’s financial position or results of operations. See Contingency withinNote 1 – Background, Organization, and Summary of Significant Accounting Policies for potential future liability claims.

ITEM 1A. Described below are risk factors that we have identified that may have a negative impact on our future financial performance or affect whether we achieve the goals or expectations expressed or implied in any forward-looking statements contained herein. These risk factors supplement, and do not replace, the Risk Factors and other disclosures made in our Annual Report on Form 10-K filed February 25, 2021 or Quarterly Report on Form 10-Q for the quarter ended June 30, 2021.

Financial, Economic, and Market Risks

There may be unexpected delays in the completion of the acquisition of Questar Pipelines, or it may not be completed at all.

As mentioned above in Note 1 to Part I Item 1, in October 2021 the Company entered into an agreement to purchase Dominion Energy Questar Pipeline, LLC and related entities (“Questar Pipelines”), a FERC-regulated interstate natural gas pipeline group that provides transportation and underground storage services in Utah, Wyoming, and Colorado. The acquisition is currently expected to close near year-end 2021, conditioned on the satisfaction or waiver (where legally permissible) of conditions in the Purchase and Sale Agreement (“Agreement”). The Agreement provides that either the Company or Questar Pipelines may terminate the Agreement if the acquisition has not occurred before December 31, 2021, subject to an extension if certain conditions have not been met, subsequently extending the termination date through June 30, 2022. Certain events may delay the completion of the acquisition or result in a termination of the Agreement. Some of these events are outside the control of either party. In particular, we are obligated to obtain various other third-party consents and approvals, and we can provide no assurances that such clearances, consents, or approvals will be obtained on terms acceptable to us, or at all. We may incur significant additional costs in connection with any delay in completing the acquisition or termination of the Agreement, in addition to significant transaction costs, including legal, financial advisory, accounting, and other costs beyond that which we have already incurred. We cannot provide assurance that the conditions to the completion of the acquisition will be satisfied or waived or that any adverse change, effect, event, circumstance, occurrence, or statement of facts that could give rise to the termination of the Agreement will not occur, and we cannot provide any assurances as to whether or when the acquisition will be completed on the terms set forth in the Agreement or at all.

Failure to complete the acquisition of Questar Pipelines in a timely manner or at all could negatively affect our stock price. Completion of the acquisition could negatively impact our credit ratings.

We can provide no assurance that an acquisition will occur or that the conditions to it will be satisfied or waived in a timely manner, or at all. Also, we can provide no assurance that an event, change, or other circumstance that could give rise to the termination of an Agreement will not occur. Delays in completing an acquisition or the failure to complete one at all could negatively impact the market price of our common stock and it could decline significantly, particularly to the extent that the current market price reflects a market assumption that an acquisition will be completed. If an acquisition is delayed for any reason, we will be subject to several risks, including the diversion of management focus and resources from operational matters and other strategic opportunities while working to complete the acquisition. In addition, certain credit ratings agencies have indicated that an acquisition could have a negative impact on our current credit ratings. We can provide no assurances as to the final determination as to any downgrade in our (or Southwest’s) ratings and what impact such a downgrade would have on our businesses.

Our business could be negatively affected as a result of actions of activist shareholders.

In October 2021, certain funds affiliated with Carl Icahn initiated a tender offer for shares of our common stock and threatened a proxy contest with respect to the election of directors at our 2022 Annual Meeting of Stockholders. Responding to actions such as these and other actions by activist shareholders can be costly and time-consuming, disrupt our operations, and divert the attention of management and our employees. Perceived uncertainties among current and potential customers, employees, and other parties as to our future direction may result in the loss of potential business opportunities and may make it more difficult to attract and retain qualified personnel and business partners. These actions could also cause our stock price to experience periods of volatility.


			53


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

Following the completion of the acquisition of Questar Pipelines, we may be unable to successfully integrate Questar Pipelines into our business and realize the anticipated benefits of the acquisition.

We may not be able to achieve the anticipated benefits of the acquisition of Questar Pipelines. We may not be able to integrate Questar Pipeline’s business without increases in costs or other difficulties. We and Questar are expecting to enter into a transition services agreement for a period of time following closing of the transaction. Upon the expiration of the anticipated transition services agreement, we may not be able to hire or retain sufficient staff to operate the Questar Pipelines business efficiently. Any unexpected costs or delays incurred in connection with the integration of Questar Pipelines could have a material adverse effect on our business, results of operations, financial condition, as well as the market price of our common stock.

ITEMS 1A2 through 3. None.

ITEM 4. MINE SAFETY DISCLOSURES Not applicable.

ITEM 5. OTHER INFORMATION None.


			54


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						September 30, 2021

ITEM 6. EXHIBITS

The following documents are filed, or furnished, as applicable, as part of this report on Form 10-Q:


Exhibit 2.02*	-	Purchase and Sale Agreement, dated as of October 5, 2021, by and between Dominion Energy Questar Corporation and Southwest Gas Holdings, Inc.. Incorporated herein by reference to Exhibit 2.1 to Form 8-K dated October 5, 2021, File No. 001-37976.

Exhibit 3(i)	-	Certificate of Designations of the Series A Junior Participating Preferred Stock. Incorporated herein by reference to Exhibit 3.1 to Form 8-K dated October 10, 2021, File No. 001-37976.

Exhibit 3.01	-	Amended and Restated Bylaws of Southwest Gas Holdings, Inc., effective October 18, 2021. Incorporated herein by reference to Exhibit 3.1 to Form 8-K dated October 18, 2021, File No. 001-37976.

Exhibit 4.01	-	Second Supplemental Indenture, dated August 20, 2021, by and between Southwest Gas Corporation and The Bank of New York Mellon Trust Company, N.A., as Trustee. Incorporated herein by reference to Exhibit 4.1 to Form 8-K dated August 18, 2021, File Nos. 001-37976 and 001-07850.

Exhibit 4.02	-	Form of 3.18% Senior Note due 2051 (included in Exhibit 4.01). Incorporated herein by reference to Exhibit 4.2 to Form 8-K dated August 18, 2021, File Nos. 001-37976 and 001-07850.

Exhibit 4.03	-	Southwest Gas Corporation 3.18% Senior Notes due 2051. Incorporated herein by reference to prospectus 424(b)(5) dated August 18, 2021, File No. 333-251074-01.

Exhibit 4.04	-	Rights Agreement, dated October 10, 2021, between Southwest Gas Holdings, Inc. and Equiniti Trust Company, as Rights Agent. Incorporated herein by reference to Exhibit 4.1 to Form 8-K dated October 10, 2021, File No. 001-37976.

Exhibit 10.01	-	~~Term Loan~~Credit Agreement ~~dated~~with Wells Fargo Securities, LLC and BofA Securities, Inc., as ~~of March 23, 2021, by and among Southwest Gas Corporation, The~~joint lead arrangers, Wells Fargo Bank, National Association, as administrative agent, Bank of ~~New York Mellon,~~America, N.A., as ~~Administrative Agent,~~syndication agent, and the other lenders ~~party, book runners~~ and ~~syndication~~ agents party thereto. Incorporated herein by reference to Exhibit 10.1 to Form 8-K dated ~~March 23,~~August 27, 2021,, File No s .No. 001-37976 ~~and 001-07850~~.

Exhibit 31.01	-	Section 302 Certifications–Southwest Gas Holdings, Inc.

Exhibit 31.02	-	Section 302 Certifications–Southwest Gas Corporation

Exhibit 32.01	-	Section 906 Certifications–Southwest Gas Holdings, Inc.

Exhibit 32.02	-	Section 906 Certifications–Southwest Gas Corporation







Exhibit 101.INS	-	XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

Exhibit ~~101SCH~~101.SCH	-	XBRL Schema Document

Exhibit 101.CAL	-	XBRL Calculation Linkbase Document

Exhibit 101.DEF	-	XBRL Definition Linkbase Document

Exhibit 101.LAB	-	XBRL Label Linkbase Document

Exhibit 101.PRE	-	XBRL Presentation Linkbase Document

Exhibit 104	-	Cover Page Interactive Data File (embedded within the Inline XBRL document).

*The Company has omitted schedules and other similar attachments to such agreement pursuant to Item 601(b) of Regulation S-K. The Company will furnish a copy of such omitted document to the SEC upon request.


			4455


SOUTHWEST GAS HOLDINGS, INC.						Form 10-Q
SOUTHWEST GAS CORPORATION						~~March 31,~~September 30, 2021

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



Southwest Gas Holdings, Inc.
(Registrant)

Dated: ~~May 6,~~November 9, 2021



/s/ LORI L. COLVIN
Lori L. Colvin
Vice President/Controller and Chief Accounting Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



Southwest Gas Corporation
(Registrant)

Dated: ~~May 6,~~November 9, 2021



/s/ LORI L. COLVIN
Lori L. Colvin
Vice President/Controller and Chief Accounting Officer


			4556


	Twelve Months Ended March 31, 2021						Twelve Months Ended March 31, 2020
(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
Defined benefit pension plans:
Net actuarial gain/(loss)	$	(57,539)	$	13,809	$	(43,730)	$	(71,087)	$	17,061	$	(54,026)
Amortization of prior service cost	1,106		(266)		840		1,243		(298)		945
Amortization of net actuarial (gain)/loss	39,521		(9,484)		30,037		26,990		(6,477)		20,513
Prior service cost	0		0		0		(1,878)		452		(1,426)
Regulatory adjustment	6,255		(1,502)		4,753		33,896		(8,136)		25,760
Pension plans other comprehensive income (loss)	(10,657)		2,557		(8,100)		(10,836)		2,602		(8,234)
FSIRS (designated hedging activities):
Amounts reclassified into net income	2,954		(710)		2,244		3,345		(803)		2,542
FSIRS other comprehensive income (loss)	2,954		(710)		2,244		3,345		(803)		2,542
Total other comprehensive income (loss) - Southwest Gas Corporation	(7,703)		1,847		(5,856)		(7,491)		1,799		(5,692)
Foreign currency translation adjustments:
Translation adjustments	6,541		0		6,541		(2,758)		0		(2,758)
Foreign currency other comprehensive income (loss)	6,541		0		6,541		(2,758)		0		(2,758)
Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	(1,162)	$	1,847	$	685	$	(10,249)	$	1,799	$	(8,450)