UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~September~~June 30, ~~2017~~2018


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

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

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 the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether each registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of RegulationS-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ☒ No ☐

Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, anon-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 Rule12b-2 of the Exchange Act.

Southwest Gas Holdings, Inc.:

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:

Indicate by check mark whether each registrant is a shell company (as defined in Rule12b-2 of the Exchange Act). Yes ☐ No ☒

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

Southwest Gas Holdings, Inc. Common Stock, $1 Par Value, ~~47,731,840~~49,133,829 shares as of ~~October 27, 2017.~~July 31, 2018.

All of the outstanding shares of common stock ($1 par value) of Southwest Gas Corporation were held by Southwest Gas Holdings, Inc. as of January 1, 2017.

SOUTHWEST GAS CORPORATION MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION (H)(1)(a) and (b) OFFORM10-Q AND IS THEREFORE FILING THIS REPORT WITH THE REDUCED DISCLOSURE FORMAT AS PERMITTED BY GENERAL INSTRUCTION H(2).


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

FILING FORMAT

This quarterly report onForm 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 Form10-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 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.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

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)


							JUNE 30,			DECEMBER 31,
	SEPTEMBER 30, 2017			DECEMBER 31, 2016			2018			2017
ASSETS
Utility plant:
Gas plant	$	6,440,547		$	6,193,564		$	6,810,737		$	6,629,644
Less: accumulated depreciation		(2,218,796	)		(2,172,966	)		(2,260,793	)		(2,231,242	)
Acquisition adjustments, net		81			196
Construction work in progress		164,030			111,177			167,114			125,248

Net utility plant		4,385,862			4,131,971			4,717,058			4,523,650

Other property and investments		369,303			342,343			462,236			428,180

Current assets:
Cash and cash equivalents		59,152			28,066			34,730			43,622
Accounts receivable, net of allowances		301,792			285,145			357,881			347,375
Accrued utility revenue		34,100			76,200			34,200			78,200
Income taxes receivable, net		5,462			4,455			18,256			7,960
Deferred purchased gas costs		6,230			2,608			—			14,581
Prepaids and other current assets		132,182			136,833			250,992			165,294

Total current assets		538,918			533,307			696,059			657,032

Noncurrent assets:
Goodwill		147,865			139,983			174,233			179,314
Deferred income taxes		1,467			1,288			1,252			1,480
Deferred charges and other assets		411,655			432,234			425,555			447,410

Total noncurrent assets		560,987			573,505			601,040			628,204

Total assets	$	5,855,070		$	5,581,126		$	6,476,393		$	6,237,066

CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock, $1 par (authorized—60,000,000 shares; issued and outstanding—47,731,840 and 47,482,068 shares)	$	49,362		$	49,112
Common stock, $1 par (authorized - 60,000,000 shares; issued and outstanding - 49,126,254 and 48,090,470 shares)							$	50,756		$	49,720
Additionalpaid-in capital		924,213			903,123			1,021,508			955,332
Accumulated other comprehensive income (loss), net		(42,818	)		(48,008	)		(55,520	)		(47,682	)
Retained earnings		784,934			759,263			916,275			857,398

Total Southwest Gas Holdings, Inc. equity		1,715,691			1,663,490			1,933,019			1,814,768
Noncontrolling interest		(2,295	)		(2,217	)		(452	)		(2,365	)

Total equity		1,713,396			1,661,273			1,932,567			1,812,403
Redeemable noncontrolling interest		—			22,590
Long-term debt, less current maturities		1,731,981			1,549,983			2,037,743			1,798,576

Total capitalization		3,445,377			3,233,846			3,970,310			3,610,979

Current liabilities:
Current maturities of long-term debt		28,453			50,101			31,928			25,346
Short-term debt		110,500			—			22,500			214,500
Accounts payable		159,382			184,669			188,156			228,315
Customer deposits		70,162			72,296			69,247			69,781
Income taxes payable		1,543			1,909			—			5,946
Accrued general taxes		48,998			42,921			42,826			43,879
Accrued interest		24,543			17,939			20,512			17,870
Deferred purchased gas costs		14,971			90,476			26,365			6,841
Other current liabilities		197,854			168,064			262,113			203,403

Total current liabilities		656,406			628,375			663,647			815,881

Deferred income taxes and other credits:
Deferred income taxes and investment tax credits		894,011			840,653			510,536			476,960
Accumulated removal costs		312,000			308,000			319,000			315,000
Other deferred credits and other long-term liabilities		547,276			570,252			1,012,900			1,018,246

Total deferred income taxes and other credits		1,753,287			1,718,905			1,842,436			1,810,206


Total capitalization and liabilities	$	5,855,070		$	5,581,126		$	6,476,393		$	6,237,066

The accompanying notes are an integral part of these statements.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(In thousands, except per share amounts)

(Unaudited)


	THREE MONTHS ENDED						NINE MONTHS ENDED						TWELVE MONTHS ENDED						THREE MONTHS ENDED						SIX MONTHS ENDED						TWELVE MONTHS ENDED
	SEPTEMBER 30,						SEPTEMBER 30,						SEPTEMBER 30,						JUNE 30,						JUNE 30,						JUNE 30,
	2017			2016			2017			2016			2017			2016			2018			2017			2018			2017			2018			2017
Operating revenues:
Gas operating revenues	$	213,059		$	200,179		$	935,823		$	980,927		$	1,276,308		$	1,376,388		$	275,679		$	260,162		$	769,992		$	722,764		$	1,349,536		$	1,263,428
Construction revenues		380,094			339,790			872,536			838,038			1,173,576			1,127,982			395,204			300,307			655,221			492,442			1,409,263			1,133,272

Total operating revenues		593,153			539,969			1,808,359			1,818,965			2,449,884			2,504,370			670,883			560,469			1,425,213			1,215,206			2,758,799			2,396,700

Operating expenses:
Net cost of gas sold		45,539			39,056			261,839			324,072			334,888			460,836			83,466			69,421			269,198			216,300			407,943			328,405
Operations and maintenance		102,278			102,438			314,488			301,979			414,233			400,222			105,435			98,203			207,786			202,498			398,051			394,802
Depreciation and amortization		58,529			69,845			189,089			217,764			260,457			286,977			61,307			58,082			123,785			130,560			244,176			271,773
Taxes other than income taxes		14,046			12,480			43,325			39,480			56,221			51,810			14,666			14,497			29,923			29,279			58,590			54,655
Construction expenses		342,629			300,611			806,586			757,919			1,073,090			1,009,188			352,671			272,001			611,623			463,957			1,296,629			1,031,072

Total operating expenses		563,021			524,430			1,615,327			1,641,214			2,138,889			2,209,033			617,545			512,204			1,242,315			1,042,594			2,405,389			2,080,707

Operating income		30,132			15,539			193,032			177,751			310,995			295,337			53,338			48,265			182,898			172,612			353,410			315,993

Other income and (expenses):
Net interest deductions		(19,494	)		(18,158	)		(56,863	)		(54,100	)		(76,423	)		(71,884	)		(23,652	)		(18,655	)		(46,283	)		(37,369	)		(86,978	)		(75,087	)
Other income (deductions)		2,876			2,565			8,788			6,756			11,501			10,861			(2,706	)		(2,810	)		(7,040	)		(3,800	)		(9,270	)		(8,401	)

Total other income and (expenses)		(16,618	)		(15,593	)		(48,075	)		(47,344	)		(64,922	)		(61,023	)		(26,358	)		(21,465	)		(53,323	)		(41,169	)		(96,248	)		(83,488	)

Income (loss) before income taxes		13,514			(54	)		144,957			130,407			246,073			234,314
Income tax expense (benefit)		3,094			(2,961	)		47,411			43,046			82,833			80,255
Income before income taxes																				26,980			26,800			129,575			131,443			257,162			232,505
Income tax expense																				5,429			8,679			29,730			44,317			50,501			76,778

Net income		10,420			2,907			97,546			87,361			163,240			154,059			21,551			18,121			99,845			87,126			206,661			155,727
Net income attributable to noncontrolling interests		216			435			170			500			684			1,079
Net income (loss) attributable to noncontrolling interest																				—			257			(797	)		(46	)		(650	)		903

Net income attributable to Southwest Gas Holdings, Inc.	$	10,204		$	2,472		$	97,376		$	86,861		$	162,556		$	152,980		$	21,551		$	17,864		$	100,642		$	87,172		$	207,311		$	154,824

Basic earnings per share	$	0.21		$	0.05		$	2.05		$	1.83		$	3.42		$	3.22		$	0.44		$	0.38		$	2.07		$	1.83		$	4.29		$	3.26

Diluted earnings per share	$	0.21		$	0.05		$	2.03		$	1.82		$	3.39		$	3.20		$	0.44		$	0.37		$	2.07		$	1.82		$	4.28		$	3.24

Dividends declared per share	$	0.495		$	0.450		$	1.485		$	1.350		$	1.935		$	1.755		$	0.520		$	0.495		$	1.040		$	0.990		$	2.030		$	1.890

Average number of common shares outstanding		47,628			47,481			47,577			47,464			47,553			47,442
Average shares outstanding (assuming dilution)		47,986			47,830			47,912			47,802			47,896			47,787
Average number of common shares																				48,826			47,571			48,622			47,550			48,338			47,516
Average shares (assuming dilution)																				48,880			47,884			48,671			47,874			48,387			47,857

The accompanying notes are an integral part of these statements.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Thousands of dollars)

(Unaudited)


	THREE MONTHS ENDED						NINE MONTHS ENDED						TWELVE MONTHS ENDED						THREE MONTHS ENDED						SIX MONTHS ENDED						TWELVE MONTHS ENDED
	SEPTEMBER 30,						SEPTEMBER 30,						SEPTEMBER 30,						JUNE 30,						JUNE 30,						JUNE 30,
	2017			2016			2017			2016			2017			2016			2018			2017			2018			2017			2018			2017
Net income	$	10,420		$	2,907		$	97,546		$	87,361		$	163,240		$	154,059		$	21,551		$	18,121		$	99,845		$	87,126		$	206,661		$	155,727

Other comprehensive income (loss), net of tax
Defined benefit pension plans:
Net actuarial gain (loss)		—			—			—			—			(14,118	)		(18,922	)		—			—			—			—			(32,701	)		(14,118	)
Amortization of prior service cost		207			207			621			621			828			828			254			207			508			414			922			828
Amortization of net actuarial loss		3,944			4,196			11,832			12,586			16,027			17,915			6,387			3,944			12,774			7,888			20,662			16,279
Regulatory adjustment		(3,555	)		(3,796	)		(10,667	)		(11,388	)		(2,741	)		(404	)		(5,744	)		(3,556	)		(11,490	)		(7,112	)		8,212			(2,982	)

Net defined benefit pension plans		596			607			1,786			1,819			(4	)		(583	)		897			595			1,792			1,190			(2,905	)		7

Forward-starting interest rate swaps:
Amounts reclassified into net income		518			518			1,554			1,556			2,073		��	2,073			636			518			1,271			1,036			2,308			2,073

Net forward-starting interest rate swaps		518			518			1,554			1,556			2,073			2,073			636			518			1,271			1,036			2,308			2,073

Foreign currency translation adjustments		1,012			(238	)		1,861			614			1,408			233			(690	)		629			(1,601	)		849			(679	)		158

Total other comprehensive income, net of tax		2,126			887			5,201			3,989			3,477			1,723
Total other comprehensive income (loss), net of tax																				843			1,742			1,462			3,075			(1,276	)		2,238

Comprehensive income		12,546			3,794			102,747			91,350			166,717			155,782			22,394			19,863			101,307			90,201			205,385			157,965
Comprehensive income attributable to noncontrolling interests		198			427			181			521			679			1,089
Comprehensive income (loss) attributable to noncontrolling interests																				—			279			(797	)		(17	)		(668	)		908

Comprehensive income attributable to Southwest Gas Holdings, Inc.	$	12,348		$	3,367		$	102,566		$	90,829		$	166,038		$	154,693		$	22,394		$	19,584		$	102,104		$	90,218		$	206,053		$	157,057

The accompanying notes are an integral part of these statements.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of dollars)

(Unaudited)


	NINE MONTHS ENDED						TWELVE MONTHS ENDED						SIX MONTHS ENDED						TWELVE MONTHS ENDED
	SEPTEMBER 30						SEPTEMBER 30						JUNE 30,						JUNE 30,
	2017			2016			2017			2016			2018			2017			2018			2017
CASH FLOW FROM OPERATING ACTIVITIES:
Net income	$	97,546		$	87,361		$	163,240		$	154,059		$	99,845		$	87,126		$	206,661		$	155,727
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		189,089			217,764			260,457			286,977			123,785			130,560			244,176			271,773
Deferred income taxes		49,409			43,702			74,439			86,526			33,318			47,836			48,871			70,652
Changes in current assets and liabilities:
Accounts receivable, net of allowances		(15,330	)		28,531			(13,765	)		(17,889	)		(12,704	)		3,545			(57,196	)		(19,266	)
Accrued utility revenue		42,100			41,700			(1,100	)		(800	)		44,000			42,600			(600	)		(1,100	)
Deferred purchased gas costs		(79,127	)		81,389			(114,658	)		79,460			34,105			(73,196	)		11,693			(111,627	)
Accounts payable		(26,771	)		(24,942	)		19,866			10,445			(44,465	)		(50,447	)		25,943			4,606
Accrued taxes		4,689			(7,055	)		38,084			(11,033	)		(17,350	)		(6,100	)		(9,138	)		32,361
Other current assets and liabilities		43,044			12,022			3,590			22,034			(16,806	)		20,390			(45,399	)		(14,803	)
Gains on sale		(1,452	)		(4,117	)		(4,483	)		(4,200	)		(250	)		(1,427	)		(3,019	)		(5,833	)
Changes in undistributed stock compensation		9,199			4,347			10,308			5,142			3,300			7,731			6,457			9,673
AFUDC		(2,077	)		(1,893	)		(2,473	)		(2,890	)		(586	)		(1,109	)		(1,773	)		(2,116	)
Changes in other assets and deferred charges		(14,470	)		3,926			(1,436	)		4,183			(5,122	)		(11,521	)		(15,870	)		5,216
Changes in other liabilities and deferred credits		3,395			(4,813	)		(10,239	)		702			5,952			2,204			7,979			(13,741	)

Net cash provided by operating activities		299,244			477,922			421,830			612,716			247,022			198,192			418,785			381,522

CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions		(449,998	)		(404,388	)		(575,141	)		(555,819	)		(339,011	)		(262,234	)		(700,426	)		(526,893	)
Acquisition of businesses, net of cash acquired		—			(17,000	)		—			(17,000	)		(4,209	)		—			(98,413	)		—
Changes in customer advances		(1,951	)		5,445			504			9,445			8,158			(1,430	)		9,911			4,318
Miscellaneous inflows		9,160			7,965			14,234			4,726			2,564			6,905			12,304			15,818

Net cash used in investing activities		(442,789	)		(407,978	)		(560,403	)		(558,648	)		(332,498	)		(256,759	)		(776,624	)		(506,757	)

CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net		11,563			530			11,505			507			69,139			(96	)		110,390			(111	)
Dividends paid		(68,503	)		(61,950	)		(89,870	)		(81,138	)		(48,985	)		(44,949	)		(96,166	)		(87,683	)
Centuri distribution to redeemable noncontrolling interest		(204	)		(99	)		(544	)		(198	)		—			(204	)		—			(544	)
Issuance of long-term debt, net		104,308			408,946			119,308			420,946			455,398			80,579			781,882			408,397
Retirement of long-term debt		(100,240	)		(196,351	)		(159,162	)		(240,999	)		(100,776	)		(60,041	)		(379,704	)		(262,348	)
Change in credit facility and commercial paper		145,000			(150,000	)		150,000			(97,000	)		(102,000	)		87,000			(44,000	)		89,500
Change in short-term debt		110,500			(18,000	)		110,500			—			(192,000	)		2,500			20,000			2,500
Principal payments on capital lease obligations		(796	)		(1,125	)		(1,025	)		(1,449	)		(316	)		(573	)		(723	)		(1,092	)
Redemption of Centuri shares from noncontrolling parties		(23,000	)		—			(23,000	)		—			—			—			(23,000	)		—
Withholding remittance—share-based compensation		(3,176	)		(2,119	)		(3,176	)		(2,164	)
Withholding remittance - share-based compensation														(2,854	)		(3,120	)		(2,910	)		(3,271	)
Other		(1,104	)		(605	)		(2,068	)		(60	)		(898	)		(1,036	)		(2,936	)		(2,481	)

Net cash provided by (used in) financing activities		174,348			(20,773	)		112,468			(1,555	)
Net cash provided by financing activities														76,708			60,060			362,833			142,867

Effects of currency translation on cash and cash equivalents		283			(14	)		103			(318	)		(124	)		143			34			(56	)

Change in cash and cash equivalents		31,086			49,157			(26,002	)		52,195			(8,892	)		1,636			5,028			17,576
Cash and cash equivalents at beginning of period		28,066			35,997			85,154			32,959			43,622			28,066			29,702			12,126

Cash and cash equivalents at end of period	$	59,152		$	85,154		$	59,152		$	85,154		$	34,730		$	29,702		$	34,730		$	29,702

Supplemental information:
Interest paid, net of amounts capitalized	$	45,771		$	47,134		$	66,077		$	68,445		$	40,082		$	35,182		$	76,843		$	69,398

Income taxes paid (received)		3,687			6,530			(21,875	)		9,899		$	16,507		$	3,043		$	19,137		$	(20,726	)

The accompanying notes are an integral part of these statements.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Thousands of dollars)

(Unaudited)


	SEPTEMBER 30,			DECEMBER 31,			JUNE 30,			DECEMBER 31,
	2017			2016			2018			2017
ASSETS
Utility plant:
Gas plant	$	6,440,547		$	6,193,564		$	6,810,737		$	6,629,644
Less: accumulated depreciation		(2,218,796	)		(2,172,966	)		(2,260,793	)		(2,231,242	)
Acquisition adjustments, net		81			196
Construction work in progress		164,030			111,177			167,114			125,248

Net utility plant		4,385,862			4,131,971			4,717,058			4,523,650

Other property and investments		115,841			108,569			120,476			119,114

Current assets:
Cash and cash equivalents		46,467			19,024			20,900			37,946
Accounts receivable, net of allowances		68,028			111,845			83,645			119,748
Accrued utility revenue		34,100			76,200			34,200			78,200
Income taxes receivable, net		6,440			4,455			6,752			—
Deferred purchased gas costs		6,230			2,608			—			14,581
Prepaids and other current assets		118,587			126,363			233,441			153,771

Total current assets		279,852			340,495			378,938			404,246

Noncurrent assets:
Goodwill		10,095			10,095			10,095			10,095
Deferred charges and other assets		393,942			410,625			410,553			425,564
Discontinued operations—construction services—assets		—			579,371

Total noncurrent assets		404,037			1,000,091			420,648			435,659

Total assets	$	5,185,592		$	5,581,126		$	5,637,120		$	5,482,669

CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock	$	49,112		$	49,112		$	49,112		$	49,112
Additionalpaid-in capital		917,581			897,346			1,006,065			948,767
Accumulated other comprehensive income (loss), net		(42,299	)		(45,639	)		(53,310	)		(47,073	)
Retained earnings		606,007			767,061			717,126			659,193

Total Southwest Gas Corporation equity		1,530,401			1,667,880			1,718,993			1,609,999
Discontinued operations—construction servicesnon-owner equity		—			15,983
Long-term debt, less current maturities		1,520,790			1,375,080			1,716,307			1,521,031

Total capitalization		3,051,191			3,058,943			3,435,300			3,131,030

Current liabilities:
Current maturities of long-term debt		—			25,000
Short-term debt		83,000			—			—			191,000
Accounts payable		92,257			138,229			102,579			158,474
Customer deposits		70,162			72,296			69,247			69,781
Income taxes payable, net								—			4,971
Accrued general taxes		48,998			42,921			42,826			43,879
Accrued interest		24,406			17,395			20,441			17,171
Deferred purchased gas costs		14,971			90,476			26,365			6,841
Payable to parent		2,560			—			285			194
Other current liabilities		109,705			95,999			162,207			108,785

Total current liabilities		446,059			482,316			423,950			601,096

Deferred income taxes and other credits:
Deferred income taxes and investment tax credits, net		853,682			806,109			473,581			445,243
Accumulated removal costs		312,000			308,000			319,000			315,000
Other deferred credits and other long-term liabilities		522,660			545,143			985,289			990,300
Discontinued operations—construction services—liabilities		—			380,615

Total deferred income taxes and other credits		1,688,342			2,039,867			1,777,870			1,750,543

Total capitalization and liabilities	$	5,185,592		$	5,581,126		$	5,637,120		$	5,482,669

The accompanying notes are an integral part of these statements.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(~~In thousands)~~Thousands of dollars)

(Unaudited)


	THREE MONTHS ENDED						NINE MONTHS ENDED						TWELVE MONTHS ENDED						THREE MONTHS ENDED						SIX MONTHS ENDED						TWELVE MONTHS ENDED
	SEPTEMBER 30,						SEPTEMBER 30,						SEPTEMBER 30,						JUNE 30,						JUNE 30,						JUNE 30,
	2017			2016			2017			2016			2017			2016			2018			2017			2018			2017			2018			2017
Continuing operations:
Gas operating revenues	$	213,059		$	200,179		$	935,823		$	980,927		$	1,276,308		$	1,376,388		$	275,679		$	260,162		$	769,992		$	722,764		$	1,349,536		$	1,263,428

Operating expenses:
Net cost of gas sold		45,539			39,056			261,839			324,072			334,888			460,836			83,466			69,421			269,198			216,300			407,943			328,405
Operations and maintenance		102,215			102,438			313,395			301,979			413,140			400,222			105,208			97,644			207,398			201,468			397,251			393,772
Depreciation and amortization		46,194			56,436			153,643			174,413			212,693			228,609			47,664			46,254			97,625			107,449			192,098			222,935
Taxes other than income taxes		14,046			12,480			43,325			39,480			56,221			51,810			14,666			14,497			29,923			29,279			58,590			54,655

Total operating expenses		207,994			210,410			772,202			839,944			1,016,942			1,141,477			251,004			227,816			604,144			554,496			1,055,882			999,767

Operating income (loss)		5,065			(10,231	)		163,621			140,983			259,366			234,911
Operating income																				24,675			32,346			165,848			168,268			293,654			263,661

Other income and (expenses):
Net interest deductions		(17,421	)		(16,364	)		(51,622	)		(49,155	)		(69,464	)		(65,146	)		(20,149	)		(16,991	)		(39,404	)		(34,201	)		(74,936	)		(68,407	)
Other income (deductions)		3,081			2,521			8,744			6,712			10,308			9,615			(2,094	)		(2,805	)		(6,697	)		(4,049	)		(9,036	)		(9,843	)

Total other income and (expenses)		(14,340	)		(13,843	)		(42,878	)		(42,443	)		(59,156	)		(55,531	)		(22,243	)		(19,796	)		(46,101	)		(38,250	)		(83,972	)		(78,250	)

Income (loss) from continuing operations before income taxes		(9,275	)		(24,074	)		120,743			98,540			200,210			179,380
Income from continuing operations before income taxes																				2,432			12,550			119,747			130,018			209,682			185,411
Income tax expense (benefit)		(5,251	)		(11,669	)		38,307			31,004			65,887			59,544			(190	)		3,028			26,776			43,558			46,353			59,469

Income (loss) from continuing operations		(4,024	)		(12,405	)		82,436			67,536			134,323			119,836
Income from continuing operations																				2,622			9,522			92,971			86,460			163,329			125,942

Discontinued operations—construction services:
Discontinued operations - construction services:
Income before income taxes		—			24,020			—			31,867			21,649			54,934			—			—			—			—			—			45,669
Income tax expense		—			8,708			—			12,042			7,842			20,711			—			—			—			—			—			16,550

Income		—			15,312			—			19,825			13,807			34,223			—			—			—			—			—			29,119
Noncontrolling interests		—			435			—			500			514			1,079			—			—			—			—			—			949

Income—discontinued operations		—			14,877			—			19,325			13,293			33,144
Income - discontinued operations																				—			—			—			—			—			28,170

Net income (loss)	$	(4,024	)	$	2,472		$	82,436		$	86,861		$	147,616		$	152,980
Net income																			$	2,622		$	9,522		$	92,971		$	86,460		$	163,329		$	154,112

The accompanying notes are an integral part of these statements.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(~~In thousands)~~Thousands of dollars)

(Unaudited)


	THREE MONTHS ENDED						NINE MONTHS ENDED						TWELVE MONTHS ENDED						THREE MONTHS ENDED						SIX MONTHS ENDED						TWELVE MONTHS ENDED
	SEPTEMBER 30,						SEPTEMBER 30,						SEPTEMBER 30,						JUNE 30,						JUNE 30,						JUNE 30,
	2017			2016			2017			2016			2017			2016			2018			2017			2018			2017			2018			2017
Continuing operations:
Net income (loss) from continuing operations	$	(4,024	)	$	(12,405	)	$	82,436		$	67,536		$	134,323		$	119,836
Net income from continuing operations																			$	2,622		$	9,522		$	92,971		$	86,460		$	163,329		$	125,942

Other comprehensive income (loss), net of tax
Defined benefit pension plans:
Net actuarial gain (loss)		—			—			—			—			(14,118	)		(18,922	)		—			—			—			—			(32,701	)		(14,118	)
Amortization of prior service cost		207			207			621			621			828			828			254			207			508			414			922			828
Amortization of net actuarial loss		3,944			4,196			11,832			12,586			16,027			17,915			6,387			3,944			12,774			7,888			20,662			16,279
Regulatory adjustment		(3,555	)		(3,796	)		(10,667	)		(11,388	)		(2,741	)		(404	)		(5,744	)		(3,556	)		(11,490	)		(7,112	)		8,212			(2,982	)

Net defined benefit pension plans		596			607			1,786			1,819			(4	)		(583	)		897			595			1,792			1,190			(2,905	)		7

Forward-starting interest rate swaps:
Amounts reclassified into net income		518			518			1,554			1,556			2,073			2,073			636			518			1,271			1,036			2,308			2,073

Net forward-starting interest rate swaps		518			518			1,554			1,556			2,073			2,073			636			518			1,271			1,036			2,308			2,073

Total other comprehensive income, net of tax from continuing operations		1,114			1,125			3,340			3,375			2,069			1,490
Total other comprehensive income (loss), net of tax from continuing operations																				1,533			1,113			3,063			2,226			(597	)		2,080

Comprehensive income (loss) from continuing operations		(2,910	)		(11,280	)		85,776			70,911			136,392			121,326
Comprehensive income from continuing operations																				4,155			10,635			96,034			88,686			162,732			128,022

Discontinued operations—construction services:
Discontinued operations - construction services:
Net income		—			14,877			—			19,325			13,293			33,144			—			—			—			—			—			28,170
Foreign currency translation adjustments		—			(238	)		—			614			(453	)		233			—			—			—			—			—			(691	)

Comprehensive income		—			14,639			—			19,939			12,840			33,377			—			—			—			—			—			27,479
Comprehensive income (loss) attributable to noncontrolling interests		—			(8	)		—			21			(16	)		10			—			—			—			—			—			(24	)

Comprehensive income attributable to discontinued operations—construction services		—			14,647			—			19,918			12,856			33,367
Comprehensive income attributable to discontinued operations - construction services																				—			—			—			—			—			27,503

Comprehensive income (loss)	$	(2,910	)	$	3,367		$	85,776		$	90,829		$	149,248		$	154,693
Comprehensive income																			$	4,155		$	10,635		$	96,034		$	88,686		$	162,732		$	155,525

The accompanying notes are an integral part of these statements.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of dollars)

(Unaudited)


	NINE MONTHS ENDED						TWELVE MONTHS ENDED						SIX MONTHS ENDED						TWELVE MONTHS ENDED
	SEPTEMBER 30						SEPTEMBER 30						JUNE 30,						JUNE 30,
	2017			2016			2017			2016			2018			2017			2018			2017
CASH FLOW FROM OPERATING ACTIVITIES:
Net Income	$	82,436		$	87,361		$	148,130		$	154,059		$	92,971		$	86,460		$	163,329		$	155,061
Income (loss) from discontinued operations		—			19,825			13,807			34,223
Income from discontinued operations														—			—			—			29,119

Income from continuing operations		82,436			67,536			134,323			119,836			92,971			86,460			163,329			125,942
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		153,643			174,413			212,693			228,609			97,625			107,449			192,098			222,935
Deferred income taxes		44,621			39,953			72,627			76,837			27,371			46,874			47,666			74,241
Changes in current assets and liabilities:
Accounts receivable, net of allowances		43,818			91,680			(7,131	)		8,543			36,104			37,484			(9,282	)		(973	)
Accrued utility revenue		42,100			41,700			(1,100	)		(800	)		44,000			42,600			(600	)		(1,100	)
Deferred purchased gas costs		(79,127	)		81,389			(114,658	)		79,460			34,105			(73,196	)		11,693			(111,627	)
Accounts payable		(45,972	)		(47,060	)		17,271			1,467			(52,095	)		(55,707	)		8,157			3,157
Accrued taxes		4,092			(5,660	)		29,143			4,567			(12,776	)		(2,823	)		430			23,024
Other current assets and liabilities		32,453			(819	)		(224	)		9,135			(24,366	)		24,265			(62,357	)		(14,022	)
Changes in undistributed stock compensation		7,999			4,347			9,108			5,142			3,220			6,931			5,577			8,873
AFUDC		(2,077	)		(1,893	)		(2,473	)		(2,890	)		(586	)		(1,109	)		(1,773	)		(2,116	)
Changes in other assets and deferred charges		(14,861	)		3,664			(1,914	)		3,834			(5,490	)		(11,801	)		(16,607	)		4,761
Changes in other liabilities and deferred credits		2,883			(4,813	)		(10,751	)		702			5,477			1,695			7,323			(14,250	)

Net cash provided by operating activities		272,008			444,437			336,914			534,442			245,560			209,122			345,654			318,845

CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions		(395,463	)		(337,921	)		(514,661	)		(485,665	)		(285,999	)		(224,085	)		(622,362	)		(466,780	)
Changes in customer advances		(1,951	)		5,445			504			9,445			8,158			(1,430	)		9,911			4,318
Miscellaneous inflows		2,407			2,464			2,925			3,506			778			1,354			2,165			2,546
Dividends received		—			2,801			9,660			5,602			—			—			—			9,660

Net cash used in investing activities		(395,007	)		(327,211	)		(501,572	)		(467,112	)		(277,063	)		(224,161	)		(610,286	)		(450,256	)

CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net		—			530			(58	)		507			—			—			—			(15	)
Contributions from parent		11,659			—			11,659			—			56,596			—			97,955			—
Dividends paid		(60,497	)		(61,950	)		(81,864	)		(81,138	)		(43,000	)		(39,896	)		(84,601	)		(82,630	)
Issuance of long-term debt, net		—			296,469			—			296,469			297,495			—			297,495			296,469
Retirement of long-term debt		(25,000	)		(124,855	)		(25,000	)		(124,855	)		—			(25,000	)		—			(149,855	)
Change in credit facility and commercial paper		145,000			(150,000	)		150,000			(97,000	)		(102,000	)		87,000			(44,000	)		89,500
Change in short-term debt		83,000			(18,000	)		83,000			—			(191,000	)		—			—			—
Withholding remittance—share-based compensation		(3,176	)		(2,119	)		(3,176	)		(2,164	)
Withholding remittance - share-based compensation														(2,855	)		(3,120	)		(2,911	)		(3,271	)
Other		(544	)		(605	)		(1,508	)		(9	)		(779	)		(525	)		(850	)		(1,970	)

Net cash provided by (used in) financing activities		150,442			(60,530	)		133,053			(8,190	)
Net cash provided by financing activities														14,457			18,459			263,088			148,228

Net cash provided by discontinued operating activities		—			33,485			57,680			78,274			—			—			—			73,607
Net cash used in discontinued investing activities		—			(80,767	)		(11,049	)		(91,536	)		—			—			—			(23,903	)
Net cash provided by (used in) discontinued financing activities		—			39,757			(44,491	)		6,635
Net cash used in discontinued financing activities														—			—			—			(46,962	)
Effects of currency translation on cash and cash equivalents		—			(14	)		(180	)		(318	)		—			—			—			(199	)

Change in cash and cash equivalents		27,443			49,157			(29,645	)		52,195			(17,046	)		3,420			(1,544	)		19,360
Change in cash and cash equivalents of discontinued operations included in discontinued operations construction services assets		—			7,539			(1,960	)		6,945			—			—			—			(2,543	)

Change in cash and cash equivalents of continuing operations		27,443			56,696			(31,605	)		59,140			(17,046	)		3,420			(1,544	)		16,817
Cash and cash equivalents at beginning of period		19,024			21,376			78,072			18,932			37,946			19,024			22,444			5,627

Cash and cash equivalents at end of period	$	46,467		$	78,072		$	46,467		$	78,072		$	20,900		$	22,444		$	20,900		$	22,444

Supplemental information:
Interest paid, net of amounts capitalized	$	40,751		$	42,804		$	59,448		$	63,031		$	33,452		$	32,205		$	66,037		$	63,221

Income taxes paid (received)	$	4		$	(3,055	)	$	(27,952	)	$	(16,600	)	$	10,886		$	19		$	3,013		$	(32,885	)

The accompanying notes are an integral part of these statements.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

Note 1 – Nature of Operations and Basis of Presentation

Nature of Operations. Southwest Gas Holdings, Inc., is a holding company, owning all of the shares of common stock of Southwest Gas Corporation and, prior to August 2017, 96.6% of the shares of common stock of Centuri Construction Group, Inc. (“Centuri” or the “construction services” segment). During August 2017, Southwest Gas Holdings, Inc. acquired the remaining 3.4% equity interest in Centuri ~~Construction Group, Inc.~~ that was held by the previous ~~owners (and was previously reflected as a redeemable noncontrolling interest). Refer to~~ ~~Note 9 – Construction Services Redeemable Noncontrolling Interest~~~~for additional information.~~

In January 2017, a previously contemplated and approved reorganization under a holding company structure was made effective. The reorganization was designed to provide further separation between regulated and unregulated businesses, and to provide additional financing flexibility. Coincident with the effective date of the reorganization, existing shareholders of Southwest Gas Corporation became shareholders of Southwest Gas Holdings, Inc., on a~~one-for-one~~ basis, with the same number of shares and same ownership percentage as they held immediately prior to the reorganization. At the same time, Southwest Gas Corporation and Centuri Construction Group, Inc. (“Centuri” or the “construction services” segment) each became subsidiaries of the publicly traded holding company; whereas, historically, Centuri had been a direct subsidiary of Southwest Gas Corporation.owners.

Southwest Gas Corporation (“Southwest” or the “natural gas operations segment”) 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 construction services enterprise dedicated to meeting the growing demands of North American utilities, energy, and industrial markets. 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”), Canyon Pipeline Construction, Inc. (“Canyon”), NPL Canada Ltd. (“NPL Canada”~~, formerly Link-Line Contractors Ltd.~~), W.S. Nicholls Construction, Inc. (“W.S. Nicholls”), and Canyon Special Projects, Inc. (“Special Projects,” formerly Brigadier Pipelines Inc. ~~(“Brigadier”~~). Typically, Centuri revenues are lowest during the first quarter of the year due to unfavorable winter weather conditions. Operating revenues typically improve as more favorable weather conditions occur during the summer and fall months. Centuri acquired New England Utility Constructors, Inc. (“Neuco”) in November 2017, thereby expanding its core services in the Northeast region of the United States. SeeNote 11 – Acquisition of Construction Services Business 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”). Certain information and footnote disclosures normally included in financial statements prepared in accordance with United States generally accepted accounting principles (“U.S. GAAP”) have been condensed or omitted pursuant to such rules and regulations. ~~As indicated above, in~~In connection with ~~the~~a holding company reorganization in January 2017, Centuri ceased to be a subsidiary of Southwest and became a subsidiary of Southwest Gas Holdings, Inc. To give effect to this change, the separate condensed consolidated financial statements related to Southwest Gas Corporation, which are included in thisForm 10-Q, depict Centuri-related amounts for periods prior to January 1, 2017 as discontinued operations. Because the transfer of Centuri from Southwest Gas Corporation to Southwest Gas Holdings, Inc. was effectuated as an equity transaction and not a sale, assets and liabilities subject to the discontinued operations presentation have been reflected as noncurrent on the Southwest Gas Corporation Condensed Consolidated Balance Sheet. Those assets and liabilities are detailed in~~Note~~ ~~10 – Reorganization Impacts – Discontinued Operations Solely Related to Southwest Gas Corporation~~~~,and include both current andnon-current~~ ~~amounts.~~

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 organizational ~~changes.~~changes, or due to the acquisition of Neuco. Following the organizational changes, Centuri operations continue to be part of continuing operations and included in the consolidated financial statements of Southwest Gas Holdings, Inc.

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.


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

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 ~~2016~~2017 Annual Report to Shareholders, which is incorporated by reference into the ~~2016~~2017Form 10-K.

Early Adoption of Accounting Standards Update (“ASU”) No. 2018-02. In January 2018, the Financial Accounting Standards Board (“FASB”) issued ASUNo. 2018-02 “Income Statement—Reporting Comprehensive Income (Topic 220)—Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.” Early adoption of the amendments in this update is permitted, including adoption in any interim period. Therefore, the Company and Southwest chose to adopt the update early, as permitted, as of January 1, 2018. The adoption of this


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

update is considered a change in accounting principle. The update addresses issues resulting from the December 22, 2017 enactment of the Tax Cuts and Jobs Act (“TCJA”). Stakeholders raised a narrow-scope financial reporting issue that arose as a consequence of the TCJA related to the fact that when deferred tax balances were remeasured in December 2017, those deferred tax balances were to be reduced, but related amounts historically accumulated in Accumulated other comprehensive income (“AOCI”) prior to the enactment of the TCJA, were required to be recognized as income tax expense rather than being relieved from AOCI. The amendments in this update allow a reclassification from AOCI to retained earnings for those otherwise “stranded” tax effects in AOCI following enactment of the TCJA. Accordingly, approximately $9.3 million of previously stranded tax effects resulting from the TCJA were reclassified to retained earnings from AOCI on the Condensed Consolidated Balance Sheets of Southwest and the Company effective with the early adoption date. Also in association with the adoption, the Company and Southwest elected an accounting policy for releasing income tax effects from AOCI, such that the release of any income tax effects from AOCI will occur as individual items in AOCI are sold or liquidated, to the extent that the related income tax effects are material. SeeNote 9 – Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income for more information.

Prepaids and other current assets. Prepaids and other current assets includes gas pipe materials and operating supplies of ~~$36~~$55 million at ~~September~~June 30, ~~2017~~2018 and ~~$30~~$33 million at December 31, ~~2016~~2017 (carried at weighted average cost) ~~and $24~~, as well as $69 million at ~~September~~June 30, ~~2017~~2018 and ~~$953,000~~$40 million at December 31, ~~2016~~2017 related to a regulatory asset associated with the Arizona decoupling mechanism (an alternative revenue program). In May 2018, El Paso Natural Gas, L.L.C. (“EPNG”), was ordered to refund approximately $49 million to Southwest related to transmission services with EPNG. The refund (which was received by Southwest in July 2018) relates to rates authorized by the Federal Energy Regulatory Commission (“FERC”) to be in effect subject to refund provisions from EPNG’s 2010 rate case. Southwest will dispense the funds received through rate adjustments associated with its purchased gas adjustment (“PGA”) mechanisms. As the refund was outstanding at June 30, 2018, it did not impact cash flows; however, it is reflected in Prepaids and other current assets and a corresponding amount is reflected in a regulatory liability included within Other current liabilities in the balance sheets of both Southwest and the Company as of that date.

Income Taxes.On December 22, 2017, the TCJA legislation was enacted. Substantially all of the provisions of the TCJA are effective for taxable years beginning after December 31, 2017. The TCJA includes extensive changes which significantly impact the taxation of business entities, including specific provisions related to regulated public utilities. The more significant change that impacts the Company includes the reduction in the corporate federal income tax rate from 35% to 21%. The tax rate reduction created excess deferred taxes, resulting in the required remeasurement of deferred tax balances, which when remeasured during the fourth quarter of 2017, reduced income tax expense. The regulated operations of Southwest experienced other impacts due to its rate-regulation and the accounting treatment prescribed by U.S. GAAP to reflect the economics of that regulation. The remeasurement for Southwest reduced the net deferred income tax liability and caused the creation of a regulatory liability with appropriate taxgross-up. Both deferred tax liabilities and excess deferred tax liabilities (included within regulatory liabilities) reduce utility rate base. The TCJA includes provisions that stipulate how these excess deferred taxes are to be passed back to customers, and ultimate facilitation will occur in conjunction with appropriate regulatory commissions. During the six months ended June 30, 2018, tax expense for the Company and Southwest reflects the lower U.S. federal income tax rate now in effect (as applicable to earnings in 2018). Amounts recorded by the Company and Southwest associated with the measurement and accounting for the effects of the TCJA are provisional reasonable estimates. Management is continuing to evaluate and finalize all provisional items during the measurement period permitted by the SEC and the FASB, which is not to exceed one year from the enactment date.

In the first quarter of 2018, management recorded a regulatory liability and reduced utility revenues by approximately $14 million for potential regulatory rate reductions to customers resulting from the reduced cost-of-service levels during the period. Based on regulatory activity in the second quarter of 2018, management has updated its estimated reserve to approximately $12.5 million.

In July 2018, the Arizona Corporation Commission (“ACC”) staff issued a recommended opinion and order that would require Southwest to return to customers amounts related to excesscost-of-service rates as a result of customer rates having been authorized prior to the reduction in federal tax expense from tax reform. Also in July, the ACC issued a decision (the “Decision”) based on the staff recommendation. The Decision provides for bill credits for excess amounts experienced through July 2018. Additionally, starting in August 2018, surcredits applied to volumes would be implemented in consideration of lower tax rates impacting tax expense on an ongoing basis. Based on these recent


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

actions of the ACC, the $12.5 million reserve is reflected in Other current liabilities. During the first quarter of 2018, related amounts were included in Other deferred credits and other long-term liabilities pending resolution of regulatory outcome and timing.

Other current liabilities. Other current liabilities offor both Southwest ~~Gas Corporation~~and the Company include ~~$21~~the $49 million regulatory liability associated with the EPNG refund (noted previously) and the $12.5 million reserve associated with tax reform noted above. This caption on Southwest’s Condensed Consolidated Balance Sheets also includes $22 million of dividends declared by Southwest Gas Corporation, but not yet paid to Southwest Gas Holdings, Inc. at ~~September~~June 30, ~~2017.~~2018.

Cash and Cash Equivalents. For purposes of reporting consolidated cash flows, cash and cash equivalents include cash on hand and financial instruments with a purchase-date maturity of three months or less. In general, cash and cash equivalents fall within Level 1 (quoted prices for identical financial instruments) of the three-level fair value hierarchy that ranks the inputs, used to measure fair value, by their reliability. However, cash and cash equivalents ~~at September 30, 2017~~for Southwest and ~~December 31, 2016~~the Company also includes money market fund investments oftotaling approximately ~~$19.8~~$1.9 million and ~~$5.3~~$13.2 million, respectively, which fall within Level 2 (significant other observable inputs) of the fair value hierarchy, due to the asset valuation methods used by money market funds.

Significantnon-cash investing and financing activities included the following: Upon contract expiration, customer advances of approximately ~~$1.9 million~~$512,000 and ~~$3.6~~$1.6 million, during the first ~~nine~~six months of ~~2017~~2018 and ~~2016,~~2017, respectively, were applied as contributions toward utility construction activity and representnon-cash investing activity.

~~Adoption of Accounting Standards Update (“ASU”) No.~~ ~~2016-09.~~ ~~As of January 1, 2017, the Company adopted Financial Accounting Standards Board (“FASB”) ASUNo. 2016-09~~ “Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.” The adoption of this update is considered a change in accounting principle. Among other things, the update clarifies that all cash payments made to taxing authorities on the employees’ behalf for withheld shares should be presented as financing activities on the statement of cash flows. This change is required to be presented in the cash flow statement retrospectively. A new category, Withholding remittance – share-based compensation has been added to the Cash Flow from Financing Activities section of the Condensed Consolidated Statements of Cash Flows for both Southwest Gas Holdings, Inc. and Southwest Gas Corporation. The withheld taxes were included in the Other current assets and liabilities line item of the Condensed Consolidated Statements of Cash Flows in previous periods. Therefore, upon adoption, amounts presented as cash inflows from Other current assets and liabilities under the Cash Flow from Operating Activities section of the Southwest Gas Holdings, Inc. Condensed Consolidated Statements of Cash Flows were revised from $9.9 million to $12 million for the nine months ended September 30, 2016 and inflows in the same category for the twelve months ended September 30, 2016 were revised from $19.9 million to $22 million. In addition, while standalone financial statements were not previously presented for natural gas operations, for reasons related to the holding company reorganization discussed above, they are now presented. Therefore, upon adoption of this standard, the Cash Flow from Operating Activities section of the Southwest Gas Corporation Condensed Consolidated Statements of Cash Flows reflects a reclassification of cash outflows from Other current assets and liabilities from $2.9 million to $819,000 for the nine months ended September 30, 2016 and cash inflows in the same category were revised from $7 million to $9.1 million for the twelve months ended September 30, 2016.

Under the new guidance, the Company can withhold any amount between the minimum and maximum individual statutory tax rates and still treat the entire award as equity. The Company intends to administer withholding such that awards under stock compensation programs will continue to be treated as equity awards.

~~In addition to the above, the update requires all incometax-related~~ cash flows resulting from share-based payments (unrelated to employee withholding) be reported as operating activities on the statement of cash flows, a change from the previous requirement to present windfall tax benefits as an inflow from financing activities and an outflow from operating activities. The Company chose to apply this presentation requirement of the update prospectively as permitted. Therefore, prior periods were not impacted in implementing this provision of the update.


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

Amendments related to the timing of when excess tax benefits are recognized, minimum statutory withholding requirements, forfeitures, and intrinsic value are required to be applied using a modified retrospective transition method by means of a cumulative-effect adjustment to equity as of the beginning of the period in which the guidance is adopted. The Company had no previously unrecognized tax benefits as a result of these changes; therefore, no cumulative effect adjustment to the Company’s opening retained earnings was required.

Goodwill. Goodwill is assessed as of October 1^steach year for impairment, ~~(required annually by U.S. GAAP),~~ or otherwise, if circumstances indicate an impairment to the carrying value of goodwill may have occurred. In consideration of the holding company reorganization, management of the Company considered its reporting units and segments and determined that historic judgments regarding its segments and reporting units continue to apply, 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 ~~nine~~six months of ~~2017.~~2018.

Goodwill:

(In thousands of dollars)    Natural Gas
Operations    Construction
Services    Consolidated
December 31, 2016
   $ 10,095    $ 129,888    $ 139,983
Foreign currency translation adjustment
   —      7,882    7,882






September 30, 2017
   $ 10,095    $ 137,770    $ 147,865


(Thousands of dollars)	Natural Gas Operations		Construction Services			Consolidated
December 31, 2017	$	10,095	$	169,219		$	179,314
Additional goodwill from Neuco acquisition		—		182			182
Foreign currency translation adjustment		—		(5,263	)		(5,263	)

June 30, 2018	$	10,095	$	164,138		$	174,233

Intercompany Transactions. Centuri recognizes revenues generated from contracts with Southwest (seeNote 3—4 -Segment Information). Centuri’s accounts receivable for these services are presented in the table below (thousands of dollars):

   September 30, 2017    December 31, 2016
Centuri accounts receivable for services provided to Southwest
   $ 11,486    $ 10,585


	June 30, 2018		December 31, 2017
Centuri accounts receivable for services provided to Southwest	$	13,899	$	12,987

The accounts receivable balance, revenues, and associated profits are included in the condensed consolidated financial statements of the Company and were not eliminated during consolidation in accordance with accounting treatment for rate-regulated entities.

~~Other Property and Investments.~~~~Other property and investments on the Southwest Gas Holdings, Inc. Condensed Consolidated Balance Sheets includes (thousands of dollars):~~

   September 30, 2017    December 31, 2016
Centuri property and equipment
   $ 493,599    $ 451,114
Centuri accumulated provision for depreciation and amortization
   (251,831 )    (228,374 )
Net cash surrender value of COLI policies
   114,052    106,744
Other property
   13,483    12,859




Total
   $ 369,303    $ 342,343


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

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


	June 30, 2018			December 31, 2017
Southwest Gas Corporation:
Net cash surrender value of COLI policies	$	118,733		$	117,341
Other property		1,743			1,773

Total Southwest Gas Corporation		120,476			119,114
Centuri property, equipment, and intangibles		606,750			554,730
Centuri accumulated depreciation/amortization		(278,209	)		(258,906	)
Other property		13,219			13,242

Total Southwest Gas Holdings, Inc.	$	462,236		$	428,180

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


	Three Months Ended						Nine Months Ended						Twelve Months Ended						Three Months Ended						Six Months Ended						Twelve Months Ended
	September 30						September 30						September 30						June 30,						June 30,						June 30,
	2017			2016			2017			2016			2017			2016			2018			2017			2018			2017			2018			2017
Southwest Gas Corporation—natural gas operations segment:
Southwest Gas Corporation - natural gas operations segment:
Change in COLI policies	$	2,100		$	2,300		$	6,800		$	5,400		$	8,800		$	7,500		$	2,000		$	1,900		$	1,300		$	4,700		$	6,900		$	9,000
Interest income		670			522			1,848			1,279			2,417			1,664			1,377			614			2,795			1,178			4,401			2,269
Equity AFUDC		968			611			2,077			1,893			2,473			2,890			357			633			586			1,109			1,773			2,116
Other components of net periodic benefit cost																				(5,264	)		(4,857	)		(10,529	)		(9,712	)		(20,241	)		(19,591	)
Miscellaneous income and (expense)		(657	)		(912	)		(1,981	)		(1,860	)		(3,382	)		(2,439	)		(564	)		(1,095	)		(849	)		(1,324	)		(1,869	)		(3,637	)

Southwest Gas Corporation—total other income (deductions)		3,081			2,521			8,744			6,712			10,308			9,615
Southwest Gas Corporation - total other income (deductions)																				(2,094	)		(2,805	)		(6,697	)		(4,049	)		(9,036	)		(9,843	)

Construction services segment:
Interest income		1			—			2			1			2			414			1			1			2			1			4			1
Foreign transaction gain (loss)		(442	)		(3	)		(640	)		(22	)		(640	)		28			202			(197	)		349			(198	)		(207	)		(201	)
Miscellaneous income and (expense)		231			47			676			65			1,825			804			(835	)		190			(720	)		445			(69	)		1,641

Centuri—total other income (deductions)		(210	)		44			38			44			1,187			1,246
Centuri - total other income (deductions)																				(632	)		(6	)		(369	)		248			(272	)		1,441

Corporate and administrative		5			—			6			—			6			—			20			1			26			1			38			1

Consolidated Southwest Gas Holdings, Inc.—total other income (deductions)	$	2,876		$	2,565		$	8,788		$	6,756		$	11,501		$	10,861
Consolidated Southwest Gas Holdings, Inc. - total other income (deductions)																			$	(2,706	)	$	(2,810	)	$	(7,040	)	$	(3,800	)	$	(9,270	)	$	(8,401	)

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 fortax-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 toNote 2 – Components of Net Periodic Benefit Cost.

Recently Issued Accounting Standards Updates. In May 2014, the FASB issued the update “Revenue from Contracts with Customers (Topic 606).” The update replaces much of the current guidance regarding revenue recognition including most industry-specific guidance. In accordance with the update, an entity will be required to identify the contract with the customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract, and recognize revenue when (or as) the entity satisfies a performance obligation. In addition to the new revenue recognition requirements, entities will be required to disclose sufficient information to enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. Entities may choose between two retrospective transition methods when applying the update. In July 2015, the FASB approved a~~one-year~~ deferral of the effective date (annual periods beginning after December 15, 2017). In March, April, May, and December of 2016, the FASB issued updates to Topic 606 related to “Principal versus Agent Considerations (Reporting Revenue Gross versus Net)”, “Identifying Performance Obligations and Licensing,” “Narrow-Scope Improvements and Practical Expedients”, and certain “Technical Corrections and Improvements.” The amendments in the first two updates, respectively, provide guidance when another party, along with the entity, is involved in providing a good or service to a customer, and provide clarification with regard to identifying performance obligations and of the licensing implementation guidance in Topic 606. The third update includes improvements to the guidance on collectibility, noncash consideration, and completed contracts at transition. In addition, a practical expedient is provided for contract modifications at transition and an accounting policy election related to the presentation of sales taxes and other similar taxes collected from customers. The fourth update affects narrow aspects of the guidance as issued to date. Management plans to adopt all of these updates at the required adoption date, which is for interim and annual reporting periods commencing January 2018.

Deliberations have been ongoing by the utility industry, notably in connection with efforts to produce an accounting guide intended to be developed by the American Institute of Certified Public Accountants (“AICPA”). In association with this undertaking, the AICPA formed a number of industry task forces, including a Power & Utilities (“P&U”) Task Force, on which Company personnel actively participate via formal membership. Industry representatives and organizations, the largest auditing firms, the AICPA’s Revenue Recognition Working Group and its Financial Reporting Executive Committee have undertaken, and continue to undertake, consideration of several items relevant to the utility industry. Where applicable or necessary, the FASB’s Transition Resource Group (“TRG”) has also participated. Through the P&U Task Force undertakings, general determinations were made that contributions received in aid of construction (“CIAC”) efforts related to the industry’s pipe distribution and transmission systems are reimbursements of expenditures rather than revenue (consistent with current accounting practices). Furthermore, regarding the “collectibility” criterion in the update that must be met for revenue recognition, general determinations have been made that contracts for utility service (including service to lower income or lower credit quality customers)


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

represent genuine and valid contracts for which revenue is able to be recognized when service is rendered (consistent with current accounting practices). These determinations by the P&U industry are based on the various measures the industry takes to help ensure collectibility (e.g., proof of creditworthiness, customer deposits, late fee assessment, disconnection, service~~re-establishment~~ fees, collection processes, etc.), in addition to the regulatory mechanisms established under rate regulation to mitigate the impacts of individual customer nonpayment. Southwest has also actively worked with its peers in the rate-regulated natural gas industry and with the public accounting profession to finalize the accounting treatment for several other issues not separately addressed by the P&U Task Force.

With regard to the construction services segment, the principles of the new revenue recognition guidance are very similar to existing guidance for construction contractors. Similar to the P&U Task Force noted above, the AICPA formed the Engineering and Construction Contractors Task Force to assist the construction industry with implementing the new guidance. The accounting guide the AICPA intends to release is expected to provide implementation guidance related to several issues including 1) combining contracts and separating performance obligations; 2) estimating change orders, incentives, penalties, liquidated damages and other variable consideration items and 3) acceptable measures of progress when recognizing revenue over time.

Management of both segments of the Company has substantially completed assessments of sources of revenue and the effects that adoption of the new guidance will have on the Company’s (and Southwest’s in the case of utility operations) financial position, results of operations, and cash flows. Based on assessments completed to date, management believes that such impacts will not be material overall. Presentation and disclosure requirements of the new guidance will have the most impact on the Company’s financial statements and note disclosures. The Company is currently planning to adopt the new guidance in 2018 under the modified retrospective transition method, as permissible.

~~In January 2016, the FASB issued the update “Financial Instruments – Overall (Subtopic825-10):~~ Recognition and Measurement of Financial Assets and Financial Liabilities” in order to improve the recognition and measurement of financial instruments. The update makes targeted improvements to existing U.S. GAAP by: 1) requiring equity investments to be measured at fair value with changes in fair value recognized in net income; 2) requiring the use of the exit price notion when measuring the fair value of financial instruments for disclosure purposes; 3) requiring separate presentation of financial assets and financial liabilities by measurement category and form of financial asset on the balance sheet or the accompanying notes to the financial statements; 4) eliminating the requirement to disclose the method(s) and significant assumptions used to estimate the fair value that is required to be disclosed for financial instruments measured at amortized cost on the balance sheet; and 5) requiring a reporting entity to present separately in other comprehensive income the portion of the total change in the fair value of a liability resulting from a change in instrument-specific credit risk when the organization has elected to measure the liability at fair value in accordance with the fair value option for financial instruments. The update is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. All entities can early adopt the provision to record fair value changes for financial liabilities under the fair value option resulting from instrument-specific credit risk in other comprehensive income. Management believes this update will not have a material impact on its consolidated financial statements and disclosures.

In February 2016, the FASB issued the update “Leases (Topic 842).” Under the update, lessees will be required to recognize the following for all leases (with the exception of short-term leases) at the commencement date:

A lease liability, which is a lessee’s obligation to make lease payments arising from a lease, measured on a discounted basis; and

Aright-of-use asset, which is an asset that represents the lessee’s right to use, or control the use of, a specified asset for the lease term.

Under the new guidance, lessor accounting is largely unchanged. Certain targeted improvements were made to align, where necessary, lessor accounting with the lessee accounting model and Topic 606, ~~Revenue~~“Revenue from Contracts with Customers.” Though companies have historically been required to make disclosures regarding leases and of associated contractual obligations, leases ~~(with~~with terms longer than a ~~year)~~year will no longer existoff-balance sheet. Lessees (for capital


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

and operating leases) and lessors (for sales-type, direct financing, and operating leases) must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The modified retrospective approach would not require any transition accounting for leases that expired before the earliest comparative period presented. Lessees and lessors may not apply


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

a full retrospective transition approach. Early application is permitted. Management currently plans to adopt the update at the required adoption date, which is for interim and annual reporting periods commencing January 1, 2019. Existing leases have been historically documented under traditional leasing arrangements by both segments. Management is in the process of evaluating other types of arrangements that have the potential to meet the definition of a lease under the new ~~standard, and is also in the process of selecting software to efficiently implement the standard for its natural gas operations segment.~~standard. The FASB recently issued ~~proposed~~ guidance that will allow the election of a practical expedient to not apply the new standard to existing easement contracts that were not previously assessed as leases under historic guidance. However, the Company and Southwest would still be required to evaluate any new easements entered into after the effective date of the standard to determine if the arrangements should be accounted for as leases. In July 2018, the FASB issued narrow-scope improvements to the standard, which include, among other things, guidance on lease classification reassessments, that reference index changes, and on their own, do not constitute resolution of a contingency requiring remeasurement of lease payments, and clarification that lessor-controlled options to terminate a lease are considered in the lease term. Management is currently ~~evaluating~~in the process of implementing a new software system to comply with Topic 842 including amendments thereto, and ~~proposed~~continues to evaluate the guidance in light of its customary leasing arrangements (and other arrangements in association with the new guidance) to determine the effect the new standard, and its amendments, will have on its financial position, results of operations, cash flows, and business processes.

In June 2016, the FASB issued the update “Financial Instruments—Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The update amends guidance on reporting credit losses for financial assets held at amortized cost basis and available for sale debt securities. For assets held at amortized cost basis, the update eliminates the “probable” threshold for initial recognition of credit losses in current U.S. GAAP and, instead, requires an entity to reflect its current estimate of all expected credit losses. The allowance for credit losses is a valuation account that is deducted from the amortized cost basis of the financial asset to present the net amount expected to be collected. For available for sale debt securities, credit losses should be measured in a manner similar to current U.S. ~~GAAP,~~GAAP; however, the update will require that credit losses be presented as an allowance rather than as a write-down. This update affects entities holding financial assets and net investment in leases that are not accounted for at fair value through net income. The update affects loans, debt securities, trade receivables, net investments in leases,off-balance sheet credit exposures, reinsurance receivables, and any other financial assets not excluded from the scope that have the contractual right to receive cash. 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 its consolidated financial statements and disclosures.

In August 2016, the FASB issued the update “Classification of Certain Cash Receipts and Cash Payments.” This update addresses the following specific cash flow issues: debt prepayment or debt extinguishment costs; settlement of~~zero-coupon~~ debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance (“COLI”) policies; distributions received from equity method investees; beneficial interests in securitization transactions; and separately identifiable cash flows, including identification of the predominant nature in cases where cash receipts and payments have aspects of more than one class of cash flows. The update is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Early adoption is permitted. Management believes this update will not have a material impact on its consolidated cash flow statements and disclosures.

In October 2016, the FASB issued the update “Accounting for Income Taxes: Intra-Entity Asset Transfers of Assets Other than Inventory.” This update eliminates the current U.S. GAAP exception for all intra-entity sales of assets other than inventory. As a result, a reporting entity would recognize the tax expense from the sale of the asset in the seller’s tax jurisdiction when the transfer occurs, even though the~~pre-tax~~ effects of that transaction are eliminated in consolidation. Any deferred tax asset that arises in the buyer’s jurisdiction would also be recognized at the time of the transfer. The update is effective for fiscal years beginning after December 15 2017, including interim periods within those fiscal years. Early adoption is permitted; however, the guidance can only be adopted in the first interim period of a fiscal year. No such election to adopt early was made by management. The modified retrospective approach will be required for transition to the new guidance, with a cumulative-effect adjustment recorded in retained earnings as of the beginning of the period of adoption. Management believes this update will not have a material impact on its consolidated financial statements and disclosures.

In January 2017, the FASB issued the update “Intangibles—Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” The update eliminates Step 2 from the goodwill impairment test. The annual, or interim, goodwill impairment test is performed by comparing the fair value of a reporting unit with its carrying amount. An impairment charge should be recognized for the amount by which the carrying amount exceeds the reporting unit’s


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

~~fair value; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. In addition, income tax effects from anytax-deductible~~ goodwill on the carrying amount of the reporting unit should be considered when measuring the goodwill impairment loss, if applicable. The update also eliminates the requirements for any reporting unit with a zero or negative carrying amount to perform a qualitative assessment and, if it fails that qualitative test, to perform Step 2 of the goodwill impairment test. An entity still has the option to perform the qualitative assessment for a reporting unit to determine if the quantitative impairment test is necessary. 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 has determined that this update would have had no impact on the consolidated financial statements for the periods presented if it had been effective during those periods.

In March 2017, the FASB issued the update “Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.” The update applies to all employers that offer employee benefits under defined benefit pension plans, other postretirement benefit plans, or other types of benefits accounted for under Topic 715, Compensation – Retirement Benefits. The update requires that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations, and be appropriately described. The update also allows only the service cost component (and not the other components of periodic benefit costs) to be eligible for capitalization when applicable, making no exception for specialized industries, including~~rate-regulated~~ ~~industries.~~

Southwest is a rate-regulated utility offering pension and postretirement benefits to retired employees. It is anticipated that Southwest would continue to request recovery of the total costs of defined benefit plans in rate applications filed with its various regulatory bodies. Rate-regulated entities providing utility and transmission services have historically capitalized a portion of periodic benefit costs (including~~non-service~~ cost components) in utility infrastructure (for instance, when productive labor is also charged to capital work orders). The portion capitalized has historically been a component of depreciation and related rate development through efforts of companies and their regulatory commissions. The Federal Energy Regulatory Commission (“FERC”) regulates interstate transmission pipelines and also establishes, via its Uniform System of Accounts, accounting practices of rate-regulated entities. Accounting guidelines by the FERC are typically also upheld by state commissions. Historically, those guidelines have been generally consistent with guidance in U.S. GAAP (including U.S. GAAP for rate-regulated entities). While formal guidance has not yet been published by the FERC, it is currently believed that the FERC will permit an election to either continue to capitalize~~non-service~~ benefit costs for regulatory reporting purposes or to cease capitalizing such costs and implement the Topic 715 update capitalization provisions “as is,” for regulatory purposes. Assuming the FERC formalizes the above elections, Southwest currently anticipates adopting the provisions of Topic 715 for both SEC reporting and regulatory purposes. Industry deliberations continue and management will be evaluating the various impacts this update will have on its consolidated financial statements and disclosures. It is estimated that approximately $3 million in~~non-service~~ ~~costs were capitalized as a component of gas plant during 2016. Totalnon-service~~ ~~costs were approximately $20 million in 2016.~~


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

Note 2 – Components of Net Periodic Benefit Cost

As of January 1, 2018, the Company and Southwest adopted “Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.” The update requires that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and be appropriately described. The update also allows only the service cost component (and not the other components of periodic benefit costs) to be eligible for capitalization when applicable, making no exception for specialized industries, includingrate-regulated industries. This guidance is required to be applied on a retrospective basis for the presentation of the service cost component and the other components of net benefit cost and on a prospective basis for the capitalization of only the service cost component of net benefit cost. Amounts capitalized as part of assets prior to the date of adoption were not adjusted through a cumulative effect adjustment. The guidance allows a practical expedient for the retrospective application that permits use of the amounts disclosed for the various components of net benefit cost in the pension and other postretirement benefit plans footnote as the basis for the retrospective application. This is in lieu of determining how much of the various components of net benefit cost were actually reflected in the income statement each period as a result of capitalization of certain costs into assets and their subsequent amortization. The Company and Southwest have elected to utilize the practical expedient. Therefore, upon adoption, amounts presented in the Condensed Consolidated Statements of Income for operations and maintenance for the three-,six-, and twelve-month periods ended June 30, 2017 were reclassified. The Operations and maintenance line item of the Southwest Gas Holdings, Inc. Condensed Consolidated Statements of Income was revised from $103.1 million to $98.2 million for the three months ended June 30, 2017, from $212.2 million to $202.5 million for the six months ended June 30, 2017, and from $414.4 million to $394.8 million for the twelve months ended June 30, 2017. The Operations and maintenance line item of the Southwest Gas Corporation Condensed Consolidated Statements of Income was revised from $102.5 million to $97.6 million for the three months ended June 30, 2017, from $211.2 million to $201.5 million for the six months ended June 30, 2017, and from $413.4 million to $393.8 million for the twelve months ended June 30, 2017. The Other income (deductions) line item of the Southwest Gas Holdings, Inc. Condensed Consolidated Statements of Income was revised from $2.1 million to ($2.8) million for the three months ended June 30, 2017, from $5.9 million to ($3.8) million for the six months ended June 30, 2017, and from $11.2 million to ($8.4) million for the twelve months ended June 30, 2017. The Other income (deductions) line item of the Southwest Gas Corporation Condensed Consolidated Statements of Income was revised from $2.1 million to ($2.8) million for the three months ended June 30, 2017, from $5.7 million to ($4.0) million for the six months ended June 30, 2017, and from $9.8 million to ($9.8) million for the twelve months ended June 30, 2017. Net income overall was not impacted by this reclassification for either the Company or Southwest.

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.

~~Net~~During the first quarter of 2018, qualifying term-vested participants were offered alump-sum present value payout of their pensions. The offer was primarily intended to reduce insurance and ongoing maintenance costs associated with qualifying participant balances. Aboutone-quarter of the approximate 385 eligible participants accepted the offer, resulting in an approximate $6.8 million payment from pension assets in July 2018. The lump sum payout will have no impact on net periodic benefit cost or pension funding requirements during 2018.

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.~~labor (refer to discussion above related to the update to Topic 715). 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, ~~net periodic benefit~~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. Refer also to the practical expedient elected related to amounts capitalized as part of assets prior to the adoption date.

   Qualified Retirement Plan
   Period Ended September 30,
   Three Months Nine Months Twelve Months
   2017 2016 2017 2016 2017 2016
(Thousands of dollars)

Service cost
   $ 5,848 $ 5,708 $ 17,544 $ 17,125 $ 23,252 $ 23,406
Interest cost
   11,520 11,507 34,561 34,520 46,068 45,577
Expected return on plan assets
   (13,799 ) (14,140 ) (41,397 ) (42,419 ) (55,536 ) (56,871 )
Amortization of net actuarial loss
   6,001 6,317 18,003 18,950 24,319 27,136


Net periodic benefit cost
   $ 9,570 $ 9,392 $ 28,711 $ 28,176 $ 38,103 $ 39,248


   SERP
   Period Ended September 30,
   Three Months Nine Months Twelve Months
   2017 2016 2017 2016 2017 2016
(Thousands of dollars)

Service cost
   $ 77 $ 83 $ 232 $ 248 $ 315 $ 328
Interest cost
   471 464 1,413 1,394 1,878 1,818
Amortization of net actuarial loss
   361 346 1,081 1,038 1,426 1,361


Net periodic benefit cost
   $ 909 $ 893 $ 2,726 $ 2,680 $ 3,619 $ 3,507


   PBOP
   Period Ended September 30,
   Three Months Nine Months Twelve Months
   2017 2016 2017 2016 2017 2016
(Thousands of dollars)

Service cost
   $ 367 $ 375 $ 1,101 $ 1,124 $ 1,476 $ 1,534
Interest cost
   808 795 2,424 2,386 3,218 3,136
Expected return on plan assets
   (839 ) (787 ) (2,518 ) (2,362 ) (3,305 ) (3,228 )
Amortization of prior service costs
   333 333 1,001 1,001 1,335 1,335
Amortization of net actuarial loss
   —   104 —   312 105 398


Net periodic benefit cost
   $ 669 $ 820 $ 2,008 $ 2,461 $ 2,829 $ 3,175


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018


	Qualified Retirement Plan
	Period Ended June 30,
	Three Months						Six Months						Twelve Months
	2018			2017			2018			2017			2018			2017
(Thousands of dollars)
Service cost	$	7,139		$	5,848		$	14,278		$	11,696		$	25,974		$	23,112
Interest cost		11,044			11,521			22,087			23,041			45,129			46,055
Expected return on plan assets		(14,688	)		(13,799	)		(29,377	)		(27,598	)		(56,975	)		(55,877	)
Amortization of net actuarial loss		8,028			6,001			16,057			12,002			28,059			24,635

Net periodic benefit cost	$	11,523		$	9,571		$	23,045		$	19,141		$	42,187		$	37,925


	SERP
	Period Ended June 30,
	Three Months						Six Months						Twelve Months
	2018			2017			2018			2017			2018			2017
(Thousands of dollars)
Service cost	$	61		$	77		$	122		$	155		$	276		$	321
Interest cost		414			471			829			942			1,770			1,871
Amortization of net actuarial loss		376			360			751			720			1,472			1,411

Net periodic benefit cost	$	851		$	908		$	1,702		$	1,817		$	3,518		$	3,603


	PBOP
	Period Ended June 30,
	Three Months						Six Months						Twelve Months
	2018			2017			2018			2017			2018			2017
(Thousands of dollars)
Service cost	$	369		$	367		$	737		$	734		$	1,471		$	1,484
Interest cost		687			808			1,374			1,616			2,990			3,205
Expected return on plan assets		(930	)		(839	)		(1,860	)		(1,679	)		(3,539	)		(3,253	)
Amortization of prior service costs		334			334			668			668			1,335			1,335
Amortization of net actuarial loss		—			—			—			—			—			209

Net periodic benefit cost	$	460		$	670		$	919		$	1,339		$	2,257		$	2,980


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Note 3 – Revenue

Effective January 2018, the Company and Southwest adopted the FASB Accounting Standards Codification update, Topic 606, “Revenue from Contracts with Customers”, using the modified retrospective transition method. Under the modified retrospective approach, the information for periods prior to the adoption date has not been restated and continues to be reported under the accounting standards in effect for those periods. As permitted under the standard, the Company and Southwest have elected to apply the guidance retrospectively only to those contracts that were not completed at January 1, 2018. Management assessed the effects the new guidance has on the Company’s (and Southwest’s, in the case of utility operations) financial position, results of operations, and cash flows. Based on these assessments, the adoption of Topic 606 had no material impact on any of the financial statements of Southwest or the Company.

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

Natural Gas Operations Segment:

Southwest is engaged in the business of purchasing, distributing, and transporting natural gas for customers in portions of Arizona, Nevada, and California. Public utility rates, practices, facilities, and service territories of Southwest are subject to regulatory oversight. Southwest recognizes revenue when it satisfies its performance by transferring gas to the customer. Revenues also include the net impacts of margin tracker/decoupling accruals based on criteria in U.S. GAAP for rate-regulated entities associated with alternative revenue programs. Revenues from customer arrangements and from alternative revenue programs are described below.

Southwest acts as an agent for state and local taxing authorities in the collection and remission of a variety of taxes, including sales and use taxes and surcharges. These taxes are not included in gas operating revenues. Management uses the net classification method to report taxes collected from customers to be remitted to governmental authorities.

Southwest generally has two types of services to its customers: tariff sales and transportation–only service. Tariff sales encompass sales to many types of customers (primarily residential) under various rate schedules, subjectto cost-of-service ratemaking, which is based on the rate-regulation of state commissions and the FERC. Southwest provides both the commodity and the related distribution service to nearly all of its approximate 2 million customers, and only several hundred customers (who are eligible to secure their own gas) subscribe to transportation-only service. Also, only a few hundred customers have contracts with stated periods. Southwest recognizes revenue when it satisfies its performance requirement by transferring volumes of gas to the customer. Natural gas is delivered and consumed by the customer simultaneously. The provision of service is represented by the turn of the meter dial and is the primary representation of the satisfaction of performance obligations of Southwest. The amount billable via regulated rates (both volumetric and fixed monthly rates as part of rate design) corresponds to the value to the customer, and management believes that the amount billable under the “invoice practical expedient” (amount Southwest has the right to invoice) is appropriate to utilize for purposes of recognizing revenue. Estimated amounts remaining unbilled since the last meter read date are restricted from being billed due only to the passage of time and therefore are also recognized for service provided through the balance sheet date. While natural gas service is typically recurring, there is generally not a contract term for utility service. Therefore, the contract term is not generally viewed to extend beyond the service provided to date, and customers can generally terminate service at will.

Transportation-only service is also governed by tariff rate provisions. Transportation-only service is generally only available to very large customers under requirements of Southwest’s various tariffs. With this service, customers secure their own gas supply and Southwest provides transportation services to move the customer-supplied gas to the intended location. Southwest concluded that transportation/transmission service is suitable to an “over time” model. Rate structures under Southwest’s regulation for transportation customers include a combination of volumetric charges and monthly “fixed” charges (including charges commonly referred to as capacity charges, demand charges, or reservation charges) as part of the rate design of regulated jurisdictions. These types of fixed charges represent a separate performance obligation associated with standing ready over the period of the month to deliver quantities of gas, regardless of whether the customer takes delivery of any quantity of gas. The performance obligations under these circumstances are satisfied over the course of the month under an output measure of progress based on time, which correlates to the period for which the charges are eligible to be invoiced.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Under its regulation, Southwest enters into negotiated rate contracts for those customers located in proximity to another pipeline, which pose a threat of bypassing its distribution system. Southwest may also enter into similar contracts for customers otherwise able to satisfy their energy needs by means of alternative fuel to natural gas. Less than two dozen customers are party to contracts with rate components subject to negotiation. Many rate provisions and terms of service for these less common types of contracts are also subject to regulatory oversight and tariff provisions. The performance obligations for these customers are satisfied similar to those for other customers by means of transporting/delivering natural gas to the customer. Many or most of the rate components, and structures, for these types of customers are the same as those for similar customers without negotiated rate components; and the negotiated rates are within the parameters of the tariff guidelines. Management determined that these arrangements qualify for the invoice practical expedient for recognizing revenue. Furthermore, while some of these contracts include contract periods extending over time, including multiple years, as amounts billable under the contract are based on rates in effect for the customer for service provided to date, no significant financing component is deemed to exist.

As indicated above, revenues also include the net impacts of margin tracker/decoupling accruals. All of Southwest’s service territories have decoupled rate structures (also referred to as alternative revenue programs) that are designed to eliminate the direct link between volumetric sales and revenue, thereby mitigating the impacts of unusual weather variability and conservation on margin. The primary alternative revenue programs involve permissible adjustments for differences between stated tariff benchmarks and amounts billable through revenue from contracts with customers via existing rates. Such adjustments are recognized monthly in revenue and in the associated regulatory asset/liability in advance of rate adjustments intended to collect or return amounts recognized. Revenues recognized for the adjustment to the benchmarks noted are required to be presented separately from revenues from contracts from customers, and as such, are provided below and identified as alternative revenue program revenue.

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				Six Months Ended					Twelve Months Ended
	June 30,				June 30,					June 30,
(Thousands of dollars)	2018		2017		2018			2017		2018			2017
Residential	$	166,702	$	158,442	$	511,313		$	501,179	$	867,338		$	850,344
Small commercial		55,653		51,018		143,596			132,143		254,966			235,684
Large commercial		13,134		12,781		28,574			26,376		54,577			49,561
Industrial/other		5,491		5,043		12,001			10,494		23,533			20,157
Transportation		20,719		20,958		44,773			43,690		88,842			86,457

Revenue from contracts with customers		261,699		248,242		740,257			713,882		1,289,256			1,242,203
Alternative revenue program revenues (deferrals)		10,393		10,135		37,602			5,903		67,046			17,280
Other revenues (a)		3,587		1,785		(7,867	)		2,979		(6,766	)		3,945

Total Gas operating revenues	$	275,679	$	260,162	$	769,992		$	722,764	$	1,349,536		$	1,263,428

(a)	Includes various other revenues, including $1.6 million during the three months, and an offset of $12.5 million in both the six months and twelve months ending June 30, 2018 related to tax reform savings adjustments. Refer toIncome Taxes inNote 1 – Nature of Operations and Basis of Presentation.

Construction Services Segment:

The majority of Centuri contracts are performed under unit-price contracts. Generally, these contracts state prices per unit of installation. Typical installations are accomplished in a few weeks or less. Revenues are recorded as installations are completed. Revenues are recorded for long-term fixed-price contracts in a pattern that reflects the transfer of control of promised goods and services to the customer over time. The amount of revenue recognized on fixed-price contracts is based on costs expended to date relative to anticipated final contract costs. Some unit-price contracts contain caps that if encroached, trigger revenue and loss recognition similar to a fixed-price contract model.

Centuri is required to collect taxes imposed by various governmental agencies on the work performed by Centuri for its customers. These taxes are not included in construction revenues. Management uses the net classification method to report taxes collected from customers to be remitted to governmental authorities.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Centuri derives revenue from the installation, replacement, repair, and maintenance of energy distribution systems, and in developing industrial construction solutions. Centuri has operations in the U.S. and Canada. The majority of Centuri’s revenues are related to construction contracts for natural gas pipeline replacement and installation work for natural gas utilities. In addition, Centuri performs certain industrial construction activities for various customers and industries. Centuri has two types of agreements with its customers: master services agreements (“MSAs”) and bid contracts. Most of Centuri’s customers supply many of their own materials in order for Centuri to complete its work under the contracts.

An MSA identifies most of the terms describing each party’s rights and obligations that will govern future work authorizations. An MSA is often effective for multiple years. A work authorization is issued by the customer to describe the location, timing, and any additional information necessary to complete the work for the customer. The combination of the MSA and the work authorization determines when a contract exists and revenue recognition may begin. Each work authorization is generally a single performance obligation as Centuri is performing a significant integration service. Centuri has elected to use the portfolio method practical expedient at the customer level as the terms and conditions of the work performed under MSAs are similar in nature with each customer but vary significantly between customers.

A bid contract is typicallya one-time agreement for a specific project that has all necessary terms defining each party’s rights and obligations. Each bid contract is evaluated for revenue recognition individually. Control of assets created under bid contracts generally passes to the customer over time. Bid contracts often have a single performance obligation as Centuri is providing a significant integration service.

Centuri’s MSA and bid contracts are characterized as either fixed-price contracts or unit-price contracts for revenue recognition purposes. Thecost-to-cost input method is used to measure progress towards the satisfaction of a performance obligation for fixed-price contracts. Input methods result in the recognition of revenue based on the entity’s effort to satisfy the performance obligation relative to the total expected effort to satisfy the performance obligation. For unit-price contracts, an output method is used to measure progress towards satisfaction of a performance obligation. Also with regard to unit-price contracts, the output measurement will be the completion of each unit that is required under the contract.

Actual revenues and project costs can vary, sometimes substantially, from previous estimates due to changes in a variety of factors including unforeseen circumstances not originally contemplated. These factors, along with other risks inherent in performing fixed-price contracts may cause actual revenues and gross profit for a project to differ from previous estimates and could result in reduced profitability or losses on projects. Changes in these factors may result in revisions to costs and earnings, the impacts for which are recognized in the period in which the changes are identified. Once identified, these types of conditions continue to be evaluated for each project throughout the project term and ongoing revisions in management’s estimates of contract value, contract cost, and contract profit are recognized as necessary in the period determined.

Centuri categorizes work performed under MSAs and bid contracts into three primary service types: replacement gas construction, new gas construction, and other construction. Replacement gas construction includes work involving previously existing gas pipelines. New gas construction involves the installation of new pipelines or service lines to areas that do not already have gas services. Other construction includes all other work and can include industrial construction, water infrastructure construction, electric infrastructure construction, etc.

Contracts can have compensation/consideration that is variable. For MSAs, variable consideration is evaluated at the customer level as the terms creating variability in pricing are included within the MSA and are not specific to a work authorization. For multi-year MSAs, variable consideration items are typically determined for each year of the contract and not for the full contract term. For bid contracts, variable consideration is evaluated at the individual contract level. The expected value method or most likely amount method is used based on the nature of the variable consideration. Types of variable consideration include liquidated damages, delay penalties, performance incentives, safety bonuses, payment discounts, and volume rebates. Centuri will typically estimate variable consideration and adjust financial information, as necessary.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Change orders involve the modification in scope, price, or both to the current contract, requiring approval by both parties. The existing terms of the contract continue to be accounted for under the current contract until such time as a change order is approved. Once approved, the change order is either treated as a separate contract or as part of the existing contract, as appropriate, under the circumstances. When the scope is agreed upon in the change order but not the price, Centuri estimates the change to the transaction price.

The following tables display Centuri’s revenue from contracts with customers disaggregated by service type and contract type:


(Thousands of dollars)	Three Months Ended				Six Months Ended				Twelve Months Ended
	June 30,				June 30,				June 30,
	2018		2017		2018		2017		2018		2017
Service Types:
Replacement gas construction		$256,070		$181,512		$413,421		$301,950		$899,537		$733,927
New gas construction		44,276		40,226		80,473		73,305		172,545		197,100
Other construction		94,858		78,569		161,327		117,187		337,181		202,245

Total Construction revenues		$395,204		$300,307		$655,221		$492,442		$1,409,263		$1,133,272


(Thousands of dollars)	Three Months Ended				Six Months Ended				Twelve Months Ended
	June 30,				June 30,				June 30,
	2018		2017		2018		2017		2018		2017
Contract Types:
Master services agreement		$290,075		$208,361		$484,539		$355,553		$1,014,517		$825,980
Bid contract		105,129		91,946		170,682		136,889		394,746		307,292
Total Construction revenues		$395,204		$300,307		$655,221		$492,442		$1,409,263		$1,133,272
Unit priced contracts		$345,390		$272,427		$579,675		$450,098		$1,249,602		$974,107
Fixed priced contracts		49,814		27,880		75,546		42,344		159,661		159,165

Total Construction revenues		$395,204		$300,307		$655,221		$492,442		$1,409,263		$1,133,272

The following table provides 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, which is included in other current liabilities as of June 30, 2018 and December 31, 2017 on the Company’s Condensed Consolidated Balance Sheets:


(Thousands of dollars)	June 30, 2018		December 31, 2017
Contracts receivable, net	$	187,485	$	221,859
Revenue earned on contracts in progress in excess of billings		86,750		5,768
Amounts billed in excess of revenue earned on contracts		8,592		9,602

The revenue earned on contracts in progress in excess of billings primarily relates to Centuri’s rights to consideration for work completed but not billed and/or approved at the reporting date. The revenue earned on contracts in progress in excess of billings are transferred to contracts receivable when the rights become unconditional. The amounts billed in excess of revenue earned on contracts primarily relates to the advance consideration received from customers for which work has not yet been completed. The amount of revenue recognized in 2018 from performance obligations satisfied (or partially satisfied) in previous periods under these contracts is $34.7 million for the three months ended June 30, 2018 and $88.7 million for the six months ended June 30, 2018.

For Centuri’s contracts that have an original duration of one year or less, Centuri uses the practical expedient applicable to such contracts and does not consider 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.

Centuri has sixteen 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 June 30, 2018 is $86 million. Centuri expects to recognize the remaining performance obligations over the next four 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.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Construction services contracts receivable consists of the following:


(Thousands of dollars)	June 30, 2018
Billed on completed contracts and contracts in progress	$	185,911
Other receivables		1,660

Contracts receivable, gross		187,571
Allowance for doubtful accounts		(86	)

Contracts receivable, net	$	187,485

The balance of contracts receivable above is included in Accounts Receivable, net of allowances in the Southwest Gas Holdings, Inc. Condensed Consolidated Balance Sheet at June 30, 2018.

Management recognizes revenue on contracts in progress in excess of billings (a contract asset) within Accounts receivable, net of allowances in the Company’s Condensed Consolidated Balance Sheets, and amounts billed in excess of revenue earned (a contract liability) in Other current liabilities. However, the following shows the significant changes in these asset and liability balances associated with Centuri since January 1, 2018:


(Thousands of dollars)	June 30, 2018
	Revenue earned on contracts in progress in excess of billings			Amounts billed in excess of revenue earned on contracts
Revenue recognized that was included in the amounts billed in excess of revenue earned on contracts balance at the beginning of the period	$	—		$	(9,602	)
Increases due to amounts billed to customers in excess of revenue earned during the period		—			8,592
Transferred to contracts receivable from revenue earned on contracts in progress in excess of billings recognized at the beginning of the period		(5,768	)		—
Increases from the reclassification of contract assets due to the adoption of topic 606		51,744			—
Increases from contract assets, contingent on a future event occurring		35,006			—

In regards to the table above, prior to the adoption of ASC Topic 606, revenue earned on contracts in progress in excess of billings was only used to recognize contract assets related to fixed-price contracts under previous accounting guidance. This balance now includes any conditional contract assets for both fixed-price contracts and unit-price contracts. Centuri considers retention and unbilled amounts to customers to be conditional contract assets, as payment is contingent on the occurrence of a future event. Contracts receivable, net, included in Accounts receivable, net of allowances, includes only amounts that are unconditional in nature, which means only the passage of time remains and Centuri has invoiced the customer. Similarly, amounts billed in excess of revenue earned on contracts, which is included in the Other current liabilities line item on the Company’s Condensed Consolidated Balance Sheets, was only used to recognize contract liabilities related to fixed-price contracts under previous accounting guidance. This line item now includes contract liabilities related to both fixed-price contracts and unit-price contracts. In the event a contract asset or contract liability is expected to be recognized for greater than one year from the financial statement date, Centuri classifies those amounts as long-term contract assets or contract liabilities, included in Other deferred credits and other long-term liabilities on the Company’s Condensed Consolidated Balance Sheets.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Note 34 – Segment Information

The Company has two reportable segments: natural gas operations and construction 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			Construction Services		Other			Total		Natural Gas Operations		Construction Services		Other			Total
Three months ended September 30, 2017
Three months ended June 30, 2018
Revenues from external customers	$	213,059		$	351,850	$	—		$	564,909	$	275,679	$	362,132	$	—		$	637,811
Intersegment revenues		—			28,244		—			28,244		—		33,072		—			33,072

Total	$	213,059		$	380,094	$	—		$	593,153	$	275,679	$	395,204	$	—		$	670,883

Segment net income (loss)	$	(4,024	)	$	14,335	$	(107	)	$	10,204	$	2,622	$	19,236	$	(307	)	$	21,551

Three months ended September 30, 2016
Three months ended June 30, 2017
Revenues from external customers	$	200,179		$	312,531	$	—		$	512,710	$	260,162	$	277,384	$	—		$	537,546
Intersegment revenues		—			27,259		—			27,259		—		22,923		—			22,923

Total	$	200,179		$	339,790	$	—		$	539,969	$	260,162	$	300,307	$	—		$	560,469

Segment net income (loss)	$	(12,405	)	$	14,877	$	—		$	2,472	$	9,522	$	8,716	$	(374	)	$	17,864


	Natural Gas Operations			Construction Services		Other			Total		Natural Gas Operations		Construction Services		Other			Total
Nine months ended September 30, 2017
Six months ended June 30, 2018
Revenues from external customers	$	935,823		$	800,073	$	—		$	1,735,896	$	769,992	$	594,991	$	—		$	1,364,983
Intersegment revenues		—			72,463		—			72,463		—		60,230		—			60,230

Total	$	935,823		$	872,536	$	—		$	1,808,359	$	769,992	$	655,221	$	—		$	1,425,213

Segment net income (loss)	$	82,436		$	15,717	$	(777	)	$	97,376	$	92,971	$	8,235	$	(564	)	$	100,642

Nine months ended September 30, 2016
Revenues from external customers	$	980,927		$	762,835	$	—		$	1,743,762
Intersegment revenues		—			75,203		—			75,203

Total	$	980,927		$	838,038	$	—		$	1,818,965

Segment net income	$	67,536		$	19,325	$	—		$	86,861


	Natural Gas Operations			Construction Services		Other			Total
Twelve months ended September 30, 2017
Six months ended June 30, 2017
Revenues from external customers	$	1,276,308		$	1,078,195	$	—		$	2,354,503	$	722,764	$	448,223	$	—		$	1,170,987
Intersegment revenues		—			95,381		—			95,381		—		44,219		—			44,219

Total	$	1,276,308		$	1,173,576	$	—		$	2,449,884	$	722,764	$	492,442	$	—		$	1,215,206

Segment net income (loss)	$	134,323		$	29,010	$	(777	)	$	162,556	$	86,460	$	1,382	$	(670	)	$	87,172

Twelve months ended September 30, 2016

											Natural Gas Operations		Construction Services		Other			Total
Twelve months ended June 30, 2018
Revenues from external customers	$	1,376,388		$	1,022,416	$	—		$	2,398,804	$	1,349,536	$	1,296,093	$	—		$	2,645,629
Intersegment revenues		—			105,566		—			105,566		—		113,170		—			113,170

Total	$	1,376,388		$	1,127,982	$	—		$	2,504,370	$	1,349,536	$	1,409,263	$	—		$	2,758,799

Segment net income	$	119,836		$	33,144	$	—		$	152,980
Segment net income (loss)											$	163,329	$	45,213	$	(1,231	)	$	207,311

Twelve months ended June 30, 2017
Revenues from external customers											$	1,263,428	$	1,038,876	$	—		$	2,302,304
Intersegment revenues												—		94,396		—			94,396

Total											$	1,263,428	$	1,133,272	$	—		$	2,396,700

Segment net income (loss)											$	125,942	$	29,552	$	(670	)	$	154,824

Note 45 – Derivatives and Fair Value Measurements

Derivatives. In managing its natural gas supply portfolios, Southwest has historically entered into fixed- and variable-price contracts, which qualify as derivatives. Additionally, Southwest utilizesfixed-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.~~

1923


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

for contracts that are probable of delivery in the normal course of business, and are exempt from fair value reporting. The variable-price contracts have no significant market value. The Swaps are recorded at fair value.

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 ~~October 2017~~July 2018 through ~~March~~October 2019. 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):

   September 30, 2017    December 31, 2016
Contract notional amounts
   10,936    10,543


	June 30, 2018		December 31, 2017
Contract notional amounts		13,035		10,929

Southwest does not utilize derivative financial instruments for speculative purposes, nor does it have trading operations.

The following table sets forth the gains and (losses) recognized on the Swaps (derivatives) for the three-, ~~nine-~~six-, and twelve-month periods ended ~~September~~June 30, ~~2017~~2018 and ~~2016~~2017 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)~~


(Thousands of dollars)																				(Thousands of dollars)
		Three Months Ended						Nine Months Ended						Twelve Months Ended								Three Months Ended						Six Months Ended						Twelve Months Ended
	Location of Gain or (Loss)	September 30						September 30						September 30							Location of Gain or (Loss) Recognized in Income on Derivative	June 30						June 30						June 30
Instrument	Recognized in Income on Derivative	2017			2016			2017			2016			2017			2016					2018			2017			2018			2017			2018			2017
Swaps	Net cost of gas sold	$	(546	)	$	(2,072	)	$	(6,851	)	$	2,253		$	(4,098	)	$	(656	)		Net cost of gas sold	$	870		$	(1,168	)	$	(4,326	)		$(6,305)			$(9,593)		$	(5,624	)
Swaps	Net cost of gas sold		546	*		2,072	*		6,851	*		(2,253	)*		4,098	*		656	*		Net cost of gas sold		(870	)*		1,168	*		4,326	*		6,305	*		9,593	*		5,624	*

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 overten-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:


September 30, 2017 Instrument	Balance Sheet Location	Asset Derivatives		Liability Derivatives			Net Total
Swaps	Prepaids and other current assets	$	56	$	(22	)	$	34
June 30, 2018 Instrument										Balance Sheet Location	Asset Derivatives		Liability Derivatives			Net Total
Swaps	Other current liabilities		27		(1,899	)		(1,872	)	Other current liabilities	$	654	$	(5,901	)	$	(5,247	)
Swaps	Other deferred credits		1		(768	)		(767	)	Other deferred credits		83		(1,016	)		(933	)

Total		$	84	$	(2,689	)	$	(2,605	)		$	737	$	(6,917	)	$	(6,180	)


December 31, 2016 Instrument	Balance Sheet Location	Asset Derivatives		Liability Derivatives			Net Total
December 31, 2017 Instrument										Balance Sheet Location	Asset Derivatives		Liability Derivatives			Net Total
Swaps	Deferred charges and other assets	$	899	$	(54	)	$	845		Other current liabilities	$	11	$	(4,468	)	$	(4,457	)
Swaps	Prepaids and other current assets		3,551		(19	)		3,532		Other deferred credits		19		(1,342	)		(1,323	)

Total		$	4,450	$	(73	)	$	4,377			$	30	$	(5,810	)	$	(5,780	)

2024


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

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 ~~purchased gas adjustment (“PGA”)~~PGA mechanism in determining its 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		Nine Months Ended		Twelve Months Ended		Three Months Ended		Six Months Ended		Twelve Months Ended
(Thousands of dollars)	September 30, 2017		September 30, 2017		September 30, 2017		June 30, 2018		June 30, 2018		June 30, 2018
Paid to counterparties	$	143	$	1,555	$	2,655	$	1,216	$	3,931	$	5,620

Received from counterparties	$	—	$	1,685	$	2,060	$	6	$	6	$	6

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).

September 30, 2017

Instrument

Balance Sheet Location

Net Total

Swaps

Other current liabilities

(34

)

June 30, 2018

Instrument

Balance Sheet Location

Net Total

Swaps

Prepaids and other current assets

1,872

Prepaids and other current assets

5,247

Swaps

Deferred charges and other assets

767

Deferred charges and other assets

933

December 31, 2016

Instrument

Balance Sheet Location

Net Total

December 31, 2017

Instrument

Balance Sheet Location

Net Total

Swaps

Other deferred credits

(845

)

Prepaids and other current assets

4,457

Swaps

Other current liabilities

(3,532

)

Deferred charges and other assets

1,323

Fair Value Measurements. The estimated fair values of Southwest’s Swaps were determined at ~~September~~June 30, ~~2017~~2018 and December 31, ~~2016~~2017 using ~~New York Mercantile Exchange (“NYMEX”)~~ futures settlement prices, published by the CME Group, for the delivery of natural gas at Henry Hub adjusted by the price of ~~NYMEX ClearPort basis Swaps,~~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 (inputs, other than quoted prices, for similar assets or liabilities) 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)	June 30, 2018			December 31, 2017
Liabilities at fair value:
Other current liabilities - Swaps	$	(5,247	)	$	(4,457	)
Other deferred credits - Swaps		(933	)		(1,323	)

Net Assets (Liabilities)	$	(6,180	)	$	(5,780	)


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

~~Level 2—Significant other observable inputs~~

(Thousands of dollars)    September 30, 2017    December 31, 2016
Assets at fair value:

Prepaids and other current assets—Swaps
   $ 34    $ 3,532
Deferred charges and other assets—Swaps
   —      845
Liabilities at fair value:

Other current liabilities—Swaps
   (1,872 )    —
Other deferred credits—Swaps
   (767 )    —




Net Assets (Liabilities)
   $ (2,605 )    $ 4,377

No financial assets or liabilities associated with the Swaps, which were accounted for at fair value, fell within Level 1 (quoted prices in active markets for identical financial assets) or Level 3 (significant unobservable inputs) of the fair value hierarchy.

With regard to the fair values of assets associated with pension and postretirement benefit plans, asset values were last updated as required as of December ~~2016.~~2017. Refer toNote 1011 – Pension and Other Post Retirement Benefits in the ~~2016~~2017 Annual Report to Shareholders on Form10-K, which is incorporated by reference into the 2017 Form10-K.

Note 56 – Common Stock

In January 2017, the holding company reorganization was made effective and each outstanding share of Southwest Gas Corporation common stock was converted into a share of common stock in Southwest Gas Holdings, Inc., on a~~one-for-one~~ ~~basis. The ticker symbol of the stock, “SWX,” remained unchanged, and Southwest Gas Corporation became a wholly owned subsidiary of Southwest Gas Holdings, Inc.~~

On March 29, 2017, the Company filed with the ~~Securities Exchange Commission (“SEC”)~~SEC an automatic shelf registration statement on FormS-3 (FileNo. 333-217018), which became effective upon filing, for the offer and sale of up to $150 million of common stock from time to time inat-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”). During the three months ~~and nine months~~ ending ~~September~~June 30, ~~2017,~~2018, the Company sold, through the continuous equity offering program with BNY Mellon Capital Markets, LLC as agent, an aggregate of ~~147,077~~748,932 shares of the Company’s common stock in the open market at a weighted average price of ~~$80.07~~$74.10 per share, resulting in proceeds to the Company of ~~$11,659,104,~~$54,940,503 net of ~~$117,769~~$554,954 in agent commissions. During the six months ending June 30, 2018, the Company sold, through the continuous equity offering program with BNY Mellon Capital Markets, LLC as agent, an aggregate of 886,232 shares of the Company’s common stock in the open market at a weighted average price of $73.00 per share, resulting in proceeds to the Company of $64,048,167 net of $646,951 in agent commissions. During the twelve months ended June 30, 2018, the Company sold, through this continuous equity offering program with the same party acting as agent, an aggregate of 1,391,939 shares of the Company’s common stock in the open market at a weighted average price of $76.49 per share, resulting in proceeds to the Company of $105,407,194, net of $1,064,719 in agent commissions. As of ~~September~~June 30, ~~2017,~~2018, the Company had up to ~~$138,223,127~~$43,528,087 of common stock available for sale under the program. Net proceeds from the sale of shares of common stock under the Equity Shelf Program are intended for general corporate purposes, including the acquisition of property for the construction, completion, extension, or improvement of pipeline systems and facilities located in and around the communities served by Southwest. ~~Commensurate with these intentions, proceeds during the 3~~^rd ~~quarter of 2017 were contributed to, and reflected in the records of, Southwest (as a capital contribution from the parent holding company).~~

During the ~~nine~~six months ended ~~September~~June 30, ~~2017,~~2018, the Company issued approximately ~~103,000~~77,000 shares of common stock through the Restricted Stock/Unit Plan and Management Incentive Plan.

Also during the six months ended June 30, 2018, the Company issued 73,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan (“DRSPP”), raising approximately $5 million.

Note 67 – Long-Term Debt

Carrying amounts of long-term debt and related estimated fair values as of ~~September~~June 30, ~~2017~~2018 and December 31, ~~2016~~2017 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


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

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.

   September 30, 2017    December 31, 2016
   Carrying    Market    Carrying    Market
   Amount    Value    Amount    Value
(Thousands of dollars)

Southwest Gas Corporation:

Debentures:

Notes, 4.45%, due 2020
   $ 125,000    $ 130,325    $ 125,000    $ 129,703
Notes, 6.1%, due 2041
   125,000    154,434    125,000    149,734
Notes, 3.875%, due 2022
   250,000    258,943    250,000    254,900
Notes, 4.875%, due 2043
   250,000    275,168    250,000    266,793
Notes, 3.8%, due 2046
   300,000    292,578    300,000    283,029
8% Series, due 2026
   75,000    97,218    75,000    94,691
Medium-term notes, 7.59% series, due 2017
   —      —      25,000    25,040
Medium-term notes, 7.78% series, due 2022
   25,000    29,174    25,000    29,290
Medium-term notes, 7.92% series, due 2027
   25,000    31,964    25,000    31,905
Medium-term notes, 6.76% series, due 2027
   7,500    8,920    7,500    8,769
Unamortized discount and debt issuance costs
   (9,498 )       (9,931 )





   1,173,002       1,197,569





Revolving credit facility and commercial paper
   150,000    150,000    5,000    5,000





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
   (2,212 )       (2,489 )





   197,788       197,511





Less: current maturities
   —         (25,000 )





Long-term debt, less current maturities - Southwest Gas Corporation
   $ 1,520,790       $ 1,375,080





Centuri:

Centuri term loan facility
   $ 107,250    107,403    $ 106,700    106,819
Unamortized debt issuance costs
   (383 )       (516 )





   106,867       106,184
Centuri secured revolving credit facility
   81,250    81,402    41,185    41,292
Centuri other debt obligations
   51,527    51,978    52,635    52,840
Less: current maturities
   (28,453 )       (25,101 )





Long-term debt, less current maturities - Centuri
   $ 211,191       $ 174,903





Consolidated Southwest Gas Holdings, Inc.:

Southwest Gas Corporation long-term debt
   $ 1,520,790       $ 1,400,080
Centuri long-term debt
   239,644       200,004
Less: current maturities
   (28,453 )       (50,101 )





Long-term debt, less current maturities - Southwest Gas Holdings, Inc.
   $ 1,731,981       $ 1,549,983


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018


	June 30, 2018					December 31, 2017
	Carrying			Fair		Carrying			Fair
	Amount			Value		Amount			Value
(Thousands of dollars)
Southwest Gas Corporation:
Debentures:
Notes, 4.45%, due 2020	$	125,000		$	127,258	$	125,000		$	129,273
Notes, 6.1%, due 2041		125,000			150,816		125,000			158,304
Notes, 3.875%, due 2022		250,000			252,108		250,000			256,163
Notes, 4.875%, due 2043		250,000			267,985		250,000			283,243
Notes, 3.8%, due 2046		300,000			281,028		300,000			302,970
Notes, 3.7%, due 2028		300,000			298,068		—			—
8% Series, due 2026		75,000			95,789		75,000			96,063
Medium-term notes, 7.78% series, due 2022		25,000			27,984		25,000			28,714
Medium-term notes, 7.92% series, due 2027		25,000			30,228		25,000			31,542
Medium-term notes, 6.76% series, due 2027		7,500			8,740		7,500			8,882
Unamortized discount and debt issuance costs		(12,259	)				(9,350	)

		1,470,241					1,173,150

Revolving credit facility and commercial paper		48,000			48,000		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		(1,934	)				(2,119	)

		198,066					197,881

Less: current maturities		—					—

Long-term debt, less current maturities - Southwest Gas Corporation	$	1,716,307				$	1,521,031

Centuri:
Centuri term loan facility	$	189,876		$	190,524	$	199,578		$	207,588
Unamortized debt issuance costs		(999	)				(1,111	)

		188,877					198,467
Centuri secured revolving credit facility		87,952			87,998		56,472			56,525
Centuri other debt obligations		76,535			76,419		47,952			48,183
Less: current maturities		(31,928	)				(25,346	)

Long-term debt, less current maturities - Centuri	$	321,436				$	277,545

Consolidated Southwest Gas Holdings, Inc.:
Southwest Gas Corporation long-term debt	$	1,716,307				$	1,521,031
Centuri long-term debt		353,364					302,891
Less: current maturities		(31,928	)				(25,346	)

Long-term debt, less current maturities - Southwest Gas Holdings, Inc.	$	2,037,743				$	1,798,576

~~In March 2017,~~ Southwest ~~amended its~~has a $400 million credit facility ~~increasing the borrowing capacity from $300 million to $400 million. Also, the facility was previously~~that is scheduled to expire in March ~~2021 and was extended to March~~ 2022. Southwest ~~continues to designate~~designates $150 million of capacity related to the facility as long-term debt and ~~with the total capacity now available,~~ 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 ~~the~~ Southwest’s senior unsecured debt rating. At ~~September~~June 30, ~~2017,~~2018, 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 ~~September~~June 30, ~~2017, $150~~2018, $48 million was outstanding on the long-term portion (not including the commercial paper program, discussed below) and ~~$83 million was~~no borrowings were outstanding on the short-term portion of this credit facility.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Southwest has a $50 million commercial paper program. Any issuance under the commercial paper program is supported by Southwest’s current revolving credit facility ~~(See~~~~Note 7 – Short-Term Debt~~).and, therefore, does not represent additional borrowing capacity. Borrowings under the commercial paper program are designated as long-term debt. Interest rates for the program are calculated at the then current commercial paper rate. At June��30, 2018, no borrowings were outstanding under the commercial paper program.

~~At September 30, 2017,~~ 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. A portion of the proceeds were used to repay amounts then outstanding under the revolving portion of the credit facility and the remainder to repay amounts then outstanding under the commercial paper program.

Centuri has a ~~$300~~$450 million senior secured revolving credit and term loan facility that is scheduled to expire in ~~October 2019.~~November 2022. This facility includes a revolving credit facility and a term loan facility. The line of credit portion of the facility is $250 million; amounts borrowed and repaid under the revolving credit facility are available to bere-borrowed. The term loan facility portion ~~had an initial~~has a limit of approximately ~~$150 million, which~~$200 million. The limit on the term loan facility was reached in ~~2014 and had $107 million outstanding (after repayments) at September 30,~~November 2017. No further borrowing is permitted under the term loan facility. The ~~$300~~$450 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 ~~September~~June 30, ~~2017~~2018 totaled ~~$526~~$659 million. At ~~September~~June 30, ~~2017, $189~~2018, $278 million in borrowings were outstanding under the Centuri facility. Additionally, for the quarter ended June 30, 2018, Centuri entered into equipment loans for approximately $40 million with a maturity date of May 2023 under an existing agreement.

Note 78 – Short-Term Debt

~~In March 2017, Southwest Gas Holdings, Inc. entered into 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. Interest rates for this facility are calculated at either the LIBOR or the “alternate base rate,” plus in each case an applicable margin that is determined based on the Company’s senior unsecured debt rating. The applicable margin ranges from 0.75% to 1.50% for loans bearing interest with reference to LIBOR and from 0% to 0.5% for loans bearing interest with reference to the alternative base rate. The Company is also required to pay a commitment fee on the unfunded portion of the commitments based on its senior unsecured long-term debt rating. The commitment fee ranges from 0.075% to 0.200% per annum. At September 30, 2017, $27.5 million was outstanding under this facility.

~~As discussed in~~~~Note 6 – Long-Term Debt~~~~, Southwest~~ has a ~~$400~~$100 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~~2022. The Company had ~~$83~~$22.5 million in short-term borrowings outstanding at ~~September~~June 30, ~~2017~~2018 under this facility.


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

Note 89 – Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income

The table below provides details of activity in equity and the ~~redeemable~~ noncontrolling interest for Southwest Gas Holdings, Inc. on a consolidated basis during the ~~nine~~six months ended ~~September~~June 30, ~~2017.~~2018.


	Southwest Gas Holdings, Inc. Equity																					Southwest Gas Holdings, Inc. Equity
							Accumulated												Redeemable										Accumulated
					Additional		Other						Non-						Noncontrolling							Additional			Other						Non-
	Common Stock				Paid-in		Comprehensive			Retained			controlling						Interest			Common Stock				Paid-in			Comprehensive			Retained			controlling
(In thousands, except per share amounts)	Shares		Amount		Capital		Income (Loss)			Earnings			Interest			Total			(Temporary Equity)			Shares		Amount		Capital			Income (Loss)			Earnings			Interest			Total
DECEMBER 31, 2016		47,482	$	49,112	$	903,123	$	(48,008	)	$	759,263		$	(2,217	)	$	1,661,273		$	22,590
DECEMBER 31, 2017																							48,090	$	49,720	$	955,332		$	(47,682	)	$	857,398		$	(2,365	)	$	1,812,403
Common stock issuances		250		250		21,090											21,340						1,036		1,036		68,886												69,922
Net income (loss)											97,376			(78	)		97,298			248													100,642			(797	)		99,845
Redemption value adjustments											(355	)					(355	)		355
Foreign currency exchange translation adj.								1,850									1,850			11										(1,601	)								(1,601	)
Redemption of Centuri shares from noncontrolling parties																				(23,000	)
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax								1,786									1,786
Net actuarial gain arising during period, less amortization of unamortized benefit plan cost, net of tax																														1,792									1,792
Amounts reclassified to net income, net of tax (FSIRS)								1,554									1,554													1,271									1,271
Centuri dividend to redeemable noncontrolling interest																				(204	)
Reclassification of excess deferred taxes (a)																														(9,300	)		9,300						—
Elimination of shares from noncontrolling interest (b)																											(2,710	)								2,710			—
Dividends declared
Common: $1.485 per share											(71,350	)					(71,350	)
Common: $0.52 per share																																	(51,065	)					(51,065	)

SEPTEMBER 30, 2017		47,732	$	49,362	$	924,213	$	(42,818	)	$	784,934		$	(2,295	)	$	1,713,396		$	—
JUNE 30, 2018																							49,126	$	50,756	$	1,021,508		$	(55,520	)	$	916,275		$	(452	)	$	1,932,567

(a)	Release of excess deferred taxes accumulated prior to December 22, 2017 (date of enactment of the TCJA), as a result of the adoption of ASU2018-02, which permitted such release.

(b)

Centuri, through its subsidiary, NPL, has historically held a 65% ownership interest in IntelliChoice Energy, LLC (“ICE”). A residual interest of 35% has been held by a third party. During the second quarter of 2018, an additional $1 million of capital was contributed by NPL, thereby increasing NPL’s ownership interest to 95%. The carrying amount


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

of the noncontrolling interest has been adjusted with a corresponding charge to Additionalpaid-in capital on the Company’s Condensed Consolidated Balance Sheet.

The table below provides details of activity in equity for Southwest Gas Corporation during the ~~nine~~six months ended ~~September~~June 30, ~~2017. Effective in January 2017, Southwest became a subsidiary of Southwest Gas Holdings, Inc., and only~~2018. Only equity shares of the ~~latter~~Company are publicly traded, under the ticker symbol “SWX.”

   Southwest Gas Corporation Equity
            Accumulated
         Additional    Other
   Common Stock    Paid-in    Comprehensive Retained
(In thousands, except per share amounts)
   Shares    Amount    Capital    Income (Loss) Earnings Total
DECEMBER 31, 2016
   47,482    $ 49,112    $ 897,346    $ (45,639 ) $ 767,061 $ 1,667,880
Net income
            82,436 82,436
Other comprehensive income (loss):

Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax
            1,786 1,786
Amounts reclassified to net income, net of tax (FSIRS)
            1,554 1,554
Distribution to Southwest Gas Holdings, Inc. investment in discontinued operations
            (182,773 ) (182,773 )
Stock-based compensation (a)
         8,576    (587 ) 7,989
Dividends declared to Southwest Gas Holdings, Inc.
            (60,130 ) (60,130 )
Contributions from Southwest Gas Holdings, Inc.
         11,659    11,659








SEPTEMBER 30, 2017
   47,482    $ 49,112    $ 917,581    $ (42,299 ) $ 606,007 $ 1,530,401


	Southwest Gas Corporation Equity
							Accumulated
					Additional		Other
	Common Stock				Paid-in		Comprehensive			Retained
(In thousands)	Shares		Amount		Capital		Income (Loss)			Earnings			Total
DECEMBER 31, 2017		47,482	$	49,112	$	948,767	$	(47,073	)	$	659,193		$	1,609,999
Net income											92,971			92,971
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax								1,792						1,792
Amounts reclassified to net income, net of tax (FSIRS)								1,271						1,271
Reclassification of excess deferred taxes (a)								(9,300	)		9,300			—
Stock-based compensation (b)						702					(338	)		364
Dividends declared to Southwest Gas Holdings, Inc.											(44,000	)		(44,000	)
Contributions from Southwest Gas Holdings, Inc.						56,596								56,596

JUNE 30, 2018		47,482	$	49,112	$	1,006,065	$	(53,310	)	$	717,126		$	1,718,993

(a)	Release of excess deferred taxes accumulated prior to December 22, 2017 (date of enactment of the TCJA), as a result of the adoption of ASU2018-02, which permitted such release.

(b)

Stock-based compensation is based on stock awards of Southwest Gas Corporation to be issued in shares of Southwest Gas Holdings, Inc. The table above gives effect to the holding company reorganization whereby Southwest and Centuri became subsidiaries of the Company. The historic investment in Centuri was distributed to the parent holding company. This presentation is only applicable to Southwest and not to the Company overall, as Centuri continues to be included in

The following information provides insight into amounts impacting the Company’s Other Comprehensive Income (Loss), both before andafter-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 table above. See Note 5 – Derivatives and Fair Value Measurements for additional information on the FSIRS.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~

the continuing operations of the Company. Also in connection with the holding company creation, compensation plans of Southwest include programs that will be settled with equity shares issued by Southwest Gas Holdings, Inc. Management has determined that when no consideration is directly exchanged for these programs between Southwest and the Company, the accounting impact at Southwest for these programs is reflected both as compensation expense and as an equity contribution (of the parent) in Southwest.

2018

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 table above, as well as the Redeemable Noncontrolling Interest. See ~~Note 4 – Derivatives and Fair Value Measurements~~ ~~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
	Three Months Ended September 30, 2017									Three Months Ended September 30, 2016									June 30, 2018									June 30, 2017
	Before-			Tax			Net-of-			Before-			Tax			Net-of-			Before-			Tax			Net-of-			Before-			Tax			Net-of-
	Tax			(Expense)			Tax			Tax			(Expense)			Tax			Tax			(Expense)			Tax			Tax			(Expense)			Tax
	Amount			or Benefit (1)			Amount			Amount			or Benefit (1)			Amount			Amount			or Benefit (1)			Amount			Amount			or Benefit (1)			Amount
Defined benefit pension plans:
Amortization of prior service cost																			$	334		$	(80	)	$	254		$	334		$	(127	)	$	207
Amortization of net actuarial (gain)/loss																				8,404			(2,017	)		6,387			6,361			(2,417	)		3,944
Regulatory adjustment																				(7,559	)		1,815			(5,744	)		(5,735	)		2,179			(3,556	)

Pension plans other comprehensive income																				1,179			(282	)		897			960			(365	)		595
FSIRS (designated hedging activities):
Amounts reclassifed into net income																				836			(200	)		636			836			(318	)		518

FSIRS other comprehensive income																				836			(200	)		636			836			(318	)		518

Total other comprehensive income - Southwest Gas Corporation																				2,015			(482	)		1,533			1,796			(683	)		1,113

Foreign currency translation adjustments:
Translation adjustments																				(690	)		—			(690	)		629			—			629

Foreign currency other comprehensive income (loss)																				(690	)		—			(690	)		629			—			629

Total other comprehensive income - Southwest Gas Holdings, Inc.																			$	1,325		$	(482	)	$	843		$	2,425		$	(683	)	$	1,742


																			Six Months Ended									Six Months Ended
																			June 30, 2018									June 30, 2017
																			Before-			Tax			Net-of-			Before-			Tax			Net-of-
																			Tax			(Expense)			Tax			Tax			(Expense)			Tax
																			Amount			or Benefit (1)			Amount			Amount			or Benefit (1)			Amount
Defined benefit pension plans:
Amortization of prior service cost																			$	668		$	(160	)	$	508		$	668		$	(254	)	$	414
Amortization of net actuarial (gain)/loss																				16,808			(4,034	)		12,774			12,722			(4,834	)		7,888
Regulatory adjustment																				(15,119	)		3,629			(11,490	)		(11,470	)		4,358			(7,112	)

Pension plans other comprehensive income																				2,357			(565	)		1,792			1,920			(730	)		1,190
FSIRS (designated hedging activities):
Amounts reclassifed into net income																				1,673			(402	)		1,271			1,672			(636	)		1,036

FSIRS other comprehensive income																				1,673			(402	)		1,271			1,672			(636	)		1,036

Total other comprehensive income - Southwest Gas Corporation																				4,030			(967	)		3,063			3,592			(1,366	)		2,226

Foreign currency translation adjustments:
Translation adjustments																				(1,601	)		—			(1,601	)		849			—			849

Foreign currency other comprehensive income (loss)																				(1,601	)		—			(1,601	)		849			—			849

Total other comprehensive income - Southwest Gas Holdings, Inc.																			$	2,429		$	(967	)	$	1,462		$	4,441		$	(1,366	)	$	3,075


																			Twelve Months Ended									Twelve Months Ended
																			June 30, 2018									June 30, 2017
																			Before-			Tax			Net-of-			Before-			Tax			Net-of-
																			Tax			(Expense)			Tax			Tax			(Expense)			Tax
																			Amount			or Benefit (1)			Amount			Amount			or Benefit (1)			Amount
Defined benefit pension plans:
Net actuarial gain/(loss)																			$	(43,027	)	$	10,326		$	(32,701	)	$	(22,770	)	$	8,652		$	(14,118	)
Amortization of prior service cost	$	333		$	(126	)	$	207		$	333		$	(126	)	$	207			1,335			(413	)		922			1,335			(507	)		828
Amortization of net actuarial (gain)/loss		6,362			(2,418	)		3,944			6,767			(2,571	)		4,196			29,531			(8,869	)		20,662			26,255			(9,976	)		16,279
Regulatory adjustment		(5,734	)		2,179			(3,555	)		(6,122	)		2,326			(3,796	)		8,691			(479	)		8,212			(4,808	)		1,826			(2,982	)

Pension plans other comprehensive income (loss)		961			(365	)		596			978			(371	)		607			(3,470	)		565			(2,905	)		12			(5	)		7
FSIRS (designated hedging activities):
Amounts reclassifed into net income		835			(317	)		518			835			(317	)		518			3,345			(1,037	)		2,308			3,344			(1,271	)		2,073

FSIRS other comprehensive income		835			(317	)		518			835			(317	)		518			3,345			(1,037	)		2,308			3,344			(1,271	)		2,073

Total other comprehensive income (loss) - Southwest Gas Corporation		1,796			(682	)		1,114			1,813			(688	)		1,125			(125	)		(472	)		(597	)		3,356			(1,276	)		2,080

Foreign currency translation adjustments:
Translation adjustments		1,012			—			1,012			(238	)		—			(238	)		(679	)		—			(679	)		158			—			158

Foreign currency other comprehensive income (loss)		1,012			—			1,012			(238	)		—			(238	)		(679	)		—			(679	)		158			—			158

Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	2,808		$	(682	)	$	2,126		$	1,575		$	(688	)	$	887		$	(804	)	$	(472	)	$	(1,276	)	$	3,514		$	(1,276	)	$	2,238


	Nine Months Ended September 30, 2017									Nine Months Ended September 30, 2017
	Before-			Tax			Net-of-			Before-			Tax			Net-of-
	Tax			(Expense)			Tax			Tax			(Expense)			Tax
	Amount			or Benefit (1)			Amount			Amount			or Benefit (1)			Amount
Defined benefit pension plans:
Amortization of prior service cost	$	1,001		$	(380	)	$	621		$	1,001		$	(380	)	$	621
Amortization of net actuarial (gain)/loss		19,084			(7,252	)		11,832			20,300			(7,714	)		12,586
Regulatory adjustment		(17,204	)		6,537			(10,667	)		(18,368	)		6,980			(11,388	)

Pension plans other comprehensive income (loss)		2,881			(1,095	)		1,786			2,933			(1,114	)		1,819
FSIRS (designated hedging activities):
Amounts reclassifed into net income		2,507			(953	)		1,554			2,508			(952	)		1,556

FSIRS other comprehensive income		2,507			(953	)		1,554			2,508			(952	)		1,556

Total other comprehensive income (loss)—Southwest Gas Corporation		5,388			(2,048	)		3,340			5,441			(2,066	)		3,375

Foreign currency translation adjustments:
Translation adjustments		1,861			—			1,861			614			—			614

Foreign currency other comprehensive income (loss)		1,861			—			1,861			614			—			614

Total other comprehensive income (loss)	$	7,249		$	(2,048	)	$	5,201		$	6,055		$	(2,066	)	$	3,989

2630


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

   Twelve Months Ended
September 30, 2017 Twelve Months Ended
September 30, 2016
   Before- Tax Net-of- Before- Tax Net-of-
   Tax (Expense) Tax Tax (Expense) Tax
   Amount or Benefit (1) Amount Amount or Benefit (1) Amount
Defined benefit pension plans:

Net actuarial gain/(loss)
   $ (22,770 ) $ 8,652 $ (14,118 ) $ (30,519 ) $ 11,597 $ (18,922 )
Amortization of prior service cost
   1,335 (507 ) 828 1,335 (507 ) 828
Amortization of net actuarial (gain)/loss
   25,850 (9,823 ) 16,027 28,895 (10,980 ) 17,915
Regulatory adjustment
   (4,420 ) 1,679 (2,741 ) (653 ) 249 (404 )


Pension plans other comprehensive income (loss)
   (5 ) 1 (4 ) (942 ) 359 (583 )
FSIRS (designated hedging activities):

Amounts reclassifed into net income
   3,344 (1,271 ) 2,073 3,344 (1,271 ) 2,073


FSIRS other comprehensive income (loss)
   3,344 (1,271 ) 2,073 3,344 (1,271 ) 2,073


Total other comprehensive income (loss)—Southwest Gas Corporation
   3,339 (1,270 ) 2,069 2,402 (912 ) 1,490


Foreign currency translation adjustments:

Translation adjustments
   1,408 —   1,408 233 —   233


Foreign currency other comprehensive income (loss)
   1,408 —   1,408 233 —   233


Total other comprehensive income (loss)—Southwest Gas Holdings, Inc.
   $ 4,747 $ (1,270 ) $ 3,477 $ 2,635 $ (912 ) $ 1,723

(1)

Tax amounts are calculated using a 24% rate following the December 22, 2017 enactment date of the TCJA. For periods prior to the enactment date (and included in specific line items of the tables for the twelve months ended June 30, 2018 and 2017), tax amounts were calculated using a 38% rate. The tax effect ofbefore-tax amounts remaining in the balance of Accumulated other comprehensive income as of June 30, 2018 is effectively computed using a 24% tax rate overall after the reclassification of previously stranded excess deferred taxes existing as a result of the TCJA (see table for Accumulated other comprehensive income, including the balance, below). 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, as repatriation of earnings is not anticipated.

Approximately ~~$2.1~~$2.5 million of realized losses (net of tax) related to the FSIRS, reported in Accumulated other comprehensive income ~~(“AOCI”)~~ at ~~September~~June 30, ~~2017,~~2018, 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—~~AOCI - Rollforward

(Thousands of dollars)

   Defined Benefit Plans FSIRS Foreign Currency Items
   Before-Tax Tax
(Expense)
Benefit (4) After-Tax Before-Tax Tax
(Expense)
Benefit (4) After-Tax Before-Tax Tax
(Expense)
Benefit    After-Tax AOCI
Beginning Balance AOCI December 31, 2016
   $ (57,613 ) $ 21,893 $ (35,720 ) $ (15,999 ) $ 6,080 $ (9,919 ) $ (2,369 ) $ —      $ (2,369 ) $ (48,008 )




Translation adjustments
   —   —   —   —   —   —   1,861 —      1,861 1,861




Other comprehensive income before reclassifications
   —   —   —   —   —   —   1,861 —      1,861 1,861
FSIRS amounts reclassified from AOCI (1)
   —   —   —   2,507 (953 ) 1,554 —   —      —   1,554
Amortization of prior service cost (2)
   1,001 (380 ) 621 —   —   —�� —   —      —   621
Amortization of net actuarial loss (2)
   19,084 (7,252 ) 11,832 —   —   —   —   —      —   11,832
Regulatory adjustment (3)
   (17,204 ) 6,537 (10,667 ) —   —   —   —   —      —   (10,667 )




Net current period other comprehensive income (loss)
   2,881 (1,095 ) 1,786 2,507 (953 ) 1,554 1,861 —      1,861 5,201
Less: Translation adjustment attributable to redeemable noncontrolling interest
   —   —   —   —   —   —   11 —      11 11




Net current period other comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.
   2,881 (1,095 ) 1,786 2,507 (953 ) 1,554 1,850 —      1,850 5,190




Ending Balance AOCI September 30, 2017
   $ (54,732 ) $ 20,798 $ (33,934 ) $ (13,492 ) $ 5,127 $ (8,365 ) $ (519 ) $ —      $ (519 ) $ (42,818 )


	Defined Benefit Plans									FSIRS									Foreign Currency Items
	Before-Tax			Tax (Expense) Benefit (5)			After-Tax			Before-Tax			Tax (Expense) Benefit (5)			After-Tax			Before-Tax			Tax (Expense) Benefit		After-Tax			Other			AOCI
Beginning Balance AOCI December 31, 2017	$	(61,520	)	$	22,293		$	(39,227	)	$	(12,655	)	$	4,809		$	(7,846	)	$	(609	)	$	—	$	(609	)	$	—		$	(47,682	)

Translation adjustments		—			—			—			—			—			—			(1,601	)		—		(1,601	)		—			(1,601	)

Other comprehensive income before reclassifications		—			—			—			—			—			—			(1,601	)		—		(1,601	)		—			(1,601	)
FSIRS amounts reclassified from AOCI (1)		—			—			—			1,673			(402	)		1,271			—			—		—			—			1,271
Amortization of prior service cost (2)		668			(160	)		508			—			—			—			—			—		—			—			508
Amortization of net actuarial loss (2)		16,808			(4,034	)		12,774			—			—			—			—			—		—			—			12,774
Regulatory adjustment (3)		(15,119	)		3,629			(11,490	)		—			—			—			—			—		—			—			(11,490	)

Net current period other comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.		2,357			(565	)		1,792			1,673			(402	)		1,271			(1,601	)		—		(1,601	)		—			1,462

Reclassification of excess deferred taxes (4)		—			—			—			—			—			—			—			—		—			(9,300	)		(9,300	)

Ending Balance AOCI June 30, 2018	$	(59,163	)	$	21,728		$	(37,435	)	$	(10,982	)	$	4,407		$	(6,575	)	$	(2,210	)	$	—	$	(2,210	)	$	(9,300	)	$	(55,520	)

(1)	The FSIRS reclassification amounts are included in the Net interest deductions line item on the Company’s Condensed Consolidated Statements of Income.

(2)	These AOCI components are included in the computation of net periodic benefit cost (seeNote 2 – Components of Net Periodic Benefit Costfor 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 the Deferred charges and other assets line item on the Company’s Condensed Consolidated Balance Sheets).

(4)	Release of excess deferred taxes accumulated prior to December 22, 2017 (date of enactment of the TCJA), as a result of the adoption of ASU2018-02, which permitted such release.

(5)	Tax amounts related to thebefore-tax balance at June 30, 2018 are calculated using a 24% rate after the release of previously stranded excess deferred taxes existing as a result of the TCJA; amounts prior to the December 22, 2017 enactment of the TCJA were calculated using a 38% rate.

2731


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

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

~~AOCI—~~AOCI - Rollforward

(Thousands of dollars)


	Defined Benefit Plans									FSIRS												Defined Benefit Plans									FSIRS
	Before-Tax			Tax (Expense) Benefit (8)			After-Tax			Before-Tax			Tax (Expense) Benefit (8)			After-Tax			AOCI			Before-Tax			Tax (Expense) Benefit (10)			After-Tax			Before-Tax			Tax (Expense) Benefit (10)			After-Tax			Other			AOCI
Beginning Balance AOCI December 31, 2016	$	(57,613	)	$	21,893		$	(35,720	)	$	(15,999	)	$	6,080		$	(9,919	)	$	(45,639	)
Beginning Balance AOCI December 31, 2017																						$	(61,520	)	$	22,293		$	(39,227	)	$	(12,655	)	$	4,809		$	(7,846	)	$	—		$	(47,073	)

FSIRS amounts reclassified from AOCI ~~(5)~~(6)		—			—			—			2,507			(953	)		1,554			1,554			—			—			—			1,673			(402	)		1,271			—			1,271
Amortization of prior service cost ~~(6)~~(7)		1,001			(380	)		621			—			—			—			621			668			(160	)		508			—			—			—			—			508
Amortization of net actuarial loss ~~(6)~~(7)		19,084			(7,252	)		11,832			—			—			—			11,832			16,808			(4,034	)		12,774			—			—			—			—			12,774
Regulatory adjustment ~~(7)~~(8)		(17,204	)		6,537			(10,667	)		—			—			—			(10,667	)		(15,119	)		3,629			(11,490	)		—			—			—			—			(11,490	)

Net current period other comprehensive income (loss) attributable to Southwest Gas Corporation		2,881			(1,095	)		1,786			2,507			(953	)		1,554			3,340
Net current period other comprehensive income attributable to Southwest Gas Corporation																							2,357			(565	)		1,792			1,673			(402	)		1,271			—			3,063

Ending Balance AOCI September 30, 2017	$	(54,732	)	$	20,798		$	(33,934	)	$	(13,492	)	$	5,127		$	(8,365	)	$	(42,299	)
Reclassification of excess deferred taxes (9)																							—			—			—			—			—			—			(9,300	)		(9,300	)

Ending Balance AOCI June 30, 2018																						$	(59,163	)	$	21,728		$	(37,435	)	$	(10,982	)	$	4,407		$	(6,575	)	$	(9,300	)	$	(53,310	)

~~(5)~~(6)

The FSIRS reclassification amounts are included in the Net interest deductions line item on Southwest’s Condensed Consolidated Statements of Income.

~~(6)~~(7)

These AOCI components are included in the computation of net periodic benefit cost (seeNote 2 – Components of Net Periodic Benefit Costfor additional details).

~~(7)~~(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 the Deferred charges and other assets line item on Southwest’s Condensed Consolidated Balance Sheets).

~~(8)~~(9)

Release of excess deferred taxes accumulated prior to December 22, 2017 (date of enactment of the TCJA), as a result of the adoption of ASU2018-02, which permitted such release.

(10)	Tax amounts related to thebefore-tax balance at June 30, 2018 are calculated using a 24% rate after the release of previously stranded excess deferred taxes existing as a result of the TCJA; amounts prior to the December 22, 2017 enactment of the TCJA were calculated using a 38% rate.

The following table represents amounts (before income tax impacts) included in AOCI (in the tables above), that have not yet been recognized in net periodic benefit cost:

Amounts Recognized in AOCI (Before Tax)

(Thousands of dollars)

   September 30, 2017    December 31, 2016
Net actuarial (loss) gain
   $ (411,889 )    $ (430,973 )
Prior service cost
   (4,702 )    (5,703 )
Less: amount recognized in regulatory assets
   361,859    379,063




Recognized in AOCI
   $ (54,732 )    $ (57,613 )

~~Note 9 – Construction Services Redeemable Noncontrolling Interest~~

In conjunction with the acquisition of the Canadian construction businesses in October 2014, the previous owners of the acquired companies retained a 3.4% equity interest in Centuri, which, subject to an eligibility timeline, would have been redeemable at the election of the noncontrolling parties (in its entirety) beginning in July 2022. In August 2017, in advance of when otherwise eligible, the parties agreed to a current redemption. Southwest Gas Holdings, Inc. paid $23 million to the previous owners, thereby acquiring the remaining 3.4% equity interest in Centuri in accordance with an early redemption agreement. Accordingly, Centuri is now a wholly owned subsidiary of the Company.


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

~~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, 2016
   $ 22,590
Net income attributable to redeemable noncontrolling interest
   248
Foreign currency exchange translation adjustment
   11
Centuri dividend to redeemable noncontrolling interest
   (204 )
Adjustment to redemption value
   355
Redemption of Centuri shares from noncontrolling parties
   (23,000 )


Balance, September 30, 2017
   $ —


	June 30, 2018			December 31, 2017
Net actuarial (loss) gain	$	(431,747	)	$	(448,555	)
Prior service cost		(3,700	)		(4,368	)
Less: amount recognized in regulatory assets		376,284			391,403

Recognized in AOCI	$	(59,163	)	$	(61,520	)

Note 10 – Reorganization Impacts – Discontinued Operations Solely Related to Southwest Gas Corporation

NoAs a result of a holding company structure in January 2017, no substantive change ~~has~~ occurred with regard to the Company’s business segments on the whole, or in the primary businesses comprising those segments (Centuri operations continue to be part of continuing operations of the controlled group of companies), and financial information related to Centuri continues to be included in condensed consolidated financial statements of Southwest Gas Holdings, Inc.

However, as part of the holding company reorganization effective January 2017, Centuri is no longer a subsidiary of Southwest; whereas historically, Centuri had been a direct subsidiary of Southwest. To give effect to this change, the condensed consolidated financial statements related to Southwest Gas Corporation, which are separately included in thisForm 10-Q, depict Centuri-related amounts as discontinued operations for periods prior to January 2017.

Due to the discontinued operations accounting reflection, the following disclosures provide additional information regarding the ~~assets, liabilities, equity,~~ revenues and expenses of Centuri which are shown as discontinued operations on the condensed consolidated financial statements of Southwest Gas Corporation for periods prior to the beginning of 2017.

The following table presents the major categories of assets and liabilities within the amounts reported as discontinued operations – construction services in the Condensed Consolidated Balance Sheet of Southwest Gas Corporation:


~~(Thousands of dollars)~~	~~December 31, 2016~~
~~Assets:~~
~~Other property and investments~~	$	~~233,774~~
~~Cash and cash equivalents~~		~~9,042~~
~~Accounts receivable, net of allowances~~		~~173,300~~
~~Prepaids and other current assets~~		~~10,470~~
~~Goodwill~~		~~129,888~~
~~Other noncurrent assets~~		~~22,897~~

~~Discontinued operations - construction services - assets~~	$	~~579,371~~

~~Liabilities:~~
~~Current maturities of long-term debt~~	$	~~25,101~~
~~Accounts payable~~		~~46,440~~
~~Other current liabilities~~		~~74,518~~
~~Long-term debt, less current maturities~~		~~174,903~~
~~Deferred income taxes and other deferred credits~~		~~59,653~~

~~Discontinued operations—construction services—liabilities~~	$	~~380,615~~


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

~~The following table presents the components of the Discontinued operations – construction servicesnon-owner~~ ~~equity amount shown in the Southwest Gas Corporation Condensed Consolidated Balance Sheet:~~

(Thousands of dollars)    December 31, 2016
Construction services equity
   $ (4,390 )
Construction services noncontrolling interest
   (2,217 )
Construction services redeemable noncontrolling interest
   22,590


Discontinued operations - construction servicesnon-owner equity
   $ 15,983

The following table presents the major income statement components of discontinued operations – construction services reported in the Condensed Consolidated ~~Income~~ Statements of Income Southwest Gas Corporation:

Results of Construction Services


	Three		Nine		Twelve		Twelve
	Months Ended		Months Ended		Months Ended		Months Ended
(Thousands of dollars)	September 30, 2016		September 30, 2016		September 30, 2017		September 30, 2016		Twelve Months Ended June 30, 2017
Construction revenues	$	339,790	$	838,038	$	301,040	$	1,127,982	$	640,830
Operating expenses:
Construction expenses		300,611		757,919		266,504		1,009,188		567,115
Depreciation and amortization		13,409		43,351		12,318		58,368		25,727

Operating income		25,770		36,768		22,218		60,426		47,988
Other income (deductions)		44		44		1,149		1,246		1,193
Net interest deductions		1,794		4,945		1,718		6,738		3,512

Income before income taxes		24,020		31,867		21,649		54,934		45,669
Income tax expense		8,708		12,042		7,842		20,711		16,550

Net income		15,312		19,825		13,807		34,223		29,119
Net income attributable to noncontrolling interests		435		500		514		1,079		949

Discontinued operations - construction services - net income	$	14,877	$	19,325	$	13,293	$	33,144	$	28,170

Note 11 – Acquisition of Construction Services Business

30In November 2017, the Company, through its subsidiaries, led principally by Centuri, completed the acquisition of a privately held construction business, New England Utility Constructors, Inc. (“Neuco”) for approximately $99 million, less assumed debt. See the Company’s 2017 Form10-K for additional information about this acquisition. While refinements were made to the estimated fair values of assets acquired and liabilities assumed when the final purchase accounting was completed during the first quarter of 2018, no subsequent adjustments were made to acquisition-date values, and no acquisition-related costs were incurred during 2018.


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

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 ~~prior to August 2017, 96.6%~~all of the shares of common stock of Centuri Construction Group Inc. (“Centuri” or the “construction services” segment). Prior to August 2017, only 96.6% of Centuri shares were owned. During August 2017, Southwest Gas Holdings, Inc. acquired the remaining 3.4% equity interest in Centuri that was held by the previous owners (and reflected as a redeemable noncontrolling interest). ~~Therefore, Centuri is now a wholly owned subsidiary of Southwest Gas Holdings, Inc. Also, as~~As part of ~~the~~a holding company reorganization effective January 2017, designed to provide further separation between regulated and unregulated businesses, Centuri and Southwest are now subsidiaries of Southwest Gas Holdings, Inc.; whereas historically, Centuri had been a direct subsidiary of Southwest. To give effect for this change, the separate consolidated financial statements of Southwest Gas Corporation depict Centuri-related amounts for periods prior to January 2017 as discontinued operations of Southwest. Southwest Gas Holdings, Inc. and its subsidiaries (the “Company”) have two business segments (natural gas operations and construction services), which are discussed below.

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 Las Vegas metropolitan area and 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.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

As of ~~September~~June 30, ~~2017 (on a seasonally adjusted basis),~~2018, Southwest had ~~1,999,000~~2,027,000 residential, commercial, industrial, and other natural gas customers, of which ~~1,065,000~~1,080,000 customers were located in Arizona, ~~741,000~~752,000 in Nevada, and ~~193,000~~195,000 in California. Residential and commercial customers represented over 99% of the total customer base. During the twelve months ended ~~September~~June 30, ~~2017,~~2018, 54% of operating margin was earned in Arizona, 35% in Nevada, and 11% in California. During this same period, Southwest earned 85% of its operating margin (gas operating revenues less the net cost of gas sold) 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~~Gas cost is a ~~financial measure~~tracked cost, which is passed through to customers without markup under purchased gas adjustment (“PGA”) mechanisms, impacting revenues and net cost of gas sold on adollar-for-dollar basis, thereby having no impact on Southwest’s profitability. Therefore, management routinely uses operating margin, defined ~~by management~~ as ~~gas~~ operating revenues less the net cost of gas ~~sold. However, operating~~sold, in its analysis of Southwest’s financial performance. Operating margin also forms a basis for Southwest’s various regulatory decoupling mechanisms. Operating margin is not, however, specifically defined in accounting principles generally accepted in the United States (“U.S. GAAP”)~~. Thus, operating margin~~ and is considered anon-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. (Refer to the Summary Operating Results table for a reconciliation of revenues to operating margin.)

The principal factors affecting changes in operating margin are general rate relief (including impacts of infrastructure trackers) and customer growth.

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 construction services enterprise dedicated to meeting the growing demands of North American utilities, energy, and industrial markets. Centuri derives revenue from installation, replacement, repair, and maintenance of energy distribution systems, and developing industrial construction solutions. Centuri operates in 2423 major markets in the United States (primarily as NPL) and in 32 major markets in Canada (as NPL Canada ~~(formerly Link-Line Contractors Ltd.),~~ and W.S. Nicholls).

Construction activity is cyclical and can be significantly impacted by changes in weather, general and local economic conditions (including the housing market), interest rates, employment levels, job growth, pipe replacement programs of utilities, and local and federal regulation (including tax rates and incentives). During the past few years, utilities


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

have implemented or modified pipeline integrity management programs to enhance safety pursuant to federal and state mandates. These programs ~~coupled with recent bonus depreciation tax deduction incentives,~~ have resulted in a significant increase in multi-year pipeline replacement projects throughout the U.S. Centuri has focused its efforts on obtaining pipe replacement work under both blanket contracts and incremental bid projects. For both the twelve months ended June 30, 2018 and 2017, revenues from replacement work provided over 65% of total revenues. 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. This is expected in both the U.S. and Canadian markets. 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~~not 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 consolidated financial statements and the notes thereto, as well as MD&A included in the ~~2016~~2017 Annual Report to Shareholders, which is incorporated by reference into the ~~2016~~2017 Form10-K.

Executive Summary

The items discussed in this Executive Summary are intended to provide an overview of the results of the Company’s operations. As needed, certain items are covered in greater detail in later sections of management’s discussion and analysis. As reflected in the table below, the natural gas operations segment accounted for an average of ~~81%~~80% oftwelve-month-to-date consolidated net income over the past two years. As such, management’s discussion


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

and analysis 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 September 30,																Period Ended June 30,
	Three Months						Nine Months					Twelve Months					Three Months						Six Months						Twelve Months
	2017			2016			2017			2016		2017			2016		2018			2017			2018			2017			2018			2017
	(In thousands, except per share amounts)																(In thousands, except per share amounts)
Contribution to net income
Natural gas operations	$	(4,024	)	$	(12,405	)	$	82,436		$	67,536	$	134,323		$	119,836	$	2,622		$	9,522		$	92,971		$	86,460		$	163,329		$	125,942
Construction services		14,335			14,877			15,717			19,325		29,010			33,144		19,236			8,716			8,235			1,382			45,213			29,552
Corporate and administrative		(107	)		—			(777	)		—		(777	)		—		(307	)		(374	)		(564	)		(670	)		(1,231	)		(670	)

Net income	$	10,204		$	2,472		$	97,376		$	86,861	$	162,556		$	152,980	$	21,551		$	17,864		$	100,642		$	87,172		$	207,311		$	154,824

Average number of common shares outstanding		47,628			47,481			47,577			47,464		47,553			47,442
Average number of common shares																		48,826			47,571			48,622			47,550			48,338			47,516

Basic earnings per share
Consolidated	$	0.21		$	0.05		$	2.05		$	1.83	$	3.42		$	3.22	$	0.44		$	0.38		$	2.07		$	1.83		$	4.29		$	3.26

Natural Gas Operations
Reconciliation of Revenue to Operating Margin(Non-GAAP measure)
Gas operating revenues	$	213,059		$	200,179		$	935,823		$	980,927	$	1,276,308		$	1,376,388	$	275,679		$	260,162		$	769,992		$	722,764		$	1,349,536		$	1,263,428
Net cost of gas sold		45,539			39,056			261,839			324,072		334,888			460,836
Less: Net cost of gas sold																		83,466			69,421			269,198			216,300			407,943			328,405

Operating margin	$	167,520		$	161,123		$	673,984		$	656,855	$	941,420		$	915,552	$	192,213		$	190,741		$	500,794		$	506,464		$	941,593		$	935,023

3235


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

~~3rd~~2nd Quarter ~~2017~~2018 Overview

Natural gas operations highlights:

~~Benefits of Arizona rate case reflected in quarterly operating results~~

~~32,000~~33,000 net new customers ~~in last 12 months~~ (1.6% growth rate)

~~Depreciation and amortization expense declined $10~~Filed Nevada general rate case, requesting approximately $33 million ~~compared to the prior-year quarter~~

Filed Gas Infrastructure Replacement (“GIR”) Advance Application with annualized revenue requirement of $22 million

Received order from PUCN approving expansion into Mesquite, Nevada

Operating ~~income increased $15.3 million compared to the prior-year quarter~~

~~Targeting $27 million~~margin reflects estimated regulatory impacts of ~~vintage steel pipe replacement in~~tax reform and associated Arizona ~~during 2017~~

~~Achieved 2 million natural gas utility customers in early November 2017~~Corporation Commission decision

Construction services highlights:

Revenues increased ~~$40.3~~$94.9 million compared to the prior-year quarter; twelve-month revenues surpassed $1.4 billion

Construction expenses increased $80.7 million compared to the prior-year quarter

Depreciation and amortization expense increased $1.8 million compared to the prior-year quarter

Net interest deductions increased $1.7 million compared to the prior-year quarter

~~Construction expenses increased $42 million compared to the prior-year quarter~~36

~~Depreciation and amortization expense declined $1.1 million compared to the prior-year quarter~~

~~The Company acquired the residual 3.4% interest in Centuri in August 2017~~

~~Southwest Gas Holdings highlights:~~

~~Amended and restated bylaws to eliminate cumulative voting and enact majority voting~~


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

Results of Natural Gas Operations

Quarterly Analysis

   Three Months Ended
September 30,
   2017    2016
   (Thousands of dollars)
Gas operating revenues
   $ 213,059    $ 200,179
Net cost of gas sold
   45,539    39,056




Operating margin
   167,520    161,123
Operations and maintenance expense
   102,215    102,438
Depreciation and amortization
   46,194    56,436
Taxes other than income taxes
   14,046    12,480




Operating income (loss)
   5,065    (10,231 )
Other income (deductions)
   3,081    2,521
Net interest deductions
   17,421    16,364




Income (loss) before income taxes
   (9,275 )    (24,074 )
Income tax expense (benefit)
   (5,251 )    (11,669 )




Contribution to consolidated net income (loss)
   $ (4,024 )    $ (12,405 )


	Three Months Ended
	June 30,
	2018			2017
	(Thousands of dollars)
Gas operating revenues	$	275,679		$	260,162
Net cost of gas sold		83,466			69,421

Operating margin		192,213			190,741
Operations and maintenance expense		105,208			97,644
Depreciation and amortization		47,664			46,254
Taxes other than income taxes		14,666			14,497

Operating income		24,675			32,346
Other income (deductions)		(2,094	)		(2,805	)
Net interest deductions		20,149			16,991

Income before income taxes		2,432			12,550
Income tax expense (benefit)		(190	)		3,028

Contribution to consolidated net income	$	2,622		$	9,522

Contribution to consolidated net income from natural gas operations decreased $6.9 million between the second quarters of 2018 and 2017. The decline was primarily due to higher operating expenses and net interest deductions, partially offset by a decrease in income tax expense. U.S. federal tax reform impacted both revenue and tax expense. The amounts above reflect a reclassification of $4.9 million for 2017 from Operations and maintenance expense to Other income (deductions) related to thenon-service cost components of net periodic benefit costs, as a result of the adoption of the update to FASB Topic 715 (refer to Note 2 to the condensed consolidated financial statements in this Form10-Q), with no impact to net income overall. The reclassification in the 2017 period is intended to make that information comparable to the current period presentation.

Operating margin increased $6$1.5 million between ~~quarters. Rate relief~~quarters, due in ~~Arizona (effective April 2017)~~part to a net $1.6 million decrease in the reserve related to U.S. tax reform, based on expectations in the rate jurisdictions in which Southwest and ~~California provided $4 million~~its subsidiaries operate. Refer to discussion ofIncome Taxes in ~~operating margin (see~~Note 1 – Nature of Operations and Basis of Presentationof thisForm10-Q andRates and Regulatory Proceedings). below. Approximately $2 million in increased operating margin was attributable to customer growth, as ~~32,000~~33,000 net new customers were added during the last twelve ~~months.~~months, with another $500,000 attributable to rate relief in California. These increases were offset by an approximate $2.6 million reduction in miscellaneous revenues (including a $2 million reduction in surcharge recoveries associated with Nevada Conservation and Energy Efficiency (“CEE”) programs, offset in Depreciation and amortization expense).

Operations and maintenance expense ~~was relatively flat~~increased $7.6 million between quarters. ~~Decreases in employee-related benefit costs more than offset increases in other~~Approximately $2 million of the increase was due to higher pension and employee medical costs. The remaining increase was primarily due to higher injuries and damages expense, incremental expenditures for pipeline integrity management and damage prevention programs, and general ~~costs.~~cost increases.

Depreciation and amortization expense ~~decreased $10~~increased $1.4 million between quarters primarily due to ~~reduced depreciation rates in Arizona, a result~~an increase of ~~the recent Arizona general rate case decision. Partially offsetting the decline was increased depreciation associated with a $317~~$448 million, or 5%7%, 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.

~~Taxes other than income taxes increased $1.6 million between quarters primarily due to higher property taxes associated with net plant additions and increased property taxes~~ See also discussion above regarding surcharge recoveries (including Nevada CEE programs), which provide offsetting impacts in ~~Arizona, including the impact of a property tax tracking mechanism enacted as part of the recently settled Arizona general rate case.~~this category.

Other income ~~increased $560,000~~(deductions) improved $711,000 between quarters primarily due to an increase in the equity portion of the allowance for funds used during construction (“AFUDC”) associated with higher construction expenditures. The equity portion of AFUDC represents the cost of equity funds used to finance utility construction. The equity AFUDC improvement was partially offset by a decline between quarters ininterest income from company-owned life insurance (“COLI”) policies. The current quarter reflects $2.1 million of income associated with COLI policy cash surrender value increases, while the prior-year quarter reflected $2.3 million of COLI-related income. COLI amounts in each quarter were greater than expected.

~~Net interest deductions increased $1.1 million between quarters, primarily due~~related to the ~~September 2016 issuance~~GIR mechanism in Nevada. See the Rates and Regulatory Proceedingssection for more information about the GIR. Amounts in both periods reflect thenon-service cost components of ~~$300 million of senior notes, partially offset by reductions associated with the redemption of debt ($24.9 million of 4.75% IDRBs in September 2016)~~employee pension and ~~lower interest expense associated with PGA balances as compared to the prior-year quarter.~~other post-retirement benefits.

3437


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

~~Results of Natural Gas Operations~~

~~Nine-Month Analysis~~

   Nine Months Ended September 30,
   2017    2016
   (Thousands of dollars)
Gas operating revenues
   $ 935,823    $ 980,927
Net cost of gas sold
   261,839    324,072




Operating margin
   673,984    656,855
Operations and maintenance expense
   313,395    301,979
Depreciation and amortization
   153,643    174,413
Taxes other than income taxes
   43,325    39,480




Operating income
   163,621    140,983
Other income (deductions)
   8,744    6,712
Net interest deductions
   51,622    49,155




Income before income taxes
   120,743    98,540
Income tax expense
   38,307    31,004




Contribution to consolidated net income
   $ 82,436    $ 67,536

The contribution to consolidated net income from natural gas operations increased $14.9 million between the first nine months of 2017 and 2016. The improvement was primarily due to higher operating margin and lower depreciation expense, partially offset by an increase in operations and maintenance expenses.

~~Operating margin increased $17 million between the comparative nine-month periods. Rate relief in the Arizona and California jurisdictions provided $10 million in operating margin (see~~~~Rates and Regulatory Proceedings~~~~). The remaining $7 million increase was attributable to customer growth.~~

Operations and maintenance expense increased $11.4 million, or 4%, between periods due primarily to higher general cost increases. Approximately $5 million of the incremental costs recognized were associated with the amount and timing of employee incentive plan grants (including accelerated recognition for retirement eligible employees).

Depreciation and amortization expense decreased $20.8 million between periods primarily due to reduced depreciation rates in Arizona, a result of the recent Arizona general rate case decision. The depreciation decrease also included a decline of approximately $3.7 million in amortization related to the recovery of regulatory assets. Partially offsetting these declines was depreciation associated with a $325 million, or 5%, increase in average gas plant in service for the current period as compared to the prior period. The increase in gas plant was attributable to pipeline capacity reinforcement work, franchise requirements, scheduled and accelerated pipe replacement activities, and new infrastructure.

Taxes other than income taxes increased $3.8 million between periods primarily due to higher property taxes associated with net plant additions and increased property taxes in Arizona, including the impact of the Arizona property tax tracking mechanism.

~~Other income, which principally includes returns on COLI policies andnon-utility~~ expenses, increased $2 million between periods. The current period reflects $6.8 million of income associated with COLI policy cash surrender value increases, while the prior-year period reflected $5.4 million of COLI-related income. COLI amounts in each period were greater than expected.

Net interest deductions increased ~~$2.5~~$3.2 million ~~between periods,~~in the second quarter of 2018, as compared to the prior-year quarter, primarily due to higher interest associated with credit facility borrowings during the ~~September 2016~~current-year quarter and the issuance of $300 million of senior notes ~~partially offset~~in March 2018.

Income taxes were impacted in 2018 by ~~reductions associated with debt redemptions ($100 million~~thepre-tax earnings impacts discussed above as well as by the December 2017 enactment of ~~4.85% IDRBs in July 2016 and $24.9 million of 4.75% IDRBs in September 2016) and lower interest expense associated with PGA balances as compared~~tax reform. Among other things, tax reform reduced the corporate federal income tax rate from 35% to ~~the prior-year period.~~21%, effective January 2018.

3538


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

Results of Natural Gas Operations

Six-Month Analysis


	Six Months Ended
	June 30,
	2018			2017
	(Thousands of dollars)
Gas operating revenues	$	769,992		$	722,764
Net cost of gas sold		269,198			216,300

Operating margin		500,794			506,464
Operations and maintenance expense		207,398			201,468
Depreciation and amortization		97,625			107,449
Taxes other than income taxes		29,923			29,279

Operating income		165,848			168,268
Other income (deductions)		(6,697	)		(4,049	)
Net interest deductions		39,404			34,201

Income before income taxes		119,747			130,018
Income tax expense		26,776			43,558

Contribution to consolidated net income	$	92,971		$	86,460	��

Contribution to consolidated net income from natural gas operations increased $6.5 million between the first six months of 2018 and 2017. The improvement was primarily due to rate relief and customer growth, lower depreciation expense, and the combined impacts of tax reform, partially offset by increases in Operations and maintenance expense, and Net interest deductions. The amounts above for Operations and maintenance expense and Other income (deductions) for the 2017 period reflect a $9.7 million reclassification related to thenon-service cost components of employee pensions and other post-retirement benefits, as a result of the adoption of the update to FASB Topic 715. The reclassification is intended to make the prior period comparable to the current period, but did not impact net income overall.

Operating margin decreased $5.7 million between the comparativesix-month periods, due to a $12.5 million reserve recognized due to the enactment of U.S. tax reform in December 2017. The reserve contemplates a pending reduction in rates to reflect the reduced cost of service during 2018, resulting from tax reform (seeRates and Regulatory Proceedings below). However, the decline in applicable U.S. income tax rates also significantly reduced income tax expense (see discussion below). Operating margin was favorably impacted by rate relief in the Arizona and California jurisdictions, which collectively provided $5.6 million in operating margin. Approximately $6 million in increased operating margin was attributable to customer growth. An approximate $5.5 million reduction in surcharge recoveries associated with Nevada CEE programs (offset in Depreciation and amortization expense below), as well as other surcharge variances and variability in other miscellaneous revenues and customers outside the decoupling mechanisms, comprise the residual variance.

Operations and maintenance expense increased $5.9 million between periods due primarily to higher pension service-cost related and other employee benefit expenses, higher injuries and damages expenses, incremental expenditures for pipeline integrity management and damage prevention programs, and other general cost increases, partially offset by lower expense for incentive compensation programs.

Depreciation and amortization expense decreased $9.8 million between periods primarily due to reduced depreciation rates in Arizona, a result of the April 2017 Arizona general rate case decision, and to the impacts of surcharge recoveries for regulatory mechanisms, as discussed above. Partially offsetting the decline was additional depreciation associated with a $444 million, or 7%, increase in average gas plant in service for the current period as compared to the prior period. The increase was attributable to pipeline capacity reinforcement work, franchise requirements, scheduled and accelerated pipe replacement activities, and new infrastructure.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Taxes other than income taxes increased $644,000 between periods primarily due to higher property taxes in Arizona, including the impacts of the Arizona property tax tracking mechanism.

Other income decreased $2.6 million between periods primarily due to a decline in income from company-owned life insurance (“COLI”) policies. The current period reflects a $1.3 million increase in COLI policy cash surrender values, while the prior-year period reflected $4.7 million of COLI-related income. Additionally, amounts in both periods reflect thenon-service cost components of employee pension and post-retirement benefits.

Net interest deductions increased $5.2 million between periods, primarily due to higher interest associated with credit facility borrowings during the current period and the issuance of $300 million of senior notes in the first quarter of 2018. The increase was partially offset by reductions in interest expense associated with deferred purchased gas adjustments (“PGA”) balances as compared to the prior-year period.

Income taxes were favorably impacted in 2018 due to the December 2017 enactment of tax reform.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Results of Natural Gas Operations

Twelve-Month Analysis


					Twelve Months Ended
	Twelve Months Ended September 30,				June 30,
	2017		2016		2018			2017
	(Thousands of dollars)				(Thousands of dollars)
Gas operating revenues	$	1,276,308	$	1,376,388	$	1,349,536		$	1,263,428
Net cost of gas sold		334,888		460,836		407,943			328,405

Operating margin		941,420		915,552		941,593			935,023
Operations and maintenance expense		413,140		400,222		397,251			393,772
Depreciation and amortization		212,693		228,609		192,098			222,935
Taxes other than income taxes		56,221		51,810		58,590			54,655

Operating income		259,366		234,911		293,654			263,661
Other income (deductions)		10,308		9,615		(9,036	)		(9,843	)
Net interest deductions		69,464		65,146		74,936			68,407

Income before income taxes		200,210		179,380		209,682			185,411
Income tax expense		65,887		59,544		46,353			59,469

Contribution to consolidated net income	$	134,323	$	119,836	$	163,329		$	125,942

Contribution to consolidated net income from natural gas operations increased by ~~$14.5~~$37.4 million between the twelve-month periods of ~~2017~~2018 and ~~2016.~~2017. The improvement was primarily due to higher operating margin, lower Depreciation and amortization expense, and lower ~~depreciation~~Income tax expense, partially offset by an increase in ~~operations~~Taxes other than income taxes and higher Net interest deductions. The amounts above for Operations and maintenance ~~expenses~~expense and ~~interest expense.~~Other income (deductions) for the 2017 period reflect a $19.6 million reclassification related to thenon-service cost components of employee pensions and other post-retirement benefits, as a result of the adoption of the update to FASB Topic 715. The reclassification is intended to make the prior period comparable to the current period, but did not impact net income overall.

Operating margin increased ~~$26~~$7 million between periods including a combined ~~$13~~$15 million of rate relief in the Arizona and California ~~jurisdictions, as well as Paiute Pipeline Company.~~jurisdictions. Customer growth provided $9$10 million in operating margin, while operating margin associated with recoveries of regulatory assets, infrastructure replacement mechanisms, customers outside the decoupling mechanisms, and other miscellaneous revenues ~~improved $4~~decreased $6 million. The $12.5 million reserve, described earlier, associated with tax reform, decreased operating margin in the current period. However, net income overall was not unfavorably impacted, as favorable impacts from tax reform are reflected in income tax expense.

Operations and maintenance ~~expense increased $12.9 million, or 3%, between periods primarily due to general cost increases, partially offset by lower pension expense. Approximately $5.6 million~~expenses in the 2018 period were within 1% of the ~~incremental costs recognized were associated with the amount~~prior year period. The overall increase of $3.5 million primarily relates to higher service-cost-related pension expense and ~~timing of employee incentive plan grants (including accelerated recognition~~expenditures for ~~retirement-eligible employees). Pipeline integrity management and~~pipeline damage prevention ~~programs collectively increased $500,000.~~programs.

Depreciation and amortization expense decreased ~~$15.9~~$30.8 million between periods primarily due to reduced depreciation rates in Arizona, a result of the ~~recent~~April 2017 Arizona general rate case decision. Partially offsetting the decline was depreciation associated with a ~~$335~~$391 million, or 6%, increase in average gas plant in service for the current period as compared to the prior period. The increase in gas plant was attributable to pipeline capacity reinforcement work, franchise requirements, scheduled and accelerated pipe replacement activities, and new infrastructure.

Taxes other than income taxes increased ~~$4.4~~$3.9 million between periods primarily due to higher property taxes associated ~~primarily~~ with net plant additions and increased property taxes in Arizona, including the impact of athe property tax regulatory tracking ~~mechanism resulting from the recent Arizona general rate case.~~mechanism.

Other income ~~increased $693,000~~(deductions) improved $807,000 between the twelve-month periods of ~~2017~~2018 and ~~2016.~~2017. The current period reflects ~~an $8.8~~a $6.9 million increase in COLI policy cash surrender values, while the prior-year period ~~reflected $7.5~~included $9 million of ~~combined~~ COLI-related income. Interest income ~~and recognized death benefits. COLI amounts in each period were greater than expected.~~

~~Net~~increased $2.1 million including interest ~~deductions increased $4.3 million between periods, primarily due~~related to the ~~September 2016 issuance of $300 million of senior notes. The increase was partially offset by reductions associated with~~GIR mechanism in Nevada.See the ~~redemption of debt ($100 million of 4.85% IDRBs in July 2016~~ Rates and ~~$24.9 million of 4.75% IDRBs in September 2016) and lower interest expense associated with PGA balances as compared to~~Regulatory Proceedingssection for more information about the ~~prior-year period.~~GIR

3641


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

~~Results~~mechanism. Amounts in both periods reflect thenon-service cost components of ~~Construction Services~~employee pension and post-retirement benefits, which increased between periods.

~~Quarterly Analysis~~

   Three Months Ended
September 30,
   2017    2016
   (Thousands of dollars)
Construction revenues
   $ 380,094    $ 339,790
Operating expenses:

Construction expenses
   342,629    300,611
Depreciation and amortization
   12,335    13,409




Operating income
   25,130    25,770
Other income (deductions)
   (210 )    44
Net interest deductions
   1,962    1,794




Income before income taxes
   22,958    24,020
Income tax expense
   8,407    8,708




Net income
   14,551    15,312
Net income attributable to noncontrolling interests
   216    435




Contribution to consolidated net income attributable to Centuri
   $ 14,335    $ 14,877

~~Contribution to consolidated net income from construction services in~~Net interest deductions increased $6.5 million between the current ~~quarter decreased by $542,000 when compared to the~~and prior-year ~~quarter. The decrease is~~period, primarily due to the issuance of $300 million of senior notes in September 2016, higher ~~construction costs relative to increased revenues, resulting from apre-tax~~ ~~loss on a project described below, partially~~interest associated with credit facility borrowings during late 2017 and early 2018, and the issuance of the $300 million senior notes in the first quarter of 2018. The increase was substantially offset by ~~a decline~~reductions in ~~depreciation~~interest expense associated with deferred PGA balances and ~~amortization.~~debt redemptions during the second half of 2016.

~~Revenues increased $40.3 million, or 12%, between quarters primarily~~Income taxes were favorably impacted during the twelve months ending June 30, 2018 due to ~~an increase~~the December 2017 enactment of tax reform, which reduced the corporate federal income tax rate from 35% to 21%, effective January 2018. Approximately $8 million ofone-time tax benefits, related to the remeasurement of deferred tax liabilities, were recorded in ~~pipe replacement work with existing customers. A significant portion of~~ the ~~increase relates to bid jobs that are expected to be substantially complete by year end.~~

Construction expenses increased $42 million, or 14%, between quarters due to additional pipe replacement work. Results were negatively impacted by higher construction costs for a water pipe replacement project, for which Centuri has requested increased cost recovery. No additional work orders will be accepted on the project pending resolution of Centuri’s request. Gains on sale of equipment (reflected as an offset to construction expenses) were approximately $25,000 and $1.4 million for the third quartersfourth quarter of 2017 ~~and 2016, respectively.~~

~~Depreciation and amortization decreased $1.1 million between quarters, primarily due~~in addition to ~~a $2 million reduction associated with~~ the ~~extension~~lower rate utilized in the first half of the estimated useful lives of certain depreciable equipment during the past 12 months, partially offset by an increase in depreciation for additional equipment purchased to support the growing volume of work being performed.2018.

3742


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

Results of Construction Services

~~Nine-Month~~Quarterly Analysis

   Nine Months Ended
September 30,
   2017    2016
   (Thousands of dollars)
Construction revenues
   $ 872,536    $ 838,038
Operating expenses:

Construction expenses
   806,586    757,919
Depreciation and amortization
   35,446    43,351




Operating income
   30,504    36,768
Other income (deductions)
   38    44
Net interest deductions
   5,095    4,945




Income before income taxes
   25,447    31,867
Income tax expense
   9,560    12,042




Net income
   15,887    19,825
Net income attributable to noncontrolling interests
   170    500




Contribution to consolidated net income attributable to Centuri
   $ 15,717    $ 19,325

~~Contribution to consolidated net income from construction services~~


	Three Months Ended
	June 30,
	2018			2017
	(Thousands of dollars)
Construction revenues	$	395,204		$	300,307
Operating expenses:
Construction expenses		352,671			272,001
Depreciation and amortization		13,643			11,828

Operating income		28,890			16,478
Other income (deductions)		(632	)		(6	)
Net interest deductions		3,308			1,629

Income before income taxes		24,950			14,843
Income tax expense		5,714			5,870

Net income		19,236			8,973
Net income attributable to noncontrolling interest		—			257

Contribution to consolidated net income attributable to Centuri	$	19,236		$	8,716

In November 2017, Centuri acquired New England Utility Constructors, Inc. (“Neuco”). Line items in the table above reflect the results of Neuco only for the ~~first nine months~~2018 period as the acquisition occurred in November 2017.

Revenues increased $94.9 million in the second quarter of ~~2017 declined by $3.6 million~~2018 when compared to the prior-year ~~period. The decrease is~~quarter, primarily due to a higher ~~construction costs relative to increased revenues, partially offset by a decline in depreciation and amortization.~~

~~Revenues increased $34.5 million, or 4%, in the first nine months~~volume of ~~2017 when compared to the prior-year period primarily due to increased~~ pipe replacement ~~work. Partially offsetting increases in~~work under blanket and bid contracts, and $34 million of revenues ~~was~~contributed by Neuco. In addition, revenues reflect a ~~temporary work stoppage by~~$9 million negotiated settlement of an outstanding contract dispute from 2017 associated with a significant customer that began in the first quarter of 2017 and continued through part of the second quarter of 2017 resulting in a $26.3 million reduction in revenues, compared to the prior-year period, and a $3.7 million~~pre-tax~~ loss in the current nine-month period. The temporary work stoppage was initiated due to state-mandated requalification of employees of all contractors working within the jurisdictional boundary of one state. Operations resumed gradually following the requalification of Centuri’s employees during the second quarter of 2017. Additionally, inclement weather in several operating areas negatively impacted revenues and reduced productivity in the first quarter of 2017.water pipe replacement project.

Construction expenses increased ~~$48.7~~$80.7 million ~~or 6%,~~ between ~~periods.~~quarters. The increase in Construction expenses is due to additional pipe replacement work and greater operating expenses to support increased growth in operations. Approximately $30 million of construction expenses ~~is disproportionate to revenues noted above due in part to logistics surrounding the timing and length of the temporary work stoppage~~associated with ~~the significant customer and to higher labor costs incurred to complete work during inclement weather conditions~~Neuco are included in the ~~first quarter. In addition, results were negatively impacted by higher construction andstart-up~~ ~~costs related to the water pipe replacement project, for which Centuri is pursuing cost recovery.~~three months ended June 30, 2018. Gains on sale of equipment (reflected as an offset to construction expenses) were approximately ~~$1.5 million~~$20,000 and ~~$4.1~~$1.1 million for the ~~first nine months~~second quarters of ~~2017~~2018 and ~~2016,~~2017, respectively.

Depreciation and amortization ~~decreased $7.9~~expense increased $1.8 million between ~~periods,~~quarters, primarily due to ~~an $8.2~~incremental amortization of finite-lived intangible assets recognized from the Neuco acquisition and to depreciation on additional equipment purchased to support the growing volume of work being performed, partially offset by a $1.9 million reduction in depreciation associated with the extension of the estimated useful lives of certain depreciable ~~equipment during~~equipment.

Net interest deductions increased by $1.7 million between quarters. The increase was due primarily to higher average debt outstanding under the ~~past 12 months, partially offset by~~existing $450 million secured revolving credit and term loan facility in 2018.

Income taxes were relatively flat between periods; however, 2018 tax expense reflects lower U.S. federal income tax rates following tax reform applied to an ~~increase in depreciation for additional equipment purchased to support the growing volume~~increased level of ~~work being performed.~~earnings.

3843


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

Results of Construction Services

~~Twelve-Month~~Six-Month Analysis


					Six Months Ended
	Twelve Months Ended September 30,				June 30,
	2017		2016		2018			2017
	(Thousands of dollars)				(Thousands of dollars)
Construction revenues	$	1,173,576	$	1,127,982	$	655,221		$	492,442
Operating expenses:
Construction expenses		1,073,090		1,009,188		611,623			463,957
Depreciation and amortization		47,764		58,368		26,160			23,111

Operating income		52,722		60,426		17,438			5,374
Other income (deductions)		1,187		1,246		(369	)		248
Net interest deductions		6,813		6,738		6,504			3,133

Income before income taxes		47,096		54,934		10,565			2,489
Income tax expense		17,402		20,711		3,127			1,153

Net income		29,694		34,223		7,438			1,336
Net income attributable to noncontrolling interests		684		1,079
Net income (loss) attributable to noncontrolling interest						(797	)		(46	)

Contribution to consolidated net income attributable to Centuri	$	29,010	$	33,144	$	8,235		$	1,382

~~Contribution to consolidated net income from construction services~~Line items in the table above reflect the results of Neuco only for the ~~twelve-month~~2018 period ~~ended September 30, 2017 decreased $4.1 million compared to~~as the ~~same period of 2016. The decrease is primarily due to higher construction costs relative to increased revenues, resulting~~acquisition occurred in~~pre-tax~~ ~~losses on certain projects, partially offset by a decline in depreciation and amortization.~~ November 2017.

Revenues increased ~~$45.6~~$162.8 million or 4%, in the current twelve-month period compared to the same period of 2016 primarily due to additional pipe replacement work for existing natural gas distribution customers. During the past several years, Centuri has focused its efforts on obtaining replacement work under both blanket contracts and incremental bid projects. For both twelve-month periods ended September 30, 2017 and 2016, revenues from replacement work provided over 60% of total revenues.

Construction expenses increased $63.9 million, or 6%, between periods, due to additional pipe replacement work, higher labor costs experienced due to changes in the mix of work with existing customers, and higher operating expenses to support increased growth in operations. The logistics surrounding the timing and length of a temporary work stoppage with a significant customer during the first six months of ~~2017~~2018 when compared to the same period in the prior year due to an increased volume of replacement work for many natural gas distribution customers, the contribution of $48 million in revenue from Neuco in 2018, the absence of a customer’s temporary work stoppage that impacted prior-year performance, and the settlement of an outstanding contract dispute associated with a water pipe replacement project.

Construction expenses increased $147.7 million between periods. The increase in Construction expenses is due to additional pipe replacement work and higher labor costs incurred to complete work during inclement weather conditions during the first quarter. Approximately $44 million of construction expenses associated with Neuco are included in the ~~first quarter of 2017 resulted in costs disproportionate to revenues. Results were negatively impacted by higherstart-up~~ and construction costs for a water pipe replacement project, for which Centuri has requested increased cost recovery. No additional work orders will be accepted on the project pending resolution of Centuri’s request.six months ended June 30, 2018. Gains on sale of equipment (reflected as an offset to construction expenses) were ~~$4.5 million~~approximately $250,000 and ~~$4.2~~$1.4 million for the ~~twelve-month periods ended September 30,~~first six months of 2018 and 2017, ~~and 2016,~~ respectively.

Depreciation and amortization ~~decreased $10.6~~increased $3 million between ~~the current and prior-year~~ periods, primarily due to ~~an $11.1~~incremental amortization of finite-lived intangible assets recognized from the Neuco acquisition and to depreciation on additional equipment purchased to support the growing volume of work being performed, partially offset by a $3.9 million reduction in depreciation associated with the extension of the estimated useful lives of certain depreciable ~~equipment over~~equipment.

Net interest deductions increased by $3.4 million between periods. The increase was due primarily to higher average debt outstanding under the ~~last twelve months, partially offset by an increase~~existing $450 million secured revolving credit and term loan facility in ~~depreciation for additional equipment purchased to support~~2018.

Income tax expense reflects both the ~~growing volume~~impacts of ~~work being performed.~~lower income tax rates in 2018 following U.S. federal tax reform and the changes in earnings, discussed above, on which new rates are applied.

3944


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

Results of Construction Services

Twelve-Month Analysis


	Twelve Months Ended
	June 30,
	2018			2017
	(Thousands of dollars)
Construction revenues	$	1,409,263		$	1,133,272
Operating expenses:
Construction expenses		1,296,629			1,031,072
Depreciation and amortization		52,078			48,838

Operating income		60,556			53,362
Other income (deductions)		(272	)		1,441
Net interest deductions		11,357			6,645

Income before income taxes		48,927			48,158
Income tax expense		4,364			17,703

Net income		44,563			30,455
Net income (loss) attributable to noncontrolling interest		(650	)		903

Contribution to consolidated net income attributable to Centuri	$	45,213		$	29,552

Line items in the table above reflect the results of Neuco only since the November 2017 acquisition date.

Revenues increased $276 million in the current twelve-month period compared to the same period of 2017, primarily due to a higher volume of pipe replacement work under blanket contracts and the contribution of approximately $65 million in revenue from Neuco since the November 2017 acquisition date. In addition, Centuri performed work on a multi-year water pipe replacement program, which began in late 2016, that contributed incremental revenues of $55.3 million and $30.8 million during the twelve-month periods ended June 30, 2018 and 2017, respectively.

Construction expenses increased $265.6 million between periods, primarily due to higher labor costs experienced due to changes in the mix of work with existing customers, lower relative productivity resulting from inclement weather, and greater operating expenses to support increased growth in operations. In addition, results were negatively impacted by higher construction costs and an unfavorable mix of work performed during the period related to the water pipe replacement program noted above. Approximately $57 million of construction expenses from Neuco are included in the twelve months ended June 30, 2018. Gains on sale of equipment (reflected as an offset to construction expenses) were $3 million and $5.8 million for the twelve-month periods of 2018 and 2017, respectively.

Depreciation and amortization expense increased $3.2 million between the current and prior-year periods primarily due to incremental amortization of finite-lived intangible assets recognized from the Neuco acquisition and to depreciation on additional equipment purchased to support the growing volume of work being performed, partially offset by a $5.9 million reduction in depreciation associated with the extension of the estimated useful lives of certain depreciable equipment.

Net interest deductions increased $4.7 million between periods. The increase was due primarily to higher average debt outstanding under the existing $450 million secured revolving credit and term loan facility in the current twelve-month period.

Income tax expense decreased $13.3 million between periods, primarily due to approximately $12 million ofone-time tax benefits related to the remeasurement of Centuri’s deferred tax liabilities that were recorded in the fourth quarter of 2017, and to lower income tax rates in effect in 2018 (collectively, the result of U.S. tax reform).


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Rates and Regulatory Proceedings

Arizona Jurisdiction

Arizona General Rate Case.In May 2016, Southwest filed a general rate application with the Arizona Corporation Commission (“ACC”). Following undertakings associated with the filing, a settlement hearing was held in ~~May 2016 requesting an increase~~February 2017, and the ACC approved the settlement in ~~authorized~~April 2017 (with new rates effective the same month), providing for, among other things, rate changes that would result in a combined net annual operating ~~revenues~~income increase of ~~approximately $32~~$60.7 million ~~or 4.2%, to reflect existing levels of expense~~(including $16 million in additional operating revenue and ~~requested returns,~~a $44.7 million decrease in ~~addition to reflecting capital investments made by Southwest since June 2010.~~depreciation expense). The ~~application requested an overall~~decision included a 7.82% rate of return ~~of 7.82%~~ on an original cost rate base of $1.336 billion, a ~~10.25%~~9.5% return on common equity, and a capital structure utilizing 52% common equity. The filing included a depreciation study that supported a proposal to reduce currently effective depreciation expense by approximately $42 million, which was considered in the overall requested amount. This expense reduction coupled with the requested revenue increase, resulted in a net annual operating income increase request of $74 million. A settlement was reached among several parties in December 2016 and a formal draft settlement was filed in January 2017. Hearings were held in February 2017, and the ACC approved the settlement agreement in April 2017. The settlement provides for an overall operating revenue increase of $16 million and the capital structure and cost of capital as proposed by Southwest, with the exception of the return on common equity, which was set at 9.50%. Depreciation expense is expected to be reduced by $44.7 million, for a combined net annual operating income increase of $60.7 million. Other key elements ofincluded the ~~settlement include~~ approval of the continuation ~~and expansion~~ of the ~~current~~ Customer-Owned Yard Line (“COYL”) program, ~~(adding~~ the ~~ability to seek out COYLs through a targeted approach and mobilization of work crews for replacement),~~ implementation of a vintage steel pipe (“VSP”) replacement program, and a continuation of the current decoupled rate design, excluding athe previous winter-period adjustment to rates, making the mechanism fundamentally similar to that which exists in Nevada. The settlement also included a property tax tracking mechanism, towhich will defer changes in ~~property tax~~related expense for recovery ~~or return~~ in the next general rate case. ~~New rates were effective April 2017. The settlement~~It also ~~includes~~included a three-year moratorium on filing another general rate ~~case moratorium prohibiting a new~~ application ~~to adjust base rates from being filed~~ prior to May 2019.

Tax Reform. In January 2018, the ACC held a workshop specifically to address U.S. tax reform with all jurisdictional public service corporations and directed ACC staff (“the Staff”) to prepare a recommended order for consideration at an open meeting. The Staff-recommended order provided that all utilities apply regulatory accounting treatment to address impacts from the enactment of tax reform beginning January 1, 2018. Additionally, the Staff recommended that all jurisdictional utilities file an application to address savings associated with tax reform within 60 days of the open meeting through a tax expense adjustor mechanism, a notice of intent to file a rate case within 90 days, or to file an application to address the impacts of tax reform. At the referenced open meeting in February, the ACC issued an order adopting the Staff’s recommendations. 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. The tax refund process was designed to ensure customers receive the benefits from tax reform through anACC-approved earnings test whereby a tax refund application will be made annually to refund to customers any margin contributing to earnings above theACC-authorized rate of return. The Staff drafted another order (the “subsequent draft order”), recommending that Southwest refund customers aone-time credit to reflect the tax savings from January through July 2018, effective with Southwest’s August 2018 billing cycles and that, effective August 2018, surcredits be established on aper-therm basis until newcost-of-service rates become effective following the Company’s next general rate case. Other recommendations included supplemental compliance reports related to excess deferred income taxes and an annualtrue-up to account for differences between the actual tax savings and the amount authorized by the ACC. In July 2018 the ACC issued a decision (the “Decision”) approving the Staff’s subsequent draft order. While the ACC Decision addressed current tax reductions due to tax reform, it did not direct refunding to commence with regard to excess amounts from the remeasurement of deferred tax balances, which continue to be recognized in a regulatory liability since the enactment date of tax reform in December 2017.

LNG (“Liquefied Natural Gas”) 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 in 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 grantingpre-approval of Southwest’s application to construct the LNG facility and the deferral of costs, up to $50 ~~million. Following the December 2014 preapproval, Southwest purchased the site for the facility~~million, which was later approved (December 2016) to be modified not to exceed $80 million, following land purchase and ~~completed detailed engineering design specifications for the purpose of soliciting bids~~bid solicitation for the engineering, procurement and construction ~~(“EPC”)~~ of the facility. ~~Southwest solicited requests for proposals for the EPC phase of the project, and in October 2016 made a filing with the ACC to modify the previously issued Order to update thepre-approved~~ ~~costs to reflect anot-to-exceed~~ amount of $80 million, which was approved by the ACC in December 2016. Through September 2017, Southwest has incurred approximately $21.7 million in capital expenditures toward the project (including land acquisition costs). Construction commenced during the third quarter of 2017 and is expected to be completed by the end of 2019. Through June 2018, Southwest has incurred approximately $45 million in capital expenditures toward the project (including land acquisition costs).

COYL Program. Southwest received approval, in connection with an earlier 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, which is not a traditional configuration. ~~Customers with this configuration were previously responsible for~~“Phase II” of the ~~cost~~COYL program included the replacement of ~~maintaining these lines and were subject to the immediate cessation of natural gas service iflow-pressure~~non-leaking ~~leaks occurred. Effective June 2013, the ACC authorized a surcharge to recover the costs of depreciation andpre-tax~~ ~~return on the costs incurred to replace and relocate service lines and meters.~~COYLs. The surcharge is revised annually as the program progresses. In ~~2014, Southwest received approval to add a “Phase II” component to~~ the ~~COYL program to include the replacement ofnon-leaking~~ ~~COYLs. In the most recent~~ annual COYL filing made in February 2017, Southwest requested to establish an annual surcharge to collect $1.8 million related to the revenue requirement associated with $12.1 million in capital


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

projects completed under both ~~Phase I and Phase II~~phases during 2016. In June 2017, the ACC issued a decision approving the surcharge application. All capital work completed in earlier years was incorporated in Southwest’s Arizona rate base in connection with the recently completed general rate case proceeding, as discussed above.


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

In the annual COYL filing made in February 2018, Southwest requested surcharge revenue of $4.2 million (an increase of $2.4 million from $1.8 million) related to 2017 expenditures of $18 million. ACC Staff issued a recommended order approving the proposed surcharge application, while modifying the surcharge revenue to $3.5 million (an increase of $1.7 million) to reflect the impact of tax reform on the revenue requirement calculation. ACC consideration is expected during the third quarter of 2018.

~~Vintage Steel Pipe Program~~VSP Program.. Southwest received approval, in connection with its most recent Arizona general rate case, to implement a ~~vintage steel pipe (“VSP”)~~VSP replacement program. Southwest currently has approximately 6,000 miles ofpre-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 will be made in February of each year. The surcharge is designed to be revised annually as the program progresses. A Plan of Administration (“POA”), which was filed in March of 2017 and was approved in conjunction with the general rate case, outlined the VSP program requirements and established the timeline for future project plans and surcharge requests. Southwest ~~is currently targeting the replacement of nearly~~replaced approximately 40 miles of VSP during 2017 totaling approximately $27 million and is targeting replacement projects during 2018 of approximately $100 million. In the annual VSP filing made in February 2018, Southwest requested an increase in surcharge revenue to collect $3.1 million related to 2017 expenditures. ACC Staff issued a recommended order approving the proposal surcharge application, while modifying the surcharge revenue to $2.4 million to reflect the impact of tax reform on the revenue requirement calculation. ACC consideration is expected during the third quarter of 2018.

California Jurisdiction

~~Attrition Filing.~~ In November 2016, Southwest made its latest annual post-test year (“PTY”) attrition filing with the California Public Utilities Commission (“CPUC”), requesting annual revenue increases of $2.1 million in southern California, $513,000 in northern California, and $256,000 for South Lake Tahoe. This filing was approved in December 2016 and rates were made effective in January 2017. At the same time, rates were updated to recover the regulatory asset associated with the revenue decoupling mechanism, or margin tracker.

California General Rate ~~Case~~Case.. 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 ~~PTY~~post-test year (“PTY”) attrition adjustments through 2020 from 2018. That latest rate case decision would have otherwise required Southwest to file its next general rate application by September 2017. Expedited consideration was requested and in June 2017, the ~~CPUC~~California Public Utilities Commission (“CPUC”) approved the request, thereby extending the rate case filing ~~deadline.~~deadline to September 2019. Southwest believes this extension is in the public interest as it provides rate stability to customers for two additional years consistent with the current reasonable rates approved as part of the last general rate case, and the ~~current revenue requirement and rate of return are not in need of adjustment (with the~~ continuation of the currently approved 2.75% PTY attrition adjustment for the two additional ~~years).~~years. Also seeAttrition Filing below.

Tax Reform. In its 2017 decision approving Southwest’s request to extend the filing date of its next general rate case, the CPUC 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. Southwest does not currently anticipate making an ad hoc filing in advance of the next general rate case filing to implement any changes resulting from tax reform.

Attrition Filing. In November 2017, Southwest made its latest annual PTY attrition filing, requesting annual revenue increases of $2 million in southern California, $527,000 in northern California, and $263,000 for South Lake Tahoe. This filing was approved in December 2017 and rates were made effective in January 2018. 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 years2015-2017 beginning in the second quarter of 2018. Southwest has a net cost balance, which will be amortized over a12-month period in rates for all applicable rate schedules, effective July 2018. In addition, for years 2019-2020, the decision adopted an allocation methodology to distribute the revenue proceeds through a California Climate Credit to active residential customers in April of each year. GHG compliance costs will be recovered through rates (including transportation rates) as prescribed byDecision D.15-10-032. There is no impact on earnings.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

Nevada Jurisdiction

Nevada General ~~Revenues Adjustment.~~Rate Case.~~In June 2016, Southwest requested authorization~~ The currently effective general rate case decision was received from the Public Utilities Commission of Nevada (“PUCN”) in November 2012 as amended in a Rehearing Decision in April 2013. Southwest filed its most recent general rate case with the PUCN in May 2018. The filing requests a statewide overall general rate increase of approximately $32.5 million to account for changes in the cost of service ($14.4 million) since the last general rate case, including those resulting from the TCJA, and another $18.1 million associated with the inclusion in rate base of GIR projects previously approved by the PUCN under the ongoing program. The application also requests a return on common equity of 10.30%, and a capital structure utilizing a 49.3% equity ratio. In association with the proposed changes, depreciation expense is expected to increase by approximately $4 million, for a net operating income impact of approximately $28 million. Southwest also seeks to adjust the GIR rate as part of the rate case process in lieu of filing a separate GIR rate application later this year. That adjustment would result in estimated incremental margin of $6.5 million for southern Nevada and $136,000 for northern Nevada.

In addition to the foregoing, Southwest is requesting to implement a pension tracker to account for the changes in pension expense between rate cases. Southwest also proposes to include two new tariff schedules (1) compression service and (2) biogas and renewable natural gas service. There are no changes to rate design overall, and a request to continue the general revenues adjustment (“GRA”) mechanism (revenue decoupling mechanism) is included. Management currently expects that an order will be received during the fourth quarter of 2018 and that new rates will become effective no later than January 1, 2019. See alsoTax ReformandInfrastructure Replacement Mechanisms below.

Tax Reform. The PUCN opened an investigation into the TCJA, requiring comments to be filed by April 2018. Southwest filed comments, whereby it described its plan to address the tax changes in its upcoming general rate case that was filed in May 2018. In addition, PUCN Staff and the Bureau of Consumer Protection (“BCP”) filed reply comments, whereby both the PUCN Staff and the BCP agreed that the pending Nevada rate case is the appropriate forum for addressing the impact of the TCJA on ratepayers, and recommended that the Company refrain from amortizing any excess accumulated deferred tax balances until the rate case is resolved.

General Revenues Adjustment.As part of the Annual Rate Adjustment (“ARA”) filing in 2016, the PUCN authorized rate adjustments associated with ~~its revenue decoupling mechanism (General Revenues Adjustment, or “GRA”).~~the GRA. The ~~filing was approved~~rate adjustment collected $13.6 million from customers during 2017, a decrease in ~~December 2016,~~collections of $11.8 million, as compared to 2016. For the 2017 filing, with rates effective January ~~2017. The rate adjustment is expected to refund approximately $16.7 million during 2017. In June 2017, Southwest filed to adjust the GRA surcharge effective January~~ 2018, ~~which was approved by~~ the PUCN ~~during the third quarter of 2017. This will~~authorized rate adjustments that are expected to result in a decrease in collections from customers of $15.4 million, ~~based on~~as compared to the ~~over-recovered balance~~2017 levels. In association with the most recent annual submission in June 2018, Southwest filed to adjust the ~~account at the end~~GRA surcharge effective January 2019, to result in an increase in collections from customers of ~~April 2017.~~$5.6 million. While there is no impact to net income overall from this rate adjustment, operating cash flows will be ~~reduced~~increased as the associated regulatory ~~liability~~ balance is ~~refunded.~~reduced.

Infrastructure Replacement ~~Mechanisms.~~Mechanism.In January 2014, the PUCN approved final rules for a mechanism to defer and recover certain costs associated with accelerated replacement of infrastructure that ~~does~~would not otherwise currently provide incremental revenues. Associated with ~~such~~the replacement of various types of pipe infrastructure under the mechanism (Early Vintage Plastic Pipe, COYL and VSP), each year Southwest files a ~~Gas Infrastructure Replacement (“GIR”) Advance Application~~GIR “Advance Application” requesting ~~authority~~authorization to replace qualifying ~~infrastructure and files separately as part~~infrastructure. Approximately $57.3 million of ~~an annual GIR filing to reset the recovery surcharge, related to previously~~replacement work was approved ~~and completed projects. For projects approved in 2015 and completed in 2016, the~~for 2017 with an annualized revenue ~~was~~requirement estimated at approximately ~~$4.5~~$5.3 million. In ~~September 2016,~~May 2017, Southwest filed to adjust the GIR surcharge to recover the annual revenue requirement for amounts previously deferred. This filing was approved in December 2016 and new rates became effective January 2017. In June 2016, Southwest filed anits Advance Application for projects totaling approximately $66 million that are expected to be completed during 2017, proposing approximately $60 million of accelerated pipe replacement to include early vintage plastic, early vintage steel, and a COYL program. The COYL program, while not large in magnitude, represents the first of its kind in Nevada, modeled after the program in place for several years in Southwest’s Arizona jurisdiction.2018. The PUCN issued an ~~Order~~order on ~~the~~that Advance Application in ~~October 2016,~~September 2017, approving approximately ~~$57.3~~$66 million of replacement work with an annualized revenue requirement estimated at ~~approximately $5.3~~$6 million. With regard to the proposed COYL program, approval was granted for the northern Nevada rate jurisdiction, but consideration for the southern Nevada rate jurisdiction was deferred until 2020, at which time certain early vintage plastic pipe programs are expected

In June 2018, Southwest filed its Advance Application with projects totaling $228 million to be ~~completed. In September 2017, Southwest filed to adjust the GIR surcharge to recover the annual~~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 is requesting to move to a multi-year approval process for ~~amounts previously deferred. For~~ projects ~~approved in 2016~~to improve operational flexibility and ~~completed by July~~enhance coordination with contractors and governmental agencies. A final decision is expected during the fourth quarter of ~~2017~~2018.

4148


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

,Filed separately, as part of each GIR filing, Southwest requests authorization to reset the GIR recovery surcharge related to previously approved and completed projects, with new rates becoming effective each January. In November 2017, for projects approved in 2016 and completed by July 2017, a deferred annualized revenue requirement ~~is approximately~~of $8.7 ~~million. This filing~~million was approved to be recovered from customers through updated rates effective January 2018. The updated surcharge is expected to ~~be approved~~result in ~~December 2017 with rates becoming effective January 2018.~~

~~In May 2017, Southwest filed~~incremental annual margin of $4.2 million. If the above noted transition to a GIR Advance Application with the PUCN for projects totaling approximately $66 million that are expected to be completed during 2018. Similar to previous years, the proposed projects consist of early vintage plastic and early vintage steel pipe, as well as the continuation of the previously approved COYL program in northern Nevada. Southwest entered into a settlement agreement with the intervening parties and filed a proposed stipulation requesting the Commission approve the settlement agreement. The settlement agreement proposed that the request bethree-year project plan is approved as ~~filed and that Southwest be authorized~~requested, management would continue to ~~start replacing COYLs in southern Nevada in certain situations, and to recover costs through~~update surcharges annually under the GIR mechanism. The PUCN issued an Order on the GIR Advance Application in September 2017, approving approximately $65.7 million of replacement work (with an annualized revenue requirement estimated at approximately $6 million) and the COYL provisions in southern Nevada.

Subsequent to three GIR rate applications, the GIR regulations require Southwest to either file a general rate case or a request for waiver before it can file another GIR advance application. The October 2016 approved rate application was the third such filing by Southwest subject to these regulations, necessitating a request for waiver to permit Southwest to proceed with the GIR program without filing a general rate case in 2017. This waiver was approved by the PUCN in January 2017; however, in order to continue the GIR program in 2018 (for projects recommended for completion under the program after 2018), a general rate case will need to be filed before June 2018.program.

Conservation and Energy ~~Efficiency (“~~Efficiency(“CEE”). In June 2015, Southwest requested recovery of energy efficiency and conservation development and implementation costs, including promotions and incentives for various programs, as originally approved for deferral by the PUCN effective November 2009. While recovery of initial program costs was approved as part of the most recent general rate case, amounts incurred subsequent to May 2012 (the certification period) continued to be deferred. Approved rates for thepost-May 2012 costs deferred (including previously expected program expenditures for 2016) became effective January ~~2016 and resulted in annualized margin increases of $2 million in northern Nevada and $8.5 million in southern Nevada. Then, as part of the~~2016. The 2017 ARA filing approved in ~~December 2016, Southwest~~November 2017, with modified rates effective January ~~2017,~~2018, is expected to result in annualized margin decreases of $8.2 million in southern Nevada and $1.4 million in northern Nevada ~~and $1.3~~to return over-collected balances. As part of the 2018 ARA filing, Southwest requested modified rates, effective January 2019, authorizing an annualized margin decrease of $4 million in southern Nevada ~~to return over-collected balances.~~and $100,000 increase in northern Nevada. There is, however, no anticipated impact to net income overall from these decreases as amortization expense will also be reduced.

Expansion and Economic Development Legislation.In ~~February 2015,~~January 2016, final regulations were approved by the PUCN associated with legislation (“SB 151”) ~~was~~previously introduced and signed into law in ~~Nevada directing the PUCN to adopt regulations authorizing~~Nevada. The legislation authorized natural gas utilities to expand their ~~infrastructure consistent with a program of economic development.~~infrastructure. This includes providing gas service to unserved and underserved areas in Nevada, as well as attracting and retaining utility customers and accommodating the expansion of existing business customers. SB 151 was signed into law in May 2015. The draft regulations were reviewed by the Legislative Council Bureau and final regulations were approved by the PUCN in January 2016.Nevada.

In November 2017, Southwest filed for preapproval of a project to extend service to ~~include the service territory of~~ Mesquite, Nevada, in accordance with the SB 151 regulations. ~~This project proposes~~Hearings took place in April 2018, and in May, the ~~extension of existing facilities~~PUCN issued an order approving the Southwest proposal to ~~Mesquite at an estimated cost~~expand natural gas infrastructure to Mesquite. The order approves a capital investment of approximately ~~$30 million.~~$28 million and the construction of approximately 37 miles of distribution pipeline (including the approach main). The cost is ~~proposed~~expected to be recovered through a volumetric ~~surcharge on~~rates from all southern Nevada ~~customers. A second phase~~customers (including new customers in Mesquite). The annual revenue requirement associated with the project is ~~then proposed to convert existing homes to natural gas service, which will be charged as a separate surcharge to Mesquite customers only. A decision on this proposal is expected within the required210-day~~ ~~time period for filings of this type.~~$2.8 million.

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 May 2019. SeeTax 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 ~~Pipeline Company (“Paiute”)~~ evaluated shipper interest in acquiring additional transportation capacity and executed precedent agreements for incremental transportation capacity with Southwest during the third quarter of 2016. In October 2016, Paiute initiated apre-filing review process with the FERC for an expansion project, which was approved during the same month. In July 2017, a certificate application was filed, which included an applicant environmental assessment. ~~The project is anticipated~~In May 2018, the FERC issued a Certificate of Public Convenience and Necessity authorizing Paiute to construct the project. Construction work began in July 2018 and will consist of 8.5 miles of additional transmission pipeline ~~infrastructure at an approximate cost of $18 million. If the process progresses as planned, a decision should~~infrastructure. The project is expected to be ~~received by April 2018 and the additional facilities could be in place~~completed by the end of ~~2018.~~2018 at a cost of approximately $22 million.

Tax Reform. The FERC issued a Notice of Proposed Rulemaking (“NOPR”) on whether the federal income tax changes of the TCJA 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 its rates by the percentage reduction in its 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 is necessary; or 4) file the new FERC form without taking any other action. The FERC would also ultimately consider whether to initiate an investigation of any pipeline that would not have submitted a limited Section 4 rate

4249


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

reduction filing or committed to file a general rate case. In July 2018, the FERC issued a final rule (Order No. 849) adopting procedures for determining which jurisdictional pipelines may be collecting unjust and unreasonable rates in light of tax reform. The rule becomes effective 45 days after publication in the Federal Register. Paiute Pipeline Company and Southwest Gas Transmission Company, the Company’s FERC-regulated subsidiaries are each expected to file a Form No.501-G during the fourth quarter of 2018.

PGA Filings

The rate schedules in all of Southwest’s service territories contain provisions that permit adjustments to rates as the cost of purchased gas changes. These deferred energy provisions and purchased gas adjustment clauses are collectively referred to as “PGA” clauses. Differences between gas costs recovered from customers and amounts paid for gas by Southwest result in over- or under-collections. At ~~September~~June 30, ~~2017, under-collections in Arizona and Northern Nevada resulted in an asset of approximately $6.2 million and~~2018, over-collections in ~~Southern Nevada and California~~all jurisdictions resulted in a liability of ~~$15~~$26.4 million on the Company’s and Southwest’s condensed consolidated balance sheets. Gas cost rates paid to suppliers have been higher than amounts recovered from customers during the first nine months of 2017, resulting in fluctuations since December 31, 2016. Tariff rates have been adjusted in all jurisdictions during this period.Condensed Consolidated Balance Sheets. 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)~~(in thousands):


	September 30, 2017			December 31, 2016			September 30, 2016			June 30, 2018			December 31, 2017			June 30, 2017
Arizona	$	1,324		$	(20,349	)	$	(34,425	)	$	(9,167	)	$	5,069		$	4,822
Northern Nevada		4,906			(3,339	)		(10,326	)		(4,555	)		8,189			1,134
Southern Nevada		(13,711	)		(66,788	)		(77,402	)		(7,364	)		(6,841	)		(17,741	)
California		(1,260	)		2,608			(1,246	)		(5,279	)		1,323			(2,887	)

	$	(8,741	)	$	(87,868	)	$	(123,399	)	$	(26,365	)	$	7,740		$	(14,672	)

As discussed inNote 1 – Nature of Operations and Basis of Presentation in this Form10-Q, in July 2018, a refund of approximately $49 million was received by Southwest from El Paso Natural Gas, L.L.C. (“EPNG”), related to transmission services with EPNG. The refund (including applicable interest) relates to rates authorized by the FERC to have been in effect, and which were in effect, subject to refund provisions, from EPNG’s 2010 rate case, including subsequent procedural waivers thereto since 2011. Pursuant to Opinion No.528-B issued by the FERC in May 2018, refunds were determined for the period April 2011 through May 2018. As a result of these actions having taken place prior to the end of the second quarter of 2018, Southwest recorded its applicable refund in its records as of June 30, 2018. The amount is reflected in Prepaids and other current assets and as a regulatory liability included within Other current liabilities on the balance sheets of both Southwest and the Company. As Southwest expects to return to its customers all amounts that it received in July 2018, the June entry will be reversed, and the amount will then be reflected as part of the PGA balances associated with the respective jurisdictions to which the refund from EPNG relates. Refunding to Southwest’s customers will be subject to requirements of the individual states; however, management anticipates that amounts will be returned within twelve months or less. As the refund from EPNG was received after June 30, 2018, it did not impact Southwest’s, or the Company’s, cash balances as of that date.

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, certain pipe replacement has been accelerated to ~~take advantage of bonus depreciation tax incentives and to~~ fortify system integrity and reliability, notably in association with ~~new~~ gas infrastructure replacement programs as discussed above. During this same time, benefits were derived from ~~debt refinancing~~new borrowings and strategic debt redemptions. The Company’s capitalization strategy is 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 ~~decreased $179~~increased $49 million in the first ~~nine~~six months of ~~2017~~2018 as compared to the same period of ~~2016. The decline~~2017. Changes in operating cash flows ~~was primarily attributable to~~are typically influenced


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

significantly by the change in ~~deferred~~ purchased gas costs, ~~noted above.~~including amounts incurred and deferred, as well as when amounts are incorporated in customer bills to recover the deferred balances. Refer toResults of Natural Gas Operations andRates and Regulatory Proceedings.

Investing Cash Flows.Cash used in consolidated investing activities increased ~~$35~~$76 million in the first ~~nine~~six months of ~~2017~~2018 as compared to the same period of ~~2016.~~2017. The change was primarily due to increased construction expenditures in the natural gas operations segment, including scheduled and accelerated replacement activity. ~~The prior period included an outflow of $17 million to facilitate a construction services acquisition.~~

Financing Cash Flows.Net cash provided by consolidated financing activities increased ~~$195~~$17 million in the first ~~nine~~six months of ~~2017~~2018 as compared to the same period of ~~2016.~~2017. The increase was primarily due to activity under the credit facility and commercial paper program (an increase in borrowings in the current-year nine-month period and the repayment of borrowings in the prior-year nine-month period). The prior period included proceeds in utility operations from the issuance of $300 million in senior ~~notes.~~notes in March 2018, offset by the repayment of credit facility and commercial paper program borrowings in the currentsix-month period. The Company also issued approximately ~~$12~~$63 million during ~~2017~~the first six months of 2018 in stock under its Equity Shelf Program. See alsoNote 56 – Common Stock, and the discussion below. ~~The first nine months of 2017 includes the August 2017 $23 million purchase of the previous owners’ interest in Centuri. See also~~~~Note 9 – Construction Services Redeemable Noncontrolling Interest~~ ~~for additional information.~~


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

Dividends paid increased in the first ~~nine~~six months of ~~2017~~2018 as compared to the same period of ~~2016~~2017 as a result of an increase in the quarterly dividend rate and an increase in the number of shares outstanding.

The Company issued approximately ~~103,000~~77,000 additional shares of common stock collectively through the Restricted Stock/Unit Plan and the Management Incentive Plan. Also during the six months ended June 30, 2018, the Company issued 73,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan (“DRSPP”), raising approximately $5 million.

Southwest Gas Corporation:

Operating Cash Flows.Cash flows provided by operating activities ~~decreased $172~~increased $36.5 million in the first ~~nine~~six months of ~~2017~~2018 as compared to the same period of ~~2016.~~2017. The ~~decline~~increase in operating cash flows was primarily attributable to the change in deferred purchased gas costs as discussed ~~above.~~above, and other changes in working capital. Refer toResults of Natural Gas Operations andRates and Regulatory Proceedings.

Investing Cash Flows.Cash used in investing activities increased ~~$68~~$53 million in the first ~~nine~~six months of ~~2017~~2018 as compared to the same period of ~~2016.~~2017. The change was primarily due to additional construction expenditures, as indicated above.

Financing Cash Flows.Net cash provided by financing activities ~~increased $211~~decreased $4 million in the first ~~nine~~six months of ~~2017~~2018 as compared to the same period of ~~2016.~~2017. The ~~increase~~decrease was primarily due to activity under the credit facility and commercial paper program (an increase in borrowings in the current-year nine-month period and the repayment of borrowings in the prior-year nine-month period). The prior period included proceeds from the issuance of $300 million in senior notes ~~as discussed above. The current period included capital contributions from Southwest Gas Holdings, Inc.~~in March 2018 offset by the repayment of the credit facility and commercial paper program borrowings then outstanding.

The capital requirements and resources of the Company generally are determined independently for the natural gas operations and construction services segments. Each business activity is generally responsible for securing its own external financing sources.

Gas Segment Construction Expenditures and Financing

During the twelve-month period ended ~~September~~June 30, ~~2017,~~2018, construction expenditures for the natural gas operations segment were ~~$515~~$622 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 ~~$337~~$346 million during this time and provided approximately ~~57%~~49% of construction expenditures and dividend requirements.

~~Southwest~~Management estimates natural gas segment construction expenditures during the three-year period ending December 31, ~~2019~~2020 will be ~~between $1.6 billion and $1.8~~approximately $2 billion. Of this amount, approximately ~~$570~~$670 million is expected to be incurred in ~~2017.~~2018. Southwest plans to continue ~~as appropriate,~~ to request regulatory support to accelerate projects that improve system flexibility and reliability (including replacement of early vintage plastic and steel pipe). This includes the recent approval to complete accelerated replacement projects in Nevada of $57.3 million and $65.7 million in 2017 and 2018, respectively. It also incorporates programs included in the recently approved Arizona general rate case settlement (the continuation of the COYL program and implementation of a vintage steel pipe replacement program). Southwest may expand existing, or initiate new, programs. If efforts continue to be successful, significant replacement activities are expected to continue well beyond the next few years.reliability. See alsoRates and Regulatory Proceedings for discussion of Nevada infrastructure (including the recent filing to move to a multi-year approval program), Arizona COYL, and an LNG facility. During the three-year period, cash flows from operating activities of Southwest are expected to provide approximately ~~60%~~50% to ~~70%~~60% 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 Southwest Gas Holdings, Inc. and/or other external financing sources. The timing, types, and amounts of any additional external


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

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 of 2017, 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. See additional discussion in the Notes to financial statements (specifically,Note6 – Common Stockand Note 7 – Long-Term Debt).

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 Securities and Exchange Commission (“SEC”) an automatic shelf registration statement for the offer and sale of up to $150 million of common stock from time to time inat-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”). Sales of the shares will


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

continue to be made at market prices prevailing at the time of sale. Net proceeds from the sale of shares of common stock under the Equity Shelf Program are intended for general corporate purposes, including the acquisition of property for the construction, completion, extension or improvement of pipeline systems and facilities located in and around the communities Southwest serves.

During the ~~nine~~six months ended ~~September~~June 30, ~~2017, 147,077~~2018, 870,132 shares were issued inat-the-market offerings at an average price of ~~$80.07~~$72.94 per share with gross proceeds of ~~$11.8~~$63.5 million, agent commissions of ~~$118,000,~~$635,000, and net proceeds of ~~$11.7~~$62.8 million. SeeNote 56 – Common Stock for more information. See also discussion above regarding the Company’s issuances under the DRSPP.

Bonus Depreciation

In ~~December 2015,~~2017, with the ~~Protecting Americans from~~enactment of the Tax ~~Hikes~~Cuts and Jobs Act, ~~of 2015 (“PATH Act”) was enacted extending~~ the ~~50%~~ bonus depreciation ~~tax~~ deduction percentage changed from 50% to 100% for ~~qualified property acquired or constructed~~“qualified property” placed in service after September 27, 2017 and ~~placedin-service~~ ~~during 2015 (and additional years as noted below) as well as other tax deductions, credits, and incentives.~~before 2023. The bonus depreciation tax deduction ~~will be phased~~phases out ~~over five years. The PATH Act provides~~starting in 2023, by 20% for a 50% bonus depreciation tax deduction in 2015 through 2017, 40% in 2018, 30% in 2019, and no deduction after 2019. Based on forecasted qualifying construction expenditures, Southwest estimates the bonus depreciation provisioneach of the ~~PATH Act~~five following years. Qualified property excludes public utility property. The Company estimates bonus depreciation will defer the payment of approximately ~~$29~~$14 million (none of which relates to utility operations) of federal income taxes for ~~2017, resulting in a minimal amount of federal income tax being paid.~~2018.

Dividend Policy

Dividends are payable on the Company’s common stock at the discretion of the Board of Directors (“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, ~~our payout ratio,~~ and our ability to maintain strong credit ratings and liquidity. The Company has paid dividends on its common stock since 1956 and has increased that dividend each year since 2007. In February ~~2017,~~2018, the Board elected to increase the quarterly dividend from ~~$0.45~~$0.495 to ~~$0.495~~$0.52 per share, representing a ~~10%~~5% increase, effective with the June ~~2017~~2018 payment. ~~The Board currently targets a payout ratio of 55% to 65% of consolidated earnings per share.~~

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 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 ~~September~~June 30, ~~2017,~~2018, the combined balance in the PGA accounts totaled an over-collection of ~~$8.7~~$26.4 million. SeePGA Filingsfor


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

more information.

~~In March 2017, Southwest Gas Holdings, Inc. entered into~~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 ~~September~~June 30, ~~2017, $27.5~~2018, $22.5 million was outstanding on this facility.

~~In March 2017,~~ Southwest ~~Gas Corporation amended its~~has a credit facility, ~~increasing the~~with borrowing capacity ~~from $300 million to~~of $400 million, ~~and extended the term of the facility from March 2021 to~~that expires in March 2022. Southwest ~~continues to designate~~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 credit facility (including a commercial paper program, as noted below) during the first ~~nine~~six months of ~~2017~~2018 was $150 million. At ~~September~~June 30, ~~2017, $150~~2018, $48 million was outstanding on the long-term portion and ~~$83 million was~~no borrowings were outstanding on the short-term portion of this credit facility. Commercial paper borrowings are discussed below. 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


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

adequate for Southwest’s working capital needs outside of funds raised through operations and other types of external financing.

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 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 ~~September~~June 30, ~~2017,~~2018, there were no borrowings ~~were~~ outstanding under this program.

Centuri has a ~~$300 million~~senior secured revolving credit and term loan facility ~~that~~with borrowing capacity of $450 million. The line of credit portion of the facility is scheduled to expire in October 2019. The term loan facility portion had an initial limit of approximately $150 million, which was reached in 2014 and; $107 million was outstanding (after repayments) at September 30, 2017. The secured revolving credit facility portion also has a limit of $150$250 million; amounts borrowed and repaid under ~~this portion of~~ the revolving credit facility are available to bere-borrowed. The term loan facility portion, has a limit of approximately $200 million. The limit on the term loan facility was reached in November 2017. No further borrowing is permitted under the term loan facility. The $450 million credit and term loan facility expires in November 2022. The $450 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 June 30, 2018 totaled $659 million. The maximum amount outstanding on the credit facility during the first ~~nine~~six months of ~~2017~~2018 was ~~$104~~$293 million. At ~~September~~June 30, ~~2017, $81.3~~2018, $88 million was outstanding on the secured revolving credit facility. Also at ~~September~~June 30, ~~2017,~~2018, there was approximately ~~$52~~$144 million, net of letters of credit, available under the line of credit.

The following table sets forth the ratios of earnings to fixed charges for the Company. Due to the seasonal nature of the Company’s business, these ratios are computed on a twelve-month basis:

   For the Twelve Months Ended
   September 30,
2017    December 31,
2016
Ratio of earnings to fixed charges
   3.50    3.46


	For the Twelve Months Ended
	June 30,		December 31,
	2018		2017
Ratio of earnings to fixed charges		3.28		3.54

Earnings are defined as the sum of pretax income plus fixed charges. Fixed charges consist of all interest expense including capitalized interest,one-third of rent expense (that approximates the interest component of such expense), and net amortized debt costs.

The following table sets forth the ratios of earnings to fixed charges for Southwest. Due to the seasonal nature of Southwest’s business, these ratios are computed on a twelve-month basis:


	For the Twelve Months Ended
	June 30,		December 31,
	2018		2017
Ratio of earnings to fixed charges		3.65		4.01


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

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,” “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, the impacts of the Tax Cuts and Jobs Act legislation including disposition as to both timing and amounts in regulatory proceedings, bonus depreciation tax deductions, amount and timing for completion of estimated future construction expenditures, including the LNG facility in southern Arizona, the ~~cost of~~Mesquite expansion in Nevada, and the Paiute 2018 ~~Paiute~~ expansion project in northern Nevada and northern California, forecasted operating cash flows and results of operations, ~~net earnings~~ impacts from gas infrastructure replacement programs and surcharges, funding sources of cash requirements, amounts generally expected to be reflected in ~~2017~~2018 or future period revenues from regulatory rate proceedings including amounts resulting from the settled Arizona general rate case, the recently filed Nevada general rate case, 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 common stock under the Equity Shelf Program, the intent and ability to issue various financing instruments and stock under the December 2017 shelf registration statement, future dividend increases and the Board’s current target dividend payout ratio, pension and post-retirement benefits, certain ~~benefits~~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 ~~the~~ COYL ~~program, statements regarding~~programs, future gas prices, gas purchase contracts and derivative financial instruments, recoverability of regulatory assets, the time period and means for returning to customers proceeds from the recent EPNG refund, the impact of certain legal proceedings, and the timing and results of future rate hearings and approvals are forward-looking


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

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, the impacts of alternative energy sources to natural gas, the timing and amount of rate relief, the timing, amount, and methods determined by regulators to refund amounts to customers resulting from 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, results of Neuco (including the ability to be accretive to earnings over the first twelve months), Centuri construction expenses, differences between actual and originally expected outcomes of Centuri bid or other fixed-price construction agreements, outcomes from contract and change order negotiations, ~~and~~ 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 the recent work stoppage,~~ 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, seeItem 1A. Risk Factors


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

andItem 7A. Quantitative and Qualitative Disclosures About Market Risk in the Annual Report onForm 10-K for the year ended December 31, ~~2016.~~2017.

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).

~~ITEM 3.~~

~~QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK~~

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

SeeItem 7A. Quantitative and Qualitative Disclosures about Market Risk in the ~~2016~~2017 Annual Report on Form10-K filed with the SEC. No material changes have occurred related to the disclosures about market risk.

~~ITEM 4.~~

~~CONTROLS AND PROCEDURES~~

ITEM 4. CONTROLS AND PROCEDURES

Management of Southwest Gas Holdings, Inc. and Southwest Gas Corporation has established disclosure controls and procedures (as defined in Rules13a-15(e) and15d-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 ~~September~~June 30, ~~2017,~~2018, management of Southwest Gas Holdings, Inc., including the Chief Executive Officer and Chief Financial Officer, believe the Company’s disclosure controls and procedures are effective at attaining the level of reasonable assurance noted above.


~~SOUTHWEST GAS HOLDINGS, INC.~~		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~

There have been no changes in the Company’s internal ~~controls~~control over financial reporting (as defined in Rules13a-15(f) and15d-15(f) of the Exchange Act) during the ~~third~~second quarter of ~~2017~~2018 that have materially affected, or are likely to materially affect, the Company’s internal ~~controls~~control over financial reporting.

Based on the most recent evaluation, as of ~~September~~June 30, ~~2017,~~2018, management of Southwest Gas Corporation, including the Chief Executive Officer and Chief Financial Officer, believe 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 ~~controls~~control over financial reporting (as defined in Rules13a-15(f) and15d-15(f) of the Exchange Act) during the ~~third~~second quarter of ~~2017~~2018 that have materially affected, or are likely to materially affect Southwest’s internal ~~controls~~control over financial reporting.


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		June 30, 2018

PART ~~II—~~II - OTHER INFORMATION

~~ITEM 1.~~

~~LEGAL PROCEEDINGS~~

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.

~~ITEMS 1A through 3.~~ ~~None.~~

ITEM 4. MINE SAFETY DISCLOSURESNot applicable.

~~ITEM 4.~~

~~MINE SAFETY DISCLOSURES~~~~Not applicable.~~

ITEM 5. OTHER INFORMATIONNone.

~~ITEM 5.~~

~~OTHER INFORMATION~~~~None.~~

~~ITEM 6.~~

~~EXHIBITS~~

ITEM 6. EXHIBITS

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


Exhibit ~~3(i)~~12.01	-	—	~~Amendment to Articles of Incorporation of Southwest Gas Holdings, Inc.~~
~~Exhibit 3(ii)~~	—	~~Amended and Restated Bylaws of Southwest Gas Holdings, Inc.~~
Exhibit 10.01*	—	~~Centuri 2017 Short-Term Incentive Plan.~~
~~Exhibit 12.01~~	—	Computation of Ratios of Earnings to Fixed Charges – Southwest Gas Holdings, Inc.

Exhibit 12.02	-	Computation of Ratios of Earnings to Fixed Charges – Southwest Gas Corporation

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
~~Exhibit101.PRE~~
Exhibit 101.PRE	-	—	XBRL Presentation Linkbase Document

*	~~Management Incentive Plan~~

4856


SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		~~September~~June 30, ~~2017~~2018

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: ~~November 7, 2017~~August 8, 2018

/s/ ~~GREGORY J. PETERSON~~LORI L. COLVIN

~~Gregory J. Peterson~~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: ~~November 7, 2017~~August 8, 2018

/s/ ~~GREGORY J. PETERSON~~LORI L. COLVIN

~~Gregory J. Peterson~~Lori L. Colvin

Vice President/Controller and Chief Accounting Officer

4957


(In thousands of dollars)	Natural Gas Operations		Construction Services		Consolidated
December 31, 2016	$	10,095	$	129,888	$	139,983
Foreign currency translation adjustment		—		7,882		7,882

September 30, 2017	$	10,095	$	137,770	$	147,865


	September 30, 2017			December 31, 2016
Centuri property and equipment	$	493,599		$	451,114
Centuri accumulated provision for depreciation and amortization		(251,831	)		(228,374	)
Net cash surrender value of COLI policies		114,052			106,744
Other property		13,483			12,859

Total	$	369,303		$	342,343


	Redeemable Noncontrolling Interest
(Thousands of dollars):
Balance, December 31, 2016	$	22,590
Net income attributable to redeemable noncontrolling interest		248
Foreign currency exchange translation adjustment		11
Centuri dividend to redeemable noncontrolling interest		(204	)
Adjustment to redemption value		355
Redemption of Centuri shares from noncontrolling parties		(23,000	)

Balance, September 30, 2017	$	—


(Thousands of dollars)	December 31, 2016
Construction services equity	$	(4,390	)
Construction services noncontrolling interest		(2,217	)
Construction services redeemable noncontrolling interest		22,590

Discontinued operations - construction servicesnon-owner equity	$	15,983


	Three Months Ended September 30,
	2017			2016
	(Thousands of dollars)
Gas operating revenues	$	213,059		$	200,179
Net cost of gas sold		45,539			39,056

Operating margin		167,520			161,123
Operations and maintenance expense		102,215			102,438
Depreciation and amortization		46,194			56,436
Taxes other than income taxes		14,046			12,480

Operating income (loss)		5,065			(10,231	)
Other income (deductions)		3,081			2,521
Net interest deductions		17,421			16,364

Income (loss) before income taxes		(9,275	)		(24,074	)
Income tax expense (benefit)		(5,251	)		(11,669	)

Contribution to consolidated net income (loss)	$	(4,024	)	$	(12,405	)


	Nine Months Ended September 30,
	2017		2016
	(Thousands of dollars)
Gas operating revenues	$	935,823	$	980,927
Net cost of gas sold		261,839		324,072

Operating margin		673,984		656,855
Operations and maintenance expense		313,395		301,979
Depreciation and amortization		153,643		174,413
Taxes other than income taxes		43,325		39,480

Operating income		163,621		140,983
Other income (deductions)		8,744		6,712
Net interest deductions		51,622		49,155

Income before income taxes		120,743		98,540
Income tax expense		38,307		31,004

Contribution to consolidated net income	$	82,436	$	67,536


	Nine Months Ended September 30,
	2017		2016
	(Thousands of dollars)
Construction revenues	$	872,536	$	838,038
Operating expenses:
Construction expenses		806,586		757,919
Depreciation and amortization		35,446		43,351

Operating income		30,504		36,768
Other income (deductions)		38		44
Net interest deductions		5,095		4,945

Income before income taxes		25,447		31,867
Income tax expense		9,560		12,042

Net income		15,887		19,825
Net income attributable to noncontrolling interests		170		500

Contribution to consolidated net income attributable to Centuri	$	15,717	$	19,325

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company

Emerging growth company