10-Q

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, 2019

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.	California	81-3881866
	5241 Spring Mountain Road
	Post Office Box 98510
	Las Vegas, Nevada 89193-8510
	(702) 876-7237
1-7850	Southwest Gas Corporation	California	88-0085720
	5241 Spring Mountain Road
	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

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  x    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  x    No  ☐

Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or 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	x	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	x	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.  ☐

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

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, 53,396,583 shares as of April 30, 2019.

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, 2019.

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).

1

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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, and statements of cash flows) 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, 2019

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, 2019			December 31, 2018
ASSETS
Utility plant:
Gas plant	$	7,268,255		$	7,134,239
Less: accumulated depreciation	(2,257,017		)	(2,234,029		)
Construction work in progress	204,370			193,028
Net utility plant	5,215,608			5,093,238
Other property and investments	716,722			623,551
Current assets:
Cash and cash equivalents	97,037			85,361
Accounts receivable, net of allowances	429,248			413,926
Accrued utility revenue	47,000			77,200
Income taxes receivable	14,069			14,653
Deferred purchased gas costs	65,242			4,928
Prepaid and other current assets	177,784			243,701
Total current assets	830,380			839,769
Noncurrent assets:
Goodwill	364,482			359,045
Deferred income taxes	1,074			1,264
Deferred charges and other assets	441,166			440,862
Total noncurrent assets	806,722			801,171
Total assets	$	7,569,432		$	7,357,729
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock, $1 par (authorized - 60,000,000 shares; issued and outstanding - 53,391,731 and 53,026,848 shares)	$	55,021		$	54,656
Additional paid-in capital	1,332,793			1,305,769
Accumulated other comprehensive income (loss), net	(50,623		)	(52,668		)
Retained earnings	1,009,809			944,285
Total Southwest Gas Holdings, Inc. equity	2,347,000			2,252,042
Noncontrolling interest	(452		)	(452		)
Total equity	2,346,548			2,251,590
Redeemable noncontrolling interest	82,406			81,831
Long-term debt, less current maturities	2,106,274			2,107,258
Total capitalization	4,535,228			4,440,679
Current liabilities:
Current maturities of long-term debt	34,915			33,060
Short-term debt	188,000			152,000
Accounts payable	231,343			248,993
Customer deposits	68,593			67,940
Income taxes payable	—			1,083
Accrued general taxes	69,423			43,560
Accrued interest	31,439			21,369
Deferred purchased gas costs	72,213			79,762
Other current liabilities	278,552			290,878
Total current liabilities	974,478			938,645
Deferred income taxes and other credits:
Deferred income taxes and investment tax credits	556,063			529,201
Accumulated removal costs	385,000			383,000
Other deferred credits and other long-term liabilities	1,118,663			1,066,204
Total deferred income taxes and other credits	2,059,726			1,978,405
Total capitalization and liabilities	$	7,569,432		$	7,357,729

The accompanying notes are an integral part of these statements.

3

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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,
	2019			2018			2019			2018
Operating revenues:
Gas operating revenues	$	520,677		$	494,313		$	1,384,092		$	1,334,019
Utility infrastructure services revenues	312,862			260,017			1,575,130			1,314,366
Total operating revenues	833,539			754,330			2,959,222			2,648,385
Operating expenses:
Net cost of gas sold	192,604			185,732			426,260			393,898
Operations and maintenance	106,245			102,351			410,287			390,819
Depreciation and amortization	77,539			62,478			264,273			240,951
Taxes other than income taxes	16,206			15,257			60,847			58,421
Utility infrastructure services expenses	300,465			258,952			1,429,202			1,215,959
Total operating expenses	693,059			624,770			2,590,869			2,300,048
Operating income	140,480			129,560			368,353			348,337
Other income and (expenses):
Net interest deductions	(26,397		)	(22,631		)	(100,437		)	(81,981		)
Other income (deductions)	6,839			(4,334		)	(6,253		)	(9,374		)
Total other income and (expenses)	(19,558		)	(26,965		)	(106,690		)	(91,355		)
Income before income taxes	120,922			102,595			261,663			256,982
Income tax expense	25,538			24,301			62,921			53,751
Net income	95,384			78,294			198,742			203,231
Net income (loss) attributable to noncontrolling interests	575			(797		)	747			(393		)
Net income attributable to Southwest Gas Holdings, Inc.	$	94,809		$	79,091		$	197,995		$	203,624
Basic earnings per share	$	1.78		$	1.63		$	3.91		$	4.23
Diluted earnings per share	$	1.77		$	1.63		$	3.91		$	4.23
Average number of common shares	53,369			48,416			50,640			48,105
Average shares (assuming dilution)	53,424			48,459			50,701			48,139

The accompanying notes are an integral part of these statements.

4

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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,
	2019			2018			2019			2018
Net income	$	95,384		$	78,294		$	198,742		$	203,231
Other comprehensive income (loss), net of tax
Defined benefit pension plans:
Net actuarial gain (loss)	—			—			(15,524		)	(32,701		)
Amortization of prior service cost	241			254			1,002			875
Amortization of net actuarial loss	4,441			6,387			23,603			18,219
Regulatory adjustment	(4,063		)	(5,746		)	(4,574		)	10,400
Net defined benefit pension plans	619			895			4,507			(3,207		)
Forward-starting interest rate swaps (“FSIRS”):
Amounts reclassified into net income	635			635			2,541			2,190
Net forward-starting interest rate swaps	635			635			2,541			2,190
Foreign currency translation adjustments	791			(911		)	(1,308		)	640
Total other comprehensive income (loss), net of tax	2,045			619			5,740			(377		)
Comprehensive income	97,429			78,913			204,482			202,854
Comprehensive income (loss) attributable to noncontrolling interests	575			(797		)	747			(389		)
Comprehensive income attributable to Southwest Gas Holdings, Inc.	$	96,854		$	79,710		$	203,735		$	203,243

The accompanying notes are an integral part of these statements.

5

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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,
	2019			2018			2019			2018
CASH FLOW FROM OPERATING ACTIVITIES:
Net income	$	95,384		$	78,294		$	198,742		$	203,231
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	77,539			62,478			264,273			240,951
Deferred income taxes	24,923			23,228			52,736			49,372
Changes in current assets and liabilities:
Accounts receivable, net of allowances	(15,562		)	8,858			(40,282		)	(68,978		)
Accrued utility revenue	30,200			30,900			300			(1,400		)
Deferred purchased gas costs	(67,863		)	(10,628		)	25,339			(36,330		)
Accounts payable	(12,643		)	(48,497		)	47,632			26,762
Accrued taxes	25,400			18,776			(5,331		)	491
Other current assets and liabilities	47,848			(643		)	(5,582		)	(29,945		)
Gains on sale	(233		)	(230		)	(1,706		)	(4,087		)
Changes in undistributed stock compensation	3,188			1,861			7,438			6,638
AFUDC	(960		)	(229		)	(4,358		)	(2,050		)
Changes in other assets and deferred charges	(16,328		)	(1,845		)	(20,221		)	(16,941		)
Changes in other liabilities and deferred credits	(2,782		)	18,244			17,420			20,965
Net cash provided by operating activities	188,111			180,567			536,400			388,679
CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions	(210,662		)	(154,542		)	(822,034		)	(662,401		)
Acquisition of businesses, net of cash acquired	—			(4,209		)	(247,164		)	(98,413		)
Changes in customer advances	3,078			3,038			13,503			2,304
Miscellaneous inflows	262			1,505			3,200			13,429
Net cash used in investing activities	(207,322		)	(154,208		)	(1,052,495		)	(745,081		)
CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net	25,879			11,220			369,061			52,375
Dividends paid	(27,602		)	(23,839		)	(104,003		)	(94,572		)
Centuri distribution to redeemable noncontrolling interest	—			(102		)	—			(204		)
Issuance of long-term debt, net	29,666			335,382			259,456			716,165
Retirement of long-term debt	(31,160		)	(21,102		)	(247,816		)	(312,308		)
Change in credit facility and commercial paper	—			(111,000		)	111,000			24,000
Change in short-term debt	36,000			(192,000		)	165,500			22,500
Principal payments on finance lease obligations	(70		)	(165		)	(553		)	(946		)
Redemption of Centuri shares from noncontrolling parties	—			—			—			(23,000		)
Withholding remittance - share-based compensation	(1,838		)	(2,852		)	(2,096		)	(3,510		)
Other	(53		)	(337		)	(2,460		)	(2,498		)
Net cash provided by (used in) financing activities	30,822			(4,795		)	548,089			378,002
Effects of currency translation on cash and cash equivalents	65			(71		)	(72		)	114
Change in cash and cash equivalents	11,676			21,493			31,922			21,714
Cash and cash equivalents at beginning of period	85,361			43,622			65,115			43,401
Cash and cash equivalents at end of period	$	97,037		$	65,115		$	97,037		$	65,115
Supplemental information:
Interest paid, net of amounts capitalized	$	15,850		$	13,294		$	89,118		$	74,949
Income taxes paid (received)	$	454		$	4,418		$	(2,743	)	$	8,264

The accompanying notes are an integral part of these statements.

6

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Thousands of dollars)

(Unaudited)

	March 31, 2019			December 31, 2018
ASSETS
Utility plant:
Gas plant	$	7,268,255		$	7,134,239
Less: accumulated depreciation	(2,257,017		)	(2,234,029		)
Construction work in progress	204,370			193,028
Net utility plant	5,215,608			5,093,238
Other property and investments	123,783			116,146
Current assets:
Cash and cash equivalents	75,148			31,962
Accounts receivable, net of allowances	170,471			140,057
Accrued utility revenue	47,000			77,200
Income taxes receivable	10,602			13,444
Deferred purchased gas costs	65,242			4,928
Prepaid and other current assets	165,382			229,562
Total current assets	533,845			497,153
Noncurrent assets:
Goodwill	10,095			10,095
Deferred charges and other assets	423,495			424,952
Total noncurrent assets	433,590			435,047
Total assets	$	6,306,826		$	6,141,584
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock	$	49,112		$	49,112
Additional paid-in capital	1,089,002			1,065,242
Accumulated other comprehensive income (loss), net	(47,795		)	(49,049		)
Retained earnings	797,584			717,155
Total equity	1,887,903			1,782,460
Long-term debt, less current maturities	1,818,959			1,818,669
Total capitalization	3,706,862			3,601,129
Current liabilities:
Short-term debt	188,000			152,000
Accounts payable	148,309			184,982
Customer deposits	68,593			67,940
Accrued general taxes	69,423			43,560
Accrued interest	30,398			20,243
Deferred purchased gas costs	72,213			79,762
Payable to parent	1,038			472
Other current liabilities	100,556			94,136
Total current liabilities	678,530			643,095
Deferred income taxes and other credits:
Deferred income taxes and investment tax credits, net	517,124			490,458
Accumulated removal costs	385,000			383,000
Other deferred credits and other long-term liabilities	1,019,310			1,023,902
Total deferred income taxes and other credits	1,921,434			1,897,360
Total capitalization and liabilities	$	6,306,826		$	6,141,584

The accompanying notes are an integral part of these statements.

7

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Thousands of dollars)

(Unaudited)

	Three Months Ended March 31,						Twelve Months Ended March 31,
	2019			2018			2019			2018
Gas operating revenues	$	520,677		$	494,313		$	1,384,092		$	1,334,019
Operating expenses:
Net cost of gas sold	192,604			185,732			426,260			393,898
Operations and maintenance	105,542			102,190			408,165			389,687
Depreciation and amortization	57,612			49,961			199,467			190,688
Taxes other than income taxes	16,206			15,257			60,847			58,421
Total operating expenses	371,964			353,140			1,094,739			1,032,694
Operating income	148,713			141,173			289,353			301,325
Other income and (expenses):
Net interest deductions	(23,099		)	(19,255		)	(85,584		)	(71,778		)
Other income (deductions)	5,946			(4,603		)	(6,691		)	(9,747		)
Total other income and (expenses)	(17,153		)	(23,858		)	(92,275		)	(81,525		)
Income from continuing operations before income taxes	131,560			117,315			197,078			219,800
Income tax expense	28,171			26,966			45,196			49,571
Net income	$	103,389		$	90,349		$	151,882		$	170,229

The accompanying notes are an integral part of these statements.

8

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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,
	2019			2018			2019			2018
Net income	$	103,389		$	90,349		$	151,882		$	170,229
Other comprehensive income (loss), net of tax
Defined benefit pension plans:
Net actuarial gain (loss)	—			—			(15,524		)	(32,701		)
Amortization of prior service cost	241			254			1,002			875
Amortization of net actuarial loss	4,441			6,387			23,603			18,219
Regulatory adjustment	(4,063		)	(5,746		)	(4,574		)	10,400
Net defined benefit pension plans	619			895			4,507			(3,207		)
Forward-starting interest rate swaps (“FSIRS”):
Amounts reclassified into net income	635			635			2,541			2,190
Net forward-starting interest rate swaps	635			635			2,541			2,190
Total other comprehensive income (loss), net of tax	1,254			1,530			7,048			(1,017		)
Comprehensive income	$	104,643		$	91,879		$	158,930		$	169,212

The accompanying notes are an integral part of these statements.

9

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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,
	2019			2018			2019			2018
CASH FLOW FROM OPERATING ACTIVITIES:
Net Income	$	103,389		$	90,349		$	151,882		$	170,229
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	57,612			49,961			199,467			190,688
Deferred income taxes	26,270			18,676			50,593			46,622
Changes in current assets and liabilities:
Accounts receivable, net of allowances	(30,414		)	(28,201		)	(22,522		)	(29,031		)
Accrued utility revenue	30,200			30,900			300			(1,400		)
Deferred purchased gas costs	(67,863		)	(10,628		)	25,339			(36,330		)
Accounts payable	(39,574		)	(34,564		)	18,398			14,717
Accrued taxes	28,704			27,476			(17,504		)	12,683
Other current assets and liabilities	81,625			3,163			(12,982		)	(47,905		)
Changes in undistributed stock compensation	2,597			2,118			5,834			5,695
AFUDC	(960		)	(229		)	(4,358		)	(2,050		)
Changes in other assets and deferred charges	(18,238		)	(1,998		)	(23,289		)	(17,655		)
Changes in other liabilities and deferred credits	(2,977		)	17,887			16,805			20,230
Net cash provided by operating activities	170,371			164,910			387,963			326,493
CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions	(163,636		)	(131,743		)	(714,762		)	(591,184		)
Changes in customer advances	3,078			3,038			13,503			2,304
Miscellaneous inflows (outflows)	(78		)	293			(357		)	2,250
Net cash used in investing activities	(160,636		)	(128,412		)	(701,616		)	(586,630		)
CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net	—			—			—			41,359
Contributions from parent	22,842			—			136,391			—
Dividends paid	(23,500		)	(21,000		)	(89,500		)	(83,997		)
Issuance of long-term debt, net	—			297,495			—			297,495
Change in credit facility and commercial paper	—			(111,000		)	111,000			24,000
Change in short-term debt	36,000			(191,000		)	188,000			—
Withholding remittance - share-based compensation	(1,838		)	(2,852		)	(2,096		)	(3,510		)
Other	(53		)	(298		)	(783		)	(371		)
Net cash provided by (used in) financing activities	33,451			(28,655		)	343,012			274,976
Change in cash and cash equivalents	43,186			7,843			29,359			14,839
Cash and cash equivalents at beginning of period	31,962			37,946			45,789			30,950
Cash and cash equivalents at end of period	$	75,148		$	45,789		$	75,148		$	45,789
Supplemental information:
Interest paid, net of amounts capitalized	$	11,585		$	10,296		$	75,094		$	66,097
Income taxes paid (received)	$	(22	)	$	—		$	(5,878	)	$	(7,816	)

The accompanying notes are an integral part of these statements.

10

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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). At the annual meeting of shareholders of Southwest Gas Holdings, Inc., held on May 2, 2019, shareholders voted to approve changing the state of incorporation for Southwest Gas Holdings, Inc. from California to Delaware. The reincorporation is expected to be effective during the second or third quarter of 2019. However, the reincorporation remains subject to certain regulatory approvals, which are currently pending.

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 from installation, replacement, repair, and maintenance of energy distribution systems, and developing industrial construction solutions. Centuri operations are generally conducted under the business names of NPL Construction Co. (“NPL”), NPL Canada Ltd. (“NPL Canada”), New England Utility Constructors, Inc. (“Neuco”) and Linetec Services, LLC (“Linetec”). Utility infrastructure services activity is seasonal in 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. In November 2017, Centuri acquired Neuco, thereby expanding its core services in the northeast region of the U.S. Additionally, in November 2018, Centuri expanded its operations in the southeast region of the U.S. through the acquisition of an 80% interest in Linetec. See Note 12 – Business Acquisitions for more information.

Basis of Presentation. The condensed consolidated financial statements for 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, or in the primary businesses comprising those segments as a result of the foregoing acquisitions of Neuco and Linetec.

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 at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. In the opinion of management, all adjustments, consisting of normal recurring items and estimates necessary for a fair statement of results for the interim periods, have been made. It is suggested that these condensed consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the 2018 Annual Report to Shareholders, which is incorporated by reference into the 2018 Form 10-K.

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.

11

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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

Other Property and Investments. Other property and investments on the Condensed Consolidated Balance Sheets includes (thousands of dollars):

	March 31, 2019			December 31, 2018
Southwest Gas Corporation:
Net cash surrender value of COLI policies	$	122,048		$	114,405
Other property	1,735			1,741
Total Southwest Gas Corporation	123,783			116,146
Centuri property, equipment, and intangibles	894,739			792,191
Centuri accumulated depreciation/amortization	(316,832		)	(298,939		)
Other property	15,032			14,153
Total Southwest Gas Holdings, Inc.	$	716,722		$	623,551

Cash and Cash Equivalents. For purposes of reporting consolidated cash flows, cash and cash equivalents include cash on hand and financial instruments with maturities of three months or less. Such investments are carried at cost, which approximates market value. Cash and cash equivalents for Southwest and the Company also include money market fund investments totaling approximately $41 million and $54.4 million, respectively, at March 31, 2019, and $18 million and $59.9 million, respectively, at December 31, 2018, which fall within Level 2 of the fair value hierarchy, due to the asset valuation methods used by money market funds.

Typical non-cash investing activities for Southwest include customer advances applied as contributions toward utility construction activity and capital expenditures that were not paid as of quarter end that are included in accounts payable. Amounts related to such activities were immaterial for the periods presented herein. Non-cash investing activities for the three months and twelve months ended March 31, 2019 included $73.5 million of purchase consideration related to the Linetec acquisition by Centuri, in the form of liabilities incurred that remained unpaid as of March 31, 2019; such amounts are included in Other current liabilities on the Condensed Consolidated Balance Sheets of the Company. Also, see Recent Accounting Standards Updates and Note 4 – Leases for information related to right-of-use assets obtained in exchange for lease liabilities, which are non-cash investing and financing activities.

Intercompany Transactions. Centuri recognizes revenues generated from contracts with Southwest (see Note 10 – Segment Information). Centuri’s accounts receivable for these services are presented in the table below (thousands of dollars):

	March 31, 2019		December 31, 2018
Centuri accounts receivable for services provided to Southwest	$	16,837	$	18,830

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.

Income Taxes. In 2017, the Tax Cuts and Jobs Act (the “TCJA”) was enacted. The TCJA had significant impacts on the taxation of business entities, including specific provisions related to regulated public utilities. The more significant changes that impacted the Company and Southwest include the reduction in the corporate federal income tax rate from 35% to 21%, and limiting the utilization of net operating losses (“NOLs”) to 80% of taxable income, with the ability to indefinitely carryforward unutilized NOLs to reduce future taxable income.

Prepaid and Other Current Assets. Prepaid and other current assets includes gas pipe materials and operating supplies of $55 million at March 31, 2019 and $56 million at December 31, 2018 (carried at weighted average cost), as well as $55 million at March 31, 2019 and $74 million at December 31, 2018 related to a regulatory asset associated with the Arizona decoupling mechanism (an alternative revenue program).

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 consistent between periods presented below, and that no change was necessary with regard to the level at which goodwill is assessed for impairment. No impairment was deemed to have occurred in the first three months of 2019.

12

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

(Thousands of dollars)	Natural Gas Operations		Utility Infrastructure Services		Total Company
December 31, 2018	$	10,095	$	348,950	$	359,045
Measurement Period Adjustment - Linetec acquisition	—		3,303		3,303
Foreign currency translation adjustment	—		2,134		2,134
March 31, 2019	$	10,095	$	354,387	$	364,482

Other Current Liabilities. Other current liabilities for Southwest include $22.8 million of dividends declared by Southwest Gas Corporation, but not yet paid to Southwest Gas Holdings, Inc. at March 31, 2019.

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

	Three Months Ended						Twelve Months Ended
	March 31,						March 31,
	2019			2018			2019			2018
Southwest Gas Corporation - natural gas operations segment:
Change in COLI policies	$	7,600		$	(700	)	$	5,100		$	6,800
Interest income	1,597			1,418			6,199			3,638
Equity AFUDC	960			229			4,358			2,049
Other components of net periodic benefit cost	(3,765		)	(5,265		)	(19,560		)	(19,834		)
Miscellaneous income and (expense)	(446		)	(285		)	(2,788		)	(2,400		)
Southwest Gas Corporation - total other income (deductions)	5,946			(4,603		)	(6,691		)	(9,747		)
Utility infrastructure services segment:
Interest income	—			1			87			4
Foreign transaction gain (loss)	531			147			162			(606		)
Miscellaneous income and (expense)	344			115			125			956
Centuri - total other income (deductions)	875			263			374			354
Corporate and administrative	18			6			64			19
Consolidated Southwest Gas Holdings, Inc. - total other income (deductions)	$	6,839		$	(4,334	)	$	(6,253	)	$	(9,374	)

Included in the table above is the change in cash surrender values of company-owned life insurance (“COLI”) policies (including net death benefits recognized). 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. 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 Note 2 – Components of Net Periodic Benefit Cost.

Recent Accounting Standards Updates.

Accounting pronouncements adopted in 2019:

In February 2016, the FASB issued the update “Leases (Topic 842).” Under the update, lessees were required to recognize a lease liability for the obligation to make lease payments, measured on a discounted basis; and a right-of-use asset for the right to use, or control the use of, a specified asset for the lease term. The Company and Southwest adopted Topic 842 in the first quarter of 2019 through an optional transition method, which was elected, permitting the application of the provisions of the standard at the adoption date, rather than to earlier comparative periods. As a result, the Company and Southwest have not recast prior periods to reflect the adoption of this standard. See Note 4 – Leases.

Accounting pronouncements that will be effective after 2019:

In June 2016, the FASB issued ASU 2016-13 update “Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The update requires the measurement of all expected credit losses for financial assets held at the reporting date based on historical experience, current conditions, and reasonable and supportable forecasts. The inputs currently used to estimate credit losses will still be used; however, they may be adapted to reflect the full amount of expected losses. The update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. All entities may adopt the amendments in this update earlier as of fiscal years beginning after December 15, 2018, including interim

13

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

periods within those fiscal years. Management is evaluating what impact, if any, this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures.

In January 2017, the FASB issued ASU 2017-04 “Intangibles – Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” Currently, unless meeting the criteria for qualitative assessment only, an entity is required to perform a two-step test to determine the amount, if any, of goodwill impairment. In Step 1, an entity compares the fair value of a reporting unit with its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, the entity performs Step 2 and compares the implied fair value of goodwill with the carrying amount of that goodwill for that reporting unit, requiring a hypothetical purchase price allocation to measure the amount of a goodwill impairment. An impairment charge equal to the amount by which the carrying amount of goodwill for the reporting unit exceeds the implied fair value of that goodwill is recorded, limited to the amount of goodwill allocated to that reporting unit. Under the update, an entity will apply a one-step quantitative test and record the amount of goodwill impairment as the excess of a reporting unit's carrying amount over its fair value, not to exceed the total amount of goodwill allocated to the reporting unit. The new guidance does not amend the optional qualitative assessment. The amount of any goodwill impairment calculated under the update could vary from the calculation under existing guidance, largely due to the consideration to be given to unrecognized differences between the fair value and carrying values of the other assets and liabilities in the reporting unit under the new guidance. The amendments should be applied on a prospective basis. The update is effective for fiscal and interim periods beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. Management is evaluating the impacts this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures.

In August 2018, the FASB issued ASU 2018-15 “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract.” The update generally aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement (that is a service contract) with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. The update also requires the entity to expense the capitalized implementation costs of such hosting arrangements over the term of the hosting arrangement, including reasonably certain renewal periods. The update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption of the amendments in this update is permitted for interim and related annual fiscal periods after December 15, 2018. Management is evaluating the impacts this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures.

In August 2018, the FASB issued ASU 2018-14 “Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans.” This update removes disclosures that are no longer considered cost-beneficial, clarifies the specific requirements of disclosures, and adds disclosure requirements identified as relevant. The update applies to all employers that sponsor defined benefit pension or other postretirement plans. The update is effective for fiscal years ending after December 15, 2020. Upon adoption, the Company and Southwest will modify their disclosures to conform to the requirements of the update.

In August 2018, the FASB issued ASU 2018-13 “Fair Value Measurement: Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement.” The update is intended to improve the effectiveness of fair value measurement disclosures and removes the following disclosure requirements: the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy; the policy for timing of transfers between levels; and the valuation processes for Level 3 fair value measurements. The update also modifies or clarifies for investments in certain entities that calculate net asset value, a requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse (in cases when the timing has been communicated or announced publicly). It also clarifies communication requirements about measurement uncertainty as of the reporting date. For certain unobservable inputs, an entity may disclose other quantitative information in lieu of the weighted average if it would be a more reasonable and rational method to reflect the distribution of inputs to the measurements. The update is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. Management is evaluating the impacts this update might have on its disclosures.

14

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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 are components of an overhead loading process associated with the cost of labor. The overhead process ultimately results in allocation of that portion of overall net periodic benefit costs to the same accounts to which productive labor is charged. As a result, service costs become components of various accounts, primarily operations and maintenance expense, net utility plant, and deferred charges and other assets for both the Company and Southwest. The other components of net periodic benefit cost are reflected in Other income (deductions) on the Condensed Consolidated Statements of Income of the Company and Southwest.

	Qualified Retirement Plan
	Period Ended March 31,
	Three Months						Twelve Months
	2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	6,466		$	7,139		$	27,882		$	24,683
Interest cost	12,252			11,043			45,383			45,606
Expected return on plan assets	(15,061		)	(14,689		)	(59,127		)	(56,086		)
Amortization of net actuarial loss	5,589			8,029			29,675			26,032
Net periodic benefit cost	$	9,246		$	11,522		$	43,813		$	40,235
	SERP
	Period Ended March 31,
	Three Months						Twelve Months
	2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	66		$	61		$	250		$	292
Interest cost	440			415			1,683			1,827
Amortization of net actuarial loss	255			375			1,382			1,456
Net periodic benefit cost	$	761		$	851		$	3,315		$	3,575
	PBOP
	Period Ended March 31,
	Three Months						Twelve Months
	2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	319		$	368		$	1,424		$	1,469
Interest cost	762			687			2,823			3,111
Expected return on plan assets	(789		)	(930		)	(3,577		)	(3,448		)
Amortization of prior service costs	317			334			1,318			1,335
Net periodic benefit cost	$	609		$	459		$	1,988		$	2,467

15

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Note 3 – Revenue

The following information about the Company’s revenues is presented by segment. Southwest encompasses one segment – natural gas operations.

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						Twelve Months Ended
	March 31,						March 31,
(Thousands of dollars)	2019			2018			2019			2018
Residential	$	417,228		$	344,611		$	959,837		$	859,078
Small commercial	89,610			87,943			256,750			250,331
Large commercial	13,962			15,440			51,714			54,224
Industrial/other	6,478			6,510			23,457			23,085
Transportation	24,902			24,054			87,838			89,081
Revenue from contracts with customers	552,180			478,558			1,379,596			1,275,799
Alternative revenue program revenues (deferrals)	(34,545		)	27,209			(15,775		)	66,788
Other revenues (a)	3,042			(11,454		)	20,271			(8,568		)
Total Gas operating revenues	$	520,677		$	494,313		$	1,384,092		$	1,334,019

(a) Includes various other revenues which, in the periods presented ending March 31, 2018, were offset by a $14 million reserve against revenue associated with a tax reform savings adjustment.

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:

(Thousands of dollars)	Three Months Ended				Twelve Months Ended
	March 31,				March 31,
	2019		2018		2019		2018
Service Types:
Gas infrastructure services	$	197,893	$	193,527	$	1,128,048	$	938,342
Electric power infrastructure services	52,301		5,402		79,528		19,893
Other	62,668		61,088		367,554		356,131
Total Utility infrastructure services revenues	$	312,862	$	260,017	$	1,575,130	$	1,314,366

(Thousands of dollars)	Three Months Ended				Twelve Months Ended
	March 31,				March 31,
	2019		2018		2019		2018
Contract Types:
Master services agreement	$	235,655	$	194,464	$	1,143,603	$	932,804
Bid contract	77,207		65,553		431,527		381,562
Total Utility infrastructure services revenues	$	312,862	$	260,017	$	1,575,130	$	1,314,366
Unit priced contracts	$	235,686	$	197,322	$	1,296,783	$	1,013,642
Fixed priced contracts	38,538		25,541		130,295		137,724
Time and materials contracts	38,638		37,154		148,052		163,000
Total Utility infrastructure services revenues	$	312,862	$	260,017	$	1,575,130	$	1,314,366

The following table provides information about contracts receivable and revenue earned on contracts in progress in excess of billings (contract asset), which are both included within Accounts receivable, net of allowances, as well as amounts billed in excess

16

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

of revenue earned on contracts (contract liability), which are included in Other current liabilities as of March 31, 2019 and December 31, 2018 on the Company’s Condensed Consolidated Balance Sheets:

(Thousands of dollars)	March 31, 2019		December 31, 2018
Contracts receivable, net	$	160,973	$	186,249
Revenue earned on contracts in progress in excess of billings	97,642		87,520
Amounts billed in excess of revenue earned on contracts	4,588		4,211

The revenue earned on contracts in progress in excess of billings (contract asset) primarily relates to Centuri’s rights to consideration for work completed but not billed and/or approved at the reporting date. These contract assets are transferred to contracts receivable when the rights become unconditional. The amounts billed in excess of revenue earned (contract liability) primarily relates 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, 2018 to March 31, 2019 is due to revenue recognized of $4.2 million that was included in this item as of January 1, 2019, after which time it became earned and the balance was reduced, and to increases due to cash received, net of revenue recognized during the period related to contracts that commenced during the period.

For contracts that have an original duration of one year or less, Centuri uses the practical expedient applicable to such contracts and does not consider/compute an interest component based on the time value of money. Further, 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, 2019, Centuri has seventeen contracts that had 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, 2019 is $60.7 million. Centuri expects to recognize the remaining performance obligations over the next three years; 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)	March 31, 2019			December 31, 2018
Billed on completed contracts and contracts in progress	$	159,829		$	184,100
Other receivables	1,527			2,588
Contracts receivable, gross	161,356			186,688
Allowance for doubtful accounts	(383		)	(439		)
Contracts receivable, net	$	160,973		$	186,249

17

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Note 4 – Leases

The Company and Southwest adopted Topic 842 as of January 1, 2019. In association with the adoption, the Company recorded adjustments to its Condensed Consolidated Balance Sheet to record right-of-use (“ROU”) assets and lease liabilities of $58.4 million and $60.8 million, respectively. Included in those amounts, Southwest recorded $1.9 million related to both its ROU assets and lease liabilities. Neither the Company nor Southwest experienced a material impact to the Condensed Consolidated Statements of Income from the adoption and no cumulative-effect adjustment to the opening balance of retained earnings was recognized. Management elected to adopt the standard under the optional transition method (refer to Recent Accounting Standards Updates in Note 1 – Background, Organization, and Summary of Significant Accounting Policies), and elected the following Topic 842 practical expedients and accounting policy elections:

• To use the “package”, which is a set of three practical expedients that must be elected as a package and applied consistently to all of Southwest’s and Centuri’s leases. These include: not reassessing whether any expired or existing contracts are or contain leases; not reassessing the lease classification for expired or existing leases (that is, existing operating and capital leases in accordance with current lease guidance will in each case be classified as operating and finance leases, respectively, under the updated guidance); and not reassessing initial direct costs for any existing leases.

• To utilize the practical expedient to exclude all easements in place prior to January 1, 2019 from treatment under Topic 842. However, Southwest will evaluate new easements entered into after the effective date of the standard to determine if the arrangements should be accounted for as leases.

• To make an accounting policy election by asset class to include both the lease and non-lease components (as defined in the guidance) as a single component.

• To make an accounting policy election to not apply Topic 842 to short-term leases, as permitted.

• To not elect to use hindsight in determining the lease term and in assessing impairment of ROU assets.

• To utilize a portfolio approach to effectively account for the operating lease ROU assets and liabilities with regard to certain equipment leases at Centuri.

Southwest and Centuri determine if an arrangement is a lease at inception. ROU assets represent the right to use an underlying asset for the lease term; lease liabilities represent obligations to make lease payments arising from the lease. Operating lease ROU assets and liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. As most of Southwest’s and Centuri’s leases do not provide an implicit interest rate, an incremental borrowing rate based on information available at commencement is used in determining the present value of lease payments; an implicit rate, if readily determinable, is used. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised.

Southwest’s leases are comprised primarily of operating leases of buildings, land, and equipment. Southwest has no finance leases and no significant short-term leases. Southwest’s leases have a remaining term of 1 to 10 years, some of which include options to extend the lease up to 3 years. Southwest is currently not a lessor in any significant lease arrangements. Southwest’s ROU assets are included in Gas plant, and its lease liabilities are included in, depending upon maturity, Other current liabilities or Other deferred credits and other long-term liabilities on the Company’s and Southwest’s Condensed Consolidated Balance Sheet as of March 31, 2019.

Centuri has operating and finance leases for corporate and field offices, construction equipment, and transportation vehicles. Centuri is currently not a lessor in any significant lease arrangements. Centuri’s leases have remaining lease terms of 1 to 14 years. Some of these include options to extend the leases, generally for optional terms of up to 5 years, and some include options to terminate the leases within 1 year. Centuri’s equipment leases may include variable payment terms in addition to the fixed lease payments if machinery is used in excess of the standard work periods. These variable payments are not probable of occurring under the current operating environment and have not been included in consideration of lease payments. Expense for short-term leases of Centuri during the quarter ended March 31, 2019 was $2.6 million, and such leases were not accounted for under the provisions of Topic 842, as permitted. Due to the seasonality of Centuri’s business, expense for short-term leases will fluctuate throughout the year with higher expense incurred during the warmer months. Centuri’s ROU assets are included in Other property and investments, and its lease liabilities for operating and finance leases are included, depending upon maturity, in Other current liabilities or Other deferred credits and other long-term liabilities on the Company’s Condensed Consolidated Balance Sheet as of March 31, 2019.

18

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

The components of lease expense were as follows:

(Thousands of dollars)	Three Months Ended
	March 31, 2019
Southwest:
Operating lease cost	$	406
Centuri:
Operating lease cost	$	2,805
Finance lease cost:
Amortization of ROU assets	$	35
Interest on lease liabilities	7
Total finance lease cost	42
Short-term lease cost	2,575
Total lease cost	$	5,828

Supplemental cash flow information related to leases for the three months ended March 31, 2019 was as follows:

(Thousands of dollars)	Southwest		Centuri		Consolidated Total
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	396	$	2,555	$	2,951
Operating cash flows from finance leases	—		7		7
Financing cash flows from finance leases	—		51		51
ROU assets obtained in exchange for lease obligations:
Operating leases	$	523	$	2,321	$	2,844
Finance leases	—		84		84

19

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Supplemental information related to leases, including location in the Condensed Consolidated Balance Sheets, is as follows:

(Thousands of dollars)	March 31, 2019
Southwest:
Operating leases:
Net Utility Plant	$	1,977
Other current liabilities	$	745
Other deferred credits and other long-term liabilities	1,253
Total operating lease liabilities	$	1,998
Weighted average remaining lease term (in years)	4.22
Weighted average discount rate	3.39		%
Centuri:
Operating leases:
Other property and investments	$	57,267
Other current liabilities	7,178
Other deferred credits and other long-term liabilities	52,647
Total operating lease liabilities	$	59,825
Finance leases:
Other property and investments	$	639
Other current liabilities	256
Other deferred credits and other long-term liabilities	239
Total finance lease liabilities	$	495
Weighted average remaining lease term (in years)
Operating leases	9.33
Finance leases	1.63
Weighted average discount rate
Operating leases	4.08		%
Finance leases	5.84		%

20

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

The following is a schedule of maturities of lease liabilities as of March 31, 2019:

(Thousands of dollars)	Operating leases
Southwest:
2020	$	800
2021	556
2022	295
2023	124
2024	78
Thereafter	307
Total lease payments	2,160
Less imputed interest	162
Total	$	1,998

(Thousands of dollars)	Operating leases		Finance leases
Centuri:
2020	$	10,394	$	281
2021	9,327		128
2022	8,328		67
2023	7,645		38
2024	5,710		25
Thereafter	31,303		—
Total lease payments	72,707		539
Less imputed interest	12,882		44
Total	$	59,825	$	495

As the Company and Southwest adopted Topic 842 using the optional transition method referred to in Note 1 – Background, Organization, and Summary of Significant Accounting Policies, the recent annual disclosure of rental and lease payments as of December 31, 2018 in accordance with Topic 840 is presented in the table below:

	2018		2017
Southwest Gas Corporation	$	4,556	$	4,926
Centuri	59,491		62,310
Consolidated rental payments/lease expense	$	64,047	$	67,236

The following is a schedule of future minimum lease payments for operating leases (with initial or remaining terms in excess of one year) as of December 31, 2018 (thousands of dollars):

	Southwest		Centuri		Consolidated Total
2019	$	898	$	10,053	$	10,951
2020	363		7,656		8,019
2021	299		5,760		6,059
2022	163		5,163		5,326
2023	79		3,681		3,760
Thereafter	177		10,511		10,688
Total minimum lease payments	$	1,979	$	42,824	$	44,803

As of December 31, 2018 Centuri leased certain construction equipment under capital leases arrangements which were not significant.

21

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Note 5 – Derivatives

In managing its natural gas supply portfolios, Southwest has historically entered into fixed- and variable-price contracts, which qualify as derivatives. Additionally, Southwest utilizes fixed-for-floating swap contracts (“Swaps”) to supplement its fixed-price contracts. The fixed-price contracts, firm commitments to purchase a fixed amount of gas in the future at a fixed price, qualify for the normal purchases and normal sales exception that is allowed for contracts that are probable of delivery in the normal course of business, and are exempt from fair value reporting. The variable-price contracts qualify as derivative instruments; however, because the contract price is the prevailing price at the future transaction date, the contract has no determinable fair value. The Swaps’ contract prices are determined at the beginning of each month to reflect that month’s published first of month index price and are recorded at fair value. Southwest does not utilize derivative financial instruments for speculative purposes, nor does it have trading operations.

The fixed-price contracts and Swaps are utilized by Southwest under its volatility mitigation programs to effectively fix the price on a portion (up to 25% in the Arizona and California jurisdictions) of its natural gas supply portfolios. The maturities of the Swaps highly correlate to forecasted purchases of natural gas, during time frames ranging from April 30, 2019 through October 31, 2020. Under such contracts, Southwest pays the counterparty a fixed rate and receives from the counterparty a floating rate per MMBtu (“dekatherm”) of natural gas. Only the net differential is actually paid or received. The differential is calculated based on the notional amounts under the contracts, which are detailed in the table below (thousands of dekatherms):

	March 31, 2019	December 31, 2018
Contract notional amounts	14,757	13,387

The following table sets forth the gains and (losses) recognized on the Swaps (derivatives) for the three- and twelve-month periods ended March 31, 2019 and 2018 and their location in the Condensed Consolidated Statements of Income for both the Company and Southwest:

Gains (losses) recognized in income for derivatives not designated as hedging instruments:

(Thousands of dollars)
		Three Months Ended								Twelve Months Ended
	Location of Gain or (Loss) Recognized in Income on Derivatives	March 31,								March 31,
Instrument		2019				2018				2019				2018
Swaps	Net cost of gas sold	$	(3,533	)		$	(5,196	)		$	(450	)		$	(11,631	)
Swaps	Net cost of gas sold	3,533			*	5,196			*	450			*	11,631			*
Total		$	—			$	—			$	—			$	—

* Represents the impact of regulatory deferral accounting treatment under U.S. GAAP for rate-regulated entities.

No gains (losses) were recognized in net income or other comprehensive income during the periods presented for derivatives designated as cash flow hedging instruments. Previously, Southwest entered into two forward-starting interest rate swaps (“FSIRS”), both of which were designated cash flow hedges, to partially hedge the risk of interest rate variability during the period leading up to the planned issuance of debt. The first FSIRS terminated in December 2010. The second FSIRS terminated in March 2012. Losses on both FSIRS are being amortized over ten-year periods from Accumulated other comprehensive income (loss) into interest expense.

22

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

The following table sets forth the fair values of the Swaps and their location in the Condensed Consolidated Balance Sheets for both the Company and Southwest (thousands of dollars):

Fair values of derivatives not designated as hedging instruments:

March 31, 2019		Asset		Liability
Instrument	Balance Sheet Location	Derivatives		Derivatives			Net Total
Swaps	Other current liabilities	$	805	$	(4,472	)	$	(3,667	)
Swaps	Other deferred credits	60		(809		)	(749		)
Total		$	865	$	(5,281	)	$	(4,416	)
December 31, 2018		Asset		Liability
Instrument	Balance Sheet Location	Derivatives		Derivatives			Net Total
Swaps	Prepaid and other current assets	$	243	$	(99	)	$	144
Swaps	Other current liabilities	1,595		(3,347		)	(1,752		)
Swaps	Other deferred credits	141		(251		)	(110		)
Total		$	1,979	$	(3,697	)	$	(1,718	)

The estimated fair values of the natural gas derivatives were determined using future natural gas index prices (as more fully described below). Master netting arrangements exist with each counterparty that provide for the net settlement (in the settlement month) of all contracts through a single payment. As applicable, management has elected to reflect the net amounts in its balance sheets. There was no outstanding collateral associated with the Swaps during either period shown in the above table.

Pursuant to regulatory deferral accounting treatment for rate-regulated entities, unrealized gains and losses in fair value of the Swaps are recorded as a regulatory asset and/or liability. When the Swaps mature, any prior positions held are reversed and the settled position is recorded as an increase or decrease of purchased gas under the related purchase gas adjustment (“PGA”) mechanism in determining the deferred PGA balances. Neither changes in fair value nor settled amounts of Swaps have a direct effect on earnings or other comprehensive income.

The following table shows the amounts Southwest paid to and received from counterparties for settlements of matured Swaps.

	Three Months Ended		Twelve Months Ended
(Thousands of dollars)	March 31, 2019		March 31, 2019
Paid to counterparties	$	1,882	$	5,948
Received from counterparties	$	1,047	$	1,653

The following table details the regulatory assets/(liabilities) offsetting the derivatives at fair value in the Condensed Consolidated Balance Sheets for both the Company and Southwest (thousands of dollars).

March 31, 2019
Instrument	Balance Sheet Location	Net Total
Swaps	Prepaid and other current assets	$	3,667
Swaps	Deferred charges and other assets	749
December 31, 2018
Instrument	Balance Sheet Location	Net Total
Swaps	Other current liabilities	$	(144	)
Swaps	Prepaid and other current assets	1,752
Swaps	Deferred charges and other assets	110

The estimated fair values of Southwest’s Swaps were determined at March 31, 2019 and December 31, 2018 using futures settlement prices for the delivery of natural gas at Henry Hub adjusted by the price of future settlement bases, which reflect the difference between the price of natural gas at a given delivery basin and the Henry Hub pricing points. These Level 2 inputs are observable in the marketplace throughout the full term of the Swaps, but have been credit-risk adjusted with no significant impact to the overall fair value measurement.

23

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

The following table sets forth, by level within the three-level fair value hierarchy that ranks the inputs used to measure fair value by their reliability, the financial assets and liabilities that were accounted for at fair value by both the Company and Southwest:

Level 2 - Significant other observable inputs

(Thousands of dollars)	March 31, 2019			December 31, 2018
Assets at fair value:
Prepaid and other current assets - Swaps	$	—		$	144
Liabilities at fair value:
Other current liabilities - Swaps	(3,667		)	(1,752		)
Other deferred credits - Swaps	(749		)	(110		)
Net Assets (Liabilities)	$	(4,416	)	$	(1,718	)

No financial assets or liabilities associated with the Swaps, which were accounted for at fair value, fell within Level 1 or Level 3 of the fair value hierarchy.

Note 6 – Common Stock

On March 29, 2017, the Company filed with the SEC an automatic shelf registration statement on Form S-3 (File No. 333-217018), which became effective upon filing, for the offer and sale of up to $150 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 March 29, 2017, between the Company and BNY Mellon Capital Markets, LLC (the “Equity Shelf Program”). The following table provides activity in the Equity Shelf Program for the three and twelve months ended March 31, 2019:

	Three Months Ended						Twelve Months Ended
	March 31,						March 31,
	2019			2018			2019			2018
Gross proceeds	$	23,073,149		$	9,199,661		$	99,023,464		$	50,976,456
Less: agent commissions	(230,731		)	(91,997		)	(990,234		)	(509,765		)
Net proceeds	$	22,842,418		$	9,107,664		$	98,033,230		$	50,466,691
Number of shares sold	277,829			137,300			1,286,234			643,007
Weighted average price per share	$	83.05		$	67.00		$	76.99		$	79.28

During the quarter ended March 31, 2019, the Company sold all of the remaining common stock available for sale under the program. Net proceeds from the sales of shares of common stock under the Equity Shelf Program are intended for general corporate purposes, including the acquisition of property for the construction, completion, extension or improvement of pipeline systems and facilities located in and around the communities served by Southwest. Net proceeds during the three months ended March 31, 2019 were contributed to, and reflected in the records of, Southwest (as a capital contribution from Southwest Gas Holdings, Inc.).

During the three months ended March 31, 2019, the Company issued approximately 53,000 shares of common stock through the Restricted Stock/Unit Plan and Management Incentive Plan.

Also during the three months ended March 31, 2019, the Company issued 34,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan (“DRSPP”), raising approximately $2.8 million.

On May 2, 2019, at the Company’s annual meeting of shareholders, the Company’s shareholders approved an amendment to the Company’s Articles of Incorporation to increase the number of shares of common stock available for issuance from 60,000,000 to 120,000,000.

24

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Note 7 – Long-Term Debt

Carrying amounts of long-term debt and related estimated fair values as of March 31, 2019 and December 31, 2018 are disclosed in the following table. Southwest’s revolving credit facility (including commercial paper) and the variable-rate Industrial Development Revenue Bonds (“IDRBs”) approximate their carrying values, as they are repaid quickly (in the case of credit facility borrowings) and have interest rates that reset frequently. These are categorized as Level 1 due to Southwest’s ability to access similar debt arrangements at measurement dates with comparable terms, including variable/market rates. The fair values of Southwest’s debentures, senior notes, and fixed-rate IDRBs were determined utilizing a market-based valuation approach, where fair values are determined based on evaluated pricing data, such as broker quotes and yields for similar securities adjusted for observable differences. Significant inputs used in the valuation generally include benchmark yield curves, credit ratings and issuer spreads. The external credit rating, coupon rate, and maturity of each security are considered in the valuation, as applicable. The fair values of debentures and fixed-rate IDRBs are categorized as Level 2 (observable market inputs based on market prices of similar securities). The Centuri secured revolving credit and term loan facility and Centuri other debt obligations (not actively traded) are categorized as Level 3, based on significant unobservable inputs to their fair values. Because Centuri’s debt is not publicly traded, fair values for the secured revolving credit and term loan facility and other debt obligations were based on a conventional discounted cash flow methodology and utilized current market pricing yield curves, across Centuri’s debt maturity spectrum, of other industrial bonds with an assumed credit rating comparable to the Company’s.

25

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

	March 31, 2019					December 31, 2018
	Carrying Amount			Market Value		Carrying Amount			Market Value
(Thousands of dollars)
Southwest Gas Corporation:
Debentures:
Notes, 4.45%, due 2020	$	125,000		$	126,990	$	125,000		$	126,213
Notes, 6.1%, due 2041	125,000			154,294		125,000			150,728
Notes, 3.875%, due 2022	250,000			255,015		250,000			254,195
Notes, 4.875%, due 2043	250,000			277,683		250,000			268,985
Notes, 3.8%, due 2046	300,000			283,635		300,000			267,030
Notes, 3.7%, due 2028	300,000			306,465		300,000			298,926
8% Series, due 2026	75,000			95,128		75,000			93,827
Medium-term notes, 7.78% series, due 2022	25,000			27,715		25,000			27,497
Medium-term notes, 7.92% series, due 2027	25,000			30,824		25,000			30,016
Medium-term notes, 6.76% series, due 2027	7,500			8,845		7,500			8,651
Unamortized discount and debt issuance costs	(11,641		)			(11,807		)
	1,470,859					1,470,693
Revolving credit facility and commercial paper	150,000			150,000		150,000			150,000
Industrial development revenue bonds:
Variable-rate bonds:
Tax-exempt Series A, due 2028	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	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	(1,900		)			(2,024		)
	198,100					197,976
Less: current maturities	—					—
Long-term debt, less current maturities - Southwest Gas Corporation	$	1,818,959				$	1,818,669
Centuri:
Centuri term loan facility	$	254,534		$	257,579	$	255,959		$	260,135
Unamortized debt issuance costs	(1,343		)			(1,414		)
	253,191					254,545
Centuri secured revolving credit facility	6,361			6,363		—			—
Centuri other debt obligations	62,678			63,365		67,104			67,053
Less: current maturities	(34,915		)			(33,060		)
Long-term debt, less current maturities - Centuri	$	287,315				$	288,589
Consolidated Southwest Gas Holdings, Inc.:
Southwest Gas Corporation long-term debt	$	1,818,959				$	1,818,669
Centuri long-term debt	322,230					321,649
Less: current maturities	(34,915		)			(33,060		)
Long-term debt, less current maturities - Southwest Gas Holdings, Inc.	$	2,106,274				$	2,107,258

26

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Southwest has a $400 million credit facility that is scheduled to expire in March 2022. Southwest designates $150 million of capacity related to the facility as long-term debt and has designated the remaining $250 million for working capital purposes. Interest rates for the credit facility are calculated at either the London Interbank Offered Rate (“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, 2019, the applicable margin is 1% for loans bearing interest with reference to LIBOR and 0% for loans bearing interest with reference to the alternative base rate. At March 31, 2019, $150 million was outstanding on the long-term portion (including the commercial paper program, discussed below) and $188 million was outstanding on the short-term portion of this credit facility (see Note 8 – Short-Term Debt).

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 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, 2019, as noted above, $50 million was outstanding under the commercial paper program.

In November 2018, Centuri, in association with the acquisition of Linetec, amended and restated its senior secured revolving credit and term loan facility, increasing the capacity from $450 million to $590 million; the amended facility is scheduled to expire in November 2023. This facility includes a revolving credit facility and a term loan facility. The line of credit portion of the facility is $325 million; amounts borrowed and repaid under the revolving credit facility are available to be re-borrowed. The term loan facility portion has a limit of approximately $265 million. The $590 million revolving credit and term loan facility is secured by substantially all of Centuri’s assets except those explicitly excluded under the terms of the agreement (including owned real estate and certain certificated vehicles). Centuri assets securing the facility at March 31, 2019 totaled $1.1 billion. At March 31, 2019, $261 million in borrowings were outstanding under the Centuri facility.

Note 8 – Short-Term Debt

The Company has a $100 million credit facility that is scheduled to expire in March 2022. The Company had no short-term borrowings outstanding at March 31, 2019 under this facility.

As discussed in Note 7 – Long-Term Debt, Southwest has a $400 million credit facility that is scheduled to expire in March 2022, of which $250 million has been designated by management for working capital purposes. Southwest had $188 million in short-term borrowings outstanding at March 31, 2019 under this facility.

27

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Note 9 – Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income

The tables below provide details of activity in equity, the noncontrolling interest, and the redeemable noncontrolling interest for the Company on a consolidated basis for the three-month periods ended March 31, 2019 and March 31, 2018.

	Southwest Gas Holdings, Inc. Equity
(In thousands, except per share amounts)	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Non-controlling Interest						Redeemable Noncontrolling Interest (Temporary Equity)
	Shares	Amount													Total
December 31, 2018	53,026	$	54,656	$	1,305,769	$	(52,668	)	$	944,285		$	(452	)	$	2,251,590		$	81,831
Common stock issuances	365	365		27,024											27,389
Net income (loss)									94,809						94,809			575
Foreign currency exchange translation adjustment						791									791
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax						619									619
FSIRS amounts reclassified to net income, net of tax						635									635
Dividends declared
Common: $0.545 per share									(29,285		)				(29,285		)
March 31, 2019	53,391	$	55,021	$	1,332,793	$	(50,623	)	$	1,009,809		$	(452	)	$	2,346,548		$	82,406

	Southwest Gas Holdings, Inc. Equity
	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Non-controlling Interest
(In thousands, except per share amounts)	Shares	Amount													Total
December 31, 2017	48,090	$	49,720	$	955,332	$	(47,682	)	$	857,398		$	(2,365	)	$	1,812,403
Common stock issuances	247	247		10,148											10,395
Net income (loss)									79,091			(797		)	78,294
Foreign currency exchange translation adjustment						(911		)							(911		)
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax						895									895
FSIRS amounts reclassified to net income, net of tax						635									635
Reclassification of excess deferred taxes (a)						(9,300		)	9,300						—
Dividends declared
Common: $0.52 per share									(25,335		)				(25,335		)
March 31, 2018	48,337	$	49,967	$	965,480	$	(56,363	)	$	920,454		$	(3,162	)	$	1,876,376

(a) Reclassification for the release of excess deferred taxes as a result of the adoption of ASU No. 2018-02 “Income Statement—Reporting Comprehensive Income—Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income,” which permitted release of excess amounts created following the December 2017 enactment of U.S. tax reform.

28

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

The tables below provide details of activity in equity for Southwest during the three-month periods ended March 31, 2019 and March 31, 2018. Only equity shares of the Company are publicly traded, under the ticker symbol “SWX.”

	Southwest Gas Corporation Equity
	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings
(In thousands)	Shares	Amount										Total
December 31, 2018	47,482	$	49,112	$	1,065,242	$	(49,049	)	$	717,155		$	1,782,460
Net income									103,389			103,389
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax						619						619
FSIRS amounts reclassified to net income, net of tax						635						635
Stock-based compensation (a)				918					(160		)	758
Dividends declared to Southwest Gas Holdings, Inc.									(22,800		)	(22,800		)
Contributions from Southwest Gas Holdings, Inc.				22,842								22,842
March 31, 2019	47,482	$	49,112	$	1,089,002	$	(47,795	)	$	797,584		$	1,887,903

	Southwest Gas Corporation Equity
	Common Stock			Additional Paid-in Capital			Accumulated Other Comprehensive Income (Loss)			Retained Earnings
(In thousands)	Shares	Amount											Total
December 31, 2017	47,482	$	49,112	$	948,767		$	(47,073	)	$	659,193		$	1,609,999
Net income										90,349			90,349
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax							895						895
FSIRS amounts reclassified to net income, net of tax							635						635
Reclassification of excess deferred taxes (b)							(9,300		)	9,300			—
Stock-based compensation (a)				(568		)				(166		)	(734		)
Dividends declared to Southwest Gas Holdings, Inc.										(22,000		)	(22,000		)
March 31, 2018	47,482	$	49,112	$	948,199		$	(54,843	)	$	736,676		$	1,679,144

(a) Stock-based compensation is based on stock awards of Southwest Gas Corporation to be issued in shares of Southwest Gas Holdings, Inc.

(b) Reclassification for the release of excess deferred taxes as a result of the adoption of ASU No. 2018-02, which permitted release of excess amounts created following the December 2017 enactment of U.S. tax reform.

The following information provides insight into amounts impacting 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 in the Condensed Consolidated Balance Sheets and the associated column in the equity tables above. See Note 5 – Derivatives for additional information on the FSIRS.

29

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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

(Thousands of dollars)

	Three Months Ended									Three Months Ended
	March 31, 2019									March 31, 2018
	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:
Amortization of prior service cost	$	317		$	(76	)	$	241		$	334		$	(80	)	$	254
Amortization of net actuarial (gain)/loss	5,844			(1,403		)	4,441			8,404			(2,017		)	6,387
Regulatory adjustment	(5,347		)	1,284			(4,063		)	(7,560		)	1,814			(5,746		)
Pension plans other comprehensive income	814			(195		)	619			1,178			(283		)	895
FSIRS (designated hedging activities):
Amounts reclassified into net income	836			(201		)	635			837			(202		)	635
FSIRS other comprehensive income	836			(201		)	635			837			(202		)	635
Total other comprehensive income - Southwest Gas Corporation	1,650			(396		)	1,254			2,015			(485		)	1,530
Foreign currency translation adjustments:
Translation adjustments	791			—			791			(911		)	—			(911		)
Foreign currency other comprehensive income (loss)	791			—			791			(911		)	—			(911		)
Total other comprehensive income - Southwest Gas Holdings, Inc.	$	2,441		$	(396	)	$	2,045		$	1,104		$	(485	)	$	619

	Twelve Months Ended									Twelve Months Ended
	March 31, 2019									March 31, 2018
	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)	$	(20,426	)	$	4,902		$	(15,524	)	$	(43,027	)	$	10,326		$	(32,701	)
Amortization of prior service cost	1,318			(316		)	1,002			1,335			(460		)	875
Amortization of net actuarial (gain)/loss	31,057			(7,454		)	23,603			27,488			(9,269		)	18,219
Regulatory adjustment	(6,020		)	1,446			(4,574		)	10,515			(115		)	10,400
Pension plans other comprehensive income (loss)	5,929			(1,422		)	4,507			(3,689		)	482			(3,207		)
FSIRS (designated hedging activities):
Amounts reclassified into net income	3,344			(803		)	2,541			3,345			(1,155		)	2,190
FSIRS other comprehensive income	3,344			(803		)	2,541			3,345			(1,155		)	2,190
Total other comprehensive income (loss) - Southwest Gas Corporation	9,273			(2,225		)	7,048			(344		)	(673		)	(1,017		)
Foreign currency translation adjustments:
Translation adjustments	(1,308		)	—			(1,308		)	640			—			640
Foreign currency other comprehensive income (loss)	(1,308		)	—			(1,308		)	640			—			640
Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	7,965		$	(2,225	)	$	5,740		$	296		$	(673	)	$	(377	)

(1) Tax amounts are calculated using a 24% rate following the December 22, 2017 enactment date of U.S. tax reform. For periods prior to the enactment date (and included in specific line items of the tables for the twelve months ended March 31, 2018), tax amounts were calculated using a 38% rate. The tax effect of before-tax amounts remaining in the balance of Accumulated other comprehensive income (loss) as of March 31, 2019 is effectively computed using a 24% tax rate overall. With regard to foreign currency translation adjustments, the Company has elected to indefinitely reinvest the earnings of Centuri’s Canadian subsidiaries in Canada, thus preventing deferred taxes on such earnings. As a result of this assertion, the Company is not recognizing any tax effect or presenting a tax expense or benefit for the currency translation adjustment amount reported in Other comprehensive income (loss), as repatriation of earnings is not anticipated.

30

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Approximately $2.5 million of realized losses (net of tax) related to the FSIRS, reported in Accumulated other comprehensive income (loss) at March 31, 2019, will be reclassified into interest expense within the next 12 months as the related interest payments on long-term debt occur.

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

AOCI - Rollforward    

(Thousands of dollars)

	Defined Benefit Plans									FSIRS									Foreign Currency Items
	Before-Tax			Tax (Expense) Benefit (4,5)			After-Tax (5)			Before-Tax			Tax (Expense) Benefit (4,5)			After-Tax (5)			Before-Tax			Tax (Expense) Benefit		After-Tax			AOCI
Beginning Balance AOCI December 31, 2018	$	(55,227	)	$	13,254		$	(41,973	)	$	(9,310	)	$	2,234		$	(7,076	)	$	(3,619	)	$	—	$	(3,619	)	$	(52,668	)
Translation adjustments	—			—			—			—			—			—			791			—		791			791
Other comprehensive income (loss) before reclassifications	—			—			—			—			—			—			791			—		791			791
FSIRS amounts reclassified from AOCI (1)	—			—			—			836			(201		)	635			—			—		—			635
Amortization of prior service cost (2)	317			(76		)	241			—			—			—			—			—		—			241
Amortization of net actuarial loss (2)	5,844			(1,403		)	4,441			—			—			—			—			—		—			4,441
Regulatory adjustment (3)	(5,347		)	1,284			(4,063		)	—			—			—			—			—		—			(4,063		)
Net current period other comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.	814			(195		)	619			836			(201		)	635			791			—		791			2,045
Ending Balance AOCI March 31, 2019	$	(54,413	)	$	13,059		$	(41,354	)	$	(8,474	)	$	2,033		$	(6,441	)	$	(2,828	)	$	—	$	(2,828	)	$	(50,623	)

(1) The FSIRS reclassification amounts are 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.

(5) The beginning balances depict amounts attributable to the individual components of AOCI (Defined Benefit Plans and FSIRS) following the adoption of ASU No. 2018-02, with no impact to the total balance of AOCI resulting from the depiction.

31

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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

AOCI - Rollforward

(Thousands of dollars)

	Defined Benefit Plans									FSIRS
	Before-Tax			Tax (Expense) Benefit (9,10)			After-Tax (10)			Before-Tax			Tax (Expense) Benefit (9,10)			After-Tax (10)			AOCI
Beginning Balance AOCI December 31, 2018	$	(55,227	)	$	13,254		$	(41,973	)	$	(9,310	)	$	2,234		$	(7,076	)	$	(49,049	)
FSIRS amounts reclassified from AOCI (6)	—			—			—			836			(201		)	635			635
Amortization of prior service cost (7)	317			(76		)	241			—			—			—			241
Amortization of net actuarial loss (7)	5,844			(1,403		)	4,441			—			—			—			4,441
Regulatory adjustment (8)	(5,347		)	1,284			(4,063		)	—			—			—			(4,063		)
Net current period other comprehensive income attributable to Southwest Gas Corporation	814			(195		)	619			836			(201		)	635			1,254
Ending Balance AOCI March 31, 2019	$	(54,413	)	$	13,059		$	(41,354	)	$	(8,474	)	$	2,033		$	(6,441	)	$	(47,795	)

(6) The FSIRS reclassification amounts are included in Net interest deductions on Southwest’s Condensed Consolidated Statements of Income.

(7) 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).

(8) The regulatory adjustment represents the portion of the activity above that is expected to be recovered through rates in the future (the related regulatory asset is included in Deferred charges and other assets on Southwest’s Condensed Consolidated Balance Sheets).

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

(10) The beginning balances depict amounts attributable to the individual components of AOCI (Defined Benefit Plans and FSIRS) following the adoption of ASU No. 2018-02, with no impact to the total balance of AOCI resulting from the depiction.

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:

Amounts Recognized in AOCI (Before Tax)

(Thousands of dollars)

	March 31, 2019			December 31, 2018
Net actuarial (loss) gain	$	(429,520	)	$	(435,364	)
Prior service cost	(2,716		)	(3,033		)
Less: amount recognized in regulatory assets	377,823			383,170
Recognized in AOCI	$	(54,413	)	$	(55,227	)

32

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Note 10 – Segment Information

The Company has two reportable segments: natural gas operations and utility infrastructure services. Southwest has a single reportable segment that is referred to herein as the natural gas operations segment of the Company. In order to reconcile to net income as disclosed in the Condensed Consolidated Statements of Income, an Other column is included associated with impacts related to corporate and administrative activities related to Southwest Gas Holdings, Inc. The following tables present revenues from external customers, intersegment revenues, and segment net income for the two reportable segments (thousands of dollars):

	Natural Gas Operations		Utility Infrastructure Services			Other			Total
Three Months Ended March 31, 2019
Revenues from external customers	$	520,677	$	274,189		$	—		$	794,866
Intersegment revenues	—		38,673			—			38,673
Total	$	520,677	$	312,862		$	—		$	833,539
Segment net income (loss)	$	103,389	$	(8,031	)	$	(549	)	$	94,809
Three Months Ended March 31, 2018
Revenues from external customers	$	494,313	$	232,859		$	—		$	727,172
Intersegment revenues	—		27,158			—			27,158
Total	$	494,313	$	260,017		$	—		$	754,330
Segment net income (loss)	$	90,349	$	(11,001	)	$	(257	)	$	79,091
	Natural Gas Operations		Utility Infrastructure Services			Other			Total
Twelve Months Ended March 31, 2019
Revenues from external customers	$	1,384,092	$	1,427,701		$	—		$	2,811,793
Intersegment revenues	—		147,429			—			147,429
Total	$	1,384,092	$	1,575,130		$	—		$	2,959,222
Segment net income (loss)	$	151,882	$	47,947		$	(1,834	)	$	197,995
Twelve Months Ended March 31, 2018
Revenues from external customers	$	1,334,019	$	1,211,345		$	—		$	2,545,364
Intersegment revenues	—		103,021			—			103,021
Total	$	1,334,019	$	1,314,366		$	—		$	2,648,385
Segment net income (loss)	$	170,229	$	34,693		$	(1,298	)	$	203,624

Note 11 – Redeemable Noncontrolling Interest

In connection with the acquisition of Linetec in November 2018, the previous owner retained a 20% equity interest in Linetec, the reduction of which is subject to certain rights based on the passage of time or upon the occurrence of certain triggering events. Effective January 2022, the Company has the right, but not the obligation, to purchase at fair value (subject to a floor) a portion of the interest held by the noncontrolling party, and in incremental amounts each year thereafter. The shares subject to the election accumulate (if earlier elections are not made) such that 100% of the interest retained by the noncontrolling party is subject to the election beginning in 2024. If the Company does not exercise its rights at each or any of the specified intervals, the noncontrolling party has the ability, but not the obligation, to exit their investment retained by requiring Centuri to purchase a similar portion of their interest up to the maximum cumulative amounts specified at each interval discussed above. The Company has determined that this noncontrolling interest is a redeemable noncontrolling interest and, in accordance with SEC guidance, is classified as mezzanine equity (temporary equity) in the Company’s Condensed Consolidated Balance Sheets.

33

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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. However, the carrying value of the redeemable noncontrolling interest was greater than its fair value as of March 31, 2019, and no previous upward redemption value adjustments were made following the acquisition date. SEC guidance indicates that a redemption value adjustment would not be made under these circumstances. The following depicts changes to the balance of the redeemable noncontrolling interest between the indicated periods.

	Redeemable Noncontrolling Interest
(Thousands of dollars):
Balance, December 31, 2018	$	81,831
Net income attributable to redeemable noncontrolling interest	575
Balance, March 31, 2019	$	82,406

Note 12 – Business Acquisitions

In November 2018, the Company, through its subsidiaries, led principally by Centuri, completed the acquisition of an 80% interest in a privately held infrastructure services business, Linetec Services, LLC (“Linetec”) with the remaining 20% retained by the seller. See the Company’s 2018 Form 10-K for additional information about this acquisition.

Assets acquired and liabilities assumed in the transaction were recorded, generally, 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 customer relationships, trade names, and customer contracts. Certain payments were estimated as of the acquisition date and will be adjusted when paid; the final purchase accounting has not yet been completed. Further refinement is expected to occur, including potential changes to income taxes and intangibles, as well as additional consideration payments held back.

The preliminary estimated fair values of assets acquired and liabilities assumed as of November 30, 2018, are as follows (millions of dollars):

	Acquisition Date		Measurement Period Adjustments			Revised Acquisition Date
Cash and cash equivalents	$	3.9	$	—		$	3.9
Accounts receivable	32.8		(0.5		)	32.3
Revenue earned on contracts in progress in excess of billings	21.6		1.7			23.3
Prepaid expenses and other current assets	1.1		0.2			1.3
Property and equipment	89.4		(0.5		)	88.9
Intangible assets	89.3		—			89.3
Goodwill	188.5		3.3			191.8
Total assets acquired	426.6		4.2			430.8
Accounts payable	8.0		—			8.0
Accrued liabilities	6.9		1.6			8.5
Deferred compensation and related accrued taxes	3.4		—			3.4
Redeemable noncontrolling interest	81.7		—			81.7
Total liabilities assumed and noncontrolling interest	100.0		1.6			101.6
Net assets acquired	$	326.6	$	2.6		$	329.2

34

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

The Company incurred and expensed acquisition costs of $6.9 million for the twelve months ended March 31, 2019 which are included in Utility infrastructure services expenses on the Company’s Condensed Consolidated Statement of Income. No acquisition-related costs were incurred during the three months ended March 31, 2019.

The preliminary allocation of the purchase price of Linetec 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 Linetec was deemed an asset purchase for tax purposes, the tax-basis goodwill is expected to be deductible for tax purposes. In the first quarter of 2019, values at the acquisition date were adjusted as reflected in the table above on the Company’s Condensed Consolidated Balance Sheets.

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). At the annual meeting of shareholders of Southwest Gas Holdings, Inc., held on May 2, 2019, shareholders voted to approve changing the state of incorporation of Southwest Gas Holdings, Inc. from California to Delaware. We expect the reincorporation to be effective during the second or third quarter of 2019. However, the reincorporation remains subject to certain regulatory approvals, which are currently pending, and we can provide no assurances as to the timing for such approvals. For more information about the reincorporation, please refer to Southwest Gas Holdings, Inc.’s Definitive Proxy Statement on Schedule 14A, filed with the Securities and Exchange Commission (the “SEC”) on March 18, 2019. Southwest Gas Holdings, Inc. and its subsidiaries are collectively referred to as the “Company.”

Southwest is engaged in the business of purchasing, distributing, and transporting natural gas for customers in portions of Arizona, Nevada, and California. Southwest is the largest distributor of natural gas in Arizona, selling and transporting natural gas in most of central and southern Arizona, including the Phoenix and Tucson metropolitan areas. Southwest is also the largest distributor of natural gas in Nevada, serving the majority of southern Nevada, including the Las Vegas metropolitan area, and portions of northern Nevada. In addition, Southwest distributes and transports natural gas for customers in portions of California, including the Lake Tahoe area and the high desert and mountain areas in San Bernardino County.

As of March 31, 2019, Southwest had 2,058,000 residential, commercial, industrial, and other natural gas customers, of which 1,096,000 customers were located in Arizona, 765,000 in Nevada, and 197,000 in California. Residential and small commercial customers represented over 99% of the total customer base. During the twelve months ended March 31, 2019, 53% of operating margin (gas operating revenues less the net cost of gas sold) was earned in Arizona, 36% in Nevada, and 11% in California. During this same period, Southwest earned 85% of its operating margin from residential and small commercial customers, 3% from other sales customers, and 12% from transportation customers. These general patterns are expected to remain materially consistent for the foreseeable future.

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. Refer to the Summary Operating Results table for a reconciliation of revenues to operating margin.

The demand for natural gas is seasonal, with greater demand in the colder winter months and decreased demand in the warmer summer months. All of Southwest’s service territories have decoupled rate structures (alternative revenue programs), which are designed to eliminate the direct link between volumetric sales and revenue, thereby mitigating the impacts of weather variability and conservation on operating margin, allowing Southwest to pursue energy efficiency initiatives.

Centuri is a comprehensive utility infrastructure services enterprise dedicated to delivering a diverse array of solutions to North America’s gas and electric providers. Centuri derives revenue from installation, replacement, repair, and maintenance of energy distribution systems, and developing industrial construction solutions. Centuri operates in 26 major markets in the United States (“U.S.”), primarily as NPL, and in 2 major markets in Canada, primarily as NPL Canada. In November 2017, Centuri expanded its operations in the northeast region of the U.S. through the acquisition of New England Utility Constructors, Inc. (“Neuco”), and

35

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

again in November 2018, in the southeast region of the U.S. through the acquisition of an 80% interest in Linetec Services, LLC (“Linetec”). Both companies were privately owned utility infrastructure services businesses.

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). During the past few years, utilities have implemented or modified system integrity management programs to enhance safety pursuant to federal and state mandates. These programs, coupled with historic bonus depreciation tax deduction incentives, have resulted in a significant increase 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 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.

This Management’s Discussion and Analysis (“MD&A”) of Financial Condition and Results of Operations should be read in conjunction with the unaudited consolidated financial statements and the notes thereto included in this Quarterly Report on Form 10-Q and the audited financial statements and the notes thereto, as well as MD&A, included in the 2018 Annual Report to Shareholders, which is incorporated by reference into the 2018 Form 10-K.

36

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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 average of 80% of twelve-month-to-date consolidated net income over the past two years. As such, MD&A is primarily focused on that segment. 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,
	Three Months						Twelve Months
	2019			2018			2019			2018
	(In thousands, except per share amounts)
Contribution to net income
Natural gas operations	$	103,389		$	90,349		$	151,882		$	170,229
Utility infrastructure services	(8,031		)	(11,001		)	47,947			34,693
Corporate and administrative	(549		)	(257		)	(1,834		)	(1,298		)
Net income	$	94,809		$	79,091		$	197,995		$	203,624
Average number of common shares	53,369			48,416			50,640			48,105
Basic earnings per share
Consolidated	$	1.78		$	1.63		$	3.91		$	4.23
Natural Gas Operations
Reconciliation of Revenue to Operating Margin (Non-GAAP measure)
Gas operating revenues	$	520,677		$	494,313		$	1,384,092		$	1,334,019
Less: Net cost of gas sold	192,604			185,732			426,260			393,898
Operating margin	$	328,073		$	308,581		$	957,832		$	940,121

1st Quarter 2019 Overview

Natural gas operations highlights:

• 32,000 net new customers (1.6% growth rate) during the last 12 months

• Operating margin increased $19 million

• Other income improved $8.3 million from returns on Company-Owned Life Insurance policies

• $57 million Arizona general rate case filed in May 2019

Utility infrastructure services highlights:

• Revenues increased $52.8 million (including $47.6 million from Linetec)

• Quarterly net loss improved by $3 million

37

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Results of Natural Gas Operations

Quarterly Analysis

	Three Months Ended
	March 31,
	2019		2018
	(Thousands of dollars)
Gas operating revenues	$	520,677	$	494,313
Net cost of gas sold	192,604		185,732
Operating margin	328,073		308,581
Operations and maintenance expense	105,542		102,190
Depreciation and amortization	57,612		49,961
Taxes other than income taxes	16,206		15,257
Operating income	148,713		141,173
Other income (deductions)	5,946		(4,603		)
Net interest deductions	23,099		19,255
Income before income taxes	131,560		117,315
Income tax expense	28,171		26,966
Contribution to consolidated net income	$	103,389	$	90,349

Contribution from natural gas operations to consolidated net income increased $13 million between the first quarters of 2019 and 2018. The increase was primarily due to rate relief, customer growth, and higher Other income (deductions), partially offset by an increase in Operations and maintenance expense, Depreciation and amortization, and Net interest deductions.

Operating margin increased $19 million, including a $4 million increase attributable to customer growth, as 32,000 net new customers were added during the last twelve months. Rate relief in California and Nevada added an additional $4 million in operating margin. The current quarter includes a $4 million improvement as reserves for the regulatory impacts of tax reform were recognized in the prior-year quarter. The remaining increase includes the combined impact of surcharge recoveries for infrastructure replacement programs and other mechanisms, and changes in other miscellaneous revenues and margin from customers outside the decoupling mechanisms, offset by a $4.7 million one-time adjustment by the Arizona Corporation Commission (“ACC”) to reflect the impacts of U.S. tax reform on the Arizona decoupling mechanism.

Operations and maintenance expense increased $3.4 million, or 3%, between quarters. Higher pipeline integrity management and damage prevention programs and other general cost increases were mitigated by decreases in pension and medical costs between quarters.

Depreciation and amortization expense increased $7.7 million between quarters primarily due to regulatory account amortization, notably from California Public Purpose and environmental programs (approximately $5 million combined), and due to a $527 million, or 8%, increase in average gas plant in service for the current quarter as compared to the corresponding quarter a year ago. The increase in gas plant was attributable to pipeline capacity reinforcement work, franchise requirements, scheduled and accelerated pipe replacement activities, and new infrastructure.

Other income (deductions) improved $10.5 million between quarters primarily due to an increase in income from company-owned life insurance (“COLI”) policies. The current quarter reflects a $7.6 million increase in COLI policy cash surrender values, while the prior-year quarter reflected a $700,000 COLI-related loss. The non-service cost components of employee pension and other postretirement benefits improved $1.5 million between quarters.

Net interest deductions increased $3.8 million in the first quarter of 2019, as compared to the prior-year quarter, primarily due to the issuance of $300 million of senior notes in March 2018, higher borrowings outstanding under the revolving credit and term-loan facility, and carrying cost on PGA balances payable in the current quarter.

38

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Results of Natural Gas Operations

Twelve-Month Analysis

	Twelve Months Ended
	March 31,
	2019			2018
	(Thousands of dollars)
Gas operating revenues	$	1,384,092		$	1,334,019
Net cost of gas sold	426,260			393,898
Operating margin	957,832			940,121
Operations and maintenance expense	408,165			389,687
Depreciation and amortization	199,467			190,688
Taxes other than income taxes	60,847			58,421
Operating income	289,353			301,325
Other income (deductions)	(6,691		)	(9,747		)
Net interest deductions	85,584			71,778
Income before income taxes	197,078			219,800
Income tax expense	45,196			49,571
Contribution to consolidated net income	$	151,882		$	170,229

Contribution to consolidated net income from natural gas operations decreased by $18.3 million between the twelve-month periods of 2019 and 2018. The decrease was primarily due to higher Operations and maintenance expense, Net interest deductions, and Depreciation and amortization expense, partially offset by rate relief and lower Income tax expense.

Operating margin increased $18 million between periods. Customer growth provided $11 million and combined rate relief in Nevada and California provided $5 million of incremental operating margin. The remaining increase in operating margin includes recoveries of regulatory assets, infrastructure replacement mechanisms, customers outside the decoupling mechanisms, and other miscellaneous revenues, net of reserve and related regulatory adjustments associated with the impacts of U.S. tax reform.

Operations and maintenance expense increased $18.5 million between periods primarily due to higher technology, administrative and other general cost increases. Included in the increase were pension-related service cost and expenditures for pipeline damage prevention programs, which increased $3 million and $3.5 million, respectively.

Depreciation and amortization expense increased $8.8 million between periods primarily due to a $487 million, or 8%, increase in average gas plant in service for the current period as compared to the prior period. The increase reflects an offsetting reduction in regulatory amortization between periods of approximately $1 million.

Taxes other than income taxes increased $2.4 million, or 4%, between periods primarily due to higher property taxes associated with net plant additions.

Other income (deductions) improved $3.1 million between the twelve-month periods of 2019 and 2018 primarily due to an increase in interest income related to the Gas Infrastructure Replacement (“GIR”) mechanism in Nevada and the equity component of the allowance for funds used during construction (“AFUDC”) due to greater construction expenditures and higher AFUDC rates in the current period. Income from changes in the cash surrender value of COLI policies and net death benefits was $5.1 million in the current period and $6.8 million in the prior-year period.

Net interest deductions increased $13.8 million between periods primarily due to higher interest associated with issuance of the $300 million of senior notes in March 2018, higher credit facility borrowings, and impacts from PGA balances payable in the current period.

39

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Results of Utility Infrastructure Services

Quarterly Analysis

	Three Months Ended
	March 31,
	2019			2018
	(Thousands of dollars)
Utility infrastructure services revenues	$	312,862		$	260,017
Operating expenses:
Utility infrastructure services expenses	300,465			258,952
Depreciation and amortization	19,927			12,517
Operating income (loss)	(7,530		)	(11,452		)
Other income (deductions)	875			263
Net interest deductions	3,269			3,196
Loss before income taxes	(9,924		)	(14,385		)
Income tax benefit	(2,468		)	(2,587		)
Net loss	(7,456		)	(11,798		)
Net income (loss) attributable to noncontrolling interest	575			(797		)
Contribution to consolidated net income (loss) attributable to Centuri	$	(8,031	)	$	(11,001	)

In November 2018, Centuri acquired Linetec. The table above, therefore, includes results for Linetec only in the 2019 period, including $47.6 million of revenue and $2.3 million of net income attributable to Linetec in 2019.

Utility infrastructure services revenues increased $52.8 million in the first quarter of 2019 when compared to the prior-year quarter, primarily due to the $47.6 million of revenues contributed by Linetec, in addition to a higher volume of pipe replacement work under blanket and bid contracts.

Utility infrastructure services expenses increased $41.5 million in the first quarter of 2019 when compared to the prior-year quarter due to $37.9 million of Linetec expenses and costs to complete additional pipe replacement work, in addition to higher labor-related costs incurred to complete work during inclement weather conditions in the current-year quarter. Net gains on sale of equipment (reflected as an offset to Utility infrastructure services expenses) were approximately $200,000 for each of the first quarters of 2019 and 2018.

Depreciation and amortization expense increased $7.4 million between quarters. Approximately $5.7 million of the increase is due to the Linetec acquisition, including amortization of finite-lived intangible assets and depreciation of property and equipment of $900,000 and $4.8 million, respectively, for the first quarter 2019. The remaining increase in depreciation was attributable to additional equipment purchased to support the growing volume of work being performed.

Net interest deductions increased by $73,000 between quarters due primarily to higher average debt outstanding under the existing $590 million secured revolving credit and term loan facility in 2019.

40

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Results of Utility Infrastructure Services

Twelve-Month Analysis

	Twelve Months Ended
	March 31,
	2019		2018
	(Thousands of dollars)
Utility infrastructure services revenues	$	1,575,130	$	1,314,366
Operating expenses:
Utility infrastructure services expenses	1,429,202		1,215,959
Depreciation and amortization	64,806		50,263
Operating income	81,122		48,144
Other income (deductions)	374		354
Net interest deductions	14,263		9,678
Income before income taxes	67,233		38,820
Income tax expense	18,539		4,520
Net income	48,694		34,300
Net income (loss) attributable to noncontrolling interest	747		(393		)
Contribution to consolidated net income attributable to Centuri	$	47,947	$	34,693

Results for Linetec have been included in the table above during the period following the November 2018 acquisition date, including $61.7 million of revenue and $3 million of net income reflected in the twelve-month period ending in March 2019. Furthermore, in November 2017, Centuri acquired Neuco. Results for Neuco have been included following its acquisition date, including $155.4 million and $31.2 million of revenues, and $28.5 million and $1.5 million of net income, in each case, respectively, during the comparative twelve-month periods ending in March 2019 and 2018.

Utility infrastructure services revenues increased $260.8 million overall in the current twelve-month period compared to the same period of 2018, primarily due to the combined $185.9 million in incremental revenue noted above for Linetec and Neuco, and to continued growth with existing customers under existing master service and bid agreements. In addition, revenue was favorably impacted year over year by certain non-routine projects with customers.

Utility infrastructure services expenses increased $213.2 million between periods, primarily due to related expenses for Linetec and Neuco of $48.1 million and $78.6 million, respectively, and additional pipe replacement work and higher labor-related operating expenses to support growth in operations. Net gains on sale of equipment (reflected as an offset to Utility infrastructure services expenses) were $1.7 million and $4.1 million for the twelve-month periods of 2019 and 2018, respectively.

Depreciation and amortization expense increased $14.5 million between the current and prior-year periods. The increase was attributable to the incremental depreciation and amortization related to certain tangible and intangible assets recognized as a result of the Linetec and Neuco acquisitions, as well as increased depreciation on additional property and equipment purchased to support the growing volume of work being performed.

Net interest deductions increased $5 million between periods due primarily to interest expense and amortization of debt issuance costs associated with incremental borrowings under the $590 million secured revolving credit and term loan facility (primarily related to the Neuco and Linetec acquisitions).

Income tax expense during the twelve-month period ending March 31, 2018 was favorably impacted by approximately $12 million of one-time tax benefits related to the remeasurement of Centuri’s deferred tax liabilities when U.S. tax reform was enacted in December 2017.

41

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Rates and Regulatory Proceedings

Southwest is subject to the regulation of the Arizona Corporation Commission (the “ACC”), the Public Utilities Commission of Nevada (the “PUCN”), the California Public Utilities Commission (the “CPUC”), and the Federal Energy Regulatory Commission (the “FERC”).

General Rate Relief and Rate Design

Rates charged to customers vary according to customer class and rate jurisdiction and are set by the individual state and federal regulatory commissions that govern Southwest’s service territories. Southwest makes periodic filings for rate adjustments as the cost of providing service (including the cost of natural gas purchased) changes, and as additional investments in new or replacement pipeline and related facilities are made. Rates are intended to provide for recovery of all commission-approved costs and provide 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 the 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. On March 18, 2019, Southwest filed its Notice of Intent to file a new general rate application, which was filed in May 2019. In this latest application, Southwest requests to update rates to reflect recent U.S. tax reform, including the flow back of approximately $20.6 million of excess deferred income taxes and to update the cost of service to consider, among other things, capital investments of approximately $670 million, including post-test year additions for, among other things, the southern Arizona LNG facility discussed below. Overall, the request includes an increase in revenue of approximately $57 million, including a proposed 10.3% return on equity relative to a capital structure of 51.1% equity. The request also includes the retention of a decoupled rate design, previously approved regulatory mechanisms, and a new infrastructure tracking mechanism for specific plastic pipe. The request also includes a proposal for a renewable natural gas program that authorizes Southwest to purchase renewable natural gas for its customers and to recover the cost as part of its purchased gas adjustment mechanism.

Delivery Charge Adjustment. The annual Delivery Charge Adjustment (“DCA”) rate adjustment is filed each April, which along with other reporting requirements, contemplates a rate to recover the over- or under-collected margin tracker amounts based on the balance at the end of the preceding calendar year. The DCA rate adjustment filed in April 2018 reflected the December 31, 2017 balance of approximately $40 million. Following a brief administrative delay, Southwest updated its request to instead include the balance at December 31, 2018 of $73 million. The ACC approved a surcharge to recover approximately $69 million, the difference of which relates to a one-time modification to reflect one-time benefits attributable to the impact of recent landmark U.S. tax reform on the decoupled balance existing at the enactment date of such reform. The updated rate will replace the existing rate effective May 1, 2019.

Tax Reform. In February 2018, the ACC directed all Arizona utilities to address tax savings from the enactment of U.S. tax reform beginning January 1, 2018 through one of various means. In April 2018, Southwest filed an application with the ACC, requesting approval for a tax refund process or, in the alternative, the authority to file a general rate case to reflect tax reform. Ultimately, Southwest was instructed to refund customers a one-time credit to reflect the tax savings from January through July 2018, effective with Southwest’s August 2018 billing cycles. In addition, effective August 2018, per-therm surcredits were established and will be effective until new cost-of-service rates are implemented following the conclusion of the general rate case filed in May 2019. These undertakings are expected to refund $20 million annually, as compared to rate levels established in the previously concluded general rate case effective April 2017. Through March 2019, Southwest has reflected relevant proportional amounts associated with the annualized $20 million as a reduction in revenue and is tracking monthly differences between amounts expected to be returned and amounts actually returned to customers, which has resulted in a liability balance of $1.5 million as of March 31, 2019. See related discussion above with regard to the DCA.

Liquefied Natural Gas (“LNG”) Facility. In January 2014, Southwest filed an application with the ACC seeking 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, to be operated by Southwest and connected directly to its distribution system. In December 2014, Southwest received an order from the ACC granting preapproval of the construction and deferral of costs, up to $50 million, which was later approved (December 2016) to be modified not to exceed $80 million, following land purchase and bid solicitation for the engineering, procurement, and construction of the facility. Construction began during the third quarter of 2017 and is expected to be substantially complete in the second quarter of 2019 with the facility available for use during the winter of 2019/2020. Through March 2019, Southwest has incurred approximately $64 million in capital expenditures toward the project (including land acquisition costs).

42

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

COYL Program. Southwest received approval, in connection with its 2010 Arizona general rate case, to implement a program to conduct leak surveys, and if leaks were present, to replace and relocate service lines and meters for Arizona customers whose meters were set off from the customer’s home, representing a non-traditional configuration. “Phase II” of the COYL program included the replacement of non-leaking COYLs. The surcharge is revised annually as the program progresses. In the annual filing made in February 2019, Southwest requested to increase its surcharge revenue by $3.2 million (to $6.7 million overall) related to the revenue requirement associated with $26.6 million in capital projects completed under both phases during 2018. The surcharge application is expected to be considered by the ACC in the third quarter of 2019.

Vintage Steel Pipe (“VSP”) Program. Southwest received approval, in connection with its 2016 Arizona general rate case, to implement a VSP replacement program. Southwest currently has approximately 6,000 miles of pre-1970s vintage steel pipe in Arizona. Southwest proposed to start replacing the pipe on an accelerated basis and to recover the costs through an annual surcharge filing that is made in February of each year. The surcharge is designed to be revised annually as the program progresses. Southwest replaced approximately 119 miles of vintage steel pipe during 2018 totaling approximately $100 million, and is targeting a similar amount for projects during 2019. In the February 2019 VSP filing, Southwest requested to increase its surcharge revenue by $9.5 million (to $11.9 million) related to 2018 expenditures. The surcharge application is expected to be considered by the ACC in the third quarter of 2019.

Customer Data Modernization Initiative. Southwest is embarking on an initiative to replace both its customer service system and gas transaction system, which are referred to as the Customer Data Modernization Initiative (the “CDMI”). In March 2019, Southwest filed an application with the ACC seeking an accounting order which, if approved, would authorize Southwest to track and defer all costs associated with the CDMI to mitigate adverse financial implications associated with this significant multi-year project. Total cost for the CDMI is an estimated $174 million, approximately $96 million of which would be allocable to the Arizona rate jurisdiction. The initiative is currently expected to be completed during the third quarter of 2021. Resolution of this request is expected before the end of 2019.

California Jurisdiction

California General Rate Case. As part of the most recent Southwest general rate case application, with rates effective June 2014, the CPUC authorized an overall revenue increase of $7.1 million, a Post-Test Year (“PTY”) Ratemaking Mechanism, which allowed for attrition increases of 2.75% annually for 2015 to 2018, a depreciation reduction as requested, a limited COYL inspection program for schools, and an Infrastructure Reliability and Replacement Adjustment Mechanism (“IRRAM”) to recover the costs associated with the new limited COYL program. The CPUC decision also provided for a two-way pension balancing account to track differences between authorized and actual pension funding amounts.

In December 2016, Southwest filed to modify the most recent general rate case decision to extend the current rate case cycle by two years, including extension of the annual 2.75% PTY attrition adjustments for 2019 and 2020, which was approved by the CPUC in June 2017. Southwest expects to file a general rate case application in the third quarter of 2019.

Tax Reform. In its 2017 decision approving Southwest’s request to extend the filing date of its next general rate case, the CPUC also directed Southwest to track income tax expenses resulting from mandatory or elective changes in tax law, procedure, or policy. The purpose is to identify differences between Southwest’s authorized income tax expenses and its actual incurred income tax expenses, the result of which would be reviewed in Southwest’s next general rate case. During the first quarter of 2019, Southwest reflected $1.8 million as a reserve for amounts attributable to the impact of U.S. tax reform on the ratemaking revenue requirement. Excluding advance requested or required procedural changes, Southwest does not currently anticipate making an ad hoc filing in advance of the next general rate case filing to implement rate changes resulting from U.S. tax reform.

Attrition Filing. In November 2018, Southwest made its latest annual PTY attrition filing, requesting annual revenue increases of $2 million in southern California, $542,000 in northern California, and $271,000 for South Lake Tahoe. This filing was approved in December 2018 and rates were made effective in January 2019. At the same time, rates were updated to recover the regulatory asset associated with the revenue decoupling mechanism, or margin tracker.

Greenhouse Gas (“GHG”) Compliance. California Assembly Bill Number 32 and the regulations promulgated by the California Air Resources Board, require Southwest, as a covered entity, to comply with all applicable requirements associated with California GHG emissions reporting and the California Cap and Trade Program. The CPUC issued a decision in March 2018 adopting an allocation methodology to distribute the net revenues or costs for years 2015-2017 beginning in the second quarter of 2018. 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 directed the adoption of an allocation methodology to distribute the revenue proceeds through a California Climate Credit to active residential customers in April of each year, following initial required credits in October 2018. GHG compliance costs recovered through rates (including transportation customer rates) have no impact on earnings overall.

43

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Customer Data Modernization Initiative. As discussed above for Arizona, Southwest is embarking on an initiative to replace both its customer service system and its gas transaction system, referred to as its CDMI. On April 26, 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 significant multi-year project. Total cost for the CDMI is an estimated $174 million, approximately $19 million of which would be allocable to the California rate jurisdiction. Resolution of this request is expected before the end of 2019.

Nevada Jurisdiction

Nevada General Rate Case. Southwest filed its most recent general rate case with the PUCN in May 2018 and updated the request following the certification period ending in July 2018. The filing requested a statewide overall revenue increase of approximately $29.7 million.

The PUCN issued a rate case decision in December 2018, which authorized a return on equity (“ROE”) of 9.25% relative to the Company’s proposed capital structure of 49.66% equity applicable to both southern and northern Nevada and provided for an overall revenue increase of $9.5 million in southern Nevada and a revenue decrease in northern Nevada of $2 million. New rates associated with the PUCN’s decision became effective in January 2019.

The rate relief was lower than the amounts requested due to several factors, including the 9.25% granted return on equity, as opposed to a requested 10.3%, and the exclusion from rates at this time of costs attributable to several software applications, albeit allowing the Company to request recovery in its next general rate case filing. In response to the PUCN’s decision, management filed a Petition for Reconsideration (the “Petition”) of several rate case issues in January 2019. The PUCN Staff also filed a Petition for Reconsideration requesting several technical clarifications on the rate case decision with respect to how to calculate the intended results of the decision. The PUCN, in turn, issued a decision regarding both petitions in February 2019 that modified certain parts of the original order, but granted no further rate relief. The modified final decision resulted in a revenue increase of $9.2 million in southern Nevada and a revenue decrease in northern Nevada of $2.1 million. The decision included a reduction in depreciation expense of $800,000 and overall, resulted in a net increase in revenues of $7.1 million and an increase in operating income of $7.9 million. The resulting modified rates became effective March 2019. Management decided to seek judicial review of the Commission’s rate order, the resolution of which is expected by the end of 2019.

General Revenues Adjustment. As part of the Annual Rate Adjustment (“ARA”) filing in 2018, the PUCN authorized rate adjustments associated with the General Revenues Adjustment (“GRA”), to recover $5.6 million from customers during 2019. The continuation of the GRA was affirmed as part of the December 2018 rate case decision. While there is no impact to net income overall from this rate adjustment, operating cash flows will increase as the associated regulatory asset balance is recovered.

Infrastructure Replacement Mechanism. In 2014, the PUCN approved final rules for the GIR mechanism which defers and recovers certain costs associated with accelerated replacement of qualifying infrastructure that would not otherwise currently provide incremental revenues. Associated with the replacement of various types of pipe infrastructure under the mechanism (Early Vintage Plastic Pipe (“EVPP”), COYL, and VSP), each year Southwest files a GIR “Advance Application” in May and a “Rate Application,” generally in October. In June 2018, Southwest filed its Advance Application requesting authorization to replace qualifying infrastructure with projects totaling $228 million to be completed over a three-year period, with a total annualized revenue requirement (following the three-year replacement period) of approximately $21.7 million. Historically, Southwest has requested approval of projects on an annual basis; however, it requested to move to a multi-year approval process for projects to improve operational flexibility and enhance coordination with contractors and governmental agencies. The PUCN issued a decision limiting its approval to the 2019 projects, resulting in an approval of $34.3 million for projects to be completed in 2019 (EVPP $9.3 million, COYL $1.3 million, and VSP $23.7 million).

The Rate Application is generally filed each October to reset the GIR recovery surcharge related to previously approved and completed projects, with new rates becoming effective each January. During the third quarter of 2018, management proposed to adjust the GIR surcharge rate as part of the rate case in lieu of filing a separate application, which was approved and implemented in January 2019. It is expected to result in incremental annual margin of approximately $6 million.

Conservation and Energy Efficiency (“CEE”). The PUCN allows deferral (and later recovery) of approved conservation and energy efficiency costs, recovery rates for which are adjusted in the annual rate adjustment filing. As part of the 2018 ARA filing, Southwest requested and received modified rates, effective January 2019, which are expected to result in an annualized margin decrease of $4.1 million in southern Nevada and a $58,000 decrease in northern Nevada. There is, however, no anticipated impact to net income overall from these changes as amortization expense is impacted by approximately the same amounts.

Expansion and Economic Development Legislation. In January 2016, final regulations were approved by the PUCN associated with legislation (“SB 151”) previously introduced and signed into law in Nevada. The legislation authorized natural gas utilities to expand their infrastructure to provide service to unserved and underserved areas in Nevada.

44

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

In November 2017, Southwest filed for pre-approval 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 to expand natural gas infrastructure to Mesquite, including a capital investment of approximately $28 million and the construction of approximately 37 miles of distribution pipeline (including the approach main). The cost is expected to be recovered through volumetric rates from all southern Nevada customers (including new customers in Mesquite). The annual revenue requirement associated with the project is approximately $2.8 million. Southwest conducted preliminary design work and began serving certain customers with an approved virtual pipeline network in February 2019, which provides temporary natural gas supply using portions of the approved distribution system and compressed natural gas tanks. It is estimated that permitting and construction of the approach main to bring the permanent supply to Mesquite and construction of the remaining approved distribution system could take an additional two years to complete.

Customer Data Modernization Initiative. As indicated in the other jurisdictions, Southwest is planning to embark on an initiative to replacement both its customer service system and gas transaction system with the CDMI. In March 2019, Southwest filed a request seeking authority to establish a regulatory asset to defer the revenue requirement related to the CDMI to mitigate the financial attrition associated with this significant multi-year project. Of the total $174 million estimated cost of the CDMI, approximately $59 million would be allocable to the Nevada rate jurisdictions. Resolution of this request is expected before the end of 2019.

Federal Energy Regulatory Commission (“FERC”) Jurisdiction

General Rate Case. Paiute Pipeline Company (“Paiute”), a wholly owned subsidiary of Southwest, filed its most recent general rate case with the FERC in February 2014, and following settlement proceedings, tariff changes were filed in March 2015. The settlement implied an 11.5% pre-tax rate of return, and as part of the agreement, Paiute agreed to file a rate case no later than the end of May 2019. See Tax Reform below.

2018 Expansion. In response to growing demand in the Carson City and South Lake Tahoe areas of northern California and northern Nevada, Paiute evaluated shipper interest in acquiring additional transportation capacity, and executed precedent agreements for incremental transportation capacity with Southwest. The FERC approved the project at a cost of $22 million, which approximates the total cost incurred to complete the project. Construction work began in July 2018, consisting of 8.5 miles of additional transmission pipeline infrastructure. The project was completed and placed in service in November 2018.

Tax Reform.  The FERC issued a Notice of Proposed Rulemaking (“NOPR”) on whether the federal income tax changes from U.S. tax reform cause pipeline rates to no longer be just and reasonable. The NOPR provided for pipelines to file a FERC Form No. 501‑G to evaluate the impact of tax reform on their revenue requirement. In addition to filing the form, pipelines would select one of the following four options: (1) make a limited “Section 4” filing to reduce rates by the percentage reduction in cost of service shown in its FERC Form No. 501-G; (2) commit to file either a prepackaged uncontested rate settlement or a general Section 4 rate case; (3) file a statement explaining why no change in rates was necessary; or (4) file the new FERC form without taking any other action. In July 2018, the FERC issued a final rule (Order No. 849), effective in September 2018, adopting procedures for determining which jurisdictional pipelines may be collecting unjust and unreasonable rates in light of tax reform. Paiute filed its Form No. 501-G in the fourth quarter of 2018. Two of Paiute’s shippers requested that FERC evaluate Paiute’s rates and/or take action to ensure that Paiute’s customers are afforded the relief contemplated in Order No. 849. The FERC has not acted on these requests; however, in the absence of any action in advance, Paiute’s general rate case application, expected to be filed in late May 2019, will further address tax reform. In November 2018, Southwest Gas Transmission Company (“SGTC”), also a FERC-regulated subsidiary of Southwest, filed an uncontested, prepackaged settlement in lieu of filing the FERC Form No. 501-G, with no material impacts overall. FERC issued an Order approving the settlement in December 2018, and new rates became effective in January 2019.

45

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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. At March 31, 2019, under-collections in northern and southern Nevada and California resulted in an asset of $65.2 million and over-collections in Arizona resulted in a liability of $72.2 million on the Company’s and Southwest’s Condensed Consolidated Balance Sheets. During the third quarter of 2018, a $49 million refund was received by Southwest from El Paso Natural Gas, L.L.C. (“EPNG”) as part of a rate case settlement, the majority of which relates to Southwest’s transmission service into Arizona and resulted in a liability included in Deferred purchased gas costs. This amount is included in the over-collected balance noted above. In October 2018, Southwest filed an application with the ACC requesting an alternate methodology for refunding the EPNG funds allocated to the Arizona rate jurisdiction customers, which would have involved offsetting sizable amounts receivable from Arizona customers under the DCA mechanism. This proposal was offered as an alternative to refunding the amounts through the PGA in order to provide administrative efficiency. Ultimately, the ACC considered the EPNG issue separately and approved, effective May 1, 2019, the return of the EPNG rate case settlement dollars as a special per-therm PGA credit, which is expected to be in place for approximately twelve months.

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 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):

	March 31, 2019			December 31, 2018			March 31, 2018
Arizona	$	(72,213	)	$	(72,878	)	$	11,687
Northern Nevada	12,962			4,928			2,993
Southern Nevada	51,221			(5,951		)	4,059
California	1,059			(933		)	(371		)
	$	(6,971	)	$	(74,834	)	$	18,368

Capital Resources and Liquidity

Cash on hand and cash flows from operations in the past twelve months have generally provided the majority of cash used in investing activities (primarily for construction expenditures and property additions). In recent years, the Company has accelerated pipe replacement activities to fortify system integrity and reliability, notably in association with gas infrastructure replacement programs as discussed previously. 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 maintain strong investment-grade credit ratings, which should minimize interest costs.

Cash Flows

Southwest Gas Holdings, Inc.:

Operating Cash Flows. Cash flows provided by consolidated operating activities increased $8 million in the first three months of 2019 as compared to the same period of 2018. The improvements in cash flows included an increase in net income and benefits from depreciation as well as the impacts of working capital components overall. Additionally, changes in operating cash flows are typically influenced significantly by the change in purchased gas costs, including amounts incurred and deferred, as well as when amounts are incorporated in customer bills to recover the deferred balances.

Investing Cash Flows. Cash used in consolidated investing activities increased $53 million in the first three months of 2019 as compared to the same period of 2018. The change was primarily due to increased construction expenditures in the natural gas operations segment, including scheduled and accelerated replacement activity.

Financing Cash Flows. Net cash provided by consolidated financing activities increased $36 million in the first three months of 2019 as compared to the same period of 2018. The increase was primarily due to increased borrowings under Southwest’s credit facility (see Note 8 – Short-Term Debt), as well as an increase in issuances of stock under the Company’s Equity Shelf Program during the first three months of 2019 (see Note 6 – Common Stock).

The Company issued approximately $22.8 million in stock during the first three months of 2019 under its Equity Shelf Program and approximately 53,000 additional shares of common stock collectively through the Restricted Stock/Unit Plan and the

46

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Management Incentive Plan. Also during the three months ended March 31, 2019, the Company issued 34,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan (“DRSPP”), raising approximately $2.8 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 financing sources. However, the holding company may raise funds through stock issuance or other external financing sources in support of each business segment, as discussed in Note 6 – Common Stock.

Southwest Gas Corporation:

Operating Cash Flows. Cash flows provided by operating activities increased $5 million in the first three months of 2019 as compared to the same period of 2018. The increase in operating cash flows was primarily attributable to an increase in net income and benefits from depreciation as well as the impacts of working capital components overall. Offsetting those increases were the impacts related to deferred purchased gas costs noted above.

Investing Cash Flows. Cash used in investing activities increased $32 million in the first three months of 2019 as compared to the same period of 2018. The change was primarily due to additional construction expenditures, as indicated above.

Financing Cash Flows. Net cash provided by financing activities increased $62 million in the first three months of 2019 as compared to the same period of 2018. The increase was primarily due to borrowing under the short-term portion of the credit facility in 2019 and capital contributions from Southwest Gas Holdings, Inc. The prior period included repayment of the credit facility and commercial paper program borrowings following the issuance of $300 million in senior notes in March 2018.

Gas Segment Construction Expenditures and Financing

During the twelve-month period ended March 31, 2019, construction expenditures for the natural gas operations segment were $715 million. The majority of these expenditures represented costs associated with scheduled and accelerated replacement of existing transmission, distribution, and general plant. Cash flows from operating activities of Southwest were $388 million during this time and provided approximately 48% of construction expenditures and dividend requirements.

Management estimates natural gas segment construction expenditures during the three-year period ending December 31, 2021 will be approximately $2.1 billion. Of this amount, approximately $710 million is expected to be incurred in 2019. Southwest plans to continue to request regulatory support to accelerate projects that improve system flexibility and reliability (including replacement of early vintage plastic and steel pipe). 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 for discussion of Nevada infrastructure, Arizona COYL, and an LNG facility. During the three-year period, cash flows from operating activities of Southwest are expected to provide approximately 45% to 50% of the funding for gas operations total construction expenditures and dividend requirements. Any additional cash requirements are expected to be provided by existing credit facilities, equity contributions from the Company, and/or other external financing sources. The timing, types, and amounts of any additional external financings will be dependent on a number of factors, including the cost of gas purchases, conditions in the capital markets, timing and amounts of rate relief, timing differences between U.S. federal taxes embedded in customer rates and amounts implemented under tax reform, as well as growth levels in Southwest’s service areas and earnings. External financings could include the issuance of debt securities, bank and other short-term borrowings, and other forms of financing.

In March 2018, Southwest issued $300 million in 3.7% Senior Notes at a discount of 0.185%. The notes will mature in April 2028. The proceeds were used to repay amounts then outstanding under the revolving portion of its credit facility and under the commercial paper program.

In March 2017, the Company filed with the SEC an automatic shelf registration statement for the offer and sale of up to $150 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 March 29, 2017, between the Company and BNY Mellon Capital Markets, LLC (the “Equity Shelf Program”). The Company has issued the full capacity of the equity program, concluding during the quarter ended March 31, 2019.

During the twelve months ended March 31, 2019, 1,286,234 shares were issued in at-the-market offerings at an average price of $76.99 per share with gross proceeds of $99 million, agent commissions of $990,234, and net proceeds of $98 million. See Note 6 – 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

47

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

Company estimates bonus depreciation will defer the payment of approximately $30 million ($4 million of which relates to utility operations) of federal income taxes for 2019.

Dividend Policy

Dividends are payable on the Company’s common stock at the discretion of the Board of Directors (the “Board”). In setting the dividend rate, the Board 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 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 2019, the Board elected to increase the quarterly dividend from $0.52 to $0.545 per share, representing a 4.8% increase, effective with the June 2019 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 general factors (some of which are out of the control of the Company) that could significantly affect liquidity in future years include: variability of natural gas prices, changes in the ratemaking policies of regulatory commissions, regulatory lag, customer growth in the natural gas segment’s service territories, the ability to access and obtain capital from external sources, interest rates, changes in income tax laws, pension funding requirements, inflation, and the level of earnings. Natural gas prices and related gas cost recovery rates, as well as plant investment, have historically had the most significant impact on liquidity.

On an interim basis, Southwest defers over- or under-collections of gas costs to PGA balancing accounts. In addition, Southwest uses this mechanism to either refund amounts over-collected or recoup amounts under-collected as compared to the price paid for natural gas during the period since the last PGA rate change went into effect. At March 31, 2019, the combined balance in the PGA accounts totaled an over-collection of $7 million, which included the EPNG rate case settlement of $49 million. See PGA Filings for more information.

The Company has a credit facility with a borrowing capacity of $100 million that expires in March 2022. The Company intends to utilize this facility for short-term financing needs. At March 31, 2019, no borrowings were outstanding under this facility.

Southwest has a credit facility, with borrowing capacity of $400 million, which expires in March 2022. 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) during the first three months of 2019 was $150 million, the same amount which was outstanding at March 31, 2019. Commercial paper borrowings are discussed below. Additionally, $188 million was outstanding on the short-term portion of this credit facility. The credit facility can be used as necessary to meet liquidity requirements, including temporarily financing under-collected PGA balances, if any, or meeting the refund needs of over-collected balances. This credit facility has been adequate for Southwest’s working capital needs outside of funds raised through operations and other types of external financing, and 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 2019 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, 2019, there was $50 million outstanding under this program.

Centuri has a senior secured revolving credit and term loan facility with borrowing capacity of $590 million (refer to Note 7 – Long-Term Debt). The line of credit portion of the facility is $325 million; amounts borrowed and repaid under the revolving credit facility are available to be re-borrowed. The term loan facility portion has a limit of approximately $265 million. The $590 million credit and term loan facility expires in November 2023. The $590 million revolving credit and term loan facility is secured by substantially all of Centuri’s assets except those explicitly excluded under the terms of the agreement (including owned real estate and certain certificated vehicles). Centuri assets securing the facility at March 31, 2019 totaled $1.1 billion. The maximum amount outstanding on the revolving credit facility during the first three months of 2019 was $25 million. At March 31, 2019, $6 million was outstanding on the secured revolving credit facility. Also at March 31, 2019, there was approximately $300 million, net of letters of credit, available under the line of credit.

48

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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 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, interest savings, the Company’s COLI strategy, replacement market and new construction market, expected impacts of valuation adjustments associated with the redeemable noncontrolling interest in Linetec, the impacts of the U.S. tax reform including disposition in regulatory proceedings and bonus depreciation tax deductions, the impact of recent PHMSA rulemaking, the amounts and timing for completion of estimated future construction expenditures, including the LNG facility in southern Arizona, forecasted operating cash flows and results of operations, net earnings impacts from gas infrastructure replacement surcharges, funding sources of cash requirements, amounts generally expected to be reflected in 2019 or future period revenues from regulatory rate proceedings including amounts requested from the recently filed Arizona general rate case, the approved recovery of the Arizona DCA balance, the outcome of judicial review of the recently concluded Nevada rate case, the anticipated timing of the Company’s reincorporation in Delaware, rates and surcharges, PGA, 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 December 2017 shelf registration statement 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 rate changes or regulatory proceedings, contract or construction change order negotiations, impacts of accounting standard updates, infrastructure replacement mechanisms and COYL programs, statements regarding future gas prices, gas purchase contracts and derivative financial instruments, recoverability of regulatory assets, the impact of certain legal proceedings, and the timing and results of future rate hearings, including the multi-jurisdictional filings for recovery of the CDMI, and 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 ability to recover costs through the PGA mechanisms or other regulatory assets, the effects of regulation/deregulation, governmental or regulatory policy regarding natural gas or alternative energy, 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 conditions in the capital markets on financing costs, changes in construction expenditures and financing, changes in operations and maintenance expenses, effects of pension expense forecasts, accounting changes and regulatory treatment related thereto, currently unresolved and future liability claims, changes in pipeline capacity for the transportation of gas and related costs, results of Centuri bid work, Centuri’s projections about the acquired business’ earnings (including accretion within the first twelve months) and future acquisition-related costs, impacts of changes in value of the redeemable noncontrolling interest if at other than fair value, resolution of events subject to cash consideration held back associated with representations, warranties, and other estimates including working capital adjustments related to the Linetec acquisition and impacts from final purchase accounting related thereto, Centuri utility infrastructure expenses, differences between actual and originally expected outcomes of Centuri bid or other fixed-price construction agreements, outcomes from contract and change order negotiations, ability to successfully procure new work, impacts from work awarded or failing to be awarded from significant customers, the mix of work awarded, the amount of work awarded to Centuri following the lifting of work stoppages, acquisitions, and management’s plans related thereto, competition, our ability to raise capital in external financings, our ability to continue to remain within the ratios and other limits subject to our debt covenants, and ongoing evaluations in regard to goodwill and other intangible assets. In addition, the Company can provide no assurance that its discussions regarding certain trends relating to its financing and operating expenses will continue or cease to continue in future periods. For additional information on the risks associated with the Company’s business, see Item 1A. Risk Factors and Item 7A. Quantitative and Qualitative Disclosures About Market Risk in the Annual Report on Form 10‑K for the year ended December 31, 2018.

All forward-looking statements in this quarterly report are made as of the date hereof, based on information available to the Company as of the date hereof, and the Company assumes 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).

49

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

See Item 7A. Quantitative and Qualitative Disclosures about Market Risk in the 2018 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.

Based on the most recent evaluation, as of March 31, 2019, management of Southwest Gas Holdings, Inc., including the Chief Executive Officer and Chief Financial Officer, believes the Company’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 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 2019 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, 2019, 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.

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 2019 that have materially affected, or are likely to materially affect Southwest’s internal control over financial reporting.

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.

ITEMS 1A through 3. None.

ITEM 4. MINE SAFETY DISCLOSURES Not applicable.

ITEM 5. OTHER INFORMATION None.

50

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

ITEM 6. EXHIBITS

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

Exhibit 10.01		Amendment to the Centuri Group, Inc. Executive Long-Term Incentive Plan.
Exhibit 10.02		Amendment to the Centuri Group, Inc. Long-Term Capital Investment Plan.
Exhibit 10.03		Form of Paul Daily Award Agreement under the Centuri Group, Inc. Executive Long-Term Incentive Plan.
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
Exhibit 101SCH	-	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

51

SOUTHWEST GAS HOLDINGS, INC.	Form 10-Q
SOUTHWEST GAS CORPORATION	March 31, 2019

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)

Date: May 8, 2019

/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)

Date: May 8, 2019

/s/ LORI L. COLVIN

Lori L. Colvin

Vice President/Controller and Chief Accounting Officer

52

EX-10.01

Centuri Construction Group, Inc.

Executive Long-Term Incentive Plan (LTIP)

Effective: January 1, 2019

CONFIDENTIAL

Executive Summary

This Centuri Long-Term Incentive Plan (“LTIP” or the “Plan”) provides an opportunity for key-management level employees of Centuri Construction Group, Inc. (“Centuri”) and/or its affiliates to be rewarded for management decisions and actions that create long-term value for Centuri and/or its affiliates. Along with a competitive base-salary, benefits package and a short-term incentive plan (STIP), the LTIP completes key-management compensation by rewarding effective leadership over a multiyear period.

Eligible personnel can earn an LTIP cash-award for a Plan Year that will be determined using a three-year measurement period and an approximately three and one-half year cliff-vesting schedule. In addition, pursuant to the Southwest Gas Holdings, Inc. Omnibus Incentive Plan, Participants may be granted restricted stock units for a Plan Year based upon the three-year measurement period and the formulas contained in this Plan and in a stock award agreement executed by the Participant. The LTIP is intended to be an unfunded plan of deferred compensation for a select group of higher compensated and managerial employees of Centuri and its affiliated companies.

Table of Contents

SECTION    PAGE

PLAN OBJECTIVES1

ELIGIBILITY AND TARGET LONG-TERM INCENTIVE OPPORTUNITY1

PLAN DESIGN WITH PERFORMANCE MEASURES AND GOALS    2

PLAN DESCRIPTION2

MEASURES AND MEASUREMENT PERIOD3

PARTICIPANTS3

VESTING AND PAYMENT3

DEFERRAL OF AN LTIP AWARD PAYMENT AND PAYMENT OF

DEFERRED AMOUNTS    7

LTIP CALCULATION AND EXAMPLE7

TERMS AND CONDITIONS8

GOVERNING TERMS AND CONDITIONS9

APPENDIX A: THREE-YEAR COMPOUNDED EV GROWTH (%) AND AWARD PERCENTAGES

Plan Objectives

• Retain key executives for the long-term.

• Connect long-term compensation to Centuri’s long-term strategy.

• Incentivize key executives to act like owners.

Eligibility and Target Long-Term Incentive Opportunity

With a view towards rewarding those executives and managers with significant influence over Centuri’s performance, eligibility for the Plan will be based upon such pay-grades (including appropriate executives and managers) as are selected by the Centuri Compensation Steering Committee (the “Committee”) which group shall be comprised of the Centuri President & CEO (the “Centuri CEO”), the Centuri Executive Vice- President/Chief Financial Officer, and the Centuri Senior Vice-President/Human Resources.

Each eligible executive will be required to execute an award agreement each year which will contain his or her Plan Year LTIP target incentive opportunity expressed as a percentage of Base Salary at both “Target” and “Maximum” performance (see below), with incentives based on attainment of earnings growth. An eligible executive’s Base Salary will be based on the executive’s salary as of the end of the calendar year preceding the Plan Year, and the executive’s target percentage will be based on his/her position as of the end of the calendar year preceding the Plan Year.

The term “Plan Year” or “year” means the calendar year. The Plan shall remain in effect from year to year until amended or terminated as provided herein.

An executive eligible to participate in the LTIP must be employed by Centuri, or one of Centuri’s affiliated companies, on the first day of the Plan Year. Notwithstanding the foregoing, during the three-year measurement period (each three-year measurement period a “Performance Period”) commencing at the beginning of a Plan Year, the Centuri CEO may designate one or more other executives as eligible to participate in the LTIP; provided, however, that any LTIP award payable to such designated executive shall be a prorated award, as determined by the Committee, with such proration based on the portion of the Performance Period in which the designated executive actually participates in the LTIP. The salary amount used for the proration will be the base salary for the year the executive began participation in the Plan.

The LTIP opportunity will be calculated based on the Participant’s target award percentage of Base Salary as shown in the Participant’s award agreement and the three-year compounded EV growth percentages and award percentages (Appendix A) for the Performance Period. The award agreements and Appendix A will be approved by the Committee and the Centuri Board of Directors (the “Board”) yearly.

Plan Design with Performance Measures and Goals

The purpose of the LTIP is to align the interests (and motivate the actions) of Centuri’s key executives and managers with the interests of Centuri’s owners in growing Centuri’s earnings. The LTIP award is determined based upon Centuri’s 3-Yr compounded Enterprise Value (EV) growth (%) rate. Where EV is defined as:

Enterprise Value = (EBITDA x Multiplier) – Net Debt

The term “Net Debt” is defined as bank borrowings less cash. On an annual basis the management of Centuri will recommend a multiplier to the Board for approval. The multiplier will be a number approved by the Board for a particular Plan Year and shall be used in the calculation of Centuri’s 3-Yr compounded Enterprise Value (EV) growth (%) rate for such year.

All determinations of Centuri’s 3-Yr compounded Enterprise Value (EV) growth (%) rate for a Plan Year shall be made by the Committee, subject to policies and procedures approved by the Board, and shall be final and conclusive with respect to all executives participating in the LTIP for a particular Plan Year.

Plan Description

Three-Year Compounded EV Growth (%)

At the beginning of a Plan Year, the Committee shall set a target three-year growth in EV goal, as a percent for Centuri. At the end of the three-year Performance Period, actual performance will be measured and compared against the pre-set goal.

Appendix A states the actual three-year compounded EV growth (%) and the award percentage applicable for different rates of actual three-year compounded EV growth (%) performance (actual performance is to be round down to the closest whole percentage). In the event that actual performance produces an EV growth (%) that straddles two percentages set forth in the “Award” column of Appendix A, the award percentage for such performance shall be the interpolated value of the two award percentages.

If the three-year compounded EV growth (%) for Centuri for the three-year Performance Period is less than the threshold indicated (i.e., the “Threshold”), then the LTIP award set forth in Appendix A shall be $0 dollars. This means that there is no LTIP payout award for such Plan Year if Centuri’s three-year compounded EV growth (%) comes in below Threshold. At or above the Threshold, the award starts at the percentage indicated of Target. The award increases until it caps out at the percentage indicated for performing at Maximum or better. Appendix A specifies the award percentage for performance levels between the minimum and maximum.

Measures and Measurement Period

The objective of the LTIP is to grow Centuri’s EV year over year. Therefore, the measurement period for compounded earnings growth is three-years. This LTIP utilizes a three-year measurement period commencing on January 1 of a particular Plan Year, and any award earned will generally be paid out, if at all, in a lump sum payment occurring during the first six calendar months following the end of the three-year measurement period conditioned upon the LTIP participant’s continued employment through the payment date.

New three-year Performance Periods and any revision to Appendix A, will be created and implemented in the discretion of the Committee and subject to approval by the Board for each Plan Year.

Participants

Pre-established for each participant are target payout amounts stated as a percent of Base Salary and shown in their award agreement. For purposes of this LTIP, the term “Base Salary” means an LTIP participant’s base salary as of the end of the calendar year preceding the Plan Year, as shown on the participant’s employer’s payroll system; provided, however, that in no event will “Base Salary” include overtime pay, disability pay, bonuses or any other type of incentive pay, cash or non- cash taxable or non-taxable fringe benefits including but not limited to car, club or other allowances, or any other supplemental compensation.

Vesting and Payment

Vesting:

An LTIP participant’s LTIP award will remain 0% vested unless the participant remains an employee of Centuri, or one of its affiliated companies, on the payment date that the LTIP award for such Plan Year is paid to the participant. Vesting of the employment condition is accelerated in the event a participating executive incurs a Separation from Service due to death, Disability, or Retirement. The terms “Disability” “Retirement” and “Separation from Service” are defined in the Payment section below.

For example:

(1)At the beginning of a Plan Year, the Committee sets the three-year target EV growth rate goal (subject to Board approval).

(2)Prior to the payment date that an LTIP award for such Plan Year is paid to a participant while he/she is still an employee of Centuri, or an affiliated company of Centuri, the participant will remain 0% vested in his/her potential LTIP award. Notwithstanding the foregoing, accelerated pro-rata vesting of a participating executive’s LTIP award employment condition applies if, prior to the payment date for the LTIP award, the executive incurs a Separation from Service due to death, Disability, or Retirement.

(3)In the first six months following the end of the Performance Period for a Plan Year (once the Centuri books are closed, three-year compounded EV growth (%) can be determined, and the award can be calculated) an award that has been earned will be paid to the participating executive in a lump sum payment if, and only if, the executive remains employed by Centuri at the time of payment. The Centuri CEO shall have the discretion to pay an award to individuals who leave employment after the Performance Period but prior to the payment date, provided such payments shall remain subject to the performance conditions of the entire Performance Period.

If during the Performance Period a participating executive incurs a Separation from Service due to death, Disability, or Retirement, the participating executive will, on such date, have his/her vesting of the employment condition accelerated on a pro-rata basis (to the nearest month of completed service) based on the percentage of the vesting period the executive has actually completed, provided that any payment shall remain subject to the performance conditions of the entire Performance Period.

Payment:

Provided that an executive has complied with the non-solicitation, non-compete, and confidentiality requirements described in Section 3.12 and achievement of the performance condition, any full or prorated LTIP award payable with respect to the participating executive will (subject to the Specified Employee rule set forth below and any existing timely and properly made deferral election made pursuant to the rules in the Centuri Construction Group, Inc. Executive Deferred Compensation Plan (the “Centuri DC Plan”) and the election requirements of Treasury Regulation Section 1.409A-2(a)(8) and Section 409A (defined below)) be paid in one lump sum payment to the executive, or if the executive has died his/her beneficiary(ies), during the first six calendar months of the calendar year immediately following the end of the Performance Period, and in all events in the year following the end of the Performance Period.

Notwithstanding the foregoing paragraph (i), if a participating executive incurs a Separation from Service due to Disability or Retirement, no award shall be paid to such executive, and such award shall be forfeited, if the executive is under age 70 and the executive has failed, prior to the end of the above-stated six-month payment period, to execute an agreement with Centuri that contains non-solicitation, non-compete, and confidentiality provisions that are acceptable to the Committee and substantially similar to the terms that the executive should have already agreed to pursuant to Section 3.12, and (ii) in the case of the restricted stock units granted to the Centuri Participants, such units shall be payable as provided in the underlying stock awards and, if applicable, the Centuri Construction Group, Inc. Long-Term Capital Investment Plan.

Payout amounts will be based upon complete service years only. For example, if an executive’s Separation from Service due to death, Disability, or Retirement occurs on June 30th in year 2 of the Performance Period, the executive’s service will yield a 50% payout of any actual LTIP award and such 50% prorated award will be multiplied by the executive’s prorated 50% vesting resulting in an LTIP award equal to 50% x 50% = 25% of the actual LTIP award that the executive would have earned if the executive’s Separation from Service had not occurred until after the end of the three-year measurement period.

The time and form of LTIP payments, as set forth in this Payment section, may not be modified unless modification is:

(1)Allowed by Section 409A of the Internal Revenue Code of 1986 (the “Code”) and the rules, regulations, and published guidance of the Internal Revenue Service (the “IRS”) for Code Section 409A (hereinafter all collectively referred to as “Section 409A”), and

(2)Approved by the Committee or the Board.

Separation from Service for any reason other than death, Disability or Retirement will result in immediate and total forfeiture of any LTIP award payments that, at the time of Separation from Service, have not been paid.

Notwithstanding the foregoing rules, if a Change in Control (as defined below) occurs, the above described pro-rated vesting and payment methodology will apply to a participating executive if:

(1)The executive incurs an employer-initiated involuntary Separation from Service within 6 months following the Change in Control transaction, or

(2)    The acquiring surviving/acquiring entity fails to assume the LTIP in its current form.

Notwithstanding the foregoing payment provisions, and subject to any deferral election made by the executive under the Centuri DC Plan, if a participating executive is a Specified Employee as of the date of his or her Separation from Service, no distribution on account of the executive’s Separation From Service, due to Retirement, may be made with respect to such executive before the date that is six months after the executive’s Separation From Service (or, if earlier than the end of the six-month period, the date of the executive’s death). In such case, any payment that would be made within such six-month period will be accumulated and paid in a single lump sum on the earliest business day that complies with the requirements of Section 409A.

For purposes of this LTIP, a “Change in Control” shall be deemed to have occurred on the date that one of the following events has occurred: (a) any one person, or more than one person acting as a group, acquires (including through purchase or by merger or other business combination) ownership of stock of Centuri that, together with stock held by such person or group, constitutes more than fifty percent (50%) of the total voting power of the stock of Centuri; provided, that (i) if any one person or more than one person acting as a group, is considered to own more than fifty percent (50%) of the total voting power of the stock of Centuri, the acquisition of additional stock by the same person or persons is not considered to cause a Change in the Control, and (ii) no Change in Control shall be deemed to have occurred by virtue of the acquisition of additional stock by any person who is a Centuri stockholder on the LTIP’s effective date (or by any group including such person); or (b) any one person, or more than one person acting as a group, acquires (or has acquired during the 12-month period ending on the date of the most recent acquisition by such person or persons) assets from Centuri that have a total gross fair market value equal to all or substantially all of the total gross fair market value of all of the assets of Centuri immediately before such acquisition or acquisitions; provided, that (i) gross fair market value means the value of the assets of Centuri, or the value of the assets being disposed of, determined without regard to any liabilities associated with such assets, and (ii) there is no Change in Control when there is a transfer to an entity that is controlled by the stockholders of Centuri immediately after such transfer. For purposes of the Plan, determinations of whether a Change in Control has occurred, whether more than one person is acting as a group, or whether an entity is controlled by the stockholders of Centuri shall all be made in accordance with Section 409A.

For purposes of this LTIP, an executive participant shall be deemed to be “Disabled” or incurred a “Disability” only if the executive has been determined to be disabled in accordance with the disability insurance maintained by Centuri.

For purposes of this LTIP, an executive will have “Retired” or incurred a Separation from Service due to “Retirement” when:

(1)With approval from the Centuri CEO, the executive elects to terminate his/her employment with Centuri, or one of its affiliated companies, after both attaining age 59½, and completing 12 complete calendar months of employment; or

(2)The executive has attained age 65 and elects to leave his/her employment with Centuri, or one of its affiliated companies.

The term “Separation From Service” means the termination of a participating executive’s employment by Centuri, or one of its affiliated companies, if the executive dies, retires, or otherwise has a termination of employment with Centuri, or one of its affiliated companies; provided, that an executive’s employment relationship is treated as continuing intact while on military leave, sick leave or other bona fide leave of absence if the period of such leave does not exceed six months or longer, if an executive’s right to reemployment is provided either by statute or by contract. A leave of absence constitutes a bona fide leave of absence only if there is a reasonable expectation that the executive will return to perform services for Centuri. If the period of leave exceeds six months and the executive does not retain a right to reemployment under an applicable statute or by contract, the employment relationship is deemed to terminate on the first date immediately following such six-month period. Notwithstanding the foregoing, where a leave of absence is due to any medically determinable physical or mental impairment that can be expected to result in death or can be expected to last for a continuous period of not less than six months, where such impairment causes the employee to be unable to perform the duties of his or her position of employment, or any substantially similar position of employment, a 29-month period of absence may be substituted for such six-month period. For purposes of the definition of “Separation from Service,” the term “Centuri” includes all other organizations that together with Centuri are part of the Code Section 414(b-c) controlled group of organizations. Whether an executive has incurred a Separation from Service shall be determined based in accordance with Section 409A. Additionally, if an executive ceases to work as a Centuri employee, but is retained to provide services as an independent contractor of Centuri, the determination of whether the executive has incurred a Separation From Service shall be determined based in accordance with Section 409A.

The term “Specified Employee” means, for any year in which Centuri (or a Code Section 414(b-c) controlled group member of Centuri) is publicly traded, any executive who is determined to be a “key employee” (as defined under Code Section 416(i) without regard to paragraph (5) thereof) for the applicable period, as determined by the Committee in accordance with Section 409A and in particular, Treasury Regulations Section 1.409A-1(i) Specified Employees.

Deferral of an LTIP Award Payment and Payment of Deferred Amounts

Payment of a Participant’s LTIP award payment may be deferred if and only if the Participant makes a timely and proper deferral election pursuant to the rules in the Centuri DC Plan and such election is compliant with the election requirements of Treasury Regulation Section 1.409A-2 and Section 409A. If a deferral election is made, the amount deferred shall be paid out at the times and in the manner dictated by the terms of such election and the payment provisions of the Centuri DC Plan.

LTIP Calculation and Example

The goal of this LTIP is to provide a long-term incentive for key executives; accordingly, the LTIP includes a mix of time based and performance-based award opportunities. This mix, the performance-based award opportunities, and the classification by executive in either Group 1 or Group 2 is shown in each participant’s award agreement.

The time-based award is not subject to a threshold to generate a payment to the executive. Time-based award amounts, however, are impacted by the change in EV at the end of the measurement period. If the EV increases by 5% or more over the measurement period, the time-based award is increased by the percent of increase, similarly, if EV decreases by 3% or more at the end of the measurement period, the time-based award amount is decreased by the percentage decrease.

Time-based awards are capped at 33.1% (10% compounded over 3 years) so as to provide the Company a quantifiable maximum payout of the time-based awards at the beginning of each plan year. Additionally, the maximum for performance-based awards is capped at the percentage indicated of target.

The amount attributable to performance-based awards is dependent on the growth of EV achieved over the three-year measurement period. If at the end of the measurement period EV grows by the target level, then the payout is at target. If EV growth does not achieve threshold, then no amount is paid.

Sample Group 1 Individual with Target Award =$100,000

30% Time-Based = $30,000

70% Performance-Based = $70,000

Assumes a target of 5% annual growth in Enterprise Value (“EV”),

a 25% Threshold and 200% Maximum

Level of Performance	Performance-Based Award	Time-Based Award		Total Award
Below Threshold (‐5% three‐year decline in EV)	0%		$28,5001	$28,500
Threshold (6.1% three‐year growth in EV)	$17,5002 (25% payout)		$31,8303	$49,330
Target (15.8% three‐year growth in EV)	$70,0004 (100% payout)		$34,7405	$104,740
Maximum (33.1% three‐year growth in EV)	$140,0006 (200% payout)		$39,9307,8	$179,930

F/N

1.    [($100,000 x 30%)] – [($100,000 x 30%) x -5%⁹] = $28,500

2.    [($100,000 x 70%) x 25%] =$17,500

3.    [($100,000 x 30%) x 6.1%⁹] =$31,830

4.    [$100,000 x 70%] = $70,000

5.    [($100,000 x 30%) x 15.8%⁹] = $34,740

6.    [($100,000 x 200%) x 70%] = $140,000

7.    Subject to 133.1% cap

8.    [($100,000 x 30%) x 133.1%] = $39,930

9.Percentage increase in EV

Terms and Conditions

LTIP adoption, amendment or termination is at the sole discretion of the Board. Plan administration and interpretation is at the sole discretion of the Committee. Nothing herein should be interpreted to communicate any manner of a promise; no obligations are created beyond those expressly stated in this document, subject to the above-reserved discretion and all other reservations herein made. Neither this document (nor the LTIP it describes) amount to, or result in, any manner of an employment contract or rights to continued employment.

The LTIP and any participation thereto, are also subject to the additional terms and conditions contained in the following section, Governing Terms and Conditions.

Governing Terms and Conditions     

1.LTIP Amendment and Termination.

The Board may, at any time, and in its discretion, alter, amend, modify, suspend or terminate the LTIP or any portion thereof; provided, however, that no such amendment, modification, suspension or termination shall, without the consent of an employee participating in the LTIP (a “Participant”), adversely affect such Participant's rights with respect to future payouts under a previously approved plan, and provided further, that, no payment of benefits shall occur upon termination of the LTIP unless the requirements of Section 409A have been met.

2.Plan Administration.

2.1Administration by Committee. The LTIP shall be administered by the Centuri Compensation Steering Committee or its express delegate, which shall have the authority to:

(a) construe and interpret the LTIP and apply its provisions;

(b) promulgate, amend and rescind rules and regulations relating to the administration of the LTIP;

(c) authorize any person to execute, on behalf of the Centuri, any instrument required to carry out the purposes of the LTIP;

(d) determine minimum or maximum Awards and payouts under the LTIP;

(e) select, subject to the limitations set forth in the LTIP, those employees who shall be participants;

(f) interpret, administer, reconcile any inconsistency in, correct any defect in and/or supply any omission in the LTIP and any instrument or agreement relating to the LTIP; and

(g) exercise discretion to make any and all other determinations which it determines to be necessary or advisable for the administration of the LTIP.

2.2Non-Uniform Treatment. Board/Committee determinations under the Plan need not be uniform and any such determinations may be made selectively among Participants.

2.3Board Decisions Final. All decisions made by the Board pursuant to the provisions of the LTIP shall be final and binding on the executives participating in the LTIP.

3. Miscellaneous.

3.1No Employment or Other Service Rights. Nothing in the LTIP or any instrument executed pursuant thereto shall confer upon any Participant any right to continue to be employed by Centuri or interfere in any way with the right of the Centuri to terminate the Participant's employment or service at any time with or without notice and with or without cause.

3.2Tax Withholding. Centuri shall have the right to deduct from any amounts otherwise payable under the LTIP any federal, state, local, or other applicable taxes required to be withheld.

3.3Governing Law. The LTIP shall be administered, construed and governed in all respects under and by the laws of Arizona, without reference to the principles of conflicts of law (except and to the extent preempted by applicable Federal law).

3.4Section 409A. The payments and benefits provided hereunder are intended to be structured in a manner to avoid the implication of any penalty taxes under Section 409A. In no event shall Centuri or any of its affiliates be liable for any additional tax, interest or penalties that may be imposed on a Participant as a result of Section 409A or any damages for failing to comply with Section 409A (other than for withholding obligations or other obligations applicable to employers, if any, under Section 409A). Notwithstanding any provision in the Agreement to the contrary:

(a)If any LTIP payment is determined to be subject to Section 409A, the LTIP shall be interpreted and administered such that such payments comply to the fullest extent possible with Section 409A.

(b)Each payment hereunder shall be deemed to be a separate and distinct payment for purposes of Section 409A.

3.5General Assets/Trust. All amounts provided under the LTIP shall be paid from the general assets of Centuri and no separate fund shall be established to secure payment.

3.6No Warranties. Neither Centuri nor the Board warrants or represents that the value of any Participant's potential payout.

3.7Beneficiary Designation. Subject to the provisions of any Committee approved LTIP Beneficiary Designation Form, each executive participating in this LTIP (a “Participant”) may from time to time name any beneficiary or beneficiaries to receive the Participant's interest in the LTIP in the event of the Participant's death. Each designation will revoke all prior designations by the same Participant, shall be in a form reasonably prescribed by the Committee and shall be effective only when filed by the Participant in writing with Centuri during the Participant's lifetime. If a Participant fails to designate a beneficiary, then the Participant's designated beneficiary shall be deemed to be the Participant's lawful spouse and if the Participant has no lawful surviving spouse then the Participant’s estate.

3.8No Assignment and Unsecured Creditor. Neither a Participant nor any other person shall have any right to sell, assign, transfer, pledge, anticipate or otherwise encumber, transfer, hypothecate or convey any amounts payable hereunder prior to the date that such amounts are paid, except for the designation of beneficiaries. A Participant’s rights to Plan benefits represent rights of only a Centuri general unsecured creditor. The Plan constitutes a mere promise by Centuri to make benefit payments in the future. It is the intention of Centuri that the Plan be unfunded for tax purposes and for purposes of Title I of ERISA.

3.9Expenses. The costs of administering the LTIP shall be paid by Centuri.

3.10Severability. If any provision of the LTIP is held to be invalid, illegal or unenforceable, whether in whole or in part, such provision shall be deemed modified to the extent of such invalidity, illegality or unenforceability and the remaining provisions shall not be affected.

3.11Headings and Subheadings. Headings and subheadings in the LTIP are for convenience only and are not to be considered in the construction of the provisions hereof.

3.12Obligations of Non-Solicitation/Non-Compete/Confidentiality

(a)A precondition to eligibility under the LTIP and payment of LTIP award(s), shall be that of the Participant agreeing to the following obligations (which agreement shall be evidenced by Participant’s signature to the “congratulations” letter, issued by the Centuri CEO, with which the LTIP was submitted for Participant’s review):

1.For purposes of the Section 3.12, the term “Centuri” shall include its subsidiaries. At no time during Participant’s employment at Centuri (or any affiliate) or within a period of one year immediately following termination of same (for any reason and no matter by whom) shall Participant in any way:

i.solicit or persuade any officer, employee, consultant or agent of Centuri to leave the services thereof or, if Participant is no longer employed at Centuri, hire any such individual who was a Centuri employee at the time of such solicitation or hiring.

ii.solicit or persuade any customer, prospective customer, licensee, vendor, consultant, referral source or other account of Centuri to not purchase, or reduce or discontinue purchasing any products or services from Centuri, or from providing any products or services to Centuri.

iii.organize or operate in any way (or assist any person, organization or entity in organizing and operating) any business in the United States or Canada that in any way competes, directly or indirectly, with the products or services of Centuri.

2.Participant also acknowledges that, irrespective of his or her eligibility under the LTIP, and at all times while employed at Centuri and for all times after termination (voluntarily or involuntarily, with or without cause) he or she has an ongoing obligation to neither disclose nor use any confidential, trade secret and/or proprietary information (as hereinafter defined, any and all of which is also referred to herein as “Protected Information”) belonging to Centuri or any Customer, except as done in the course of Participant’s employment with Centuri or as expressly authorized by Centuri, it being understood and agreed:

i.Centuri’s Protected Information is one of its most important assets, the unauthorized disclosure or use of which would be highly detrimental to Centuri’s interests, and any and all such information is Centuri’s exclusive property having independent economic value.

ii.As an employee of Centuri, Participant will be exposed to Protected Information in the course of day to day business activities, inasmuch as such exposure is essential to the performance of Participant’s job duties. The provisions of this Section 3.12 and each of its subparts are a condition of Participant’s continued employment with Centuri, and Participant’s employment and compensation by Centuri are induced by and in consideration of Participant’s acknowledgement and fulfillment of his or her obligations described within this Section 3.12 and each of its subparts (and, if in supplementation, as stated elsewhere by Centuri, such as but not limited to its policies and procedures and its Code of Business Conduct and Ethics).

iii.The business of Centuri and the nature of Participant’s employment will also permit access to protected information belonging to Customers, which is the Customer’s property and the unauthorized disclosure or use of which would be highly detrimental to Centuri, as well as the Customer.

iv.At no time shall Participant disclose or use, directly or indirectly, any Protected Information, except as approved by Participant’s supervisor and done in the course of Participant’s employment with Centuri, or as expressly authorized by Centuri.

v.Should Participant’s employment at Centuri be terminated (for voluntarily or involuntarily, with or without cause), Participant shall immediately return to Centuri any and all documents and tangible items (and all copies, facsimiles and specimens thereof) embodying or containing any Protected Information belonging to Centuri or any Customer or both, along with all copies, facsimiles and specimens thereof, and at no time following Participant’s termination shall he or she disclose or use any Protected Information belonging to Centuri or the Customer, it being expressly understood that Participant has no right to use, practice or disclose the Protected Information for Participant’s own benefit or for the benefit of any third party.

3.As used in this Section 3.12, “Customer” shall mean any person or entity for whom Centuri performs services or from whom Centuri, its employees, agents and consultants obtain protected information. “Confidential, Trade Secret and/or Proprietary Information” shall mean any information not generally known in the industries in which Centuri or any Customer is engaged in, and includes but is not limited to information relating to any existing or contemplated services, costing data of any sort, technology, concepts, processes, methods, techniques, know-how, business plans, sales or marketing methods of doing business, customer lists, customer usages or requirements, or supplier/subcontractor information, which is owned or licensed by Centuri or its Customer, or is held by Centuri or its Customer in confidence and, to the extent not covered by the foregoing, includes the following:

i.technical information and know-how on all Centuri products, equipment, processes, services, and systems;

ii.Centuri business planning information, such as new services, customer strategy, expansion plans, relocation, downsizing, acquisition and mergers;

iii.financial information on costs, investments, profit, margins and forecasts;

iv.problems in any area of Centuri’s business;

v.Centuri production information, progress reports and other productivity information;

vi.marketing strategies, pricing, supplier/subcontractor information, bid information and Centuri developed bid programs;

vii.quality and improvement program results; and

viii.Centuri employee information (such as, but not limited to changes in staffing, relocation, wages and salaries, and bonus program results).

4.    Nothing contained in this Section 3.12 shall be constructed as precluding the Participant from the use or practice of any skill or expertise generally associated with his or her employment but not special or unique to Centuri.

5    Any breach of Section 3.12 or any of its subparts shall constitute grounds for termination (if Participant is still employed at Centuri at time of breach), and shall provide Centuri the basis for obtaining injunctive relief by a court of law (whether permanent or preliminary or a temporary restraining order), and shall entitle Centuri to an action at law or in equity for any damages related to or arising out of any such breach, and shall automatically cause a forfeiture of any and all amounts paid, and a discontinuance of any and all amounts or otherwise due and owing to Participant under the LTIP, none of which shall require prior notice.

3.13 Claims Procedures

(A)    Claims for Benefits. For the purpose of this procedure, a claim for benefits under this Plan is defined as: (a) a request for withdrawal or distribution of funds; or (b) a request for correction of a perceived administrative error.

Any claim for benefits under the Plan must be submitted in writing to the Committee within the “applicable limitations period.” The “applicable limitations period” shall be one year, beginning on the earliest of (a) in the case of any lump-sum payment, the date on which the payment was made, or (b) for all other claims, the date on which the action complained or grieved occurred. If such claim for benefits is wholly or partially denied, the Committee shall, within a reasonable period of time not to exceed ninety (90) days after receipt of the claim, notify the Participant or Beneficiary or other party making the claim (the “Claimant”) of the denial of the claim. Such notice of denial (a) shall be in writing, (b) shall be written in a manner calculated to be understood by the Claimant, and (c) shall contain (1) the specific reason or reasons for denial of the claim, (2) a specific reference to the pertinent Plan provisions upon which the denial is based, (3) a description of any additional material or information necessary to perfect the claim, along with an explanation of why such material or information is necessary, and (4) an explanation of the claim review procedures and the time limits applicable to such procedures and a statement of the Claimant’s right to bring a civil action under ERISA Section 502(a) following an adverse benefit determination upon review. The ninety (90) day period may, under special circumstances, be extended up to an additional ninety (90) days upon written notice of such extension to the Claimant which notice shall specify the special circumstances that require an extension of time and the date by which the Committee expects to communicate to the Claimant a decision on the claim. If the claim is denied the Claimant may file a request for review as provided in Section 3.13(B).

(B)    Request for Review. Within sixty (60) days after the receipt of the decision denying a claim by the Claimant, the Claimant may file a written request with the Committee that it conduct a full and fair review of the denial of the claim for benefits. The Claimant or his/her duly authorized representative may review pertinent documents and submit issues and comments in writing to the Committee in connection with the review.

(C)    Decision on Review of Denial. The Committee shall deliver to the Claimant a written decision on the review of the denial within a reasonable period of time not to exceed sixty (60) days after the receipt of the aforesaid request for review, except that if there are special circumstances (such as the need to hold a hearing, if necessary) which require an extension of time for processing, the aforesaid sixty (60) day period shall, upon written notice to the Claimant be extended an additional sixty (60) days. Notice of an extension shall be given within the initial sixty (60) day review period. The extension notice shall indicate the special circumstances that require an extension of time and the date by which the Committee expects to render a decision upon review. Upon review the Claimant shall be given the opportunity to (1) submit written comments, documents, records, and other information relating to its claim, and (2) request and receive, free of charge, reasonable access to, and copies of, all documents, records, and other information relevant to the Claimant’s claim for benefits. Whether a document, record, or other information is relevant to a claim for benefits shall be determined by reference to applicable ERISA regulations. The review of a denied claim shall take into account all comments, documents, records, and other information submitted by the Claimant relating to the claim, without regard to whether such information was submitted or considered in the initial benefit determination. The decision on review shall be written in a manner calculated to be understood by the Claimant and, if adverse, shall (1) include the specific reason or reasons for the decision, (2) contain a specific reference to the pertinent Plan provisions upon which the decision is based, (3) contain a statement that the Claimant is entitled to receive, upon request and free of charge, reasonable access to, and copies of, all documents, records, and other information relevant to the Claimant’s claim for benefits (whether a document, record, or other information is relevant to a claim for benefits shall be determined by reference to applicable ERISA regulations), and (4) contain a statement describing the Claimant’s right to bring an action under ERISA Section 502(a).

(D)    Notice of Time Limits. When a Participant or a Beneficiary files a claim, the Committee, or its designee, shall notify him or her of the claim and review procedure including the time periods involved.

3.14 Limitation on Claims and Venue.

No action at law or in equity to recover under this Plan shall be commenced later than one year from the date of the Committee’s decision on review (or if no decision is furnished within 120 days of the Committee’s receipt of the request for review, one year after the 120th day after receipt of the request for review). Failure to file suit within this time period shall extinguish any and all rights to benefits under the Plan. Any lawsuit to recover benefits under this Plan shall be filed in Federal District Court in Maricopa County Arizona.

IN WITNESS WHEREOF, Centuri has caused this LTIP to be signed effective as of the Effective Date.

Centuri Construction Group, Inc.

By: _______________________

Paul M. Daily

Its: Chief Executive Officer

Appendix A: Three-year Compounded EV Growth (%) and Award Percentages

Performance			Award
	Annual	3-Year
	>10.0%	>33.1%	200%
Maximum	10.0%	33.1%	200%
	9.5%	31.4%	190%
	9.0%	29.7%	180%
	8.5%	27.9%	170%
	8.0%	26.2%	160%
	7.5%	24.5%	150%
	7.0%	22.8%	140%
	6.5%	21.0%	130%
	6.0%	19.3%	120%
	5.5%	17.6%	110%
Target	5.0%	15.8%	100%
	4.5%	14.1%	87.5%
	4.0%	12.5%	75%
	3.5%	10.9%	62.5%
	3.0%	9.3%	50%
	2.5%	7.7%	37.5%
Threshold	2.0%	6.1%	25%
<Threshold	<2.0%	<6.1%	0%

EX-10.02

RESTATED CENTURI CONSTRUCTION GROUP, INC. LONG-TERM CAPITAL INVESTMENT PLAN

(F.K.A. NPL CONSTRUCTION CO. LONG TERM CAPITAL INVESTMENT PROGRAM)

THIS RESTATED CENTURI CONSTRUCTION GROUP, INC. LONG-TERM

CAPITAL INVESTMENT PLAN (the “Plan”) is effective January 1, 2019 for Centuri Construction Group, Inc. (hereinafter referred to as “Centuri”). The purpose of this Plan is to cause key selected executives of Centuri and its related companies (collectively the “Employer”) to participate in this Plan (these executives are defined below as “Participant[s]”) and thereby have a personal financial interest in the Employer’s and its parent Company’s Southwest Gas Holdings, Inc. (hereinafter referred to as “Holdings”) financial success and performance. This Plan works in combination with the Centuri Construction Group, Inc. Executive Deferred Compensation Plan (the “EDCP”), to provide for elective and non-elective deferrals under the EDCP that are in total or in part credited to an EDCP investment option (referred to herein as the “EDCP Performance Fund”) the performance of which for a calendar year is tied to the Employer’s financial performance for such year, and the Centuri Construction Group, Inc. Executive Long-Term Incentive Plan (the “LTIP”) to provide for deferred stock awards.

WITNESSETH:

WHEREAS, the Employer desires to adopt this Plan restatement.

NOW, THEREFORE, the Employer hereby adopts this restated Centuri Construction Group, Inc. Long Term Capital Investment Plan that reads as follows:

ARTICLE I

Definitions

1.1    Introduction. The following terms, as heretofore and hereafter used in this Plan, shall have the meanings set forth unless the context clearly indicates a different meaning is required:

“Beneficiary” means a person who, pursuant to the EDCP, is designated to receive EDCP benefits in the event of the Participant’s death.

“Board” or “Board of Directors” means the Centuri Board of Directors.

“Centuri” means Centuri Construction Group, Inc.

“Code” means the Internal Revenue Code of 1986, as amended.

“EDCP” means the Centuri Construction Group, Inc. Executive Deferred Compensation Plan.

“EDCP Performance Fund” means an EDCP investment option the performance of which for a calendar year is tied to the Employer’s financial performance for such year.

“Effective Date” means the Plan’s original effective date of January 1, 2013; the “Restatement Effective Date” means January 1, 2019.

“Employee” means an employee of the Employer.

“Employer” or “Company” means Centuri and the Participating Employers.

“ERISA” means the Employee Retirement Income Security Act of 1974, as amended.

“Holdings” means Southwest Gas Holdings, Inc.

“LTIP” means the Centuri Construction Group, Inc. Executive Long-Term Incentive Plan.

“Maximum Amount” shall have the meaning specified in Section 3.2.

“Participant” means an Employee that has deferrals made to the EDCP pursuant to this Plan and the EDCP and deferred stock awards pursuant to the LTIP.

“Participating Employer” means an affiliate of Employer who has adopted this Plan pursuant to Article XIII.

“Plan” means this Centuri Construction Group, Inc. Long Term Capital Investment Plan. Prior to this restatement the Plan was named the NPL Construction Long Term Capital Investment Program.

“Plan Administrator” or “Administrator” means the individual or individuals that comprise the committee that serves as the administrator of the EDCP or the LTIP, as applicable.

“Plan Year” means each twelve (12) month period beginning January 1st and ending the following December 31st.

“Section 409A” means Code Section 409A and the regulations and other guidance promulgated or issued thereunder.

“Separation From Service” a Participant incurs a Separation From Service with the Employer if the Participant’s employment with Employer is terminated; provided, that Participant's employment relationship shall be treated as continuing intact (a) while the Participant is on military leave, sick leave or other bona fide leave of absence if the period of such leave does not exceed six months or longer, (b) if the Participant’s right to reemployment is provided either by statute or by contract; or (c) if the Participant continues to provide services to the Employer in any capacity after termination or expiration of this Plan or termination of Participant’s employment relationship with the Employer. The determination of whether a Participant has incurred a "Separation From Service" shall be made by the Plan Administrator in accordance with Section 409A and the regulations promulgated thereunder and the term “Employer” as used in this definition of “Separation From Service” shall include all other organizations that together with the Employer are part of a Code Section 414(b-c) controlled or common control group of organizations.

“Spouse” means the spouse, if any, to whom the Participant is legally married on the Participant’s date of death.

“STIP” means the Centuri Construction Group, Inc. Short Term Incentive Plan for Exempt Executive Employees for a particular calendar year.

“Stock Account” means the deferred stock awards granted through the LTIP and maintained by Holdings.

“Termination Date” means the date on which the Participant incurs a Separation From Service.

ARTICLE II

Participation in the Plan

An Employee shall become a Participant only if the Employee (1) holds a position listed in Section 3.1, and (2) is selected by Centuri to participate in the Plan. An Employee who becomes a Participant shall remain a Participant until all amounts that are credited to the EDCP and the Stock Account pursuant to this Plan and are either paid to the Participant or forfeited.

ARTICLE III

Plan Deferrals

3.1Mandatory Deferrals.

(a)STIP Deferrals. Twenty-five percent (25%) of the STIP award bonus otherwise payable to a Participant in a calendar year shall be automatically deferred under the EDCP and credited to the Participant’s EDCP account and invested in the EDCP Performance Fund investment option, provided that the Plan Administrator has determined, prior to the award date that (1) a deferral election may be made pursuant to the EDCP and Section 409A with respect to such award, and (2) all or part of such credit can be made to the participant’s EDCP account without causing all of the amount to be credited to the Participant’s EDCP Performance Fund investment option to exceed the applicable target amount (the “Participant’s Target Amount”) set forth below.

(b)Stock Deferrals. One hundred percent (100%) of any stock award granted to a Participant pursuant to the LTIP shall be automatically deferred as provided herein, provided that the Plan Administrator has determined, prior to the award date that (1) a deferral may be applied to such stock award and Section 409A, and (2) all or part of such deferred amount will not cause the amount to be credited to the Participant’s Stock Account to exceed the Participant’s Target Amount set forth below. Participants receiving stock pursuant to the LTIP will be required to execute award agreements which will detail how the target amount below is divided between the EDCP and stock deferrals. The award agreements will also dictate a retention percentage for stock awards that must be maintained until the target amount is achieved, as well as any other details regarding requirements for stock awards.

(c)Target Amounts.

Participant Title Centuri Chief Executive Officer and President Centuri Executive Vice President – CFO/Treasurer Centuri Executive Vice President – CAO Centuri Executive Vice President – Electric T&D Centuri Executive Vice President – Chief Counsel Centuri Executive Vice President – COO Centuri Executive Vice President – CCO Centuri Senior Vice President – General Counsel NPL Business Unit Division President Meritus Business Unit Division President Centuri Senior Vice President - HR Target Amount 400% base salary 200% base salary 200% base salary 200% base salary 200% base salary 200% base salary 200% base salary 200% base salary 200% base salary 200% base salary 100% base salary

To the extent the STIP award bonus otherwise payable to a Participant in a calendar year is not, pursuant to subparagraph (a), automatically deferred under the EDCP and credited to the EDCP Performance Fund investment option, such portion shall be paid to the Participant as provided in the STIP unless the Participant has timely elected to defer the payment of such portion pursuant to the EDCP deferral rules and such election is compliant with the election requirements of Section 409A. If a deferral election is made, the amount deferred shall be paid out at the times and in the manner dictated by the terms of such election and the payment provisions of the EDCP.

To the extent a stock award otherwise payable in a calendar year is not, pursuant to subparagraph (b), automatically deferred, such portion shall be paid to the Participant as provided in the stock award unless the Participant has timely elected to defer the payment of such portion pursuant to any applicable deferral rules and such election is compliant with the election requirements of Section 409A. If a deferral election is made, the amount deferred shall be paid out at the times and in the manner dictated by the terms of such election and the payment provisions of the stock award.

A Participant’s ability to defer STIP bonus awards and/or stock awards not subject to automatic deferral, as discussed in the preceding paragraph, shall be determined based on the deferral timing and form rules set forth in the EDCP, the applicable stock award, and Section 409A.

3.2EDCP Performance Fund Date and Limit on Amount Credited to EDCP Performance Fund. The EDCP provides the rules for the administration of the EDCP Performance Fund and the investment return earned by such fund; provided, however, that such EDCP rules shall to the extent possible be written so as to be consistent with the rules set forth in this Section 3.2.

The EDCP Performance Fund rate of return for a calendar year before 2019 shall be the average of Centuri’s period-to-period Earnings Before Interest, Tax, Depreciation, and Amortization (“EBITDA”) for each of the three preceding twelve month periods ending September 30th with a minimum return floor of a negative five percent (-5%) and a maximum return ceiling of a positive fifteen percent (15%).

The EDCP Performance Fund rate of return for a calendar year after 2018 shall be determined using a formula for Centuri’s enterprise value which shall be:

(EBITDA x multiplier) – Net Debt = Rate of Return (subject to a floor minimum return of a negative five percent (-5%) and a maximum return ceiling of a positive fifteen percent (15%)).

The Board shall in its discretion determine the EBITDA, multiplier, and Net Debt numbers to be utilized in determining the EDCP Performance Fund rate of return for a calendar year.

There shall be a limit on the amount a Participant can have credited to the EDCP Performance Fund. To the extent that at the beginning of a Plan Year the portion of the Participant’s EDCP account that is credited to the EDCP Performance Fund investment option exceeds the Maximum Amount, the excess shall be debited from such option and credited to a default EDCP investment option selected by the EDCP Plan Administrator; the amount credited to the default fund shall remain credited to such fund until the Participant, in accordance with the EDCP investment rules, makes a new investment election with respect to such excess. In Plan Years beginning before January 1, 2019, the term “Maximum Amount” shall mean an amount equal to the Participant’s Target Amount. In any Plan Year beginning on or after January 1, 2019, the term “Maximum Amount” shall mean one hundred fifty percent (150%) of the Participant’s Target Amount.

In the calendar year in which a Participant incurs a Separation From Service (the “Termination Year”), the portion of the Participant’s EDCP account that is credited to the EDCP Performance Fund investment option shall, within 30 days of the Termination Date, be debited from such option and credited to another EDCP investment option selected by the EDCP Plan Administrator and shall remain credited to such option until the Participant, in accordance with the EDCP, makes an election to have such amount credited to another EDCP investment option. For the segment of the Termination Year that all or part of the terminating Participant’s EDCP account is credited to the EDCP Performance Fund investment option, the amount so credited will be deemed to have solely earned a rate of return equal to the average Moody’s Corporate Bond Index rate of return as of the immediately preceding December.

3.3Payment of Plan Benefits. Deferrals under this Plan are made pursuant to the terms of the EDCP or applicable stock awards comprising the Stock Account; accordingly, all Plan benefits are payable at such times and in such manner as provided for in the EDCP or applicable stock awards comprising the Stock Account subject to the Participant’s EDCP or applicable stock awards distribution and payment elections made in the manner and form required by the EDCP or applicable stock awards.

ARTICLE IV

Plan Administrator

4.1 Plan Administrator Powers.

(a)The general administration of the Plan shall be by the Plan Administrator.

(b)The Plan Administrator shall have full discretionary power and authority to (1) operate and administer the Plan, (2) interpret and construe the Plan so as to determine all factual and non-factual questions arising under or in connection with all Plan matters including, but not limited to, an individual’s Plan benefits and/or eligibility; and (3) from time to time, prescribe and amend rules and regulations for such administration. Whenever directions, designations, applications, requests or other notices are to be given by a Participant under the Plan, they shall be on forms prescribed by the Plan Administrator and shall be filed in the manner specified by the Plan Administrator.

(c)The Plan Administrator may act to correct any defect, supply any omission, or reconcile any inconsistency in the terms of the Plan. The Plan Administrator’s decisions, interpretations, constructions, determinations, and all other actions shall be final and binding on all parties.

(d)In addition to the powers described elsewhere in this Article IV and other Articles of the Plan, the Plan Administrator shall have the power to (1) change or waive any requirements of the Plan to conform with the law, provided such change does not materially increase or is not reasonably expected to materially increase the cost to the Employer of maintaining the Plan; (2) employ such agents, assistants, counsel (who may be counsel to the Employer) and such clerical and other service providers as the Plan Administrator may require in carrying out the provisions of the Plan; and (3) authorize one or more agents to execute or

deliver any instrument on behalf of the Plan Administrator.

(e)Ministerial duties in connection with the administration of the Plan may be delegated by the Plan Administrator to any agent or agents as it may select.

(f)The Plan Administrator and the Employer and its officers and directors shall be entitled to rely upon all valuations, certificates and reports made by an accountant or actuary and upon all opinions given by any legal counsel selected or approved by Centuri. The Plan Administrator, the Employer, and the Employer’s officers and directors shall be fully protected in respect of any action taken or suffered by them in good faith in reliance upon such valuations, certificates, reports, opinions, or other advice of any such accountant, actuary or counsel, and all action so taken or suffered is to be conclusive upon each of them and upon all Participants, Beneficiaries, and other persons.

ARTICLE V

Actions by the Plan Administrator or Employer, Claims Procedures and Arbitration

5.1Statement of Participant’s Account. The Plan Administrator may create a procedure whereby from time to time he/she/it shall notify each Participant of his/her EDCP benefits and any Stock Account. Such statement shall be deemed to have been accepted as correct unless written notice to the contrary is received by the Plan Administrator within thirty

(30) days after the mailing of such statement to the Participant.

5.2Delivery of Notices, Reports, and Statements to Participants. All notices, reports, and statements given, made, delivered, or transmitted to a Participant or Beneficiary shall be deemed duly given, made, delivered, or transmitted when actually delivered to the Participant or Beneficiary or when mailed, by such class as the sender may deem appropriate, with postage prepaid and addressed to the Participant at the address last appearing on the records of the Employer with respect to this Plan.

5.3Delivery of Notices, Directions, and Communications to the Plan Administrator. All notices, directions, or other communications given, made, delivered, or transmitted by a Participant to the Plan Administrator or Employer, as the case may be, shall not be deemed to have been duly given, made, delivered, transmitted, or received unless and until actually received by the Plan Administrator or by the Employer, as the case may be.

5.4Plan Administrator and Employer Records Conclusive. Subject to the provisions of this Article V, the records of the Plan Administrator and the Employer shall be conclusive in respect to all matters involved in the administration of this Plan.

5.5Payment of Expenses. All costs and expenses incurred in administering this Plan, including the fees and expenses of the Plan Administrator, shall be paid by the Employer, unless specified herein to the contrary.

5.6Limitation of Liability. No director, member of the Board, officer, or Employee of the Employer shall be personally liable for any act or omission to act in connection with the operation or administration of the Plan, except for his/her own willful misconduct or gross negligence.

5.7Recognition of Participant’s Agent. The Plan Administrator shall not be bound to recognize the authority or agency of any party for a Participant unless and until it shall receive documentary evidence thereof in form and substance satisfactory to it and thereafter from time to time, as the Plan Administrator may require, further documentary evidence disclosing the status of any agency.

5.8Legal Actions. In any action or application to the courts, only the Employer shall be a necessary party and no other person, firm, or corporation shall be entitled to any notice or process. Any final judgment entered on such action or proceeding shall be conclusive upon all persons claiming under the Plan. Every right of action by any Participant or former Participant with respect to the Plan shall, irrespective of the place where such action may be brought, cease and be barred three years after the end of the period for appealing a denied claim as described in the review of denied claim provisions of Section 5.11(b).

5.9Construction of Plan. To the extent not preempted by ERISA, this Plan shall be governed and construed in accordance with the laws of the State of Arizona.

5.10No Effect on Employment. Nothing in this Plan shall be deemed or construed to impair or affect in any manner whatsoever the right of Employer, in its discretion, to for any reason discharge or terminate the employment of an Employee/Participant.

5.11Benefit Claims Procedure.

(a)Initial claim review. Any claim for benefits under the Plan shall be made in writing to the Plan Administrator. If such claim for benefits is wholly or partially denied, the Plan Administrator shall, within a reasonable period of time not to exceed ninety (90) days after receipt of the claim, notify the Participant or Beneficiary or other party making the claim (the “Claimant”) of the denial of the claim. Such notice of denial (a) shall be in writing, (b) shall be written in a manner calculated to be understood by the Claimant, and (c) shall contain (1) the specific reason or reasons for denial of the claim, (2) a specific reference to the pertinent Plan provisions upon which the denial is based, (3) a description of any additional material or information necessary to perfect the claim, along with an explanation of why such material or information is necessary, and (4) an explanation of the claim review procedures and the time limits applicable to such procedures and a statement of the Claimant’s right to arbitration following an adverse benefit determination upon review. The ninety (90) day period may, under special circumstances, be extended up to an additional ninety (90) days upon written notice of such extension to the Claimant which notice shall specify the extraordinary circumstances and the extended date of the decision. Notice of extension must be given prior to expiration of the initial ninety (90) day period. The extension notice shall indicate the special circumstances that require an extension of time and the date by which the Plan Administrator expects to render a decision on the claim. If the claim is denied the Claimant may file a request for review as provided in the next paragraph.

(b)Review of denied claim. Within sixty (60) days after the receipt of the decision denying a claim by the Claimant, the Claimant may file a written request with the Plan Administrator that it conduct a full and fair review of the denial of the claim for benefits. The Claimant or his/her duly authorized representative may review pertinent documents and submit issues and comments in writing to the Plan Administrator in connection with the review.

The Plan Administrator shall deliver to the Claimant a written decision on the review of the denial within a reasonable period of time not to exceed sixty (60) days after the receipt of the aforesaid request for review, except that if there are special circumstances (such as the need to hold a hearing, if necessary) which require an extension of time for processing, the aforesaid sixty (60) day period shall, upon written notice to the Claimant, be extended an additional sixty (60) days. Notice of an extension shall be given within the initial sixty (60) day review period. The extension notice shall indicate the special circumstances that require an extension of time and the date by which the Plan Administrator expects to render a decision upon review.

Upon review the Claimant shall be given the opportunity to (a) submit written comments, documents, records, and other information relating to its claim, and (b) request and receive, free of charge, reasonable access to, and copies of, all Plan documents, records, and other information relevant to the Claimant’s claim for benefits. Whether a document, record, or other information is relevant to a claim for benefits shall be determined by reference to applicable ERISA regulations. The review of a denied claim shall take into account all comments, documents, records, and other information submitted by the Claimant relating to the claim, without regard to whether such information was submitted or considered in the initial benefit determination.

The decision on review shall be written in a manner calculated to be understood by the Claimant and, if adverse, shall (a) include the specific reason or reasons for the decision, (b) contain a specific reference to the pertinent Plan provisions upon which the decision is based, (c) contain a statement that the Claimant is entitled to receive, upon request and free of charge, reasonable access to, and copies of, all documents, records, and other information relevant to the Claimant’s claim for benefits (whether a Plan document, record, or other information is relevant to a claim for benefits shall be determined by reference to applicable ERISA Regulations), and (d) contain a statement describing the Claimant’s right to arbitration.

5.12    Arbitration. In the event that any dispute or controversy (between the Participant, a Beneficiary, the Employer and/or the Plan Administrator (collectively the “Parties”)) that arises out of this Plan cannot be settled by the Parties through the claims procedure set forth in this Article V, the Parties hereby agree to resolve the controversy or

dispute by submission to binding arbitration with the American Arbitration Association (“AAA”) in Phoenix, Arizona.

In the event the Parties have not agreed upon an arbitrator within thirty (30) business days after either party files a demand for arbitration with the AAA’s Phoenix regional office, an arbitrator shall be appointed in accordance with the then existing Commercial Arbitration Rules of the AAA.

Discovery may be conducted either upon mutual consent of the Parties, or by order of the arbitrator upon good cause being shown. In ruling on motions pertaining to discovery, the arbitrator shall consider that the purpose of arbitration is to provide for the efficient and inexpensive resolution of disputes, and the arbitrator shall limit discovery whenever appropriate to ensure that this purpose is preserved. The arbitrator may grant summary judgment if he or she determines no issue of fact exists as to a claim.

The dispute or controversy shall be submitted for determination within sixty (60) days after the arbitrator has been selected. The arbitrator shall render his or her decision within thirty

(30) days after the conclusion of the arbitration hearing. Upon stipulation of the Parties, or upon a showing of good cause by either party, the arbitrator may lengthen or shorten the time periods set forth herein for conducting the hearing or for rendering a decision.

The decision of the arbitrator shall be final and binding upon the Parties. Judgment to enforce the arbitrator’s decision, whether for legal or equitable relief, may be entered in the Superior Court of Maricopa County, Arizona, and the Parties hereto expressly and irrevocably consent to the jurisdiction of such Court for such purpose.

The arbitrator shall conduct all proceedings pursuant to the Uniform Arbitration Act (the “Act”) as adopted in the State of Arizona and the then existing Commercial Arbitration Rules of the AAA, to the extent such rules are not inconsistent with the Act or the provisions of this Article V. The Uniform Rules of Procedure for Arbitration shall not apply to any arbitration proceeding relating to the subject matter or terms of this Plan.

ARTICLE VI

Modification and Termination

Notwithstanding that an Employee has become a Participant and thereafter performed services for Employer, the Board shall, without giving prior notice to any Participant, have the right to at any time, and in any manner, amend the terms of the Plan by adopting a written amendment thereto. The Board shall, without giving prior notice to any Participant, have the right to at any time amend the Plan or terminate this Plan by adopting a Board resolution to terminate the Plan. A Plan amendment or the termination of the Plan shall not cause a decrease to the then balance credited to the Participant’s EDCP account(s) or Stock Account without the Participant’s written consent. Any such termination or amendment shall be effective at such date as is set forth in the applicable resolution or amendment. Notwithstanding any other provision of the Plan to the contrary, if the Plan is terminated, no additional deferrals shall be permitted thereunder and notwithstanding any other provision of the Plan to the contrary, Plan benefits of all Participants shall be paid out according to the terms of the Plan.

ARTICLE VII

Non-Assignability

The right or interest of a Participant, Beneficiary, or any other person, to the payment of deferred compensation or other benefits under this Plan, as well as such Participant, Beneficiary, or person’s interest in a Participant’s EDCP benefit or Stock Account shall not be subject to anticipation, assignment, pledge, or charge in whole or in part (except as specifically allowed in the Plan), either directly or by operation of law or otherwise, including but without limitation, execution, levy, garnishment, attachment, pledge, bankruptcy, or in any other manner, but excluding devolution by death or mental incompetency, and any attempt to anticipate, assign, pledge, or charge (except as specifically allowed in the Plan) any such right or interest shall be void and no right or interest of any Participant, Beneficiary, or other person under this Plan or in a Participant’s EDCP benefit shall be liable for or subject to any obligation or liability or tort of such Participant, Beneficiary, or other person.

ARTICLE VIII

No Plan Administrator Responsibility for Employer or Participant Action or Inaction

The Plan Administrator shall not have any obligation or responsibility with respect to any action required by this Plan to be taken by the Employer or any Participant, or for the failure of any of the above to act or make any deferral, if applicable, or to otherwise provide any benefit herein contemplated, nor shall the Plan Administrator be required to collect any deferral required herein, if applicable, or determine the correctness or the amount of any deferral delivered by the Employer.

ARTICLE IX

Indemnity of Plan Administrator

To the extent allowed by ERISA, the Plan Administrator shall not incur any personal liability of any nature in connection with any act that is not a criminal act, or the result of willful misconduct and that is done or omitted to be done in good faith in the administration of this Plan, and to the extent allowed by ERISA, the Plan Administrator shall be indemnified and saved harmless by the Employer for, from, and against any and all liability to which the Plan Administrator may be subjected by reason of any such act (provided such act is not a criminal act and does not constitute willful misconduct, or conduct in their official capacity) including all expenses reasonably incurred in its/his/her defense, in case the Employer fails to provide such defense.

ARTICLE X

Contract

This Plan shall constitute a binding and effective agreement between the Employer and the Participant and any Beneficiary.

ARTICLE XI

Successors

This Plan shall be binding upon all persons entitled to benefits hereunder, their respective heirs and legal representatives, and upon the Employer, and its successors and assigns.

ARTICLE XII

Unsecured Benefits

12.1    Unsecured Creditor. Participation in this Plan shall not create, in favor of any Participant or other individual entitled to benefits hereunder, any right or lien in or against any of the assets of the Employer. All benefits payable hereunder shall be paid in cash from the general assets of the Employer, and no special or separate fund shall be established, and no other segregation of assets shall be made to assure the payment of benefits hereunder. Nothing contained in this Plan, and no action taken pursuant to its provisions, shall create or be construed to create a trust of any kind or a fiduciary relationship between the Employer and any Participant or any other person. A Participant’s or other person’s rights to Plan benefits represent the rights of only a general unsecured creditor of the Employer. The Plan constitutes a mere promise by the Employer to make benefit payments in the future. It is the intention of the Employer that the Plan be unfunded for tax purposes and for purposes of Title I of ERISA.

ARTICLE XIII

Participating Employers

13.1Participating Employers. Any other corporation, association, joint venture, proprietorship, partnership or limited liability company, whether or not an affiliated company or subsidiary, may adopt the Plan by action on its part by its highest ranking officer provided that the Chief Executive Officer of Centuri approves the participation. An entity adopting the Plan in the manner provided by this Article XIII shall be known as a “Participating Employer.” Participating Employers as of the Restatement Effective Date are listed in Exhibit A hereto.

13.2Amendment When Participating Employer. Amendment of this Plan at any time when there is a Participating Employer hereunder shall be made according to Article VI.

13.3Requirements Applicable to Participating Employers. Each Participating Employer shall be subject to the following requirements:

(a)All expenses of the Plan shall be paid by Centuri and any Participating Employers. The Plan Administrator shall allocate the cost of the benefits provided under the Plan and the cost of administration of the Plan among Centuri and any Participating Employers.

(b)It is anticipated that Employee/Participants may be transferred between a Participating Employer and Centuri or between Participating Employers. No such transfers shall affect a termination of employment hereunder.

(c)Any Participating Employer may terminate its participation in the Plan without the consent of any other Participating Employer. A Participating Employer terminating its participation in the Plan shall provide satisfactory evidence thereof to the Plan Administrator.

(d)The Plan Administrator shall have the power and authority to create any additional rules and regulations it deems necessary to:

(1) Specify the Plan rights and obligations of a Participating Employer; and

(2) Allow for the orderly operation of the Plan when there is one or more Participating Employers.

ARTICLE XIV

General

14.1Headings as a Guide. The headings of this Plan are inserted for convenience of reference only and are not to be considered in construction of the provisions hereof.

14.2Pronouns. When necessary to the meaning hereof, either the masculine or the neuter pronoun shall be deemed to include the masculine, the feminine, and the neuter, and the singular shall be deemed to include the plural.

14.3Settlor Functions. To the extent that (a) any person is designated as a Participant eligible to receive a benefit hereunder, or (b) the Plan is amended or terminated, such actions shall be deemed to be the exercise of a settlor function on behalf of the Employer and shall not

be deemed to be actions taken in a fiduciary capacity.

IN WITNESS WHEREOF, Centuri has caused this Plan to be signed effective as of the Restatement Effective Date.

CENTURI CONSTRUCTION GROUP, INC.

By ____________________________________

Its ____________________________________

EXHIBIT A

PARTICIPATING EMPLOYERS

Participating Employer: NPL Construction Co.

By ____________________________________

Its ____________________________________

Participation as of the Effective Date.

Participating Employer: Meritus Group, Inc.

By ____________________________________

Its ____________________________________

Participation effective date: _____ day of ________________, ______.

Participating Employer: ____________________________________

By ____________________________________

Its ____________________________________

Participation effective date: _____ day of ________________, ______.

Participating Employer: ____________________________________

By ____________________________________

Its ____________________________________

Participation effective date: _____ day of ________________, ______.

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EX-10.03

CENTURI CONSTRUCTION GROUP AWARD AGREEMENT

UNDER THE SOUTHWEST GAS HOLDINGS, INC.

OMNIBUS INCENTIVE PLAN, THE CENTURI LONG-TERM CAPITAL INVESTMENT

PLAN, AND THE CENTURI LONG-TERM INVESTMENT PLAN

This Award Agreement (“Award Agreement”) is dated as of ______________, 20___, by and between Centuri Construction Group, Inc., (the "Company" or “Centuri”), Southwest Gas Holdings, Inc., and ___________ ("Grantee"), pursuant to the Company's Long-Term Capital Investment Plan (“LTCIP”), Centuri Long-Term Incentive Plan (“LTIP”) and the Southwest Gas Holdings, Inc. Omnibus Incentive Plan (the "Plans"). Capitalized terms that are used, but not defined, in this Award Agreement shall have the meaning set forth in the Plans, and the Plans are incorporated by reference into this Award Agreement.

Overview of Your Long-Term Incentive Award Opportunity

Total Long-Term Incentive Target Amount:         $______

Cash Award at Target:                 $______

Value of Stock Award at Target:            $______

SWX Stock Price at Award:                $______

Aggregate Target Shares: ________ Shares

• Time Based Shares (___%): ______ Shares

• Performance Based Shares (___%): _____ Shares

Performance Period: January 1, 20__ to December 31, 20__

1.    Target Long-Term Incentive Award Opportunity. Grantee’s target long-term incentive amount is ____% of base salary. An amount equal to ___% of base salary will be awarded in cash while an amount equal to __% of base salary will be awarded in the form of Southwest Gas Holdings Inc. stock and vested pursuant to the terms of this Award Agreement and the Centuri LTCIP. The stock component of this agreement is further broken down into performance shares (__%) and time-based shares (__%).

2. Grant of Southwest Gas Holdings Shares. The Company and Southwest Gas Holdings, Inc. hereby grant to the Grantee shares of Southwest Gas Holdings common stock (“SWX” or “Share”), subject to the terms and conditions of this Award Agreement and the Plans. Each Share represents a share of Common Stock. Until the final number of Shares is determined and the Shares have vested, the Grantee shall not

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have any of the rights of a shareholder of the Company with respect to the Shares, except for the crediting of dividend equivalents as provided for in Section 9 below. Share Price for the award is determined by the closing price on the applicable stock exchange of one share of Common Stock on the last trading day immediately prior to the first day of the Performance Period.

3.     Restrictions on Alienation. Shares may not be sold, transferred, pledged, assigned, or otherwise alienated in any manner, whether voluntarily, by operation of law, or otherwise, until the restrictions on the Shares are removed and the Shares are delivered to the Grantee in the form of shares of Common Stock.

4.    Performance and Time-Based Shares. Vesting of Performance and Time-based Shares takes place at the end of the three (3) year measurement period and the number of Shares is based upon the Enterprise Value (“EV”) achievement over the three (3) year measurement period beginning with the fiscal year in which the SWX Shares are granted. EV is defined by Enterprise Value (EV) = (EBITDA x Multiplier) – Net Debt. The time-based award is not subject to a threshold to generate a payment to the Grantee. Time‑based award amounts, however, are impacted by the change in EV at the end of the measurement period. The change in EV at the end of the measurement period, will determine the number (amount) of shares. Time based awards are capped at ____% of the target amount.

Stock Award Details

Calculation based on $______ target opportunity and $_______ stock target opportunity

$_______ __% Time Based = $________

$_______ __% Performance Based = $________

SWX Share Price at time of Grant = $_____

Assumes a target of __% annual growth in Enterprise Value (“EV”), a ___% Threshold and ___% Maximum

Time Based Performance Schedule Fiscal Years 20__-20__(Example)
Performance Level	Time Based	Vested SWX Shares
Below Threshold (__%)	$______	_______
Threshold (__% growth)	$______	_______
Target (__% growth)	$______	_______
Maximum (___%)	$______	_______

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Performance Based Share Vesting Schedule Fiscal Years 20__-20__(Example)
Performance Level	Performance Based	Vested SWX Shares
Below Threshold (__% growth)	$0	0
Threshold (__% growth)	$_____	______
Target (___% growth)	$_____	______
Maximum (___%)	$_____	______

5. Holding Requirements. Grantee shall accumulate Southwest Gas Holdings, Inc. stock with a target value of a multiple of ___ (__) times base salary. Until Grantee reaches the target ownership requirement, Grantee must retain ___% of the net after-tax Shares granted under this Award Agreement. Grantee shall also accumulate a target value of __ (__) times base salary in cash deferred in the Centuri LTCIP pursuant to the deferral election to the Centuri Executive Deferred Compensation Plan (“EDCP”) and Internal Revenue Code Section 409A with respect to such award.

6. Forfeiture of Shares.

All Shares granted shall be forfeited if, prior to the removal of restrictions, the Grantee has experienced a Termination for any reason other than as described below in Section 8. The Grantee shall execute any documents reasonably requested by the Company in connection with such forfeiture. Upon any forfeiture, all rights of the Grantee with respect to the forfeited Shares shall cease and terminate, without any further obligation on the part of the Company.

7. Removal of Restrictions.

(a) Death, Disability, Certain Involuntary Terminations and Terminations following a Change in Control.

Upon Grantee's death, Termination due to Disability, Termination due to a general reduction in force or specific elimination of the Grantee's job (except if contemporaneously with such elimination Grantee suffers a Termination for Cause), or Termination for any reason following a Change in Control, restrictions placed on each Performance and Time-based Share shall be removed, and the Measurement Cycle for purposes of Section 9 and Section 10 below shall be deemed to have ended. The prorated number of Shares awarded shall be determined by multiplying the percentage of Shares awarded at the “Target” performance level first stated above, by the ratio of actual months of service to 36 months of the original Measurement Cycle, with the resulting product being increased, if appropriate, as provided below in Section 9. The Grantee, or his or her legal representatives, beneficiaries or heirs shall be entitled to a distribution of shares of Common Stock equal in number to such prorated number Shares.

(b) Retirement.

Upon Grantee's Retirement, the restrictions placed on the Performance and Time-based Shares under Section 3 above shall not be removed and the percentage of Performance and Time-based Shares earned shall not be determined until the end of the Measurement Cycle. The vested number of Performance and Time-based Shares shall be determined by multiplying the ratio of actual months of service to 36 months of the original Measurement Cycle by the percentage of Performance and Time-based Shares earned,

3

based on actual performance achieved over the original Measurement Cycle with the resulting product being increased, if appropriate, as provided below in Section 9. The Grantee, or his or her legal representatives, beneficiaries or heirs shall be entitled to a distribution of shares of Common Stock equal in number to such prorated number of Performance and Time-based Shares.

8. Credit of Dividend Equivalents.

The Grantee’s account shall be credited with a number of Shares based on the amount of dividends that were declared and paid on shares of Common Stock during each fiscal quarter of the Measurement Cycle. The number of Shares upon which dividend equivalents shall be credited for the benefit of the Grantee is the total number of Shares finally determined to have been earned by the Grantee at the end of the Measurement Cycle in accordance with Sections 4, 5, 6 and/or 8, as appropriate. The total amount of each quarterly dividend equivalent shall be converted to the number of Shares attributable to that quarterly dividend equivalent, by dividing such dividend equivalent amount by the average of the closing price of the Common Stock on the dividend payment date during the appropriate Measurement Cycle. Incremental Shares credited for dividends may also earn dividend equivalents.

9. Distribution of Common Stock or Cash.

The Grantee shall receive a distribution of whole shares of Common Stock equal to the number of vested Shares plus dividend equivalents, as applicable, provided the Grantee has remained in continuous service with the Company during the entire term of the Measurement Cycle (except in the event of Retirement pursuant to Section 8(b)). Distribution of shares of Common Stock shall occur as soon as administratively possible following the last trading day of the quarter in which the Measurement Cycle ends (the “Distribution Date”), but in no event later than 180 days following the last trading day of the applicable quarter. Notwithstanding the immediately preceding sentence, in the case of a distribution of shares of Common Stock on account of any Termination pursuant to Section 8, other than death, distribution of vested Shares, plus any dividends payable with respect to such number of shares, on behalf of the Grantee, if the Grantee is a "specified employee" as defined in §1.409A-1(i) of the Final Regulations under Internal Revenue Code Section 409A, to the extent otherwise required under Section 409A, shall not occur until the date which is six (6) months following the date of the Grantee’s Termination (or, if earlier, upon the death of the Grantee). Upon a distribution of shares of Common Stock as provided herein, the Company and Southwest Gas Holdings, Inc. shall cause the Common Stock then being distributed to be registered in the Grantee’s name, but shall not issue certificates for the Common Stock unless the Grantee requests delivery of the certificates for the Common Stock, in writing in accordance with the procedures established by the Company and Southwest Gas Holdings, Inc. The Company and Southwest Gas Holdings, Inc. shall deliver certificates to the Grantee as soon as administratively practicable following the Company’s receipt of a written request from the Grantee for delivery of the certificates. From and after the date of receipt of such distribution, the Grantee or the Grantee's legal representatives, beneficiaries or heirs, as the case may be, shall have full rights of transfer or resale with respect to such shares subject to applicable state and federal regulations.

10. Administration.

This Award Agreement and the rights of the Grantee hereunder are subject to all the terms and conditions of the Plans. Any inconsistency between this Award Agreement and the Plans shall be resolved in favor of the Plans.

4

11. Miscellaneous.

(a)Nothing in this Award Agreement or the Plans shall interfere with or limit in any way the right of the Company to terminate the Grantee’s employment, nor confer upon the Grantee any right to continued employment with the Company.

(b)The Centuri Compensation Committee (“Committee”) may terminate, amend, or modify the Long-Term Capital Incentive Plan and Long-Term Incentive Plan, and the Southwest Gas Holdings Inc. Board of Directors may terminate, amend, or modify the Omnibus Incentive Plan; provided, however, that no such termination, amendment, or modification of the Plans may in any way adversely affect the Grantee’s rights under this Award Agreement without the Grantee’s written consent.

(c)The Grantee shall not have voting rights with respect to the Shares until the Shares are settled, vested, and have been distributed as shares of Common Stock.

(d)This Award Agreement shall be subject to all applicable laws, rules, and regulations, and to such approvals by any governmental agencies or national securities exchanges as may be required.

(e)This Award Agreement shall be governed by the corporate laws of the State of Nevada, without giving effect to any choice of law provisions that might otherwise refer construction or interpretation of the Award Agreement or the Plans to the substantive law of another jurisdiction.

(f)Notwithstanding the established performance measures in this Award Agreement, in determining attainment of any such performance measures, the Committee shall exclude the impact of the following specified objective events, [___]: effects of accounting changes; effects of currency fluctuations; effects of financing activities (e.g., effect on earnings per share of issuing convertible debt securities); expenses for restructuring, productivity initiatives or new business initiatives; non-operating items; acquisition expenses; effects of divestitures; and effects of items that are considered to be of an unusual nature or of a type that indicates infrequency of occurrence or both.

Grantee acknowledges that this Award Agreement and the Plans set forth the entire understanding between Grantee and the Company regarding the acquisition of the Shares granted pursuant to this Award Agreement. Grantee has reviewed and fully understands all provisions of this Award Agreement and the Plans in their entirety. Grantee acknowledges that Shares awarded hereunder may not be sold, transferred, pledged, assigned, or otherwise alienated until the Shares are vested and the Shares are delivered to the Grantee in the form of shares of Common Stock.

SOUTHWEST GAS HOLDINGS, INC.

By: _______________________

     [Name]

     [Title]

CENTURI CONSTRUCTION GROUP, INC.

5

By: _______________________

GRANTEE

By: _______________________

6

EX-31.01

Exhibit 31.01

Certification of Southwest Gas Holdings, Inc.

I, John P. Hester, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Southwest Gas Holdings, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 8, 2019

/s/ JOHN P. HESTER

John P. Hester

President and Chief Executive Officer

Southwest Gas Holdings, Inc.

Certification of Southwest Gas Holdings, Inc.

I, Gregory J. Peterson, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Southwest Gas Holdings, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 8, 2019

/s/ GREGORY J. PETERSON

Gregory J. Peterson

Senior Vice President/Chief Financial Officer

Southwest Gas Holdings, Inc.

EX-31.02

Exhibit 31.02

Certification of Southwest Gas Corporation

I, John P. Hester, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Southwest Gas Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 8, 2019

/s/ JOHN P. HESTER

John P. Hester

President and Chief Executive Officer

Southwest Gas Corporation

Certification of Southwest Gas Corporation

I, Gregory J. Peterson, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Southwest Gas Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a.) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b.) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c.) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d.) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 8, 2019

/s/ GREGORY J. PETERSON

Gregory J. Peterson

Senior Vice President/Chief Financial Officer

Southwest Gas Corporation

EX-32.01

Exhibit 32.01

SOUTHWEST GAS HOLDINGS, INC.

CERTIFICATION

In connection with the periodic report of Southwest Gas Holdings, Inc. (the “Company”) on Form 10-Q for the period ended March 31, 2019 as filed with the Securities and Exchange Commission (the “Report”), I, John P. Hester, the President and Chief Executive Officer of the Company, hereby certify as of the date hereof, solely for purposes of Title 18, Chapter 63, Section 1350 of the United States Code, that to the best of my knowledge:

(1) the Report fully complies with the requirements of section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company at the dates and for the periods indicated.

This Certification has not been, and shall not be deemed, “filed” with the Securities and Exchange Commission.

Dated: May 8, 2019

/s/ John P. Hester

John P. Hester

President and Chief Executive Officer

SOUTHWEST GAS HOLDINGS, INC.

CERTIFICATION

In connection with the periodic report of Southwest Gas Holdings, Inc. (the “Company”) on Form 10-Q for the period ended March 31, 2019 as filed with the Securities and Exchange Commission (the “Report”), I, Gregory J. Peterson, Senior Vice President/Chief Financial Officer of the Company, hereby certify as of the date hereof, solely for purposes of Title 18, Chapter 63, Section 1350 of the United States Code, that to the best of my knowledge:

(1) the Report fully complies with the requirements of section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company at the dates and for the periods indicated.

This Certification has not been, and shall not be deemed, “filed” with the Securities and Exchange Commission.

Dated: May 8, 2019

/s/ Gregory J. Peterson

Gregory J. Peterson

Senior Vice President/Chief Financial Officer

EX-32.02

Exhibit 32.02

SOUTHWEST GAS CORPORATION

CERTIFICATION

In connection with the periodic report of Southwest Gas Corporation on Form 10-Q for the period ended March 31, 2019 as filed with the Securities and Exchange Commission (the “Report”), I, John P. Hester, the President and Chief Executive Officer of Southwest Gas Corporation, hereby certify as of the date hereof, solely for purposes of Title 18, Chapter 63, Section 1350 of the United States Code, that to the best of my knowledge:

(1) the Report fully complies with the requirements of section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Southwest Gas Corporation at the dates and for the periods indicated.

This Certification has not been, and shall not be deemed, “filed” with the Securities and Exchange Commission.

Dated: May 8, 2019

/s/ John P. Hester

John P. Hester

President and Chief Executive Officer

SOUTHWEST GAS CORPORATION

CERTIFICATION

In connection with the periodic report of Southwest Gas Corporation on Form 10-Q for the period ended March 31, 2019 as filed with the Securities and Exchange Commission (the “Report”), I, Gregory J. Peterson, Senior Vice President/Chief Financial Officer of Southwest Gas Corporation, hereby certify as of the date hereof, solely for purposes of Title 18, Chapter 63, Section 1350 of the United States Code, that to the best of my knowledge:

(1) the Report fully complies with the requirements of section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Southwest Gas Corporation at the dates and for the periods indicated.

This Certification has not been, and shall not be deemed, “filed” with the Securities and Exchange Commission.

Dated: May 8, 2019

/s/ Gregory J. Peterson

Gregory J. Peterson

Senior Vice President/Chief Financial Officer

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2019	Apr. 30, 2019
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Entity Emerging Growth Company	false
Entity Small Business	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Trading Symbol	SWX
Entity Registrant Name	Southwest Gas Holdings, Inc.
Entity Central Index Key	0001692115
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		53,396,583
Southwest Gas Corporation
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Entity Emerging Growth Company	false
Entity Small Business	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Trading Symbol	SWX
Entity Registrant Name	Southwest Gas Corporation
Entity Central Index Key	0000092416
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer

XML

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Utility plant:
Gas plant	$ 7,268,255	$ 7,134,239
Less: accumulated depreciation	(2,257,017)	(2,234,029)
Construction work in progress	204,370	193,028
Net utility plant	5,215,608	5,093,238
Other property and investments	716,722	623,551
Current assets:
Cash and cash equivalents	97,037	85,361
Accounts receivable, net of allowances	429,248	413,926
Accrued utility revenue	47,000	77,200
Income taxes receivable	14,069	14,653
Deferred purchased gas costs	65,242	4,928
Prepaid and other current assets	177,784	243,701
Total current assets	830,380	839,769
Noncurrent assets:
Goodwill	364,482	359,045
Deferred income taxes	1,074	1,264
Deferred charges and other assets	441,166	440,862
Total noncurrent assets	806,722	801,171
Total assets	7,569,432	7,357,729
Capitalization:
Common stock, $1 par (authorized - 60,000,000 shares; issued and outstanding - 53,391,731 and 53,026,848 shares)	55,021	54,656
Additional paid-in capital	1,332,793	1,305,769
Accumulated other comprehensive income (loss), net	(50,623)	(52,668)
Retained earnings	1,009,809	944,285
Total Southwest Gas Holdings, Inc. equity	2,347,000	2,252,042
Noncontrolling interest	(452)	(452)
Total equity	2,346,548	2,251,590
Redeemable noncontrolling interest	82,406	81,831
Long-term debt, less current maturities	2,106,274	2,107,258
Total capitalization	4,535,228	4,440,679
Current liabilities:
Current maturities of long-term debt	34,915	33,060
Short-term debt	188,000	152,000
Accounts payable	231,343	248,993
Customer deposits	68,593	67,940
Income taxes payable	0	1,083
Accrued general taxes	69,423	43,560
Accrued interest	31,439	21,369
Deferred purchased gas costs	72,213	79,762
Other current liabilities	278,552	290,878
Total current liabilities	974,478	938,645
Deferred income taxes and other credits:
Deferred income taxes and investment tax credits	556,063	529,201
Accumulated removal costs	385,000	383,000
Other deferred credits and other long-term liabilities	1,118,663	1,066,204
Total deferred income taxes and other credits	2,059,726	1,978,405
Total capitalization and liabilities	7,569,432	7,357,729
Southwest Gas Corporation
Utility plant:
Gas plant	7,268,255	7,134,239
Less: accumulated depreciation	(2,257,017)	(2,234,029)
Construction work in progress	204,370	193,028
Net utility plant	5,215,608	5,093,238
Other property and investments	123,783	116,146
Current assets:
Cash and cash equivalents	75,148	31,962
Accounts receivable, net of allowances	170,471	140,057
Accrued utility revenue	47,000	77,200
Income taxes receivable	10,602	13,444
Deferred purchased gas costs	65,242	4,928
Prepaid and other current assets	165,382	229,562
Total current assets	533,845	497,153
Noncurrent assets:
Goodwill	10,095	10,095
Deferred charges and other assets	423,495	424,952
Total noncurrent assets	433,590	435,047
Total assets	6,306,826	6,141,584
Capitalization:
Common stock, $1 par (authorized - 60,000,000 shares; issued and outstanding - 53,391,731 and 53,026,848 shares)	49,112	49,112
Additional paid-in capital	1,089,002	1,065,242
Accumulated other comprehensive income (loss), net	(47,795)	(49,049)
Retained earnings	797,584	717,155
Total Southwest Gas Holdings, Inc. equity	1,887,903	1,782,460
Total equity	1,887,903	1,782,460
Long-term debt, less current maturities	1,818,959	1,818,669
Total capitalization	3,706,862	3,601,129
Current liabilities:
Short-term debt	188,000	152,000
Accounts payable	148,309	184,982
Customer deposits	68,593	67,940
Accrued general taxes	69,423	43,560
Accrued interest	30,398	20,243
Deferred purchased gas costs	72,213	79,762
Payable to parent	1,038	472
Other current liabilities	100,556	94,136
Total current liabilities	678,530	643,095
Deferred income taxes and other credits:
Deferred income taxes and investment tax credits	517,124	490,458
Accumulated removal costs	385,000	383,000
Other deferred credits and other long-term liabilities	1,019,310	1,023,902
Total deferred income taxes and other credits	1,921,434	1,897,360
Total capitalization and liabilities	$ 6,306,826	$ 6,141,584

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Mar. 31, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Common stock, par (in USD per share)	$ 1	$ 1
Common stock, authorized (in shares)	60,000,000	60,000,000
Common stock, issued (in shares)	53,391,731	53,026,848
Common stock, outstanding (in shares)	53,391,731	53,026,848

XML

CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018
Operating revenues:
Gas operating revenues	$ 520,677	$ 494,313	$ 1,384,092	$ 1,334,019
Utility infrastructure services revenues	312,862	260,017	1,575,130	1,314,366
Total operating revenues	833,539	754,330	2,959,222	2,648,385
Operating expenses:
Net cost of gas sold	192,604	185,732	426,260	393,898
Operations and maintenance	106,245	102,351	410,287	390,819
Depreciation and amortization	77,539	62,478	264,273	240,951
Taxes other than income taxes	16,206	15,257	60,847	58,421
Utility infrastructure services expenses	300,465	258,952	1,429,202	1,215,959
Total operating expenses	693,059	624,770	2,590,869	2,300,048
Operating income	140,480	129,560	368,353	348,337
Other income and (expenses):
Net interest deductions	(26,397)	(22,631)	(100,437)	(81,981)
Other income (deductions)	6,839	(4,334)	(6,253)	(9,374)
Total other income and (expenses)	(19,558)	(26,965)	(106,690)	(91,355)
Income before income taxes	120,922	102,595	261,663	256,982
Income tax expense	25,538	24,301	62,921	53,751
Net income	95,384	78,294	198,742	203,231
Net income (loss) attributable to noncontrolling interests	575	(797)	747	(393)
Net income attributable to Southwest Gas Holdings, Inc.	$ 94,809	$ 79,091	$ 197,995	$ 203,624
Basic earnings per share (in USD per share)	$ 1.78	$ 1.63	$ 3.91	$ 4.23
Diluted earnings per share (in USD per share)	$ 1.77	$ 1.63	$ 3.91	$ 4.23
Average number of common shares (in shares)	53,369	48,416	50,640	48,105
Average shares (assuming dilution) (in shares)	53,424	48,459	50,701	48,139
Southwest Gas Corporation
Operating revenues:
Gas operating revenues	$ 520,677	$ 494,313	$ 1,384,092	$ 1,334,019
Operating expenses:
Net cost of gas sold	192,604	185,732	426,260	393,898
Operations and maintenance	105,542	102,190	408,165	389,687
Depreciation and amortization	57,612	49,961	199,467	190,688
Taxes other than income taxes	16,206	15,257	60,847	58,421
Total operating expenses	371,964	353,140	1,094,739	1,032,694
Operating income	148,713	141,173	289,353	301,325
Other income and (expenses):
Net interest deductions	(23,099)	(19,255)	(85,584)	(71,778)
Other income (deductions)	5,946	(4,603)	(6,691)	(9,747)
Total other income and (expenses)	(17,153)	(23,858)	(92,275)	(81,525)
Income before income taxes	131,560	117,315	197,078	219,800
Income tax expense	28,171	26,966	45,196	49,571
Net income	103,389	90,349	151,882	170,229
Net income attributable to Southwest Gas Holdings, Inc.	$ 103,389	$ 90,349	$ 151,882	$ 170,229

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018
Net income	$ 95,384	$ 78,294	$ 198,742	$ 203,231
Defined benefit pension plans:
Net actuarial gain (loss)	0	0	(15,524)	(32,701)
Amortization of prior service cost	241	254	1,002	875
Amortization of net actuarial loss	4,441	6,387	23,603	18,219
Regulatory adjustment	(4,063)	(5,746)	(4,574)	10,400
Net defined benefit pension plans	619	895	4,507	(3,207)
Forward-starting interest rate swaps (“FSIRS”):
Amounts reclassified into net income	635	635	2,541	2,190
Net forward-starting interest rate swaps	635	635	2,541	2,190
Foreign currency translation adjustments	791	(911)	(1,308)	640
Total other comprehensive income (loss), net of tax	2,045	619	5,740	(377)
Comprehensive income	97,429	78,913	204,482	202,854
Comprehensive income (loss) attributable to noncontrolling interests	575	(797)	747	(389)
Comprehensive income attributable to Southwest Gas Holdings, Inc.	96,854	79,710	203,735	203,243
Southwest Gas Corporation
Net income	103,389	90,349	151,882	170,229
Defined benefit pension plans:
Net actuarial gain (loss)	0	0	(15,524)	(32,701)
Amortization of prior service cost	241	254	1,002	875
Amortization of net actuarial loss	4,441	6,387	23,603	18,219
Regulatory adjustment	(4,063)	(5,746)	(4,574)	10,400
Net defined benefit pension plans	619	895	4,507	(3,207)
Forward-starting interest rate swaps (“FSIRS”):
Amounts reclassified into net income	635	635	2,541	2,190
Net forward-starting interest rate swaps	635	635	2,541	2,190
Total other comprehensive income (loss), net of tax	1,254	1,530	7,048	(1,017)
Comprehensive income	$ 104,643	$ 91,879	$ 158,930	$ 169,212

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018
CASH FLOW FROM OPERATING ACTIVITIES:
Net income	$ 95,384	$ 78,294	$ 198,742	$ 203,231
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	77,539	62,478	264,273	240,951
Deferred income taxes	24,923	23,228	52,736	49,372
Changes in current assets and liabilities:
Accounts receivable, net of allowances	(15,562)	8,858	(40,282)	(68,978)
Accrued utility revenue	30,200	30,900	300	(1,400)
Deferred purchased gas costs	(67,863)	(10,628)	25,339	(36,330)
Accounts payable	(12,643)	(48,497)	47,632	26,762
Accrued taxes	25,400	18,776	(5,331)	491
Other current assets and liabilities	47,848	(643)	(5,582)	(29,945)
Gains on sale	(233)	(230)	(1,706)	(4,087)
Changes in undistributed stock compensation	3,188	1,861	7,438	6,638
AFUDC	(960)	(229)	(4,358)	(2,050)
Changes in other assets and deferred charges	(16,328)	(1,845)	(20,221)	(16,941)
Changes in other liabilities and deferred credits	(2,782)	18,244	17,420	20,965
Net cash provided by operating activities	188,111	180,567	536,400	388,679
CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions	(210,662)	(154,542)	(822,034)	(662,401)
Acquisition of businesses, net of cash acquired	0	(4,209)	(247,164)	(98,413)
Changes in customer advances	3,078	3,038	13,503	2,304
Miscellaneous inflows	262	1,505	3,200	13,429
Net cash used in investing activities	(207,322)	(154,208)	(1,052,495)	(745,081)
CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net	25,879	11,220	369,061	52,375
Dividends paid	(27,602)	(23,839)	(104,003)	(94,572)
Centuri distribution to redeemable noncontrolling interest	0	(102)	0	(204)
Issuance of long-term debt, net	29,666	335,382	259,456	716,165
Retirement of long-term debt	(31,160)	(21,102)	(247,816)	(312,308)
Change in credit facility and commercial paper	0	(111,000)	111,000	24,000
Change in short-term debt	36,000	(192,000)	165,500	22,500
Principal payments on finance lease obligations	(70)	(165)	(553)	(946)
Redemption of Centuri shares from noncontrolling parties	0	0	0	(23,000)
Withholding remittance - share-based compensation	(1,838)	(2,852)	(2,096)	(3,510)
Other	(53)	(337)	(2,460)	(2,498)
Net cash provided by (used in) financing activities	30,822	(4,795)	548,089	378,002
Effects of currency translation on cash and cash equivalents	65	(71)	(72)	114
Change in cash and cash equivalents	11,676	21,493	31,922	21,714
Cash and cash equivalents at beginning of period	85,361	43,622	65,115	43,401
Cash and cash equivalents at end of period	97,037	65,115	97,037	65,115
Supplemental information:
Interest paid, net of amounts capitalized	15,850	13,294	89,118	74,949
Income taxes paid (received)	454	4,418	(2,743)	8,264
Southwest Gas Corporation
CASH FLOW FROM OPERATING ACTIVITIES:
Net income	103,389	90,349	151,882	170,229
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	57,612	49,961	199,467	190,688
Deferred income taxes	26,270	18,676	50,593	46,622
Changes in current assets and liabilities:
Accounts receivable, net of allowances	(30,414)	(28,201)	(22,522)	(29,031)
Accrued utility revenue	30,200	30,900	300	(1,400)
Deferred purchased gas costs	(67,863)	(10,628)	25,339	(36,330)
Accounts payable	(39,574)	(34,564)	18,398	14,717
Accrued taxes	28,704	27,476	(17,504)	12,683
Other current assets and liabilities	81,625	3,163	(12,982)	(47,905)
Changes in undistributed stock compensation	2,597	2,118	5,834	5,695
AFUDC	(960)	(229)	(4,358)	(2,050)
Changes in other assets and deferred charges	(18,238)	(1,998)	(23,289)	(17,655)
Changes in other liabilities and deferred credits	(2,977)	17,887	16,805	20,230
Net cash provided by operating activities	170,371	164,910	387,963	326,493
CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions	(163,636)	(131,743)	(714,762)	(591,184)
Changes in customer advances	3,078	3,038	13,503	2,304
Miscellaneous inflows	(78)	293	(357)	2,250
Net cash used in investing activities	(160,636)	(128,412)	(701,616)	(586,630)
CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net	0	0	0	41,359
Contributions from parent	22,842	0	136,391	0
Dividends paid	(23,500)	(21,000)	(89,500)	(83,997)
Issuance of long-term debt, net	0	297,495	0	297,495
Change in credit facility and commercial paper	0	(111,000)	111,000	24,000
Change in short-term debt	36,000	(191,000)	188,000	0
Withholding remittance - share-based compensation	(1,838)	(2,852)	(2,096)	(3,510)
Other	(53)	(298)	(783)	(371)
Net cash provided by (used in) financing activities	33,451	(28,655)	343,012	274,976
Change in cash and cash equivalents	43,186	7,843	29,359	14,839
Cash and cash equivalents at beginning of period	31,962	37,946	45,789	30,950
Cash and cash equivalents at end of period	75,148	45,789	75,148	45,789
Supplemental information:
Interest paid, net of amounts capitalized	11,585	10,296	75,094	66,097
Income taxes paid (received)	$ (22)	$ 0	$ (5,878)	$ (7,816)

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Background, Organization, and Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Background, Organization, and Summary of Significant Accounting Policies

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). At the annual meeting of shareholders of Southwest Gas Holdings, Inc., held on May 2, 2019, shareholders voted to approve changing the state of incorporation for Southwest Gas Holdings, Inc. from California to Delaware. The reincorporation is expected to be effective during the second or third quarter of 2019. However, the reincorporation remains subject to certain regulatory approvals, which are currently pending.

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 from installation, replacement, repair, and maintenance of energy distribution systems, and developing industrial construction solutions. Centuri operations are generally conducted under the business names of NPL Construction Co. (“NPL”), NPL Canada Ltd. (“NPL Canada”), New England Utility Constructors, Inc. (“Neuco”) and Linetec Services, LLC (“Linetec”). Utility infrastructure services activity is seasonal in 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. In November 2017, Centuri acquired Neuco, thereby expanding its core services in the northeast region of the U.S. Additionally, in November 2018, Centuri expanded its operations in the southeast region of the U.S. through the acquisition of an 80% interest in Linetec. See Note 12 – Business Acquisitions for more information.

Basis of Presentation. The condensed consolidated financial statements for 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, or in the primary businesses comprising those segments as a result of the foregoing acquisitions of Neuco and Linetec.

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 at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. In the opinion of management, all adjustments, consisting of normal recurring items and estimates necessary for a fair statement of results for the interim periods, have been made. It is suggested that these condensed consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the 2018 Annual Report to Shareholders, which is incorporated by reference into the 2018 Form 10-K.

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.

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

Other Property and Investments. Other property and investments on the Condensed Consolidated Balance Sheets includes (thousands of dollars):

	March 31, 2019			December 31, 2018
Southwest Gas Corporation:
Net cash surrender value of COLI policies	$	122,048		$	114,405
Other property	1,735			1,741
Total Southwest Gas Corporation	123,783			116,146
Centuri property, equipment, and intangibles	894,739			792,191
Centuri accumulated depreciation/amortization	(316,832		)	(298,939		)
Other property	15,032			14,153
Total Southwest Gas Holdings, Inc.	$	716,722		$	623,551

Cash and Cash Equivalents. For purposes of reporting consolidated cash flows, cash and cash equivalents include cash on hand and financial instruments with maturities of three months or less. Such investments are carried at cost, which approximates market value. Cash and cash equivalents for Southwest and the Company also include money market fund investments totaling approximately $41 million and $54.4 million, respectively, at March 31, 2019, and $18 million and $59.9 million, respectively, at December 31, 2018, which fall within Level 2 of the fair value hierarchy, due to the asset valuation methods used by money market funds.

Typical non-cash investing activities for Southwest include customer advances applied as contributions toward utility construction activity and capital expenditures that were not paid as of quarter end that are included in accounts payable. Amounts related to such activities were immaterial for the periods presented herein. Non-cash investing activities for the three months and twelve months ended March 31, 2019 included $73.5 million of purchase consideration related to the Linetec acquisition by Centuri, in the form of liabilities incurred that remained unpaid as of March 31, 2019; such amounts are included in Other current liabilities on the Condensed Consolidated Balance Sheets of the Company. Also, see Recent Accounting Standards Updates and Note 4 – Leases for information related to right-of-use assets obtained in exchange for lease liabilities, which are non-cash investing and financing activities.

Intercompany Transactions. Centuri recognizes revenues generated from contracts with Southwest (see Note 10 – Segment Information). Centuri’s accounts receivable for these services are presented in the table below (thousands of dollars):

	March 31, 2019		December 31, 2018
Centuri accounts receivable for services provided to Southwest	$	16,837	$	18,830

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.

Income Taxes. In 2017, the Tax Cuts and Jobs Act (the “TCJA”) was enacted. The TCJA had significant impacts on the taxation of business entities, including specific provisions related to regulated public utilities. The more significant changes that impacted the Company and Southwest include the reduction in the corporate federal income tax rate from 35% to 21%, and limiting the utilization of net operating losses (“NOLs”) to 80% of taxable income, with the ability to indefinitely carryforward unutilized NOLs to reduce future taxable income.

Prepaid and Other Current Assets. Prepaid and other current assets includes gas pipe materials and operating supplies of $55 million at March 31, 2019 and $56 million at December 31, 2018 (carried at weighted average cost), as well as $55 million at March 31, 2019 and $74 million at December 31, 2018 related to a regulatory asset associated with the Arizona decoupling mechanism (an alternative revenue program).

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 consistent between periods presented below, and that no change was necessary with regard to the level at which goodwill is assessed for impairment. No impairment was deemed to have occurred in the first three months of 2019.

(Thousands of dollars)	Natural Gas Operations		Utility Infrastructure Services		Total Company
December 31, 2018	$	10,095	$	348,950	$	359,045
Measurement Period Adjustment - Linetec acquisition	—		3,303		3,303
Foreign currency translation adjustment	—		2,134		2,134
March 31, 2019	$	10,095	$	354,387	$	364,482

Other Current Liabilities. Other current liabilities for Southwest include $22.8 million of dividends declared by Southwest Gas Corporation, but not yet paid to Southwest Gas Holdings, Inc. at March 31, 2019.

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

	Three Months Ended						Twelve Months Ended
	March 31,						March 31,
	2019			2018			2019			2018
Southwest Gas Corporation - natural gas operations segment:
Change in COLI policies	$	7,600		$	(700	)	$	5,100		$	6,800
Interest income	1,597			1,418			6,199			3,638
Equity AFUDC	960			229			4,358			2,049
Other components of net periodic benefit cost	(3,765		)	(5,265		)	(19,560		)	(19,834		)
Miscellaneous income and (expense)	(446		)	(285		)	(2,788		)	(2,400		)
Southwest Gas Corporation - total other income (deductions)	5,946			(4,603		)	(6,691		)	(9,747		)
Utility infrastructure services segment:
Interest income	—			1			87			4
Foreign transaction gain (loss)	531			147			162			(606		)
Miscellaneous income and (expense)	344			115			125			956
Centuri - total other income (deductions)	875			263			374			354
Corporate and administrative	18			6			64			19
Consolidated Southwest Gas Holdings, Inc. - total other income (deductions)	$	6,839		$	(4,334	)	$	(6,253	)	$	(9,374	)

Included in the table above is the change in cash surrender values of company-owned life insurance (“COLI”) policies (including net death benefits recognized). 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. 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 Note 2 – Components of Net Periodic Benefit Cost.

Recent Accounting Standards Updates.

Accounting pronouncements adopted in 2019:

In February 2016, the FASB issued the update “Leases (Topic 842).” Under the update, lessees were required to recognize a lease liability for the obligation to make lease payments, measured on a discounted basis; and a right-of-use asset for the right to use, or control the use of, a specified asset for the lease term. The Company and Southwest adopted Topic 842 in the first quarter of 2019 through an optional transition method, which was elected, permitting the application of the provisions of the standard at the adoption date, rather than to earlier comparative periods. As a result, the Company and Southwest have not recast prior periods to reflect the adoption of this standard. See Note 4 – Leases.

Accounting pronouncements that will be effective after 2019:

In June 2016, the FASB issued ASU 2016-13 update “Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The update requires the measurement of all expected credit losses for financial assets held at the reporting date based on historical experience, current conditions, and reasonable and supportable forecasts. The inputs currently used to estimate credit losses will still be used; however, they may be adapted to reflect the full amount of expected losses. The update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. All entities may adopt the amendments in this update earlier as of fiscal years beginning after December 15, 2018, including interim

periods within those fiscal years. Management is evaluating what impact, if any, this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures.

In January 2017, the FASB issued ASU 2017-04 “Intangibles – Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” Currently, unless meeting the criteria for qualitative assessment only, an entity is required to perform a two-step test to determine the amount, if any, of goodwill impairment. In Step 1, an entity compares the fair value of a reporting unit with its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, the entity performs Step 2 and compares the implied fair value of goodwill with the carrying amount of that goodwill for that reporting unit, requiring a hypothetical purchase price allocation to measure the amount of a goodwill impairment. An impairment charge equal to the amount by which the carrying amount of goodwill for the reporting unit exceeds the implied fair value of that goodwill is recorded, limited to the amount of goodwill allocated to that reporting unit. Under the update, an entity will apply a one-step quantitative test and record the amount of goodwill impairment as the excess of a reporting unit's carrying amount over its fair value, not to exceed the total amount of goodwill allocated to the reporting unit. The new guidance does not amend the optional qualitative assessment. The amount of any goodwill impairment calculated under the update could vary from the calculation under existing guidance, largely due to the consideration to be given to unrecognized differences between the fair value and carrying values of the other assets and liabilities in the reporting unit under the new guidance. The amendments should be applied on a prospective basis. The update is effective for fiscal and interim periods beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. Management is evaluating the impacts this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures.

In August 2018, the FASB issued ASU 2018-15 “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract.” The update generally aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement (that is a service contract) with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. The update also requires the entity to expense the capitalized implementation costs of such hosting arrangements over the term of the hosting arrangement, including reasonably certain renewal periods. The update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption of the amendments in this update is permitted for interim and related annual fiscal periods after December 15, 2018. Management is evaluating the impacts this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures.

In August 2018, the FASB issued ASU 2018-14 “Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans.” This update removes disclosures that are no longer considered cost-beneficial, clarifies the specific requirements of disclosures, and adds disclosure requirements identified as relevant. The update applies to all employers that sponsor defined benefit pension or other postretirement plans. The update is effective for fiscal years ending after December 15, 2020. Upon adoption, the Company and Southwest will modify their disclosures to conform to the requirements of the update.

In August 2018, the FASB issued ASU 2018-13 “Fair Value Measurement: Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement.” The update is intended to improve the effectiveness of fair value measurement disclosures and removes the following disclosure requirements: the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy; the policy for timing of transfers between levels; and the valuation processes for Level 3 fair value measurements. The update also modifies or clarifies for investments in certain entities that calculate net asset value, a requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse (in cases when the timing has been communicated or announced publicly). It also clarifies communication requirements about measurement uncertainty as of the reporting date. For certain unobservable inputs, an entity may disclose other quantitative information in lieu of the weighted average if it would be a more reasonable and rational method to reflect the distribution of inputs to the measurements. The update is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. Management is evaluating the impacts this update might have on its disclosures.

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Components of Net Periodic Benefit Cost

3 Months Ended

Mar. 31, 2019

Retirement Benefits [Abstract]

Components of Net Periodic Benefit Cost

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 are components of an overhead loading process associated with the cost of labor. The overhead process ultimately results in allocation of that portion of overall net periodic benefit costs to the same accounts to which productive labor is charged. As a result, service costs become components of various accounts, primarily operations and maintenance expense, net utility plant, and deferred charges and other assets for both the Company and Southwest. The other components of net periodic benefit cost are reflected in Other income (deductions) on the Condensed Consolidated Statements of Income of the Company and Southwest.

	Qualified Retirement Plan
	Period Ended March 31,
	Three Months						Twelve Months
	2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	6,466		$	7,139		$	27,882		$	24,683
Interest cost	12,252			11,043			45,383			45,606
Expected return on plan assets	(15,061		)	(14,689		)	(59,127		)	(56,086		)
Amortization of net actuarial loss	5,589			8,029			29,675			26,032
Net periodic benefit cost	$	9,246		$	11,522		$	43,813		$	40,235
	SERP
	Period Ended March 31,
	Three Months						Twelve Months
	2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	66		$	61		$	250		$	292
Interest cost	440			415			1,683			1,827
Amortization of net actuarial loss	255			375			1,382			1,456
Net periodic benefit cost	$	761		$	851		$	3,315		$	3,575
	PBOP
	Period Ended March 31,
	Three Months						Twelve Months
	2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	319		$	368		$	1,424		$	1,469
Interest cost	762			687			2,823			3,111
Expected return on plan assets	(789		)	(930		)	(3,577		)	(3,448		)
Amortization of prior service costs	317			334			1,318			1,335
Net periodic benefit cost	$	609		$	459		$	1,988		$	2,467

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Revenue

3 Months Ended

Mar. 31, 2019

Revenue from Contract with Customer [Abstract]

Revenue

Note 3 – Revenue

The following information about the Company’s revenues is presented by segment. Southwest encompasses one segment – natural gas operations.

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						Twelve Months Ended
	March 31,						March 31,
(Thousands of dollars)	2019			2018			2019			2018
Residential	$	417,228		$	344,611		$	959,837		$	859,078
Small commercial	89,610			87,943			256,750			250,331
Large commercial	13,962			15,440			51,714			54,224
Industrial/other	6,478			6,510			23,457			23,085
Transportation	24,902			24,054			87,838			89,081
Revenue from contracts with customers	552,180			478,558			1,379,596			1,275,799
Alternative revenue program revenues (deferrals)	(34,545		)	27,209			(15,775		)	66,788
Other revenues (a)	3,042			(11,454		)	20,271			(8,568		)
Total Gas operating revenues	$	520,677		$	494,313		$	1,384,092		$	1,334,019

(a) Includes various other revenues which, in the periods presented ending March 31, 2018, were offset by a $14 million reserve against revenue associated with a tax reform savings adjustment.

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:

(Thousands of dollars)	Three Months Ended				Twelve Months Ended
	March 31,				March 31,
	2019		2018		2019		2018
Service Types:
Gas infrastructure services	$	197,893	$	193,527	$	1,128,048	$	938,342
Electric power infrastructure services	52,301		5,402		79,528		19,893
Other	62,668		61,088		367,554		356,131
Total Utility infrastructure services revenues	$	312,862	$	260,017	$	1,575,130	$	1,314,366

(Thousands of dollars)	Three Months Ended				Twelve Months Ended
	March 31,				March 31,
	2019		2018		2019		2018
Contract Types:
Master services agreement	$	235,655	$	194,464	$	1,143,603	$	932,804
Bid contract	77,207		65,553		431,527		381,562
Total Utility infrastructure services revenues	$	312,862	$	260,017	$	1,575,130	$	1,314,366
Unit priced contracts	$	235,686	$	197,322	$	1,296,783	$	1,013,642
Fixed priced contracts	38,538		25,541		130,295		137,724
Time and materials contracts	38,638		37,154		148,052		163,000
Total Utility infrastructure services revenues	$	312,862	$	260,017	$	1,575,130	$	1,314,366

The following table provides information about contracts receivable and revenue earned on contracts in progress in excess of billings (contract asset), which are both included within Accounts receivable, net of allowances, as well as amounts billed in excess

of revenue earned on contracts (contract liability), which are included in Other current liabilities as of March 31, 2019 and December 31, 2018 on the Company’s Condensed Consolidated Balance Sheets:

(Thousands of dollars)	March 31, 2019		December 31, 2018
Contracts receivable, net	$	160,973	$	186,249
Revenue earned on contracts in progress in excess of billings	97,642		87,520
Amounts billed in excess of revenue earned on contracts	4,588		4,211

The revenue earned on contracts in progress in excess of billings (contract asset) primarily relates to Centuri’s rights to consideration for work completed but not billed and/or approved at the reporting date. These contract assets are transferred to contracts receivable when the rights become unconditional. The amounts billed in excess of revenue earned (contract liability) primarily relates 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, 2018 to March 31, 2019 is due to revenue recognized of $4.2 million that was included in this item as of January 1, 2019, after which time it became earned and the balance was reduced, and to increases due to cash received, net of revenue recognized during the period related to contracts that commenced during the period.

For contracts that have an original duration of one year or less, Centuri uses the practical expedient applicable to such contracts and does not consider/compute an interest component based on the time value of money. Further, 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, 2019, Centuri has seventeen contracts that had 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, 2019 is $60.7 million. Centuri expects to recognize the remaining performance obligations over the next three years; 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)	March 31, 2019			December 31, 2018
Billed on completed contracts and contracts in progress	$	159,829		$	184,100
Other receivables	1,527			2,588
Contracts receivable, gross	161,356			186,688
Allowance for doubtful accounts	(383		)	(439		)
Contracts receivable, net	$	160,973		$	186,249

XML

Leases

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Leases

Note 4 – Leases

The Company and Southwest adopted Topic 842 as of January 1, 2019. In association with the adoption, the Company recorded adjustments to its Condensed Consolidated Balance Sheet to record right-of-use (“ROU”) assets and lease liabilities of $58.4 million and $60.8 million, respectively. Included in those amounts, Southwest recorded $1.9 million related to both its ROU assets and lease liabilities. Neither the Company nor Southwest experienced a material impact to the Condensed Consolidated Statements of Income from the adoption and no cumulative-effect adjustment to the opening balance of retained earnings was recognized. Management elected to adopt the standard under the optional transition method (refer to Recent Accounting Standards Updates in Note 1 – Background, Organization, and Summary of Significant Accounting Policies), and elected the following Topic 842 practical expedients and accounting policy elections:

• To use the “package”, which is a set of three practical expedients that must be elected as a package and applied consistently to all of Southwest’s and Centuri’s leases. These include: not reassessing whether any expired or existing contracts are or contain leases; not reassessing the lease classification for expired or existing leases (that is, existing operating and capital leases in accordance with current lease guidance will in each case be classified as operating and finance leases, respectively, under the updated guidance); and not reassessing initial direct costs for any existing leases.

• To utilize the practical expedient to exclude all easements in place prior to January 1, 2019 from treatment under Topic 842. However, Southwest will evaluate new easements entered into after the effective date of the standard to determine if the arrangements should be accounted for as leases.

• To make an accounting policy election by asset class to include both the lease and non-lease components (as defined in the guidance) as a single component.

• To make an accounting policy election to not apply Topic 842 to short-term leases, as permitted.

• To not elect to use hindsight in determining the lease term and in assessing impairment of ROU assets.

• To utilize a portfolio approach to effectively account for the operating lease ROU assets and liabilities with regard to certain equipment leases at Centuri.

Southwest and Centuri determine if an arrangement is a lease at inception. ROU assets represent the right to use an underlying asset for the lease term; lease liabilities represent obligations to make lease payments arising from the lease. Operating lease ROU assets and liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. As most of Southwest’s and Centuri’s leases do not provide an implicit interest rate, an incremental borrowing rate based on information available at commencement is used in determining the present value of lease payments; an implicit rate, if readily determinable, is used. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised.

Southwest’s leases are comprised primarily of operating leases of buildings, land, and equipment. Southwest has no finance leases and no significant short-term leases. Southwest’s leases have a remaining term of 1 to 10 years, some of which include options to extend the lease up to 3 years. Southwest is currently not a lessor in any significant lease arrangements. Southwest’s ROU assets are included in Gas plant, and its lease liabilities are included in, depending upon maturity, Other current liabilities or Other deferred credits and other long-term liabilities on the Company’s and Southwest’s Condensed Consolidated Balance Sheet as of March 31, 2019.

Centuri has operating and finance leases for corporate and field offices, construction equipment, and transportation vehicles. Centuri is currently not a lessor in any significant lease arrangements. Centuri’s leases have remaining lease terms of 1 to 14 years. Some of these include options to extend the leases, generally for optional terms of up to 5 years, and some include options to terminate the leases within 1 year. Centuri’s equipment leases may include variable payment terms in addition to the fixed lease payments if machinery is used in excess of the standard work periods. These variable payments are not probable of occurring under the current operating environment and have not been included in consideration of lease payments. Expense for short-term leases of Centuri during the quarter ended March 31, 2019 was $2.6 million, and such leases were not accounted for under the provisions of Topic 842, as permitted. Due to the seasonality of Centuri’s business, expense for short-term leases will fluctuate throughout the year with higher expense incurred during the warmer months. Centuri’s ROU assets are included in Other property and investments, and its lease liabilities for operating and finance leases are included, depending upon maturity, in Other current liabilities or Other deferred credits and other long-term liabilities on the Company’s Condensed Consolidated Balance Sheet as of March 31, 2019.

The components of lease expense were as follows:

(Thousands of dollars)	Three Months Ended
	March 31, 2019
Southwest:
Operating lease cost	$	406
Centuri:
Operating lease cost	$	2,805
Finance lease cost:
Amortization of ROU assets	$	35
Interest on lease liabilities	7
Total finance lease cost	42
Short-term lease cost	2,575
Total lease cost	$	5,828

Supplemental cash flow information related to leases for the three months ended March 31, 2019 was as follows:

(Thousands of dollars)	Southwest		Centuri		Consolidated Total
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	396	$	2,555	$	2,951
Operating cash flows from finance leases	—		7		7
Financing cash flows from finance leases	—		51		51
ROU assets obtained in exchange for lease obligations:
Operating leases	$	523	$	2,321	$	2,844
Finance leases	—		84		84

Supplemental information related to leases, including location in the Condensed Consolidated Balance Sheets, is as follows:

(Thousands of dollars)	March 31, 2019
Southwest:
Operating leases:
Net Utility Plant	$	1,977
Other current liabilities	$	745
Other deferred credits and other long-term liabilities	1,253
Total operating lease liabilities	$	1,998
Weighted average remaining lease term (in years)	4.22
Weighted average discount rate	3.39		%
Centuri:
Operating leases:
Other property and investments	$	57,267
Other current liabilities	7,178
Other deferred credits and other long-term liabilities	52,647
Total operating lease liabilities	$	59,825
Finance leases:
Other property and investments	$	639
Other current liabilities	256
Other deferred credits and other long-term liabilities	239
Total finance lease liabilities	$	495
Weighted average remaining lease term (in years)
Operating leases	9.33
Finance leases	1.63
Weighted average discount rate
Operating leases	4.08		%
Finance leases	5.84		%

The following is a schedule of maturities of lease liabilities as of March 31, 2019:

(Thousands of dollars)	Operating leases
Southwest:
2020	$	800
2021	556
2022	295
2023	124
2024	78
Thereafter	307
Total lease payments	2,160
Less imputed interest	162
Total	$	1,998

(Thousands of dollars)	Operating leases		Finance leases
Centuri:
2020	$	10,394	$	281
2021	9,327		128
2022	8,328		67
2023	7,645		38
2024	5,710		25
Thereafter	31,303		—
Total lease payments	72,707		539
Less imputed interest	12,882		44
Total	$	59,825	$	495

As the Company and Southwest adopted Topic 842 using the optional transition method referred to in Note 1 – Background, Organization, and Summary of Significant Accounting Policies, the recent annual disclosure of rental and lease payments as of December 31, 2018 in accordance with Topic 840 is presented in the table below:

	2018		2017
Southwest Gas Corporation	$	4,556	$	4,926
Centuri	59,491		62,310
Consolidated rental payments/lease expense	$	64,047	$	67,236

The following is a schedule of future minimum lease payments for operating leases (with initial or remaining terms in excess of one year) as of December 31, 2018 (thousands of dollars):

	Southwest		Centuri		Consolidated Total
2019	$	898	$	10,053	$	10,951
2020	363		7,656		8,019
2021	299		5,760		6,059
2022	163		5,163		5,326
2023	79		3,681		3,760
Thereafter	177		10,511		10,688
Total minimum lease payments	$	1,979	$	42,824	$	44,803

As of December 31, 2018 Centuri leased certain construction equipment under capital leases arrangements which were not significant.

Leases

Note 4 – Leases

The Company and Southwest adopted Topic 842 as of January 1, 2019. In association with the adoption, the Company recorded adjustments to its Condensed Consolidated Balance Sheet to record right-of-use (“ROU”) assets and lease liabilities of $58.4 million and $60.8 million, respectively. Included in those amounts, Southwest recorded $1.9 million related to both its ROU assets and lease liabilities. Neither the Company nor Southwest experienced a material impact to the Condensed Consolidated Statements of Income from the adoption and no cumulative-effect adjustment to the opening balance of retained earnings was recognized. Management elected to adopt the standard under the optional transition method (refer to Recent Accounting Standards Updates in Note 1 – Background, Organization, and Summary of Significant Accounting Policies), and elected the following Topic 842 practical expedients and accounting policy elections:

• To use the “package”, which is a set of three practical expedients that must be elected as a package and applied consistently to all of Southwest’s and Centuri’s leases. These include: not reassessing whether any expired or existing contracts are or contain leases; not reassessing the lease classification for expired or existing leases (that is, existing operating and capital leases in accordance with current lease guidance will in each case be classified as operating and finance leases, respectively, under the updated guidance); and not reassessing initial direct costs for any existing leases.

• To utilize the practical expedient to exclude all easements in place prior to January 1, 2019 from treatment under Topic 842. However, Southwest will evaluate new easements entered into after the effective date of the standard to determine if the arrangements should be accounted for as leases.

• To make an accounting policy election by asset class to include both the lease and non-lease components (as defined in the guidance) as a single component.

• To make an accounting policy election to not apply Topic 842 to short-term leases, as permitted.

• To not elect to use hindsight in determining the lease term and in assessing impairment of ROU assets.

• To utilize a portfolio approach to effectively account for the operating lease ROU assets and liabilities with regard to certain equipment leases at Centuri.

Southwest and Centuri determine if an arrangement is a lease at inception. ROU assets represent the right to use an underlying asset for the lease term; lease liabilities represent obligations to make lease payments arising from the lease. Operating lease ROU assets and liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. As most of Southwest’s and Centuri’s leases do not provide an implicit interest rate, an incremental borrowing rate based on information available at commencement is used in determining the present value of lease payments; an implicit rate, if readily determinable, is used. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised.

Southwest’s leases are comprised primarily of operating leases of buildings, land, and equipment. Southwest has no finance leases and no significant short-term leases. Southwest’s leases have a remaining term of 1 to 10 years, some of which include options to extend the lease up to 3 years. Southwest is currently not a lessor in any significant lease arrangements. Southwest’s ROU assets are included in Gas plant, and its lease liabilities are included in, depending upon maturity, Other current liabilities or Other deferred credits and other long-term liabilities on the Company’s and Southwest’s Condensed Consolidated Balance Sheet as of March 31, 2019.

Centuri has operating and finance leases for corporate and field offices, construction equipment, and transportation vehicles. Centuri is currently not a lessor in any significant lease arrangements. Centuri’s leases have remaining lease terms of 1 to 14 years. Some of these include options to extend the leases, generally for optional terms of up to 5 years, and some include options to terminate the leases within 1 year. Centuri’s equipment leases may include variable payment terms in addition to the fixed lease payments if machinery is used in excess of the standard work periods. These variable payments are not probable of occurring under the current operating environment and have not been included in consideration of lease payments. Expense for short-term leases of Centuri during the quarter ended March 31, 2019 was $2.6 million, and such leases were not accounted for under the provisions of Topic 842, as permitted. Due to the seasonality of Centuri’s business, expense for short-term leases will fluctuate throughout the year with higher expense incurred during the warmer months. Centuri’s ROU assets are included in Other property and investments, and its lease liabilities for operating and finance leases are included, depending upon maturity, in Other current liabilities or Other deferred credits and other long-term liabilities on the Company’s Condensed Consolidated Balance Sheet as of March 31, 2019.

The components of lease expense were as follows:

(Thousands of dollars)	Three Months Ended
	March 31, 2019
Southwest:
Operating lease cost	$	406
Centuri:
Operating lease cost	$	2,805
Finance lease cost:
Amortization of ROU assets	$	35
Interest on lease liabilities	7
Total finance lease cost	42
Short-term lease cost	2,575
Total lease cost	$	5,828

Supplemental cash flow information related to leases for the three months ended March 31, 2019 was as follows:

(Thousands of dollars)	Southwest		Centuri		Consolidated Total
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	396	$	2,555	$	2,951
Operating cash flows from finance leases	—		7		7
Financing cash flows from finance leases	—		51		51
ROU assets obtained in exchange for lease obligations:
Operating leases	$	523	$	2,321	$	2,844
Finance leases	—		84		84

Supplemental information related to leases, including location in the Condensed Consolidated Balance Sheets, is as follows:

(Thousands of dollars)	March 31, 2019
Southwest:
Operating leases:
Net Utility Plant	$	1,977
Other current liabilities	$	745
Other deferred credits and other long-term liabilities	1,253
Total operating lease liabilities	$	1,998
Weighted average remaining lease term (in years)	4.22
Weighted average discount rate	3.39		%
Centuri:
Operating leases:
Other property and investments	$	57,267
Other current liabilities	7,178
Other deferred credits and other long-term liabilities	52,647
Total operating lease liabilities	$	59,825
Finance leases:
Other property and investments	$	639
Other current liabilities	256
Other deferred credits and other long-term liabilities	239
Total finance lease liabilities	$	495
Weighted average remaining lease term (in years)
Operating leases	9.33
Finance leases	1.63
Weighted average discount rate
Operating leases	4.08		%
Finance leases	5.84		%

The following is a schedule of maturities of lease liabilities as of March 31, 2019:

(Thousands of dollars)	Operating leases
Southwest:
2020	$	800
2021	556
2022	295
2023	124
2024	78
Thereafter	307
Total lease payments	2,160
Less imputed interest	162
Total	$	1,998

(Thousands of dollars)	Operating leases		Finance leases
Centuri:
2020	$	10,394	$	281
2021	9,327		128
2022	8,328		67
2023	7,645		38
2024	5,710		25
Thereafter	31,303		—
Total lease payments	72,707		539
Less imputed interest	12,882		44
Total	$	59,825	$	495

As the Company and Southwest adopted Topic 842 using the optional transition method referred to in Note 1 – Background, Organization, and Summary of Significant Accounting Policies, the recent annual disclosure of rental and lease payments as of December 31, 2018 in accordance with Topic 840 is presented in the table below:

	2018		2017
Southwest Gas Corporation	$	4,556	$	4,926
Centuri	59,491		62,310
Consolidated rental payments/lease expense	$	64,047	$	67,236

The following is a schedule of future minimum lease payments for operating leases (with initial or remaining terms in excess of one year) as of December 31, 2018 (thousands of dollars):

	Southwest		Centuri		Consolidated Total
2019	$	898	$	10,053	$	10,951
2020	363		7,656		8,019
2021	299		5,760		6,059
2022	163		5,163		5,326
2023	79		3,681		3,760
Thereafter	177		10,511		10,688
Total minimum lease payments	$	1,979	$	42,824	$	44,803

As of December 31, 2018 Centuri leased certain construction equipment under capital leases arrangements which were not significant.

XML

Derivatives

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

Note 5 – Derivatives

In managing its natural gas supply portfolios, Southwest has historically entered into fixed- and variable-price contracts, which qualify as derivatives. Additionally, Southwest utilizes fixed-for-floating swap contracts (“Swaps”) to supplement its fixed-price contracts. The fixed-price contracts, firm commitments to purchase a fixed amount of gas in the future at a fixed price, qualify for the normal purchases and normal sales exception that is allowed for contracts that are probable of delivery in the normal course of business, and are exempt from fair value reporting. The variable-price contracts qualify as derivative instruments; however, because the contract price is the prevailing price at the future transaction date, the contract has no determinable fair value. The Swaps’ contract prices are determined at the beginning of each month to reflect that month’s published first of month index price and are recorded at fair value. Southwest does not utilize derivative financial instruments for speculative purposes, nor does it have trading operations.

The fixed-price contracts and Swaps are utilized by Southwest under its volatility mitigation programs to effectively fix the price on a portion (up to 25% in the Arizona and California jurisdictions) of its natural gas supply portfolios. The maturities of the Swaps highly correlate to forecasted purchases of natural gas, during time frames ranging from April 30, 2019 through October 31, 2020. Under such contracts, Southwest pays the counterparty a fixed rate and receives from the counterparty a floating rate per MMBtu (“dekatherm”) of natural gas. Only the net differential is actually paid or received. The differential is calculated based on the notional amounts under the contracts, which are detailed in the table below (thousands of dekatherms):

	March 31, 2019	December 31, 2018
Contract notional amounts	14,757	13,387

The following table sets forth the gains and (losses) recognized on the Swaps (derivatives) for the three- and twelve-month periods ended March 31, 2019 and 2018 and their location in the Condensed Consolidated Statements of Income for both the Company and Southwest:

Gains (losses) recognized in income for derivatives not designated as hedging instruments:

(Thousands of dollars)
		Three Months Ended								Twelve Months Ended
	Location of Gain or (Loss) Recognized in Income on Derivatives	March 31,								March 31,
Instrument		2019				2018				2019				2018
Swaps	Net cost of gas sold	$	(3,533	)		$	(5,196	)		$	(450	)		$	(11,631	)
Swaps	Net cost of gas sold	3,533			*	5,196			*	450			*	11,631			*
Total		$	—			$	—			$	—			$	—

* Represents the impact of regulatory deferral accounting treatment under U.S. GAAP for rate-regulated entities.

No gains (losses) were recognized in net income or other comprehensive income during the periods presented for derivatives designated as cash flow hedging instruments. Previously, Southwest entered into two forward-starting interest rate swaps (“FSIRS”), both of which were designated cash flow hedges, to partially hedge the risk of interest rate variability during the period leading up to the planned issuance of debt. The first FSIRS terminated in December 2010. The second FSIRS terminated in March 2012. Losses on both FSIRS are being amortized over ten-year periods from Accumulated other comprehensive income (loss) into interest expense.

The following table sets forth the fair values of the Swaps and their location in the Condensed Consolidated Balance Sheets for both the Company and Southwest (thousands of dollars):

Fair values of derivatives not designated as hedging instruments:

March 31, 2019		Asset		Liability
Instrument	Balance Sheet Location	Derivatives		Derivatives			Net Total
Swaps	Other current liabilities	$	805	$	(4,472	)	$	(3,667	)
Swaps	Other deferred credits	60		(809		)	(749		)
Total		$	865	$	(5,281	)	$	(4,416	)
December 31, 2018		Asset		Liability
Instrument	Balance Sheet Location	Derivatives		Derivatives			Net Total
Swaps	Prepaid and other current assets	$	243	$	(99	)	$	144
Swaps	Other current liabilities	1,595		(3,347		)	(1,752		)
Swaps	Other deferred credits	141		(251		)	(110		)
Total		$	1,979	$	(3,697	)	$	(1,718	)

The estimated fair values of the natural gas derivatives were determined using future natural gas index prices (as more fully described below). Master netting arrangements exist with each counterparty that provide for the net settlement (in the settlement month) of all contracts through a single payment. As applicable, management has elected to reflect the net amounts in its balance sheets. There was no outstanding collateral associated with the Swaps during either period shown in the above table.

Pursuant to regulatory deferral accounting treatment for rate-regulated entities, unrealized gains and losses in fair value of the Swaps are recorded as a regulatory asset and/or liability. When the Swaps mature, any prior positions held are reversed and the settled position is recorded as an increase or decrease of purchased gas under the related purchase gas adjustment (“PGA”) mechanism in determining the deferred PGA balances. Neither changes in fair value nor settled amounts of Swaps have a direct effect on earnings or other comprehensive income.

The following table shows the amounts Southwest paid to and received from counterparties for settlements of matured Swaps.

	Three Months Ended		Twelve Months Ended
(Thousands of dollars)	March 31, 2019		March 31, 2019
Paid to counterparties	$	1,882	$	5,948
Received from counterparties	$	1,047	$	1,653

The following table details the regulatory assets/(liabilities) offsetting the derivatives at fair value in the Condensed Consolidated Balance Sheets for both the Company and Southwest (thousands of dollars).

March 31, 2019
Instrument	Balance Sheet Location	Net Total
Swaps	Prepaid and other current assets	$	3,667
Swaps	Deferred charges and other assets	749
December 31, 2018
Instrument	Balance Sheet Location	Net Total
Swaps	Other current liabilities	$	(144	)
Swaps	Prepaid and other current assets	1,752
Swaps	Deferred charges and other assets	110

The estimated fair values of Southwest’s Swaps were determined at March 31, 2019 and December 31, 2018 using futures settlement prices for the delivery of natural gas at Henry Hub adjusted by the price of future settlement bases, which reflect the difference between the price of natural gas at a given delivery basin and the Henry Hub pricing points. These Level 2 inputs are observable in the marketplace throughout the full term of the Swaps, but have been credit-risk adjusted with no significant impact to the overall fair value measurement.

The following table sets forth, by level within the three-level fair value hierarchy that ranks the inputs used to measure fair value by their reliability, the financial assets and liabilities that were accounted for at fair value by both the Company and Southwest:

Level 2 - Significant other observable inputs

(Thousands of dollars)	March 31, 2019			December 31, 2018
Assets at fair value:
Prepaid and other current assets - Swaps	$	—		$	144
Liabilities at fair value:
Other current liabilities - Swaps	(3,667		)	(1,752		)
Other deferred credits - Swaps	(749		)	(110		)
Net Assets (Liabilities)	$	(4,416	)	$	(1,718	)

No financial assets or liabilities associated with the Swaps, which were accounted for at fair value, fell within Level 1 or Level 3 of the fair value hierarchy.

XML

Common Stock

3 Months Ended

Mar. 31, 2019

Equity [Abstract]

Common Stock

Note 6 – Common Stock

On March 29, 2017, the Company filed with the SEC an automatic shelf registration statement on Form S-3 (File No. 333-217018), which became effective upon filing, for the offer and sale of up to $150 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 March 29, 2017, between the Company and BNY Mellon Capital Markets, LLC (the “Equity Shelf Program”). The following table provides activity in the Equity Shelf Program for the three and twelve months ended March 31, 2019:

	Three Months Ended						Twelve Months Ended
	March 31,						March 31,
	2019			2018			2019			2018
Gross proceeds	$	23,073,149		$	9,199,661		$	99,023,464		$	50,976,456
Less: agent commissions	(230,731		)	(91,997		)	(990,234		)	(509,765		)
Net proceeds	$	22,842,418		$	9,107,664		$	98,033,230		$	50,466,691
Number of shares sold	277,829			137,300			1,286,234			643,007
Weighted average price per share	$	83.05		$	67.00		$	76.99		$	79.28

During the quarter ended March 31, 2019, the Company sold all of the remaining common stock available for sale under the program. Net proceeds from the sales of shares of common stock under the Equity Shelf Program are intended for general corporate purposes, including the acquisition of property for the construction, completion, extension or improvement of pipeline systems and facilities located in and around the communities served by Southwest. Net proceeds during the three months ended March 31, 2019 were contributed to, and reflected in the records of, Southwest (as a capital contribution from Southwest Gas Holdings, Inc.).

During the three months ended March 31, 2019, the Company issued approximately 53,000 shares of common stock through the Restricted Stock/Unit Plan and Management Incentive Plan.

Also during the three months ended March 31, 2019, the Company issued 34,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan (“DRSPP”), raising approximately $2.8 million.

On May 2, 2019, at the Company’s annual meeting of shareholders, the Company’s shareholders approved an amendment to the Company’s Articles of Incorporation to increase the number of shares of common stock available for issuance from 60,000,000 to 120,000,000.

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Long-Term Debt

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Long-Term Debt

Note 7 – Long-Term Debt

Carrying amounts of long-term debt and related estimated fair values as of March 31, 2019 and December 31, 2018 are disclosed in the following table. Southwest’s revolving credit facility (including commercial paper) and the variable-rate Industrial Development Revenue Bonds (“IDRBs”) approximate their carrying values, as they are repaid quickly (in the case of credit facility borrowings) and have interest rates that reset frequently. These are categorized as Level 1 due to Southwest’s ability to access similar debt arrangements at measurement dates with comparable terms, including variable/market rates. The fair values of Southwest’s debentures, senior notes, and fixed-rate IDRBs were determined utilizing a market-based valuation approach, where fair values are determined based on evaluated pricing data, such as broker quotes and yields for similar securities adjusted for observable differences. Significant inputs used in the valuation generally include benchmark yield curves, credit ratings and issuer spreads. The external credit rating, coupon rate, and maturity of each security are considered in the valuation, as applicable. The fair values of debentures and fixed-rate IDRBs are categorized as Level 2 (observable market inputs based on market prices of similar securities). The Centuri secured revolving credit and term loan facility and Centuri other debt obligations (not actively traded) are categorized as Level 3, based on significant unobservable inputs to their fair values. Because Centuri’s debt is not publicly traded, fair values for the secured revolving credit and term loan facility and other debt obligations were based on a conventional discounted cash flow methodology and utilized current market pricing yield curves, across Centuri’s debt maturity spectrum, of other industrial bonds with an assumed credit rating comparable to the Company’s.

	March 31, 2019					December 31, 2018
	Carrying Amount			Market Value		Carrying Amount			Market Value
(Thousands of dollars)
Southwest Gas Corporation:
Debentures:
Notes, 4.45%, due 2020	$	125,000		$	126,990	$	125,000		$	126,213
Notes, 6.1%, due 2041	125,000			154,294		125,000			150,728
Notes, 3.875%, due 2022	250,000			255,015		250,000			254,195
Notes, 4.875%, due 2043	250,000			277,683		250,000			268,985
Notes, 3.8%, due 2046	300,000			283,635		300,000			267,030
Notes, 3.7%, due 2028	300,000			306,465		300,000			298,926
8% Series, due 2026	75,000			95,128		75,000			93,827
Medium-term notes, 7.78% series, due 2022	25,000			27,715		25,000			27,497
Medium-term notes, 7.92% series, due 2027	25,000			30,824		25,000			30,016
Medium-term notes, 6.76% series, due 2027	7,500			8,845		7,500			8,651
Unamortized discount and debt issuance costs	(11,641		)			(11,807		)
	1,470,859					1,470,693
Revolving credit facility and commercial paper	150,000			150,000		150,000			150,000
Industrial development revenue bonds:
Variable-rate bonds:
Tax-exempt Series A, due 2028	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	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	(1,900		)			(2,024		)
	198,100					197,976
Less: current maturities	—					—
Long-term debt, less current maturities - Southwest Gas Corporation	$	1,818,959				$	1,818,669
Centuri:
Centuri term loan facility	$	254,534		$	257,579	$	255,959		$	260,135
Unamortized debt issuance costs	(1,343		)			(1,414		)
	253,191					254,545
Centuri secured revolving credit facility	6,361			6,363		—			—
Centuri other debt obligations	62,678			63,365		67,104			67,053
Less: current maturities	(34,915		)			(33,060		)
Long-term debt, less current maturities - Centuri	$	287,315				$	288,589
Consolidated Southwest Gas Holdings, Inc.:
Southwest Gas Corporation long-term debt	$	1,818,959				$	1,818,669
Centuri long-term debt	322,230					321,649
Less: current maturities	(34,915		)			(33,060		)
Long-term debt, less current maturities - Southwest Gas Holdings, Inc.	$	2,106,274				$	2,107,258

Southwest has a $400 million credit facility that is scheduled to expire in March 2022. Southwest designates $150 million of capacity related to the facility as long-term debt and has designated the remaining $250 million for working capital purposes. Interest rates for the credit facility are calculated at either the London Interbank Offered Rate (“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, 2019, the applicable margin is 1% for loans bearing interest with reference to LIBOR and 0% for loans bearing interest with reference to the alternative base rate. At March 31, 2019, $150 million was outstanding on the long-term portion (including the commercial paper program, discussed below) and $188 million was outstanding on the short-term portion of this credit facility (see Note 8 – Short-Term Debt).

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 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, 2019, as noted above, $50 million was outstanding under the commercial paper program.

In November 2018, Centuri, in association with the acquisition of Linetec, amended and restated its senior secured revolving credit and term loan facility, increasing the capacity from $450 million to $590 million; the amended facility is scheduled to expire in November 2023. This facility includes a revolving credit facility and a term loan facility. The line of credit portion of the facility is $325 million; amounts borrowed and repaid under the revolving credit facility are available to be re-borrowed. The term loan facility portion has a limit of approximately $265 million. The $590 million revolving credit and term loan facility is secured by substantially all of Centuri’s assets except those explicitly excluded under the terms of the agreement (including owned real estate and certain certificated vehicles). Centuri assets securing the facility at March 31, 2019 totaled $1.1 billion. At March 31, 2019, $261 million in borrowings were outstanding under the Centuri facility.

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Short-Term Debt

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Short-Term Debt

Note 8 – Short-Term Debt

The Company has a $100 million credit facility that is scheduled to expire in March 2022. The Company had no short-term borrowings outstanding at March 31, 2019 under this facility.

As discussed in Note 7 – Long-Term Debt, Southwest has a $400 million credit facility that is scheduled to expire in March 2022, of which $250 million has been designated by management for working capital purposes. Southwest had $188 million in short-term borrowings outstanding at March 31, 2019 under this facility.

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Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income

3 Months Ended

Mar. 31, 2019

Equity [Abstract]

Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income

Note 9 – Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income

The tables below provide details of activity in equity, the noncontrolling interest, and the redeemable noncontrolling interest for the Company on a consolidated basis for the three-month periods ended March 31, 2019 and March 31, 2018.

	Southwest Gas Holdings, Inc. Equity
(In thousands, except per share amounts)	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Non-controlling Interest						Redeemable Noncontrolling Interest (Temporary Equity)
	Shares	Amount													Total
December 31, 2018	53,026	$	54,656	$	1,305,769	$	(52,668	)	$	944,285		$	(452	)	$	2,251,590		$	81,831
Common stock issuances	365	365		27,024											27,389
Net income (loss)									94,809						94,809			575
Foreign currency exchange translation adjustment						791									791
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax						619									619
FSIRS amounts reclassified to net income, net of tax						635									635
Dividends declared
Common: $0.545 per share									(29,285		)				(29,285		)
March 31, 2019	53,391	$	55,021	$	1,332,793	$	(50,623	)	$	1,009,809		$	(452	)	$	2,346,548		$	82,406

	Southwest Gas Holdings, Inc. Equity
	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Non-controlling Interest
(In thousands, except per share amounts)	Shares	Amount													Total
December 31, 2017	48,090	$	49,720	$	955,332	$	(47,682	)	$	857,398		$	(2,365	)	$	1,812,403
Common stock issuances	247	247		10,148											10,395
Net income (loss)									79,091			(797		)	78,294
Foreign currency exchange translation adjustment						(911		)							(911		)
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax						895									895
FSIRS amounts reclassified to net income, net of tax						635									635
Reclassification of excess deferred taxes (a)						(9,300		)	9,300						—
Dividends declared
Common: $0.52 per share									(25,335		)				(25,335		)
March 31, 2018	48,337	$	49,967	$	965,480	$	(56,363	)	$	920,454		$	(3,162	)	$	1,876,376

(a) Reclassification for the release of excess deferred taxes as a result of the adoption of ASU No. 2018-02 “Income Statement—Reporting Comprehensive Income—Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income,” which permitted release of excess amounts created following the December 2017 enactment of U.S. tax reform.

The tables below provide details of activity in equity for Southwest during the three-month periods ended March 31, 2019 and March 31, 2018. Only equity shares of the Company are publicly traded, under the ticker symbol “SWX.”

	Southwest Gas Corporation Equity
	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings
(In thousands)	Shares	Amount										Total
December 31, 2018	47,482	$	49,112	$	1,065,242	$	(49,049	)	$	717,155		$	1,782,460
Net income									103,389			103,389
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax						619						619
FSIRS amounts reclassified to net income, net of tax						635						635
Stock-based compensation (a)				918					(160		)	758
Dividends declared to Southwest Gas Holdings, Inc.									(22,800		)	(22,800		)
Contributions from Southwest Gas Holdings, Inc.				22,842								22,842
March 31, 2019	47,482	$	49,112	$	1,089,002	$	(47,795	)	$	797,584		$	1,887,903

	Southwest Gas Corporation Equity
	Common Stock			Additional Paid-in Capital			Accumulated Other Comprehensive Income (Loss)			Retained Earnings
(In thousands)	Shares	Amount											Total
December 31, 2017	47,482	$	49,112	$	948,767		$	(47,073	)	$	659,193		$	1,609,999
Net income										90,349			90,349
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax							895						895
FSIRS amounts reclassified to net income, net of tax							635						635
Reclassification of excess deferred taxes (b)							(9,300		)	9,300			—
Stock-based compensation (a)				(568		)				(166		)	(734		)
Dividends declared to Southwest Gas Holdings, Inc.										(22,000		)	(22,000		)
March 31, 2018	47,482	$	49,112	$	948,199		$	(54,843	)	$	736,676		$	1,679,144

(a) Stock-based compensation is based on stock awards of Southwest Gas Corporation to be issued in shares of Southwest Gas Holdings, Inc.

(b) Reclassification for the release of excess deferred taxes as a result of the adoption of ASU No. 2018-02, which permitted release of excess amounts created following the December 2017 enactment of U.S. tax reform.

The following information provides insight into amounts impacting 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 in the Condensed Consolidated Balance Sheets and the associated column in the equity tables above. See Note 5 – Derivatives for additional information on the FSIRS.

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

(Thousands of dollars)

	Three Months Ended									Three Months Ended
	March 31, 2019									March 31, 2018
	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:
Amortization of prior service cost	$	317		$	(76	)	$	241		$	334		$	(80	)	$	254
Amortization of net actuarial (gain)/loss	5,844			(1,403		)	4,441			8,404			(2,017		)	6,387
Regulatory adjustment	(5,347		)	1,284			(4,063		)	(7,560		)	1,814			(5,746		)
Pension plans other comprehensive income	814			(195		)	619			1,178			(283		)	895
FSIRS (designated hedging activities):
Amounts reclassified into net income	836			(201		)	635			837			(202		)	635
FSIRS other comprehensive income	836			(201		)	635			837			(202		)	635
Total other comprehensive income - Southwest Gas Corporation	1,650			(396		)	1,254			2,015			(485		)	1,530
Foreign currency translation adjustments:
Translation adjustments	791			—			791			(911		)	—			(911		)
Foreign currency other comprehensive income (loss)	791			—			791			(911		)	—			(911		)
Total other comprehensive income - Southwest Gas Holdings, Inc.	$	2,441		$	(396	)	$	2,045		$	1,104		$	(485	)	$	619

	Twelve Months Ended									Twelve Months Ended
	March 31, 2019									March 31, 2018
	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)	$	(20,426	)	$	4,902		$	(15,524	)	$	(43,027	)	$	10,326		$	(32,701	)
Amortization of prior service cost	1,318			(316		)	1,002			1,335			(460		)	875
Amortization of net actuarial (gain)/loss	31,057			(7,454		)	23,603			27,488			(9,269		)	18,219
Regulatory adjustment	(6,020		)	1,446			(4,574		)	10,515			(115		)	10,400
Pension plans other comprehensive income (loss)	5,929			(1,422		)	4,507			(3,689		)	482			(3,207		)
FSIRS (designated hedging activities):
Amounts reclassified into net income	3,344			(803		)	2,541			3,345			(1,155		)	2,190
FSIRS other comprehensive income	3,344			(803		)	2,541			3,345			(1,155		)	2,190
Total other comprehensive income (loss) - Southwest Gas Corporation	9,273			(2,225		)	7,048			(344		)	(673		)	(1,017		)
Foreign currency translation adjustments:
Translation adjustments	(1,308		)	—			(1,308		)	640			—			640
Foreign currency other comprehensive income (loss)	(1,308		)	—			(1,308		)	640			—			640
Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	7,965		$	(2,225	)	$	5,740		$	296		$	(673	)	$	(377	)

(1) Tax amounts are calculated using a 24% rate following the December 22, 2017 enactment date of U.S. tax reform. For periods prior to the enactment date (and included in specific line items of the tables for the twelve months ended March 31, 2018), tax amounts were calculated using a 38% rate. The tax effect of before-tax amounts remaining in the balance of Accumulated other comprehensive income (loss) as of March 31, 2019 is effectively computed using a 24% tax rate overall. With regard to foreign currency translation adjustments, the Company has elected to indefinitely reinvest the earnings of Centuri’s Canadian subsidiaries in Canada, thus preventing deferred taxes on such earnings. As a result of this assertion, the Company is not recognizing any tax effect or presenting a tax expense or benefit for the currency translation adjustment amount reported in Other comprehensive income (loss), as repatriation of earnings is not anticipated.

Approximately $2.5 million of realized losses (net of tax) related to the FSIRS, reported in Accumulated other comprehensive income (loss) at March 31, 2019, will be reclassified into interest expense within the next 12 months as the related interest payments on long-term debt occur.

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

AOCI - Rollforward    

(Thousands of dollars)

	Defined Benefit Plans									FSIRS									Foreign Currency Items
	Before-Tax			Tax (Expense) Benefit (4,5)			After-Tax (5)			Before-Tax			Tax (Expense) Benefit (4,5)			After-Tax (5)			Before-Tax			Tax (Expense) Benefit		After-Tax			AOCI
Beginning Balance AOCI December 31, 2018	$	(55,227	)	$	13,254		$	(41,973	)	$	(9,310	)	$	2,234		$	(7,076	)	$	(3,619	)	$	—	$	(3,619	)	$	(52,668	)
Translation adjustments	—			—			—			—			—			—			791			—		791			791
Other comprehensive income (loss) before reclassifications	—			—			—			—			—			—			791			—		791			791
FSIRS amounts reclassified from AOCI (1)	—			—			—			836			(201		)	635			—			—		—			635
Amortization of prior service cost (2)	317			(76		)	241			—			—			—			—			—		—			241
Amortization of net actuarial loss (2)	5,844			(1,403		)	4,441			—			—			—			—			—		—			4,441
Regulatory adjustment (3)	(5,347		)	1,284			(4,063		)	—			—			—			—			—		—			(4,063		)
Net current period other comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.	814			(195		)	619			836			(201		)	635			791			—		791			2,045
Ending Balance AOCI March 31, 2019	$	(54,413	)	$	13,059		$	(41,354	)	$	(8,474	)	$	2,033		$	(6,441	)	$	(2,828	)	$	—	$	(2,828	)	$	(50,623	)

(1) The FSIRS reclassification amounts are 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.

(5) The beginning balances depict amounts attributable to the individual components of AOCI (Defined Benefit Plans and FSIRS) following the adoption of ASU No. 2018-02, with no impact to the total balance of AOCI resulting from the depiction.

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

AOCI - Rollforward

(Thousands of dollars)

	Defined Benefit Plans									FSIRS
	Before-Tax			Tax (Expense) Benefit (9,10)			After-Tax (10)			Before-Tax			Tax (Expense) Benefit (9,10)			After-Tax (10)			AOCI
Beginning Balance AOCI December 31, 2018	$	(55,227	)	$	13,254		$	(41,973	)	$	(9,310	)	$	2,234		$	(7,076	)	$	(49,049	)
FSIRS amounts reclassified from AOCI (6)	—			—			—			836			(201		)	635			635
Amortization of prior service cost (7)	317			(76		)	241			—			—			—			241
Amortization of net actuarial loss (7)	5,844			(1,403		)	4,441			—			—			—			4,441
Regulatory adjustment (8)	(5,347		)	1,284			(4,063		)	—			—			—			(4,063		)
Net current period other comprehensive income attributable to Southwest Gas Corporation	814			(195		)	619			836			(201		)	635			1,254
Ending Balance AOCI March 31, 2019	$	(54,413	)	$	13,059		$	(41,354	)	$	(8,474	)	$	2,033		$	(6,441	)	$	(47,795	)

(6) The FSIRS reclassification amounts are included in Net interest deductions on Southwest’s Condensed Consolidated Statements of Income.

(7) 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).

(8) The regulatory adjustment represents the portion of the activity above that is expected to be recovered through rates in the future (the related regulatory asset is included in Deferred charges and other assets on Southwest’s Condensed Consolidated Balance Sheets).

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

(10) The beginning balances depict amounts attributable to the individual components of AOCI (Defined Benefit Plans and FSIRS) following the adoption of ASU No. 2018-02, with no impact to the total balance of AOCI resulting from the depiction.

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:

Amounts Recognized in AOCI (Before Tax)

(Thousands of dollars)

	March 31, 2019			December 31, 2018
Net actuarial (loss) gain	$	(429,520	)	$	(435,364	)
Prior service cost	(2,716		)	(3,033		)
Less: amount recognized in regulatory assets	377,823			383,170
Recognized in AOCI	$	(54,413	)	$	(55,227	)

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Segment Information

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

Segment Information

Note 10 – Segment Information

The Company has two reportable segments: natural gas operations and utility infrastructure services. Southwest has a single reportable segment that is referred to herein as the natural gas operations segment of the Company. In order to reconcile to net income as disclosed in the Condensed Consolidated Statements of Income, an Other column is included associated with impacts related to corporate and administrative activities related to Southwest Gas Holdings, Inc. The following tables present revenues from external customers, intersegment revenues, and segment net income for the two reportable segments (thousands of dollars):

	Natural Gas Operations		Utility Infrastructure Services			Other			Total
Three Months Ended March 31, 2019
Revenues from external customers	$	520,677	$	274,189		$	—		$	794,866
Intersegment revenues	—		38,673			—			38,673
Total	$	520,677	$	312,862		$	—		$	833,539
Segment net income (loss)	$	103,389	$	(8,031	)	$	(549	)	$	94,809
Three Months Ended March 31, 2018
Revenues from external customers	$	494,313	$	232,859		$	—		$	727,172
Intersegment revenues	—		27,158			—			27,158
Total	$	494,313	$	260,017		$	—		$	754,330
Segment net income (loss)	$	90,349	$	(11,001	)	$	(257	)	$	79,091
	Natural Gas Operations		Utility Infrastructure Services			Other			Total
Twelve Months Ended March 31, 2019
Revenues from external customers	$	1,384,092	$	1,427,701		$	—		$	2,811,793
Intersegment revenues	—		147,429			—			147,429
Total	$	1,384,092	$	1,575,130		$	—		$	2,959,222
Segment net income (loss)	$	151,882	$	47,947		$	(1,834	)	$	197,995
Twelve Months Ended March 31, 2018
Revenues from external customers	$	1,334,019	$	1,211,345		$	—		$	2,545,364
Intersegment revenues	—		103,021			—			103,021
Total	$	1,334,019	$	1,314,366		$	—		$	2,648,385
Segment net income (loss)	$	170,229	$	34,693		$	(1,298	)	$	203,624

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Redeemable Noncontrolling Interests

3 Months Ended

Mar. 31, 2019

Noncontrolling Interest [Abstract]

Redeemable Noncontrolling Interests

Note 11 – Redeemable Noncontrolling Interest

In connection with the acquisition of Linetec in November 2018, the previous owner retained a 20% equity interest in Linetec, the reduction of which is subject to certain rights based on the passage of time or upon the occurrence of certain triggering events. Effective January 2022, the Company has the right, but not the obligation, to purchase at fair value (subject to a floor) a portion of the interest held by the noncontrolling party, and in incremental amounts each year thereafter. The shares subject to the election accumulate (if earlier elections are not made) such that 100% of the interest retained by the noncontrolling party is subject to the election beginning in 2024. If the Company does not exercise its rights at each or any of the specified intervals, the noncontrolling party has the ability, but not the obligation, to exit their investment retained by requiring Centuri to purchase a similar portion of their interest up to the maximum cumulative amounts specified at each interval discussed above. The Company has determined that this noncontrolling interest is a redeemable noncontrolling interest and, in accordance with SEC guidance, is classified as mezzanine equity (temporary equity) in the Company’s Condensed Consolidated Balance Sheets.

Significant changes in the value of the redeemable noncontrolling interest, above a floor established at the acquisition date, are recognized as they occur, and the carrying value is adjusted as necessary at each reporting date. The fair value is estimated using a market approach that utilizes certain financial metrics from guideline public companies of similar industry and operating characteristics. However, the carrying value of the redeemable noncontrolling interest was greater than its fair value as of March 31, 2019, and no previous upward redemption value adjustments were made following the acquisition date. SEC guidance indicates that a redemption value adjustment would not be made under these circumstances. The following depicts changes to the balance of the redeemable noncontrolling interest between the indicated periods.

	Redeemable Noncontrolling Interest
(Thousands of dollars):
Balance, December 31, 2018	$	81,831
Net income attributable to redeemable noncontrolling interest	575
Balance, March 31, 2019	$	82,406

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Business Acquisitions

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

Business Acquisitions

Note 12 – Business Acquisitions

In November 2018, the Company, through its subsidiaries, led principally by Centuri, completed the acquisition of an 80% interest in a privately held infrastructure services business, Linetec Services, LLC (“Linetec”) with the remaining 20% retained by the seller. See the Company’s 2018 Form 10-K for additional information about this acquisition.

Assets acquired and liabilities assumed in the transaction were recorded, generally, 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 customer relationships, trade names, and customer contracts. Certain payments were estimated as of the acquisition date and will be adjusted when paid; the final purchase accounting has not yet been completed. Further refinement is expected to occur, including potential changes to income taxes and intangibles, as well as additional consideration payments held back.

The preliminary estimated fair values of assets acquired and liabilities assumed as of November 30, 2018, are as follows (millions of dollars):

	Acquisition Date		Measurement Period Adjustments			Revised Acquisition Date
Cash and cash equivalents	$	3.9	$	—		$	3.9
Accounts receivable	32.8		(0.5		)	32.3
Revenue earned on contracts in progress in excess of billings	21.6		1.7			23.3
Prepaid expenses and other current assets	1.1		0.2			1.3
Property and equipment	89.4		(0.5		)	88.9
Intangible assets	89.3		—			89.3
Goodwill	188.5		3.3			191.8
Total assets acquired	426.6		4.2			430.8
Accounts payable	8.0		—			8.0
Accrued liabilities	6.9		1.6			8.5
Deferred compensation and related accrued taxes	3.4		—			3.4
Redeemable noncontrolling interest	81.7		—			81.7
Total liabilities assumed and noncontrolling interest	100.0		1.6			101.6
Net assets acquired	$	326.6	$	2.6		$	329.2

The Company incurred and expensed acquisition costs of $6.9 million for the twelve months ended March 31, 2019 which are included in Utility infrastructure services expenses on the Company’s Condensed Consolidated Statement of Income. No acquisition-related costs were incurred during the three months ended March 31, 2019.

The preliminary allocation of the purchase price of Linetec 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 Linetec was deemed an asset purchase for tax purposes, the tax-basis goodwill is expected to be deductible for tax purposes. In the first quarter of 2019, values at the acquisition date were adjusted as reflected in the table above on the Company’s Condensed Consolidated Balance Sheets.

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Background, Organization, and Summary of Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Nature of Operations

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). At the annual meeting of shareholders of Southwest Gas Holdings, Inc., held on May 2, 2019, shareholders voted to approve changing the state of incorporation for Southwest Gas Holdings, Inc. from California to Delaware. The reincorporation is expected to be effective during the second or third quarter of 2019. However, the reincorporation remains subject to certain regulatory approvals, which are currently pending.

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 from installation, replacement, repair, and maintenance of energy distribution systems, and developing industrial construction solutions. Centuri operations are generally conducted under the business names of NPL Construction Co. (“NPL”), NPL Canada Ltd. (“NPL Canada”), New England Utility Constructors, Inc. (“Neuco”) and Linetec Services, LLC (“Linetec”). Utility infrastructure services activity is seasonal in 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. In November 2017, Centuri acquired Neuco, thereby expanding its core services in the northeast region of the U.S. Additionally, in November 2018, Centuri expanded its operations in the southeast region of the U.S. through the acquisition of an 80% interest in Linetec. See Note 12 – Business Acquisitions for more information.

Basis of Presentation

Basis of Presentation. The condensed consolidated financial statements for 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, or in the primary businesses comprising those segments as a result of the foregoing acquisitions of Neuco and Linetec.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 at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. In the opinion of management, all adjustments, consisting of normal recurring items and estimates necessary for a fair statement of results for the interim periods, have been made. It is suggested that these condensed consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the 2018 Annual Report to Shareholders, which is incorporated by reference into the 2018 Form 10-K.

Fair Value Measurements

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.

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

Cash and Cash Equivalents

Cash and Cash Equivalents. For purposes of reporting consolidated cash flows, cash and cash equivalents include cash on hand and financial instruments with maturities of three months or less. Such investments are carried at cost, which approximates market value. Cash and cash equivalents for Southwest and the Company also include money market fund investments totaling approximately $41 million and $54.4 million, respectively, at March 31, 2019, and $18 million and $59.9 million, respectively, at December 31, 2018, which fall within Level 2 of the fair value hierarchy, due to the asset valuation methods used by money market funds.Typical non-cash investing activities for Southwest include customer advances applied as contributions toward utility construction activity and capital expenditures that were not paid as of quarter end that are included in accounts payable. Amounts related to such activities were immaterial for the periods presented herein. Non-cash investing activities for the three months and twelve months ended March 31, 2019 included $73.5 million of purchase consideration related to the Linetec acquisition by Centuri, in the form of liabilities incurred that remained unpaid as of March 31, 2019; such amounts are included in Other current liabilities on the Condensed Consolidated Balance Sheets of the Company.

Income Taxes

Income Taxes. In 2017, the Tax Cuts and Jobs Act (the “TCJA”) was enacted. The TCJA had significant impacts on the taxation of business entities, including specific provisions related to regulated public utilities. The more significant changes that impacted the Company and Southwest include the reduction in the corporate federal income tax rate from 35% to 21%, and limiting the utilization of net operating losses (“NOLs”) to 80% of taxable income, with the ability to indefinitely carryforward unutilized NOLs to reduce future taxable income.

Goodwill

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 consistent between periods presented below, and that no change was necessary with regard to the level at which goodwill is assessed for impairment.

Recent Accounting Standards Updates

Recent Accounting Standards Updates.

Accounting pronouncements adopted in 2019:

In February 2016, the FASB issued the update “Leases (Topic 842).” Under the update, lessees were required to recognize a lease liability for the obligation to make lease payments, measured on a discounted basis; and a right-of-use asset for the right to use, or control the use of, a specified asset for the lease term. The Company and Southwest adopted Topic 842 in the first quarter of 2019 through an optional transition method, which was elected, permitting the application of the provisions of the standard at the adoption date, rather than to earlier comparative periods. As a result, the Company and Southwest have not recast prior periods to reflect the adoption of this standard. See Note 4 – Leases.

Accounting pronouncements that will be effective after 2019:

In June 2016, the FASB issued ASU 2016-13 update “Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The update requires the measurement of all expected credit losses for financial assets held at the reporting date based on historical experience, current conditions, and reasonable and supportable forecasts. The inputs currently used to estimate credit losses will still be used; however, they may be adapted to reflect the full amount of expected losses. The update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. All entities may adopt the amendments in this update earlier as of fiscal years beginning after December 15, 2018, including interim

periods within those fiscal years. Management is evaluating what impact, if any, this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures.

In January 2017, the FASB issued ASU 2017-04 “Intangibles – Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” Currently, unless meeting the criteria for qualitative assessment only, an entity is required to perform a two-step test to determine the amount, if any, of goodwill impairment. In Step 1, an entity compares the fair value of a reporting unit with its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, the entity performs Step 2 and compares the implied fair value of goodwill with the carrying amount of that goodwill for that reporting unit, requiring a hypothetical purchase price allocation to measure the amount of a goodwill impairment. An impairment charge equal to the amount by which the carrying amount of goodwill for the reporting unit exceeds the implied fair value of that goodwill is recorded, limited to the amount of goodwill allocated to that reporting unit. Under the update, an entity will apply a one-step quantitative test and record the amount of goodwill impairment as the excess of a reporting unit's carrying amount over its fair value, not to exceed the total amount of goodwill allocated to the reporting unit. The new guidance does not amend the optional qualitative assessment. The amount of any goodwill impairment calculated under the update could vary from the calculation under existing guidance, largely due to the consideration to be given to unrecognized differences between the fair value and carrying values of the other assets and liabilities in the reporting unit under the new guidance. The amendments should be applied on a prospective basis. The update is effective for fiscal and interim periods beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. Management is evaluating the impacts this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures.

In August 2018, the FASB issued ASU 2018-15 “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract.” The update generally aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement (that is a service contract) with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. The update also requires the entity to expense the capitalized implementation costs of such hosting arrangements over the term of the hosting arrangement, including reasonably certain renewal periods. The update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption of the amendments in this update is permitted for interim and related annual fiscal periods after December 15, 2018. Management is evaluating the impacts this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures.

In August 2018, the FASB issued ASU 2018-14 “Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans.” This update removes disclosures that are no longer considered cost-beneficial, clarifies the specific requirements of disclosures, and adds disclosure requirements identified as relevant. The update applies to all employers that sponsor defined benefit pension or other postretirement plans. The update is effective for fiscal years ending after December 15, 2020. Upon adoption, the Company and Southwest will modify their disclosures to conform to the requirements of the update.

In August 2018, the FASB issued ASU 2018-13 “Fair Value Measurement: Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement.” The update is intended to improve the effectiveness of fair value measurement disclosures and removes the following disclosure requirements: the amount of and reasons for transfers between Level 1 and Level 2 of the fair value hierarchy; the policy for timing of transfers between levels; and the valuation processes for Level 3 fair value measurements. The update also modifies or clarifies for investments in certain entities that calculate net asset value, a requirement to disclose the timing of liquidation of an investee’s assets and the date when restrictions from redemption might lapse (in cases when the timing has been communicated or announced publicly). It also clarifies communication requirements about measurement uncertainty as of the reporting date. For certain unobservable inputs, an entity may disclose other quantitative information in lieu of the weighted average if it would be a more reasonable and rational method to reflect the distribution of inputs to the measurements. The update is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. Management is evaluating the impacts this update might have on its disclosures.

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Background, Organization, and Summary of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Other Property and Investments

Other Property and Investments. Other property and investments on the Condensed Consolidated Balance Sheets includes (thousands of dollars):

	March 31, 2019			December 31, 2018
Southwest Gas Corporation:
Net cash surrender value of COLI policies	$	122,048		$	114,405
Other property	1,735			1,741
Total Southwest Gas Corporation	123,783			116,146
Centuri property, equipment, and intangibles	894,739			792,191
Centuri accumulated depreciation/amortization	(316,832		)	(298,939		)
Other property	15,032			14,153
Total Southwest Gas Holdings, Inc.	$	716,722		$	623,551

Accounts Receivable for Services

Centuri’s accounts receivable for these services are presented in the table below (thousands of dollars):

	March 31, 2019		December 31, 2018
Centuri accounts receivable for services provided to Southwest	$	16,837	$	18,830

Schedule of Goodwill

(Thousands of dollars)	Natural Gas Operations		Utility Infrastructure Services		Total Company
December 31, 2018	$	10,095	$	348,950	$	359,045
Measurement Period Adjustment - Linetec acquisition	—		3,303		3,303
Foreign currency translation adjustment	—		2,134		2,134
March 31, 2019	$	10,095	$	354,387	$	364,482

Other Income (Deductions)

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

	Three Months Ended						Twelve Months Ended
	March 31,						March 31,
	2019			2018			2019			2018
Southwest Gas Corporation - natural gas operations segment:
Change in COLI policies	$	7,600		$	(700	)	$	5,100		$	6,800
Interest income	1,597			1,418			6,199			3,638
Equity AFUDC	960			229			4,358			2,049
Other components of net periodic benefit cost	(3,765		)	(5,265		)	(19,560		)	(19,834		)
Miscellaneous income and (expense)	(446		)	(285		)	(2,788		)	(2,400		)
Southwest Gas Corporation - total other income (deductions)	5,946			(4,603		)	(6,691		)	(9,747		)
Utility infrastructure services segment:
Interest income	—			1			87			4
Foreign transaction gain (loss)	531			147			162			(606		)
Miscellaneous income and (expense)	344			115			125			956
Centuri - total other income (deductions)	875			263			374			354
Corporate and administrative	18			6			64			19
Consolidated Southwest Gas Holdings, Inc. - total other income (deductions)	$	6,839		$	(4,334	)	$	(6,253	)	$	(9,374	)

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Components of Net Periodic Benefit Cost (Tables)

3 Months Ended

Mar. 31, 2019

Retirement Benefits [Abstract]

Schedule of Net Periodic Benefit Costs

The service cost component of net periodic benefit costs included in the table below are components of an overhead loading process associated with the cost of labor. The overhead process ultimately results in allocation of that portion of overall net periodic benefit costs to the same accounts to which productive labor is charged. As a result, service costs become components of various accounts, primarily operations and maintenance expense, net utility plant, and deferred charges and other assets for both the Company and Southwest. The other components of net periodic benefit cost are reflected in Other income (deductions) on the Condensed Consolidated Statements of Income of the Company and Southwest.

	Qualified Retirement Plan
	Period Ended March 31,
	Three Months						Twelve Months
	2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	6,466		$	7,139		$	27,882		$	24,683
Interest cost	12,252			11,043			45,383			45,606
Expected return on plan assets	(15,061		)	(14,689		)	(59,127		)	(56,086		)
Amortization of net actuarial loss	5,589			8,029			29,675			26,032
Net periodic benefit cost	$	9,246		$	11,522		$	43,813		$	40,235
	SERP
	Period Ended March 31,
	Three Months						Twelve Months
	2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	66		$	61		$	250		$	292
Interest cost	440			415			1,683			1,827
Amortization of net actuarial loss	255			375			1,382			1,456
Net periodic benefit cost	$	761		$	851		$	3,315		$	3,575
	PBOP
	Period Ended March 31,
	Three Months						Twelve Months
	2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	319		$	368		$	1,424		$	1,469
Interest cost	762			687			2,823			3,111
Expected return on plan assets	(789		)	(930		)	(3,577		)	(3,448		)
Amortization of prior service costs	317			334			1,318			1,335
Net periodic benefit cost	$	609		$	459		$	1,988		$	2,467

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Revenue (Tables)

3 Months Ended

Mar. 31, 2019

Revenue from Contract with Customer [Abstract]

Summary of Revenue Disaggregated by Service Type and Contract Type

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						Twelve Months Ended
	March 31,						March 31,
(Thousands of dollars)	2019			2018			2019			2018
Residential	$	417,228		$	344,611		$	959,837		$	859,078
Small commercial	89,610			87,943			256,750			250,331
Large commercial	13,962			15,440			51,714			54,224
Industrial/other	6,478			6,510			23,457			23,085
Transportation	24,902			24,054			87,838			89,081
Revenue from contracts with customers	552,180			478,558			1,379,596			1,275,799
Alternative revenue program revenues (deferrals)	(34,545		)	27,209			(15,775		)	66,788
Other revenues (a)	3,042			(11,454		)	20,271			(8,568		)
Total Gas operating revenues	$	520,677		$	494,313		$	1,384,092		$	1,334,019

(a)

Includes various other revenues which, in the periods presented ending March 31, 2018, were offset by a $14 million reserve against revenue associated with a tax reform savings adjustment. 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:

(Thousands of dollars)	Three Months Ended				Twelve Months Ended
	March 31,				March 31,
	2019		2018		2019		2018
Service Types:
Gas infrastructure services	$	197,893	$	193,527	$	1,128,048	$	938,342
Electric power infrastructure services	52,301		5,402		79,528		19,893
Other	62,668		61,088		367,554		356,131
Total Utility infrastructure services revenues	$	312,862	$	260,017	$	1,575,130	$	1,314,366

(Thousands of dollars)	Three Months Ended				Twelve Months Ended
	March 31,				March 31,
	2019		2018		2019		2018
Contract Types:
Master services agreement	$	235,655	$	194,464	$	1,143,603	$	932,804
Bid contract	77,207		65,553		431,527		381,562
Total Utility infrastructure services revenues	$	312,862	$	260,017	$	1,575,130	$	1,314,366
Unit priced contracts	$	235,686	$	197,322	$	1,296,783	$	1,013,642
Fixed priced contracts	38,538		25,541		130,295		137,724
Time and materials contracts	38,638		37,154		148,052		163,000
Total Utility infrastructure services revenues	$	312,862	$	260,017	$	1,575,130	$	1,314,366

Summary of Information about Receivables, Revenue Earned on Contracts in Progress in Excess of Billings, Which are Included Within Accounts Receivable, Net of Allowances, and Amounts Billed in Excess of Revenue Earned on Contracts

The following table provides information about contracts receivable and revenue earned on contracts in progress in excess of billings (contract asset), which are both included within Accounts receivable, net of allowances, as well as amounts billed in excess

of revenue earned on contracts (contract liability), which are included in Other current liabilities as of March 31, 2019 and December 31, 2018 on the Company’s Condensed Consolidated Balance Sheets:

(Thousands of dollars)	March 31, 2019		December 31, 2018
Contracts receivable, net	$	160,973	$	186,249
Revenue earned on contracts in progress in excess of billings	97,642		87,520
Amounts billed in excess of revenue earned on contracts	4,588		4,211

Schedule of Construction Services Contracts Receivable

Utility infrastructure services contracts receivable consists of the following:

(Thousands of dollars)	March 31, 2019			December 31, 2018
Billed on completed contracts and contracts in progress	$	159,829		$	184,100
Other receivables	1,527			2,588
Contracts receivable, gross	161,356			186,688
Allowance for doubtful accounts	(383		)	(439		)
Contracts receivable, net	$	160,973		$	186,249

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Leases (Tables)

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Components of Lease Expense, and Supplemental Cash Flow Information Related to Leases

The components of lease expense were as follows:

(Thousands of dollars)	Three Months Ended
	March 31, 2019
Southwest:
Operating lease cost	$	406
Centuri:
Operating lease cost	$	2,805
Finance lease cost:
Amortization of ROU assets	$	35
Interest on lease liabilities	7
Total finance lease cost	42
Short-term lease cost	2,575
Total lease cost	$	5,828

Supplemental cash flow information related to leases for the three months ended March 31, 2019 was as follows:

(Thousands of dollars)	Southwest		Centuri		Consolidated Total
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	396	$	2,555	$	2,951
Operating cash flows from finance leases	—		7		7
Financing cash flows from finance leases	—		51		51
ROU assets obtained in exchange for lease obligations:
Operating leases	$	523	$	2,321	$	2,844
Finance leases	—		84		84

Supplemental Information Related to Leases Included in Balance Sheet

Supplemental information related to leases, including location in the Condensed Consolidated Balance Sheets, is as follows:

(Thousands of dollars)	March 31, 2019
Southwest:
Operating leases:
Net Utility Plant	$	1,977
Other current liabilities	$	745
Other deferred credits and other long-term liabilities	1,253
Total operating lease liabilities	$	1,998
Weighted average remaining lease term (in years)	4.22
Weighted average discount rate	3.39		%
Centuri:
Operating leases:
Other property and investments	$	57,267
Other current liabilities	7,178
Other deferred credits and other long-term liabilities	52,647
Total operating lease liabilities	$	59,825
Finance leases:
Other property and investments	$	639
Other current liabilities	256
Other deferred credits and other long-term liabilities	239
Total finance lease liabilities	$	495
Weighted average remaining lease term (in years)
Operating leases	9.33
Finance leases	1.63
Weighted average discount rate
Operating leases	4.08		%
Finance leases	5.84		%

Schedule of Maturities of Operating Lease Liabilities

The following is a schedule of maturities of lease liabilities as of March 31, 2019:

(Thousands of dollars)	Operating leases
Southwest:
2020	$	800
2021	556
2022	295
2023	124
2024	78
Thereafter	307
Total lease payments	2,160
Less imputed interest	162
Total	$	1,998

(Thousands of dollars)	Operating leases		Finance leases
Centuri:
2020	$	10,394	$	281
2021	9,327		128
2022	8,328		67
2023	7,645		38
2024	5,710		25
Thereafter	31,303		—
Total lease payments	72,707		539
Less imputed interest	12,882		44
Total	$	59,825	$	495

Schedule of Maturities of Finance Lease Liabilities

(Thousands of dollars)	Operating leases		Finance leases
Centuri:
2020	$	10,394	$	281
2021	9,327		128
2022	8,328		67
2023	7,645		38
2024	5,710		25
Thereafter	31,303		—
Total lease payments	72,707		539
Less imputed interest	12,882		44
Total	$	59,825	$	495

Schedule of Rental and Lease Payments

As the Company and Southwest adopted Topic 842 using the optional transition method referred to in Note 1 – Background, Organization, and Summary of Significant Accounting Policies, the recent annual disclosure of rental and lease payments as of December 31, 2018 in accordance with Topic 840 is presented in the table below:

	2018		2017
Southwest Gas Corporation	$	4,556	$	4,926
Centuri	59,491		62,310
Consolidated rental payments/lease expense	$	64,047	$	67,236

Schedule of Future Minimum Rental Payments for Operating Leases

The following is a schedule of future minimum lease payments for operating leases (with initial or remaining terms in excess of one year) as of December 31, 2018 (thousands of dollars):

	Southwest		Centuri		Consolidated Total
2019	$	898	$	10,053	$	10,951
2020	363		7,656		8,019
2021	299		5,760		6,059
2022	163		5,163		5,326
2023	79		3,681		3,760
Thereafter	177		10,511		10,688
Total minimum lease payments	$	1,979	$	42,824	$	44,803

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Derivatives (Tables)

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Notional Amounts under Swaps Contracts

The differential is calculated based on the notional amounts under the contracts, which are detailed in the table below (thousands of dekatherms):

	March 31, 2019	December 31, 2018
Contract notional amounts	14,757	13,387

Amount of Gain or Losses Recognized in Income on Derivatives

The following table sets forth the gains and (losses) recognized on the Swaps (derivatives) for the three- and twelve-month periods ended March 31, 2019 and 2018 and their location in the Condensed Consolidated Statements of Income for both the Company and Southwest:

Gains (losses) recognized in income for derivatives not designated as hedging instruments:

(Thousands of dollars)
		Three Months Ended								Twelve Months Ended
	Location of Gain or (Loss) Recognized in Income on Derivatives	March 31,								March 31,
Instrument		2019				2018				2019				2018
Swaps	Net cost of gas sold	$	(3,533	)		$	(5,196	)		$	(450	)		$	(11,631	)
Swaps	Net cost of gas sold	3,533			*	5,196			*	450			*	11,631			*
Total		$	—			$	—			$	—			$	—

* Represents the impact of regulatory deferral accounting treatment under U.S. GAAP for rate-regulated entities.

Fair Values of Swaps in Consolidated Balance Sheets

The following table sets forth the fair values of the Swaps and their location in the Condensed Consolidated Balance Sheets for both the Company and Southwest (thousands of dollars):

Fair values of derivatives not designated as hedging instruments:

March 31, 2019		Asset		Liability
Instrument	Balance Sheet Location	Derivatives		Derivatives			Net Total
Swaps	Other current liabilities	$	805	$	(4,472	)	$	(3,667	)
Swaps	Other deferred credits	60		(809		)	(749		)
Total		$	865	$	(5,281	)	$	(4,416	)
December 31, 2018		Asset		Liability
Instrument	Balance Sheet Location	Derivatives		Derivatives			Net Total
Swaps	Prepaid and other current assets	$	243	$	(99	)	$	144
Swaps	Other current liabilities	1,595		(3,347		)	(1,752		)
Swaps	Other deferred credits	141		(251		)	(110		)
Total		$	1,979	$	(3,697	)	$	(1,718	)

Paid to and Received from Counterparties for Settlements of Matured Swaps

The following table shows the amounts Southwest paid to and received from counterparties for settlements of matured Swaps.

	Three Months Ended		Twelve Months Ended
(Thousands of dollars)	March 31, 2019		March 31, 2019
Paid to counterparties	$	1,882	$	5,948
Received from counterparties	$	1,047	$	1,653

Regulatory Assets/Liabilities Offsetting Derivatives at Fair Value in Condensed Consolidated Balance Sheets

The following table details the regulatory assets/(liabilities) offsetting the derivatives at fair value in the Condensed Consolidated Balance Sheets for both the Company and Southwest (thousands of dollars).

March 31, 2019
Instrument	Balance Sheet Location	Net Total
Swaps	Prepaid and other current assets	$	3,667
Swaps	Deferred charges and other assets	749
December 31, 2018
Instrument	Balance Sheet Location	Net Total
Swaps	Other current liabilities	$	(144	)
Swaps	Prepaid and other current assets	1,752
Swaps	Deferred charges and other assets	110

Summary of Financial Assets and Liabilities at Fair Value

The following table sets forth, by level within the three-level fair value hierarchy that ranks the inputs used to measure fair value by their reliability, the financial assets and liabilities that were accounted for at fair value by both the Company and Southwest:Level 2 - Significant other observable inputs

(Thousands of dollars)	March 31, 2019			December 31, 2018
Assets at fair value:
Prepaid and other current assets - Swaps	$	—		$	144
Liabilities at fair value:
Other current liabilities - Swaps	(3,667		)	(1,752		)
Other deferred credits - Swaps	(749		)	(110		)
Net Assets (Liabilities)	$	(4,416	)	$	(1,718	)

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Common Stock (Tables)

3 Months Ended

Mar. 31, 2019

Equity [Abstract]

Schedule of Common Stock Activity

The following table provides activity in the Equity Shelf Program for the three and twelve months ended March 31, 2019:

	Three Months Ended						Twelve Months Ended
	March 31,						March 31,
	2019			2018			2019			2018
Gross proceeds	$	23,073,149		$	9,199,661		$	99,023,464		$	50,976,456
Less: agent commissions	(230,731		)	(91,997		)	(990,234		)	(509,765		)
Net proceeds	$	22,842,418		$	9,107,664		$	98,033,230		$	50,466,691
Number of shares sold	277,829			137,300			1,286,234			643,007
Weighted average price per share	$	83.05		$	67.00		$	76.99		$	79.28

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Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Schedule of Carrying Amounts and Estimated Fair Values of Long-Term Debt

The Centuri secured revolving credit and term loan facility and Centuri other debt obligations (not actively traded) are categorized as Level 3, based on significant unobservable inputs to their fair values. Because Centuri’s debt is not publicly traded, fair values for the secured revolving credit and term loan facility and other debt obligations were based on a conventional discounted cash flow methodology and utilized current market pricing yield curves, across Centuri’s debt maturity spectrum, of other industrial bonds with an assumed credit rating comparable to the Company’s.

	March 31, 2019					December 31, 2018
	Carrying Amount			Market Value		Carrying Amount			Market Value
(Thousands of dollars)
Southwest Gas Corporation:
Debentures:
Notes, 4.45%, due 2020	$	125,000		$	126,990	$	125,000		$	126,213
Notes, 6.1%, due 2041	125,000			154,294		125,000			150,728
Notes, 3.875%, due 2022	250,000			255,015		250,000			254,195
Notes, 4.875%, due 2043	250,000			277,683		250,000			268,985
Notes, 3.8%, due 2046	300,000			283,635		300,000			267,030
Notes, 3.7%, due 2028	300,000			306,465		300,000			298,926
8% Series, due 2026	75,000			95,128		75,000			93,827
Medium-term notes, 7.78% series, due 2022	25,000			27,715		25,000			27,497
Medium-term notes, 7.92% series, due 2027	25,000			30,824		25,000			30,016
Medium-term notes, 6.76% series, due 2027	7,500			8,845		7,500			8,651
Unamortized discount and debt issuance costs	(11,641		)			(11,807		)
	1,470,859					1,470,693
Revolving credit facility and commercial paper	150,000			150,000		150,000			150,000
Industrial development revenue bonds:
Variable-rate bonds:
Tax-exempt Series A, due 2028	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	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	(1,900		)			(2,024		)
	198,100					197,976
Less: current maturities	—					—
Long-term debt, less current maturities - Southwest Gas Corporation	$	1,818,959				$	1,818,669
Centuri:
Centuri term loan facility	$	254,534		$	257,579	$	255,959		$	260,135
Unamortized debt issuance costs	(1,343		)			(1,414		)
	253,191					254,545
Centuri secured revolving credit facility	6,361			6,363		—			—
Centuri other debt obligations	62,678			63,365		67,104			67,053
Less: current maturities	(34,915		)			(33,060		)
Long-term debt, less current maturities - Centuri	$	287,315				$	288,589
Consolidated Southwest Gas Holdings, Inc.:
Southwest Gas Corporation long-term debt	$	1,818,959				$	1,818,669
Centuri long-term debt	322,230					321,649
Less: current maturities	(34,915		)			(33,060		)
Long-term debt, less current maturities - Southwest Gas Holdings, Inc.	$	2,106,274				$	2,107,258

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Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income (Tables)

3 Months Ended

Mar. 31, 2019

Equity [Abstract]

Detailed Activities of Equity and Redeemable Noncontrolling Interest

The tables below provide details of activity in equity, the noncontrolling interest, and the redeemable noncontrolling interest for the Company on a consolidated basis for the three-month periods ended March 31, 2019 and March 31, 2018.

	Southwest Gas Holdings, Inc. Equity
(In thousands, except per share amounts)	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Non-controlling Interest						Redeemable Noncontrolling Interest (Temporary Equity)
	Shares	Amount													Total
December 31, 2018	53,026	$	54,656	$	1,305,769	$	(52,668	)	$	944,285		$	(452	)	$	2,251,590		$	81,831
Common stock issuances	365	365		27,024											27,389
Net income (loss)									94,809						94,809			575
Foreign currency exchange translation adjustment						791									791
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax						619									619
FSIRS amounts reclassified to net income, net of tax						635									635
Dividends declared
Common: $0.545 per share									(29,285		)				(29,285		)
March 31, 2019	53,391	$	55,021	$	1,332,793	$	(50,623	)	$	1,009,809		$	(452	)	$	2,346,548		$	82,406

	Southwest Gas Holdings, Inc. Equity
	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Non-controlling Interest
(In thousands, except per share amounts)	Shares	Amount													Total
December 31, 2017	48,090	$	49,720	$	955,332	$	(47,682	)	$	857,398		$	(2,365	)	$	1,812,403
Common stock issuances	247	247		10,148											10,395
Net income (loss)									79,091			(797		)	78,294
Foreign currency exchange translation adjustment						(911		)							(911		)
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax						895									895
FSIRS amounts reclassified to net income, net of tax						635									635
Reclassification of excess deferred taxes (a)						(9,300		)	9,300						—
Dividends declared
Common: $0.52 per share									(25,335		)				(25,335		)
March 31, 2018	48,337	$	49,967	$	965,480	$	(56,363	)	$	920,454		$	(3,162	)	$	1,876,376

(a) Reclassification for the release of excess deferred taxes as a result of the adoption of ASU No. 2018-02 “Income Statement—Reporting Comprehensive Income—Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income,” which permitted release of excess amounts created following the December 2017 enactment of U.S. tax reform.

The tables below provide details of activity in equity for Southwest during the three-month periods ended March 31, 2019 and March 31, 2018. Only equity shares of the Company are publicly traded, under the ticker symbol “SWX.”

	Southwest Gas Corporation Equity
	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings
(In thousands)	Shares	Amount										Total
December 31, 2018	47,482	$	49,112	$	1,065,242	$	(49,049	)	$	717,155		$	1,782,460
Net income									103,389			103,389
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax						619						619
FSIRS amounts reclassified to net income, net of tax						635						635
Stock-based compensation (a)				918					(160		)	758
Dividends declared to Southwest Gas Holdings, Inc.									(22,800		)	(22,800		)
Contributions from Southwest Gas Holdings, Inc.				22,842								22,842
March 31, 2019	47,482	$	49,112	$	1,089,002	$	(47,795	)	$	797,584		$	1,887,903

	Southwest Gas Corporation Equity
	Common Stock			Additional Paid-in Capital			Accumulated Other Comprehensive Income (Loss)			Retained Earnings
(In thousands)	Shares	Amount											Total
December 31, 2017	47,482	$	49,112	$	948,767		$	(47,073	)	$	659,193		$	1,609,999
Net income										90,349			90,349
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax							895						895
FSIRS amounts reclassified to net income, net of tax							635						635
Reclassification of excess deferred taxes (b)							(9,300		)	9,300			—
Stock-based compensation (a)				(568		)				(166		)	(734		)
Dividends declared to Southwest Gas Holdings, Inc.										(22,000		)	(22,000		)
March 31, 2018	47,482	$	49,112	$	948,199		$	(54,843	)	$	736,676		$	1,679,144

(a) Stock-based compensation is based on stock awards of Southwest Gas Corporation to be issued in shares of Southwest Gas Holdings, Inc.

(b)

Reclassification for the release of excess deferred taxes as a result of the adoption of ASU No. 2018-02, which permitted release of excess amounts created following the December 2017 enactment of U.S. tax reform.

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

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

(Thousands of dollars)

	Three Months Ended									Three Months Ended
	March 31, 2019									March 31, 2018
	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:
Amortization of prior service cost	$	317		$	(76	)	$	241		$	334		$	(80	)	$	254
Amortization of net actuarial (gain)/loss	5,844			(1,403		)	4,441			8,404			(2,017		)	6,387
Regulatory adjustment	(5,347		)	1,284			(4,063		)	(7,560		)	1,814			(5,746		)
Pension plans other comprehensive income	814			(195		)	619			1,178			(283		)	895
FSIRS (designated hedging activities):
Amounts reclassified into net income	836			(201		)	635			837			(202		)	635
FSIRS other comprehensive income	836			(201		)	635			837			(202		)	635
Total other comprehensive income - Southwest Gas Corporation	1,650			(396		)	1,254			2,015			(485		)	1,530
Foreign currency translation adjustments:
Translation adjustments	791			—			791			(911		)	—			(911		)
Foreign currency other comprehensive income (loss)	791			—			791			(911		)	—			(911		)
Total other comprehensive income - Southwest Gas Holdings, Inc.	$	2,441		$	(396	)	$	2,045		$	1,104		$	(485	)	$	619

	Twelve Months Ended									Twelve Months Ended
	March 31, 2019									March 31, 2018
	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)	$	(20,426	)	$	4,902		$	(15,524	)	$	(43,027	)	$	10,326		$	(32,701	)
Amortization of prior service cost	1,318			(316		)	1,002			1,335			(460		)	875
Amortization of net actuarial (gain)/loss	31,057			(7,454		)	23,603			27,488			(9,269		)	18,219
Regulatory adjustment	(6,020		)	1,446			(4,574		)	10,515			(115		)	10,400
Pension plans other comprehensive income (loss)	5,929			(1,422		)	4,507			(3,689		)	482			(3,207		)
FSIRS (designated hedging activities):
Amounts reclassified into net income	3,344			(803		)	2,541			3,345			(1,155		)	2,190
FSIRS other comprehensive income	3,344			(803		)	2,541			3,345			(1,155		)	2,190
Total other comprehensive income (loss) - Southwest Gas Corporation	9,273			(2,225		)	7,048			(344		)	(673		)	(1,017		)
Foreign currency translation adjustments:
Translation adjustments	(1,308		)	—			(1,308		)	640			—			640
Foreign currency other comprehensive income (loss)	(1,308		)	—			(1,308		)	640			—			640
Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	7,965		$	(2,225	)	$	5,740		$	296		$	(673	)	$	(377	)

(1)

Tax amounts are calculated using a 24% rate following the December 22, 2017 enactment date of U.S. tax reform. For periods prior to the enactment date (and included in specific line items of the tables for the twelve months ended March 31, 2018), tax amounts were calculated using a 38% rate. The tax effect of before-tax amounts remaining in the balance of Accumulated other comprehensive income (loss) as of March 31, 2019 is effectively computed using a 24% tax rate overall. With regard to foreign currency translation adjustments, the Company has elected to indefinitely reinvest the earnings of Centuri’s Canadian subsidiaries in Canada, thus preventing deferred taxes on such earnings. As a result of this assertion, the Company is not recognizing any tax effect or presenting a tax expense or benefit for the currency translation adjustment amount reported in Other comprehensive income (loss), as repatriation of earnings is not anticipated.

Rollforward of Accumulated Other Comprehensive Income

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

AOCI - Rollforward    

(Thousands of dollars)

	Defined Benefit Plans									FSIRS									Foreign Currency Items
	Before-Tax			Tax (Expense) Benefit (4,5)			After-Tax (5)			Before-Tax			Tax (Expense) Benefit (4,5)			After-Tax (5)			Before-Tax			Tax (Expense) Benefit		After-Tax			AOCI
Beginning Balance AOCI December 31, 2018	$	(55,227	)	$	13,254		$	(41,973	)	$	(9,310	)	$	2,234		$	(7,076	)	$	(3,619	)	$	—	$	(3,619	)	$	(52,668	)
Translation adjustments	—			—			—			—			—			—			791			—		791			791
Other comprehensive income (loss) before reclassifications	—			—			—			—			—			—			791			—		791			791
FSIRS amounts reclassified from AOCI (1)	—			—			—			836			(201		)	635			—			—		—			635
Amortization of prior service cost (2)	317			(76		)	241			—			—			—			—			—		—			241
Amortization of net actuarial loss (2)	5,844			(1,403		)	4,441			—			—			—			—			—		—			4,441
Regulatory adjustment (3)	(5,347		)	1,284			(4,063		)	—			—			—			—			—		—			(4,063		)
Net current period other comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.	814			(195		)	619			836			(201		)	635			791			—		791			2,045
Ending Balance AOCI March 31, 2019	$	(54,413	)	$	13,059		$	(41,354	)	$	(8,474	)	$	2,033		$	(6,441	)	$	(2,828	)	$	—	$	(2,828	)	$	(50,623	)

(1) The FSIRS reclassification amounts are 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.

(5) The beginning balances depict amounts attributable to the individual components of AOCI (Defined Benefit Plans and FSIRS) following the adoption of ASU No. 2018-02, with no impact to the total balance of AOCI resulting from the depiction.

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

AOCI - Rollforward

(Thousands of dollars)

	Defined Benefit Plans									FSIRS
	Before-Tax			Tax (Expense) Benefit (9,10)			After-Tax (10)			Before-Tax			Tax (Expense) Benefit (9,10)			After-Tax (10)			AOCI
Beginning Balance AOCI December 31, 2018	$	(55,227	)	$	13,254		$	(41,973	)	$	(9,310	)	$	2,234		$	(7,076	)	$	(49,049	)
FSIRS amounts reclassified from AOCI (6)	—			—			—			836			(201		)	635			635
Amortization of prior service cost (7)	317			(76		)	241			—			—			—			241
Amortization of net actuarial loss (7)	5,844			(1,403		)	4,441			—			—			—			4,441
Regulatory adjustment (8)	(5,347		)	1,284			(4,063		)	—			—			—			(4,063		)
Net current period other comprehensive income attributable to Southwest Gas Corporation	814			(195		)	619			836			(201		)	635			1,254
Ending Balance AOCI March 31, 2019	$	(54,413	)	$	13,059		$	(41,354	)	$	(8,474	)	$	2,033		$	(6,441	)	$	(47,795	)

(6) The FSIRS reclassification amounts are included in Net interest deductions on Southwest’s Condensed Consolidated Statements of Income.

(7) 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).

(8) The regulatory adjustment represents the portion of the activity above that is expected to be recovered through rates in the future (the related regulatory asset is included in Deferred charges and other assets on Southwest’s Condensed Consolidated Balance Sheets).

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

(10)

The beginning balances depict amounts attributable to the individual components of AOCI (Defined Benefit Plans and FSIRS) following the adoption of ASU No. 2018-02, with no impact to the total balance of AOCI resulting from the depiction.

Amount Recognized Before Income Tax in Accumulated Other Comprehensive Income

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:

Amounts Recognized in AOCI (Before Tax)

(Thousands of dollars)

	March 31, 2019			December 31, 2018
Net actuarial (loss) gain	$	(429,520	)	$	(435,364	)
Prior service cost	(2,716		)	(3,033		)
Less: amount recognized in regulatory assets	377,823			383,170
Recognized in AOCI	$	(54,413	)	$	(55,227	)

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

Schedule of Segment Reporting Information

The following tables present revenues from external customers, intersegment revenues, and segment net income for the two reportable segments (thousands of dollars):

	Natural Gas Operations		Utility Infrastructure Services			Other			Total
Three Months Ended March 31, 2019
Revenues from external customers	$	520,677	$	274,189		$	—		$	794,866
Intersegment revenues	—		38,673			—			38,673
Total	$	520,677	$	312,862		$	—		$	833,539
Segment net income (loss)	$	103,389	$	(8,031	)	$	(549	)	$	94,809
Three Months Ended March 31, 2018
Revenues from external customers	$	494,313	$	232,859		$	—		$	727,172
Intersegment revenues	—		27,158			—			27,158
Total	$	494,313	$	260,017		$	—		$	754,330
Segment net income (loss)	$	90,349	$	(11,001	)	$	(257	)	$	79,091
	Natural Gas Operations		Utility Infrastructure Services			Other			Total
Twelve Months Ended March 31, 2019
Revenues from external customers	$	1,384,092	$	1,427,701		$	—		$	2,811,793
Intersegment revenues	—		147,429			—			147,429
Total	$	1,384,092	$	1,575,130		$	—		$	2,959,222
Segment net income (loss)	$	151,882	$	47,947		$	(1,834	)	$	197,995
Twelve Months Ended March 31, 2018
Revenues from external customers	$	1,334,019	$	1,211,345		$	—		$	2,545,364
Intersegment revenues	—		103,021			—			103,021
Total	$	1,334,019	$	1,314,366		$	—		$	2,648,385
Segment net income (loss)	$	170,229	$	34,693		$	(1,298	)	$	203,624

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Redeemable Noncontrolling Interests (Tables)

3 Months Ended

Mar. 31, 2019

Noncontrolling Interest [Abstract]

Summary of Redeemable Noncontrolling Interest

The following depicts changes to the balance of the redeemable noncontrolling interest between the indicated periods.

	Redeemable Noncontrolling Interest
(Thousands of dollars):
Balance, December 31, 2018	$	81,831
Net income attributable to redeemable noncontrolling interest	575
Balance, March 31, 2019	$	82,406

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Business Acquisitions (Tables)

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

Summary of Fair Values of Assets Acquired and Liabilities Assumed

The preliminary estimated fair values of assets acquired and liabilities assumed as of November 30, 2018, are as follows (millions of dollars):

	Acquisition Date		Measurement Period Adjustments			Revised Acquisition Date
Cash and cash equivalents	$	3.9	$	—		$	3.9
Accounts receivable	32.8		(0.5		)	32.3
Revenue earned on contracts in progress in excess of billings	21.6		1.7			23.3
Prepaid expenses and other current assets	1.1		0.2			1.3
Property and equipment	89.4		(0.5		)	88.9
Intangible assets	89.3		—			89.3
Goodwill	188.5		3.3			191.8
Total assets acquired	426.6		4.2			430.8
Accounts payable	8.0		—			8.0
Accrued liabilities	6.9		1.6			8.5
Deferred compensation and related accrued taxes	3.4		—			3.4
Redeemable noncontrolling interest	81.7		—			81.7
Total liabilities assumed and noncontrolling interest	100.0		1.6			101.6
Net assets acquired	$	326.6	$	2.6		$	329.2

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Background, Organization, and Summary of Significant Accounting Policies - Schedule of Other Property and Investments (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Investment [Line Items]
Other property	$ 15,032	$ 14,153
Total	716,722	623,551
Southwest Gas Corporation
Investment [Line Items]
Net cash surrender value of COLI policies	122,048	114,405
Other property	1,735	1,741
Total	123,783	116,146
Centuri
Investment [Line Items]
Centuri property, equipment, and intangibles	894,739	792,191
Centuri accumulated depreciation/amortization	$ (316,832)	$ (298,939)

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Background, Organization, and Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2019	Dec. 31, 2018	Nov. 30, 2018
Significant Accounting Policies [Line Items]
Goodwill impairment	$ 0
Gas Pipe Materials and Supplies | Prepaid and other current assets
Significant Accounting Policies [Line Items]
Gas pipe materials and operating supplies	55,000,000	$ 55,000,000	$ 56,000,000
Prepaid and other current assets	55,000,000	55,000,000	74,000,000
Centuri | Linetec
Significant Accounting Policies [Line Items]
Percentage of voting interests acquired				80.00%
Purchase consideration	73,500,000	73,500,000
Southwest Gas Corporation
Significant Accounting Policies [Line Items]
Dividends declared but not yet paid	22,800,000	22,800,000
Pooled Funds and Mutual Funds | Level 2 - Significant Other Observable Inputs
Significant Accounting Policies [Line Items]
Money market fund investments	54,400,000	54,400,000	59,900,000
Pooled Funds and Mutual Funds | Southwest Gas Corporation | Level 2 - Significant Other Observable Inputs
Significant Accounting Policies [Line Items]
Money market fund investments	$ 41,000,000	$ 41,000,000	$ 18,000,000

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Background, Organization, and Summary of Significant Accounting Policies - Accounts Receivable for Services (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Centuri
Segment Reporting Information [Line Items]
Centuri accounts receivable for services provided to Southwest	$ 16,837	$ 18,830

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Background, Organization, and Summary of Significant Accounting Policies - Schedule of Goodwill (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Goodwill [Roll Forward]
Goodwill, beginning balance	$ 359,045
Foreign currency translation adjustment	2,134
Goodwill, ending balance	364,482
Natural Gas Operations
Goodwill [Roll Forward]
Goodwill, beginning balance	10,095
Foreign currency translation adjustment	0
Goodwill, ending balance	10,095
Utility Infrastructure Services
Goodwill [Roll Forward]
Goodwill, beginning balance	348,950
Foreign currency translation adjustment	2,134
Goodwill, ending balance	354,387
Linetec
Goodwill [Roll Forward]
Measurement Period Adjustment - Linetec acquisition	3,303
Goodwill, ending balance	191,800
Linetec | Natural Gas Operations
Goodwill [Roll Forward]
Measurement Period Adjustment - Linetec acquisition	0
Linetec | Utility Infrastructure Services
Goodwill [Roll Forward]
Measurement Period Adjustment - Linetec acquisition	$ 3,303

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Background, Organization, and Summary of Significant Accounting Policies- Other Income (Deductions) (Detail) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018
Other income (deductions)
Total other income (deductions)	$ 6,839	$ (4,334)	$ (6,253)	$ (9,374)
Southwest Gas Corporation
Other income (deductions)
Total other income (deductions)	5,946	(4,603)	(6,691)	(9,747)
Operating Segments | Natural Gas Operations | Southwest Gas Corporation
Other income (deductions)
Change in COLI policies	7,600	(700)	5,100	6,800
Interest income	1,597	1,418	6,199	3,638
Equity AFUDC	960	229	4,358	2,049
Other components of net periodic benefit cost	(3,765)	(5,265)	(19,560)	(19,834)
Miscellaneous income and (expense)	(446)	(285)	(2,788)	(2,400)
Total other income (deductions)	5,946	(4,603)	(6,691)	(9,747)
Operating Segments | Utility Infrastructure Services | Centuri
Other income (deductions)
Interest income	0	1	87	4
Foreign transaction gain (loss)	531	147	162	(606)
Miscellaneous income and (expense)	344	115	125	956
Total other income (deductions)	875	263	374	354
Corporate and administrative
Other income (deductions)
Total other income (deductions)	$ 18	$ 6	$ 64	$ 19

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Components of Net Periodic Benefit Cost (Detail) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018
Qualified Retirement Plan
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 6,466	$ 7,139	$ 27,882	$ 24,683
Interest cost	12,252	11,043	45,383	45,606
Expected return on plan assets	(15,061)	(14,689)	(59,127)	(56,086)
Amortization of net actuarial loss	5,589	8,029	29,675	26,032
Net periodic benefit cost	9,246	11,522	43,813	40,235
SERP
Defined Benefit Plan Disclosure [Line Items]
Service cost	66	61	250	292
Interest cost	440	415	1,683	1,827
Amortization of net actuarial loss	255	375	1,382	1,456
Net periodic benefit cost	761	851	3,315	3,575
PBOP
Defined Benefit Plan Disclosure [Line Items]
Service cost	319	368	1,424	1,469
Interest cost	762	687	2,823	3,111
Expected return on plan assets	(789)	(930)	(3,577)	(3,448)
Amortization of prior service costs	317	334	1,318	1,335
Net periodic benefit cost	$ 609	$ 459	$ 1,988	$ 2,467

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Revenue - Additional Information (Detail) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($) Segment Contract
Southwest Gas Corporation
Segment Reporting Information [Line Items]
Number of operating segment | Segment	1
Centuri
Segment Reporting Information [Line Items]
Change in contract liability, revenue recognized | $	$ 4.2
Number of contracts with original duration more than one year | Contract	17

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Revenue - Revenue Performance Obligation (Details) - Centuri - Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01 $ in Millions	Mar. 31, 2019 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Transaction price allocated to unsatisfied performance obligations of contracts	$ 60.7
Revenue, remaining performance obligation, expected timing of satisfaction, period	3 years

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Revenue - Schedule of Gas Operating Revenue (Detail) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 552,180	$ 478,558	$ 1,379,596	$ 1,275,799
Alternative revenue program revenues (deferrals)	(34,545)	27,209	(15,775)	66,788
Other revenues	3,042	(11,454)	20,271	(8,568)
Total Gas operating revenues	520,677	494,313	1,384,092	1,334,019
Tax Reform Savings Revenue Adjustments
Disaggregation of Revenue [Line Items]
Other revenues		14,000
Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	417,228	344,611	959,837	859,078
Small commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	89,610	87,943	256,750	250,331
Large commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	13,962	15,440	51,714	54,224
Industrial/other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	6,478	6,510	23,457	23,085
Transportation
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 24,902	$ 24,054	$ 87,838	$ 89,081

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Revenue - Summary of Revenue Disaggregated by Service Type, and Contract Type (Detail) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 552,180	$ 478,558	$ 1,379,596	$ 1,275,799
Centuri
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	312,862	260,017	1,575,130	1,314,366
Master services agreement | Centuri
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	235,655	194,464	1,143,603	932,804
Bid contract | Centuri
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	77,207	65,553	431,527	381,562
Unit priced contracts | Centuri
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	235,686	197,322	1,296,783	1,013,642
Fixed priced contracts | Centuri
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	38,538	25,541	130,295	137,724
Time and materials contracts | Centuri
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	38,638	37,154	148,052	163,000
Gas infrastructure services | Centuri
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	197,893	193,527	1,128,048	938,342
Electric power infrastructure services | Centuri
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	52,301	5,402	79,528	19,893
Other | Centuri
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 62,668	$ 61,088	$ 367,554	$ 356,131

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Revenue - Summary of Information about Receivables (Detail) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Contracts receivable, net	$ 160,973	$ 186,249
Revenue earned on contracts in progress in excess of billings	97,642	87,520
Amounts billed in excess of revenue earned on contracts	$ 4,588	$ 4,211

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Revenue - Schedule of Construction Services Contracts Receivable (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Billed on completed contracts and contracts in progress	$ 159,829	$ 184,100
Other receivables	1,527	2,588
Contracts receivable, gross	161,356	186,688
Allowance for doubtful accounts	(383)	(439)
Contracts receivable, net	$ 160,973	$ 186,249

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Leases - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Jan. 01, 2019
Accounting Standards Update 2016-02
Lessee, Lease, Description [Line Items]
Operating lease ROU assets		$ 58,400
Lease liabilities		60,800
Southwest Gas Corporation
Lessee, Lease, Description [Line Items]
Operating lease ROU assets	$ 1,977
Lease liabilities	$ 1,998
Lease renewal term (up to)	3 years
Southwest Gas Corporation | Accounting Standards Update 2016-02
Lessee, Lease, Description [Line Items]
Operating lease ROU assets		1,900
Lease liabilities		$ 1,900
Centuri
Lessee, Lease, Description [Line Items]
Operating lease ROU assets	$ 57,267
Lease liabilities	$ 59,825
Lease renewal term (up to)	5 years
Lease termination period	1 year
Short-term lease cost	$ 2,575
Minimum | Southwest Gas Corporation
Lessee, Lease, Description [Line Items]
Lease remaining lease term	1 year
Minimum | Centuri
Lessee, Lease, Description [Line Items]
Lease remaining lease term	1 year
Maximum | Southwest Gas Corporation
Lessee, Lease, Description [Line Items]
Lease remaining lease term	10 years
Maximum | Centuri
Lessee, Lease, Description [Line Items]
Lease remaining lease term	14 years

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Leases - Components of Lease Expense (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Finance lease cost:
Total lease cost	$ 5,828
Southwest Gas Corporation
Lessee, Lease, Description [Line Items]
Operating lease cost	406
Centuri
Lessee, Lease, Description [Line Items]
Operating lease cost	2,805
Finance lease cost:
Amortization of ROU assets	35
Interest on lease liabilities	7
Total finance lease cost	42
Short-term lease cost	$ 2,575

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Leases - Supplemental Cash Flow Information Related to Leases (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Lessee, Lease, Description [Line Items]
Operating cash flows from operating leases	$ 2,951
Operating cash flows from finance leases	7
Financing cash flows from finance leases	51
ROU assets obtained in exchange for operating leases obligations	2,844
ROU assets obtained in exchange for finance leases obligations	84
Southwest Gas Corporation
Lessee, Lease, Description [Line Items]
Operating cash flows from operating leases	396
Operating cash flows from finance leases	0
Financing cash flows from finance leases	0
ROU assets obtained in exchange for operating leases obligations	523
ROU assets obtained in exchange for finance leases obligations	0
Centuri
Lessee, Lease, Description [Line Items]
Operating cash flows from operating leases	2,555
Operating cash flows from finance leases	7
Financing cash flows from finance leases	51
ROU assets obtained in exchange for operating leases obligations	2,321
ROU assets obtained in exchange for finance leases obligations	$ 84

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Leases - Supplemental Information Related to Leases Included in Balance Sheet (Details) $ in Thousands	Mar. 31, 2019 USD ($)
Lessee, Lease, Description [Line Items]
Operating lease, weighted average remaining lease term (in years)	9 years 3 months 29 days
Operating lease, weighted average discount rate	4.08%
Finance lease ROU assets	$ 639
Finance lease liabilities, current	256
Finance lease liabilities, noncurrent	239
Finance lease liabilities	$ 495
Finance lease, weighted average remaining lease term (in years)	1 year 7 months 17 days
Finance lease, weighted average discount rate	5.84%
Southwest Gas Corporation
Lessee, Lease, Description [Line Items]
Operating lease ROU assets	$ 1,977
Operating lease liabilities, current	745
Operating lease liabilities, noncurrent	1,253
Operating lease liabilities	$ 1,998
Operating lease, weighted average remaining lease term (in years)	4 years 2 months 19 days
Operating lease, weighted average discount rate	3.39%
Centuri
Lessee, Lease, Description [Line Items]
Operating lease ROU assets	$ 57,267
Operating lease liabilities, current	7,178
Operating lease liabilities, noncurrent	52,647
Operating lease liabilities	59,825
Finance lease liabilities	$ 495

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Leases - Schedule of Maturities of Lease Liabilities (Details) $ in Thousands	Mar. 31, 2019 USD ($)
Finance leases
Total	$ 495
Centuri
Operating leases
2020	10,394
2021	9,327
2022	8,328
2023	7,645
2024	5,710
Thereafter	31,303
Total lease payments	72,707
Less imputed interest	12,882
Total	59,825
Finance leases
2020	281
2021	128
2022	67
2023	38
2024	25
Thereafter	0
Total lease payments	539
Less imputed interest	44
Total	495
Southwest Gas Corporation
Operating leases
2020	800
2021	556
2022	295
2023	124
2024	78
Thereafter	307
Total lease payments	2,160
Less imputed interest	162
Total	$ 1,998

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Leases - Schedule of Rental and Lease Payments (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Lessee, Lease, Description [Line Items]
Rental payments/lease expense	$ 64,047	$ 67,236
Southwest Gas Corporation
Lessee, Lease, Description [Line Items]
Rental payments/lease expense	4,556	4,926
Centuri
Lessee, Lease, Description [Line Items]
Rental payments/lease expense	$ 59,491	$ 62,310

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Leases - Schedule of Future Minimum Rental Payments for Operating Leases (Details) $ in Thousands	Dec. 31, 2018 USD ($)
Lessee, Lease, Description [Line Items]
2019	$ 10,951
2020	8,019
2021	6,059
2022	5,326
2023	3,760
Thereafter	10,688
Total minimum lease payments	44,803
Southwest Gas Corporation
Lessee, Lease, Description [Line Items]
2019	898
2020	363
2021	299
2022	163
2023	79
Thereafter	177
Total minimum lease payments	1,979
Centuri
Lessee, Lease, Description [Line Items]
2019	10,053
2020	7,656
2021	5,760
2022	5,163
2023	3,681
Thereafter	10,511
Total minimum lease payments	$ 42,824

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Derivatives - Additional Information (Detail)	3 Months Ended		12 Months Ended
	Mar. 31, 2019 USD ($) Contract	Mar. 31, 2018 USD ($)	Mar. 31, 2019 USD ($) Contract	Mar. 31, 2018 USD ($)
Derivative [Line Items]
Gains (losses) recognized in income or other comprehensive income for derivative designated cash flow hedges	$ 635,000	$ 635,000	$ 2,541,000	$ 2,190,000
Cash Flow Hedging
Derivative [Line Items]
Gains (losses) recognized in income or other comprehensive income for derivative designated cash flow hedges	$ 0
Arizona
Derivative [Line Items]
Natural gas portfolios, maximum % rate	25.00%
California
Derivative [Line Items]
Natural gas portfolios, maximum % rate	25.00%
Southwest Gas Corporation
Derivative [Line Items]
Gains (losses) recognized in income or other comprehensive income for derivative designated cash flow hedges	$ 635,000	$ 635,000	$ 2,541,000	$ 2,190,000
Derivative instrument loss at settlement amortization period	10 years
Southwest Gas Corporation | Forward-starting interest rate swaps | Cash Flow Hedging
Derivative [Line Items]
Number of derivative instruments held | Contract	2		2

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Derivatives - Notional Amounts under Swaps Contracts (Detail) - MMBTU MMBTU in Thousands	Mar. 31, 2019	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Contract notional amounts	14,757	13,387

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Derivatives - Amount of Gain or Losses Recognized in Income on Derivatives (Detail) - Cash Flow Hedging - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain or (loss) recognized in income on derivative	$ 0	$ 0	$ 0	$ 0
Net cost of gas sold
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain or (loss) recognized in income on derivative	(3,533)	(5,196)	(450)	(11,631)
Regulatory Deferral Accounting Treatment | Net cost of gas sold
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain or (loss) recognized in income on derivative	$ 3,533	$ 5,196	$ 450	$ 11,631

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Derivatives - Swaps in Balance Sheet (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Asset derivatives not designated as hedging instruments	$ 865	$ 1,979
Liability derivatives not designated as hedging instruments	(5,281)	(3,697)
Net total not designated as hedging instruments	(4,416)	(1,718)
Swaps | Prepaid and other current assets
Derivatives, Fair Value [Line Items]
Asset derivatives not designated as hedging instruments		243
Liability derivatives not designated as hedging instruments		(99)
Net total not designated as hedging instruments		144
Swaps | Other current liabilities
Derivatives, Fair Value [Line Items]
Asset derivatives not designated as hedging instruments	805	1,595
Liability derivatives not designated as hedging instruments	(4,472)	(3,347)
Net total not designated as hedging instruments	(3,667)	(1,752)
Swaps | Other deferred credits
Derivatives, Fair Value [Line Items]
Asset derivatives not designated as hedging instruments	60	141
Liability derivatives not designated as hedging instruments	(809)	(251)
Net total not designated as hedging instruments	$ (749)	$ (110)

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Derivatives - Paid to and Received from Counterparties for Settlements of Matured Swaps (Detail) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Paid to counterparties	$ 1,882	$ 5,948
Received from counterparties	$ 1,047	$ 1,653

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Derivatives - Regulatory Assets/Liabilities Offsetting Derivatives (Detail) - Swaps - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Prepaid and other current assets
Derivatives, Fair Value [Line Items]
Regulatory assets/(liabilities) offsetting the derivatives at fair value	$ 3,667	$ 1,752
Deferred charges and other assets
Derivatives, Fair Value [Line Items]
Regulatory assets/(liabilities) offsetting the derivatives at fair value	$ 749	110
Other current liabilities
Derivatives, Fair Value [Line Items]
Regulatory assets/(liabilities) offsetting the derivatives at fair value		$ (144)

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Derivatives - Summary of Financial Assets and Liabilities (Detail) - Level 2 - Significant Other Observable Inputs - Swaps - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Net Assets (Liabilities)	$ (4,416)	$ (1,718)
Deferred charges and other assets
Derivatives, Fair Value [Line Items]
Derivative assets	0	144
Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	(3,667)	(1,752)
Other deferred credits
Derivatives, Fair Value [Line Items]
Derivative liabilities	$ (749)	$ (110)

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Common Stock (Detail) - USD ($)		3 Months Ended		12 Months Ended
	Mar. 29, 2017	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018	May 02, 2019
Class of Stock [Line Items]
Maximum aggregate market value of potential common stock issuance	$ 150,000,000
Net proceeds to company		$ 25,879,000	$ 11,220,000	$ 369,061,000	$ 52,375,000
Common stock issued, amount		$ 27,389,000	10,395,000
Common stock available for issuance (in shares)		60,000,000		60,000,000
Equity Shelf Program
Class of Stock [Line Items]
Gross proceeds		$ 23,073,149	9,199,661	$ 99,023,464	50,976,456
Agent commissions		(230,731)	(91,997)	(990,234)	(509,765)
Net proceeds to company		$ 22,842,418	$ 9,107,664	$ 98,033,230	$ 50,466,691
Number of shares sold (in shares)		277,829	137,300	1,286,234	643,007
Weighted average price per share		$ 83.05	$ 67.00	$ 76.99	$ 79.28
Restricted Stock/Unit Plan, and Management Incentive Plan
Class of Stock [Line Items]
Common stock issued through Restricted Stock/Unit Plan, and Management Incentive Plan (in shares)		53,000
Dividend Reinvestment and Stock Purchase Plan
Class of Stock [Line Items]
Common stock issued through Restricted Stock/Unit Plan, and Management Incentive Plan (in shares)		34,000
Common stock issued, amount		$ 2,800,000
Subsequent Event
Class of Stock [Line Items]
Common stock available for issuance (in shares)						120,000,000

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Long-Term Debt - Schedule of Long-Term Debt (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Less: current maturities	$ (34,915)	$ (33,060)
Long-term debt, less current maturities	2,106,274	2,107,258
Long-term Debt, Current and Noncurrent Abstract
Less: current maturities	(34,915)	(33,060)
Long-term debt, less current maturities	2,106,274	2,107,258
Southwest Gas Corporation
Debt Instrument [Line Items]
Long-term debt, less current maturities	1,818,959	1,818,669
Long-term Debt, Current and Noncurrent Abstract
Long-term debt, less current maturities	$ 1,818,959	$ 1,818,669
Debentures | Notes, 4.45%, due 2020 | Southwest Gas Corporation
Long-term Debt, Current and Noncurrent Abstract
Debt instrument interest rate	4.45%	4.45%
Debentures | Notes, 6.1%, due 2041 | Southwest Gas Corporation
Long-term Debt, Current and Noncurrent Abstract
Debt instrument interest rate	6.10%	6.10%
Debentures | Notes, 3.875%, due 2022 | Southwest Gas Corporation
Long-term Debt, Current and Noncurrent Abstract
Debt instrument interest rate	3.875%	3.875%
Debentures | Notes, 4.875%, due 2043 | Southwest Gas Corporation
Long-term Debt, Current and Noncurrent Abstract
Debt instrument interest rate	4.875%	4.875%
Debentures | Notes, 3.8%, due 2046 | Southwest Gas Corporation
Long-term Debt, Current and Noncurrent Abstract
Debt instrument interest rate	3.80%	3.80%
Debentures | Notes, 3.7%, due 2028 | Southwest Gas Corporation
Long-term Debt, Current and Noncurrent Abstract
Debt instrument interest rate	3.70%	3.70%
Debentures | 8% Series, due 2026 | Southwest Gas Corporation
Long-term Debt, Current and Noncurrent Abstract
Debt instrument interest rate	8.00%	8.00%
Debentures | Medium-term notes, 7.78% series, due 2022 | Southwest Gas Corporation
Long-term Debt, Current and Noncurrent Abstract
Debt instrument interest rate	7.78%	7.78%
Debentures | Medium-term notes, 7.92% series, due 2027 | Southwest Gas Corporation
Long-term Debt, Current and Noncurrent Abstract
Debt instrument interest rate	7.92%	7.92%
Debentures | Medium-term notes, 6.76% series, due 2027 | Southwest Gas Corporation
Long-term Debt, Current and Noncurrent Abstract
Debt instrument interest rate	6.76%	6.76%
Carrying Amount
Debt Instrument [Line Items]
Long-term debt, less current maturities	$ 2,106,274	$ 2,107,258
Long-term Debt, Current and Noncurrent Abstract
Long-term debt, less current maturities	2,106,274	2,107,258
Carrying Amount | Southwest Gas Corporation
Debt Instrument [Line Items]
Less: current maturities	0	0
Long-term debt, less current maturities	1,818,959	1,818,669
Long-term Debt, Current and Noncurrent Abstract
Long-term debt	1,818,959	1,818,669
Less: current maturities	0	0
Long-term debt, less current maturities	1,818,959	1,818,669
Carrying Amount | Centuri
Debt Instrument [Line Items]
Less: current maturities	(34,915)	(33,060)
Long-term debt, less current maturities	287,315	288,589
Unamortized debt issuance costs	(1,343)	(1,414)
Long-term Debt, Current and Noncurrent Abstract
Long-term debt	322,230	321,649
Less: current maturities	(34,915)	(33,060)
Long-term debt, less current maturities	287,315	288,589
Centuri secured revolving credit facility	253,191	254,545
Carrying Amount | Centuri secured revolving credit facility | Centuri
Long-term Debt, Current and Noncurrent Abstract
Centuri secured revolving credit facility	6,361	0
Carrying Amount | Centuri term loan facility | Centuri
Long-term Debt, Current and Noncurrent Abstract
Centuri secured revolving credit facility	254,534	255,959
Carrying Amount | Centuri other debt obligations | Centuri
Long-term Debt, Current and Noncurrent Abstract
Centuri other debt obligations	62,678	67,104
Carrying Amount | Debentures | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	1,470,859	1,470,693
Unamortized discount and debt issuance costs	(11,641)	(11,807)
Carrying Amount | Debentures | Notes, 4.45%, due 2020 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	125,000	125,000
Carrying Amount | Debentures | Notes, 6.1%, due 2041 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	125,000	125,000
Carrying Amount | Debentures | Notes, 3.875%, due 2022 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	250,000	250,000
Carrying Amount | Debentures | Notes, 4.875%, due 2043 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	250,000	250,000
Carrying Amount | Debentures | Notes, 3.8%, due 2046 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	300,000	300,000
Carrying Amount | Debentures | Notes, 3.7%, due 2028 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	300,000	300,000
Carrying Amount | Debentures | 8% Series, due 2026 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	75,000	75,000
Carrying Amount | Debentures | Medium-term notes, 7.78% series, due 2022 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	25,000	25,000
Carrying Amount | Debentures | Medium-term notes, 7.92% series, due 2027 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	25,000	25,000
Carrying Amount | Debentures | Medium-term notes, 6.76% series, due 2027 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable	7,500	7,500
Carrying Amount | Debentures | Revolving credit facility and commercial paper | Southwest Gas Corporation
Debt Instrument [Line Items]
Line of credit facility	150,000	150,000
Carrying Amount | Industrial development revenue bonds | Southwest Gas Corporation
Debt Instrument [Line Items]
Unamortized discount and debt issuance costs	(1,900)	(2,024)
Unsecured debt	198,100	197,976
Carrying Amount | Industrial development revenue bonds | Tax-exempt Series A, due 2028 | Southwest Gas Corporation
Debt Instrument [Line Items]
Unsecured debt	50,000	50,000
Carrying Amount | Industrial development revenue bonds | 2003 Series A, due 2038 | Southwest Gas Corporation
Debt Instrument [Line Items]
Unsecured debt	50,000	50,000
Carrying Amount | Industrial development revenue bonds | 2008 Series A, due 2038 | Southwest Gas Corporation
Debt Instrument [Line Items]
Unsecured debt	50,000	50,000
Carrying Amount | Industrial development revenue bonds | 2009 Series A, due 2039 | Southwest Gas Corporation
Debt Instrument [Line Items]
Unsecured debt	50,000	50,000
Market Value | Centuri
Long-term Debt, Current and Noncurrent Abstract
Centuri secured revolving credit facility	257,579	260,135
Centuri other debt obligations	63,365	67,053
Market Value | Centuri secured revolving credit facility | Centuri
Long-term Debt, Current and Noncurrent Abstract
Centuri secured revolving credit facility	6,363	0
Market Value | Debentures | Notes, 4.45%, due 2020 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable, fair value disclosure	126,990	126,213
Market Value | Debentures | Notes, 6.1%, due 2041 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable, fair value disclosure	154,294	150,728
Market Value | Debentures | Notes, 3.875%, due 2022 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable, fair value disclosure	255,015	254,195
Market Value | Debentures | Notes, 4.875%, due 2043 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable, fair value disclosure	277,683	268,985
Market Value | Debentures | Notes, 3.8%, due 2046 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable, fair value disclosure	283,635	267,030
Market Value | Debentures | Notes, 3.7%, due 2028 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable, fair value disclosure	306,465	298,926
Market Value | Debentures | 8% Series, due 2026 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable, fair value disclosure	95,128	93,827
Market Value | Debentures | Medium-term notes, 7.78% series, due 2022 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable, fair value disclosure	27,715	27,497
Market Value | Debentures | Medium-term notes, 7.92% series, due 2027 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable, fair value disclosure	30,824	30,016
Market Value | Debentures | Medium-term notes, 6.76% series, due 2027 | Southwest Gas Corporation
Debt Instrument [Line Items]
Notes payable, fair value disclosure	8,845	8,651
Market Value | Debentures | Revolving credit facility and commercial paper | Southwest Gas Corporation
Debt Instrument [Line Items]
Line of credit facility, fair value	150,000	150,000
Market Value | Industrial development revenue bonds | Tax-exempt Series A, due 2028 | Southwest Gas Corporation
Debt Instrument [Line Items]
Unsecured debt	50,000	50,000
Market Value | Industrial development revenue bonds | 2003 Series A, due 2038 | Southwest Gas Corporation
Debt Instrument [Line Items]
Unsecured debt	50,000	50,000
Market Value | Industrial development revenue bonds | 2008 Series A, due 2038 | Southwest Gas Corporation
Debt Instrument [Line Items]
Unsecured debt, fair value	50,000	50,000
Market Value | Industrial development revenue bonds | 2009 Series A, due 2039 | Southwest Gas Corporation
Debt Instrument [Line Items]
Unsecured debt, fair value	$ 50,000	$ 50,000

XML

Long-Term Debt - Additional Information (Detail) - USD ($)	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Nov. 30, 2018	Oct. 31, 2018
Debt Instrument [Line Items]
Short term borrowings outstanding	$ 188,000,000	$ 152,000,000
Southwest Gas Corporation
Debt Instrument [Line Items]
Short term borrowings outstanding	188,000,000	$ 152,000,000
Southwest Gas Credit Facility
Debt Instrument [Line Items]
Credit facility maximum borrowing capacity	100,000,000
Southwest Gas Credit Facility | Southwest Gas Corporation
Debt Instrument [Line Items]
Credit facility maximum borrowing capacity	400,000,000
Line of credit designated as long term debt	150,000,000
Line of credit designated for working capital purposes	250,000,000
Long-term debt	150,000,000
Short term borrowings outstanding	$ 188,000,000
Southwest Gas Credit Facility | LIBOR | Southwest Gas Corporation
Debt Instrument [Line Items]
Applicable margin	1.00%
Southwest Gas Credit Facility | Alternative Base Rate | Southwest Gas Corporation
Debt Instrument [Line Items]
Applicable margin	0.00%
Commercial Paper Program | Southwest Gas Corporation
Debt Instrument [Line Items]
Credit facility maximum borrowing capacity	$ 50,000,000
Borrowings outstanding under facility	50,000,000
Secured Revolving Credit Facility and Term Loan | Centuri
Debt Instrument [Line Items]
Credit facility maximum borrowing capacity			$ 590,000,000	$ 450,000,000
Borrowings outstanding under facility	261,000,000
Debt secured by assets	$ 1,100,000,000
Line of Credit | Centuri
Debt Instrument [Line Items]
Credit facility maximum borrowing capacity			325,000,000
Centuri term loan facility | Centuri
Debt Instrument [Line Items]
Credit facility maximum borrowing capacity			$ 265,000,000

XML

Short-Term Debt (Detail) - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Short-term Debt [Line Items]
Short term borrowings outstanding	$ 188,000,000	$ 152,000,000
Southwest Gas Credit Facility
Short-term Debt [Line Items]
Credit facility maximum borrowing capacity	100,000,000
Southwest Gas Credit Facility | Credit Facility
Short-term Debt [Line Items]
Short term borrowings outstanding	0
Southwest Gas Corporation
Short-term Debt [Line Items]
Short term borrowings outstanding	188,000,000	$ 152,000,000
Southwest Gas Corporation | Southwest Gas Credit Facility
Short-term Debt [Line Items]
Credit facility maximum borrowing capacity	400,000,000
Short term borrowings outstanding	188,000,000
Line of credit designated for working capital purposes	$ 250,000,000

XML

Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income - Detailed Activities of Equity (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)	53,026,848
Beginning balance	$ 2,251,590	$ 1,812,403	$ 1,876,376
Common stock issuances	27,389	10,395
Net income (loss)	94,809	78,294
Foreign currency exchange translation adjustment	791	(911)
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax	619	895
FSIRS amounts reclassified to net income, net of tax	$ 635	635	$ 2,541	$ 2,190
Reclassification of excess deferred taxes		0
Ending balance (in shares)	53,391,731		53,391,731
Ending balance	$ 2,346,548	$ 1,876,376	$ 2,346,548	1,876,376
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance	81,831
Net income (loss)	575
Ending balance	$ 82,406		82,406
Dividends declared per share (in USD per share)	$ 0.545	$ 0.52
Southwest Gas Corporation
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	$ 1,782,460	$ 1,609,999	1,679,144
Net income (loss)	103,389	90,349
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax	619	895
FSIRS amounts reclassified to net income, net of tax	635	635	2,541	2,190
Reclassification of excess deferred taxes		0
Stock-based compensation	758	(734)
Dividends declared	(22,800)	(22,000)
Contributions from Southwest Gas Holdings, Inc.	22,842
Ending balance	$ 1,887,903	$ 1,679,144	$ 1,887,903	$ 1,679,144
Common Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)	53,026,000	48,090,000	48,337,000
Beginning balance	$ 54,656	$ 49,720	$ 49,967
Common stock issuances (in shares)	365,000	247,000
Common stock issuances	$ 365	$ 247
Other comprehensive income (loss):
Ending balance (in shares)	53,391,000	48,337,000	53,391,000	48,337,000
Ending balance	$ 55,021	$ 49,967	$ 55,021	$ 49,967
Common Stock | Southwest Gas Corporation
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance (in shares)	47,482,000	47,482,000	47,482,000
Beginning balance	$ 49,112	$ 49,112	$ 49,112
Other comprehensive income (loss):
Ending balance (in shares)	47,482,000	47,482,000	47,482,000	47,482,000
Ending balance	$ 49,112	$ 49,112	$ 49,112	$ 49,112
Additional Paid-in Capital
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	1,305,769	955,332	965,480
Common stock issuances	27,024	10,148
Other comprehensive income (loss):
Ending balance	1,332,793	965,480	1,332,793	965,480
Additional Paid-in Capital | Southwest Gas Corporation
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	1,065,242	948,767	948,199
Other comprehensive income (loss):
Stock-based compensation	918	(568)
Contributions from Southwest Gas Holdings, Inc.	22,842
Ending balance	1,089,002	948,199	1,089,002	948,199
Accumulated Other Comprehensive Income (Loss)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(52,668)	(47,682)	(56,363)
Foreign currency exchange translation adjustment	791	(911)
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax	619	895
FSIRS amounts reclassified to net income, net of tax	635	635
Reclassification of excess deferred taxes		(9,300)
Ending balance	(50,623)	(56,363)	(50,623)	(56,363)
Accumulated Other Comprehensive Income (Loss) | Southwest Gas Corporation
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(49,049)	(47,073)	(54,843)
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax	619	895
FSIRS amounts reclassified to net income, net of tax	635	635
Reclassification of excess deferred taxes		(9,300)
Ending balance	(47,795)	(54,843)	(47,795)	(54,843)
Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	944,285	857,398	920,454
Net income (loss)	94,809	79,091
Other comprehensive income (loss):
Reclassification of excess deferred taxes		9,300
Dividends declared	(29,285)	(25,335)
Ending balance	1,009,809	920,454	1,009,809	920,454
Retained Earnings | Southwest Gas Corporation
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	717,155	659,193	736,676
Net income (loss)	103,389	90,349
Other comprehensive income (loss):
Reclassification of excess deferred taxes		9,300
Stock-based compensation	(160)	(166)
Dividends declared	(22,800)	(22,000)
Ending balance	797,584	736,676	797,584	736,676
Non-controlling Interest
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance	(452)	(2,365)	(3,162)
Net income (loss)		(797)
Other comprehensive income (loss):
Ending balance	$ (452)	$ (3,162)	$ (452)	$ (3,162)

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Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income - Related Tax Effects Allocated to OCI (Detail) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other comprehensive income (loss) before reclassifications, net of tax	$ 791
Other comprehensive income (loss), before tax	2,441	$ 1,104	$ 7,965		$ 296
Other comprehensive income (loss), tax	(396)	(485)	(2,225)		(673)
Total other comprehensive income (loss), net of tax	$ 2,045	619	5,740		(377)
Effective income tax rate	24.00%			38.00%
Southwest Gas Corporation
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other comprehensive income (loss), before tax	$ 1,650	2,015	9,273		(344)
Other comprehensive income (loss), tax	(396)	(485)	(2,225)		(673)
Total other comprehensive income (loss), net of tax	1,254	1,530	7,048		(1,017)
Defined Benefit Plans
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other comprehensive income (loss), before tax	814	1,178	5,929		(3,689)
Other comprehensive income (loss), tax	(195)	(283)	(1,422)		482
Total other comprehensive income (loss), net of tax	619	895	4,507		(3,207)
Defined Benefit Plans | Southwest Gas Corporation
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other comprehensive income (loss), before tax	814
Other comprehensive income (loss), tax	(195)
Total other comprehensive income (loss), net of tax	619
Amortization of prior service cost
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from AOCI, before Tax	317	334	1,318		1,335
Reclassification from AOCI, tax	(76)	(80)	(316)		(460)
Reclassification from AOCI, net of tax	241	254	1,002		875
Other comprehensive income (loss), before tax	317
Other comprehensive income (loss), tax	(76)
Total other comprehensive income (loss), net of tax	241
Amortization of prior service cost | Southwest Gas Corporation
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other comprehensive income (loss), before tax	317
Other comprehensive income (loss), tax	(76)
Total other comprehensive income (loss), net of tax	241
Net actuarial gain/(loss)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other comprehensive income (loss) before reclassifications, before tax			(20,426)		(43,027)
Other comprehensive income (loss) before reclassifications, tax			4,902		10,326
Other comprehensive income (loss) before reclassifications, net of tax			(15,524)		(32,701)
Reclassification from AOCI, before Tax	5,844	8,404	31,057		27,488
Reclassification from AOCI, tax	(1,403)	(2,017)	(7,454)		(9,269)
Reclassification from AOCI, net of tax	4,441	6,387	23,603		18,219
Other comprehensive income (loss), before tax	5,844
Other comprehensive income (loss), tax	(1,403)
Total other comprehensive income (loss), net of tax	4,441
Net actuarial gain/(loss) | Southwest Gas Corporation
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other comprehensive income (loss), before tax	5,844
Other comprehensive income (loss), tax	(1,403)
Total other comprehensive income (loss), net of tax	4,441
Regulatory adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from AOCI, before Tax	(5,347)	(7,560)	(6,020)		10,515
Reclassification from AOCI, tax	1,284	1,814	1,446		(115)
Reclassification from AOCI, net of tax	(4,063)	(5,746)	(4,574)		10,400
Other comprehensive income (loss), before tax	(5,347)
Other comprehensive income (loss), tax	1,284
Total other comprehensive income (loss), net of tax	(4,063)
Regulatory adjustment | Southwest Gas Corporation
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other comprehensive income (loss), before tax	(5,347)
Other comprehensive income (loss), tax	1,284
Total other comprehensive income (loss), net of tax	(4,063)
FSIRS
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from AOCI, before Tax	836	837	3,344		3,345
Reclassification from AOCI, tax	(201)	(202)	(803)		(1,155)
Reclassification from AOCI, net of tax	635	635	2,541		2,190
Other comprehensive income (loss), before tax	836	837	3,344		3,345
Other comprehensive income (loss), tax	(201)	(202)	(803)		(1,155)
Total other comprehensive income (loss), net of tax	635	635	2,541		2,190
FSIRS | Southwest Gas Corporation
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassification from AOCI, before Tax	836
Reclassification from AOCI, tax	(201)
Reclassification from AOCI, net of tax	635
Other comprehensive income (loss), before tax	836
Other comprehensive income (loss), tax	(201)
Total other comprehensive income (loss), net of tax	635
Foreign Currency Items
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other comprehensive income (loss) before reclassifications, before tax	791	(911)	(1,308)		640
Other comprehensive income (loss) before reclassifications, tax	0	0	0		0
Other comprehensive income (loss) before reclassifications, net of tax	791	$ (911)	$ (1,308)		$ 640
Other comprehensive income (loss), before tax	791
Total other comprehensive income (loss), net of tax	$ 791

XML

Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income - Additional Information (Detail) $ in Millions	Mar. 31, 2019 USD ($)
Equity [Abstract]
Amount of FSIRS existing AOCI losses expected to reclassified income in next twelve months	$ 2.5

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Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income - AOCI Rollforward (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 2018
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ 2,251,590	$ 1,812,403	$ 1,876,376	$ 1,812,403
Beginning balance, attributable to parent	2,252,042
Other comprehensive income (loss) before reclassifications, net of tax	791
Other comprehensive income (loss), before tax	2,441	1,104	7,965		$ 296
Other comprehensive income (loss), tax	(396)	(485)	(2,225)		(673)
Total other comprehensive income (loss), net of tax	2,045	619	5,740		(377)
Ending balance, attributable to parent	2,347,000		2,347,000	2,252,042
Ending balance	$ 2,346,548	1,876,376	2,346,548	$ 2,251,590	1,876,376
Effective income tax rate	24.00%			38.00%
Defined Benefit Plans
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance, before tax	$ (55,227)
Beginning balance, tax	13,254
Beginning balance	(41,973)
Other comprehensive income (loss), before tax	814	1,178	5,929		(3,689)
Other comprehensive income (loss), tax	(195)	(283)	(1,422)		482
Total other comprehensive income (loss), net of tax	619	895	4,507		(3,207)
Ending balance, before tax	(54,413)		(54,413)	$ (55,227)
Ending balance, tax	13,059		13,059	13,254
Ending balance	(41,354)		(41,354)	(41,973)
Amortization of prior service cost
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Reclassification from AOCI, before Tax	317	334	1,318		1,335
Reclassification from AOCI, tax	(76)	(80)	(316)		(460)
Reclassification from AOCI, net of tax	241	254	1,002		875
Other comprehensive income (loss), before tax	317
Other comprehensive income (loss), tax	(76)
Total other comprehensive income (loss), net of tax	241
Amortization of net actuarial loss
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income (loss) before reclassifications, before tax			(20,426)		(43,027)
Other comprehensive income (loss) before reclassifications, net of tax			(15,524)		(32,701)
Reclassification from AOCI, before Tax	5,844	8,404	31,057		27,488
Reclassification from AOCI, tax	(1,403)	(2,017)	(7,454)		(9,269)
Reclassification from AOCI, net of tax	4,441	6,387	23,603		18,219
Other comprehensive income (loss), before tax	5,844
Other comprehensive income (loss), tax	(1,403)
Total other comprehensive income (loss), net of tax	4,441
Regulatory adjustment
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Reclassification from AOCI, before Tax	(5,347)	(7,560)	(6,020)		10,515
Reclassification from AOCI, tax	1,284	1,814	1,446		(115)
Reclassification from AOCI, net of tax	(4,063)	(5,746)	(4,574)		10,400
Other comprehensive income (loss), before tax	(5,347)
Other comprehensive income (loss), tax	1,284
Total other comprehensive income (loss), net of tax	(4,063)
FSIRS
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance, before tax	(9,310)
Beginning balance, tax	2,234
Beginning balance	(7,076)
Reclassification from AOCI, before Tax	836	837	3,344		3,345
Reclassification from AOCI, tax	(201)	(202)	(803)		(1,155)
Reclassification from AOCI, net of tax	635	635	2,541		2,190
Other comprehensive income (loss), before tax	836	837	3,344		3,345
Other comprehensive income (loss), tax	(201)	(202)	(803)		(1,155)
Total other comprehensive income (loss), net of tax	635	635	2,541		2,190
Ending balance, before tax	(8,474)		(8,474)	(9,310)
Ending balance, tax	2,033		2,033	2,234
Ending balance	(6,441)		(6,441)	(7,076)
Foreign Currency Items
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance, before tax	(3,619)
Beginning balance	(3,619)
Other comprehensive income (loss) before reclassifications, before tax	791	(911)	(1,308)		640
Other comprehensive income (loss) before reclassifications, net of tax	791	(911)	(1,308)		640
Other comprehensive income (loss), before tax	791
Total other comprehensive income (loss), net of tax	791
Ending balance, before tax	(2,828)		(2,828)	(3,619)
Ending balance	(2,828)		(2,828)	(3,619)
AOCI Attributable to Parent
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(52,668)	(47,682)	(56,363)	(47,682)
Ending balance	(50,623)	(56,363)	(50,623)	(52,668)	(56,363)
Southwest Gas Corporation
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	1,782,460	1,609,999	1,679,144	1,609,999
Beginning balance, attributable to parent	1,782,460
Other comprehensive income (loss), before tax	1,650	2,015	9,273		(344)
Other comprehensive income (loss), tax	(396)	(485)	(2,225)		(673)
Total other comprehensive income (loss), net of tax	1,254	1,530	7,048		(1,017)
Ending balance, attributable to parent	1,887,903		1,887,903	1,782,460
Ending balance	1,887,903	1,679,144	1,887,903	1,782,460	1,679,144
Southwest Gas Corporation | Defined Benefit Plans
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance, attributable to parent, before tax	(55,227)
Beginning balance, attributable to parent, tax	13,254
Beginning balance, attributable to parent	(41,973)
Other comprehensive income (loss), before tax	814
Other comprehensive income (loss), tax	(195)
Total other comprehensive income (loss), net of tax	619
Ending balance, attributable to parent, before tax	(54,413)		(54,413)	(55,227)
Ending balance, attributable to parent, tax	13,059		13,059	13,254
Ending balance, attributable to parent	(41,354)		(41,354)	(41,973)
Southwest Gas Corporation | Amortization of prior service cost
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income (loss), before tax	317
Other comprehensive income (loss), tax	(76)
Total other comprehensive income (loss), net of tax	241
Southwest Gas Corporation | Amortization of net actuarial loss
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income (loss), before tax	5,844
Other comprehensive income (loss), tax	(1,403)
Total other comprehensive income (loss), net of tax	4,441
Southwest Gas Corporation | Regulatory adjustment
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Other comprehensive income (loss), before tax	(5,347)
Other comprehensive income (loss), tax	1,284
Total other comprehensive income (loss), net of tax	(4,063)
Southwest Gas Corporation | FSIRS
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance, attributable to parent, before tax	(9,310)
Beginning balance, attributable to parent, tax	2,234
Beginning balance, attributable to parent	(7,076)
Reclassification from AOCI, before Tax	836
Reclassification from AOCI, tax	(201)
Reclassification from AOCI, net of tax	635
Other comprehensive income (loss), before tax	836
Other comprehensive income (loss), tax	(201)
Total other comprehensive income (loss), net of tax	635
Ending balance, attributable to parent, before tax	(8,474)		(8,474)	(9,310)
Ending balance, attributable to parent, tax	2,033		2,033	2,234
Ending balance, attributable to parent	(6,441)		(6,441)	(7,076)
Southwest Gas Corporation | AOCI Attributable to Parent
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(49,049)	(47,073)	(54,843)	(47,073)
Beginning balance, attributable to parent	(49,049)
Ending balance, attributable to parent	(47,795)		(47,795)	(49,049)
Ending balance	$ (47,795)	$ (54,843)	$ (47,795)	$ (49,049)	$ (54,843)

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Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income - Amounts Recognized Before Tax, Defined Benefit Plans (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Equity [Abstract]
Net actuarial (loss) gain	$ (429,520)	$ (435,364)
Prior service cost	(2,716)	(3,033)
Less: amount recognized in regulatory assets	377,823	383,170
Recognized in AOCI	$ (54,413)	$ (55,227)

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Segment Information - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019 Segment
Segment Reporting [Abstract]
Number of segments	2

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Segment Information - Schedule of Reporting Information (Detail) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019	Mar. 31, 2018
Segment Reporting Information [Line Items]
Revenues	$ 833,539	$ 754,330	$ 2,959,222	$ 2,648,385
Segment net income (loss)	94,809	79,091	197,995	203,624
Operating Segments
Segment Reporting Information [Line Items]
Revenues	794,866	727,172	2,811,793	2,545,364
Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues	38,673	27,158	147,429	103,021
Segment Reconciling Items
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Segment net income (loss)	(549)	(257)	(1,834)	(1,298)
Natural Gas Operations
Segment Reporting Information [Line Items]
Revenues	520,677	494,313	1,384,092	1,334,019
Segment net income (loss)	103,389	90,349	151,882	170,229
Natural Gas Operations | Operating Segments
Segment Reporting Information [Line Items]
Revenues	520,677	494,313	1,384,092	1,334,019
Natural Gas Operations | Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues	0	0	0	0
Utility Infrastructure Services
Segment Reporting Information [Line Items]
Revenues	312,862	260,017	1,575,130	1,314,366
Segment net income (loss)	(8,031)	(11,001)	47,947	34,693
Utility Infrastructure Services | Operating Segments
Segment Reporting Information [Line Items]
Revenues	274,189	232,859	1,427,701	1,211,345
Utility Infrastructure Services | Intersegment Eliminations
Segment Reporting Information [Line Items]
Revenues	$ 38,673	$ 27,158	$ 147,429	$ 103,021

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Redeemable Noncontrolling Interests - Additional Information (Detail)	Mar. 31, 2019	Nov. 30, 2018
Noncontrolling Interest [Line Items]
Percentage of interest retained by noncontrolling party subject to election	100.00%
Linetec
Noncontrolling Interest [Line Items]
Ownership percentage by noncontrolling owners		20.00%

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Redeemable Noncontrolling Interests - Summary of Redeemable Noncontrolling Interest (Detail) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Movement In Redeemable Noncontrolling Interest [Roll Forward]
Balance, December 31, 2018	$ 81,831
Net income attributable to redeemable noncontrolling interest	(575)
Balance, March 31, 2019	$ 82,406

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Business Acquisitions - Narrative (Detail) - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Mar. 31, 2019	Nov. 30, 2018
Linetec
Business Acquisition [Line Items]
Acquisition costs	$ 0	$ 6,900,000
Centuri | Linetec
Business Acquisition [Line Items]
Percentage of voting interests acquired			80.00%
Linetec
Business Acquisition [Line Items]
Ownership percentage by noncontrolling owners			20.00%

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Business Acquisitions - Summary of Fair Values of Assets Acquired and Liabilities Assumed (Detail) - USD ($) $ in Thousands	4 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Nov. 30, 2018
Fair Values of Assets Acquired and Liabilities Assumed
Goodwill	$ 364,482	$ 359,045
Linetec
Fair Values of Assets Acquired and Liabilities Assumed
Cash and cash equivalents	3,900		$ 3,900
Accounts receivable	32,300		32,800
Revenue earned on contracts in progress in excess of billings	23,300		21,600
Prepaid expenses and other current assets	1,300		1,100
Property and equipment	88,900		89,400
Intangible assets	89,300		89,300
Goodwill	191,800		188,500
Total assets acquired	430,800		426,600
Accounts payable	8,000		8,000
Accrued liabilities	8,500		6,900
Deferred compensation and related accrued taxes	3,400		3,400
Redeemable noncontrolling interest	81,700		81,700
Total liabilities assumed and noncontrolling interest	101,600		100,000
Net assets acquired	329,200		$ 326,600
Measurement Period Adjustments
Accounts receivable, measurement period adjustments	(500)
Revenue earned on contracts in progress in excess of billings, measurement period adjustments	1,700
Prepaid expenses and other current assets, measurement period adjustments	200
Property and equipment, measurement period adjustments	(500)
Intangible assets, measurement period adjustments	0
Goodwill, measurement period adjustments	3,300
Total assets acquired, measurement period adjustments	4,200
Accrued liabilities, measurement period adjustments	1,600
Total liabilities assumed and noncontrolling interest, measurement period adjustments	1,600
Net assets acquired, measurement period adjustments	$ 2,600