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~~



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

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

2019



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



Commission File Number	Exact name of registrant as specified in its charter and principal office address and telephone number				State of Incorporation	I.R.S. Employer Identification No.
001-37976	Southwest Gas Holdings, Inc.			~~California~~		~~81-3881866~~
Delaware	~~5241 Spring Mountain Road~~
	~~Post Office Box 98510~~
	~~Las Vegas, Nevada 89193-8510~~						81-3881866
	5241 Spring Mountain Road
	Post Office Box 98510
	Las Vegas,	Nevada	89193-8510
	(702)	876-7237

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



Securities registered pursuant to Section 12(b) of the Act:
Title of each class		~~Post Office Box 98510~~ Trading Symbol	Name of each exchange on which registered
	Southwest Gas Holdings, Inc. Common Stock, $1 Par Value
SWX		~~Las Vegas, Nevada 89193-8510~~
		~~(702) 876-7237~~		New York Stock Exchange

Indicate by check mark whether each ~~registrant~~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~~each registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes☒ No ☐

Indicate by check mark whether each registrant has submitted electronically ~~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~~each 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~~ “non-accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule12b-2 of the Exchange Act.

Southwest Gas Holdings, Inc.:



Large accelerated filer	☒		Accelerated filer	☐

~~Non-accelerated filer~~		☐
Non-accelerated filer	☐		Smaller reporting company	☐

Emerging growth company	☐

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

Southwest Gas Corporation:



Large accelerated filer	☐		Accelerated filer	☐

~~Non-accelerated filer~~		☒
Non-accelerated filer	☒		Smaller reporting company	☐

Emerging growth company	☐	��

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~~54,626,240 shares as of October ~~27, 2017.~~

31, 2019.

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

October 31, 2019.

SOUTHWEST GAS CORPORATION MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION (H)(1)(a) and (b) OF FORM10-Q AND IS THEREFORE FILING THIS REPORT WITH THE REDUCED DISCLOSURE FORMAT AS PERMITTED BY GENERAL INSTRUCTION H(2).



	1



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

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, statements of cash flows, and statements of ~~cash flows)~~equity) for Southwest Gas Holdings, Inc. and Southwest Gas Corporation, in that order. The Notes to the Condensed Consolidated Financial Statements are presented on a combined basis for both entities. All Items other than Part I – Item 1 are combined for the reporting companies.



	2



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Thousands of dollars, except par value)

(Unaudited)

   SEPTEMBER 30,
2017 DECEMBER 31,
2016
ASSETS

Utility plant:

Gas plant
   $ 6,440,547 $ 6,193,564
Less: accumulated depreciation
   (2,218,796 ) (2,172,966 )
Acquisition adjustments, net
   81 196
Construction work in progress
   164,030 111,177


Net utility plant
   4,385,862 4,131,971


Other property and investments
   369,303 342,343


Current assets:

Cash and cash equivalents
   59,152 28,066
Accounts receivable, net of allowances
   301,792 285,145
Accrued utility revenue
   34,100 76,200
Income taxes receivable, net
   5,462 4,455
Deferred purchased gas costs
   6,230 2,608
Prepaids and other current assets
   132,182 136,833


Total current assets
   538,918 533,307


Noncurrent assets:

Goodwill
   147,865 139,983
Deferred income taxes
   1,467 1,288
Deferred charges and other assets
   411,655 432,234


Total noncurrent assets
   560,987 573,505


Total assets
   $ 5,855,070 $ 5,581,126


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
Additionalpaid-in capital
   924,213 903,123
Accumulated other comprehensive income (loss), net
   (42,818 ) (48,008 )
Retained earnings
   784,934 759,263


Total Southwest Gas Holdings, Inc. equity
   1,715,691 1,663,490
Noncontrolling interest
   (2,295 ) (2,217 )


Total equity
   1,713,396 1,661,273
Redeemable noncontrolling interest
   —   22,590
Long-term debt, less current maturities
   1,731,981 1,549,983


Total capitalization
   3,445,377 3,233,846


Current liabilities:

Current maturities of long-term debt
   28,453 50,101
Short-term debt
   110,500 —
Accounts payable
   159,382 184,669
Customer deposits
   70,162 72,296
Income taxes payable
   1,543 1,909
Accrued general taxes
   48,998 42,921
Accrued interest
   24,543 17,939
Deferred purchased gas costs
   14,971 90,476
Other current liabilities
   197,854 168,064


Total current liabilities
   656,406 628,375


Deferred income taxes and other credits:

Deferred income taxes and investment tax credits
   894,011 840,653
Accumulated removal costs
   312,000 308,000
Other deferred credits and other long-term liabilities
   547,276 570,252


Total deferred income taxes and other credits
   1,753,287 1,718,905


Total capitalization and liabilities
   $ 5,855,070 $ 5,581,126



	September 30, 2019			December 31, 2018
ASSETS
Utility plant:
Gas plant	$	7,550,855		$	7,134,239
Less: accumulated depreciation	(2,303,864		)	(2,234,029		)
Construction work in progress	288,573			193,028
Net utility plant	5,535,564			5,093,238
Other property and investments	768,685			623,551
Current assets:
Cash and cash equivalents	28,480			85,361
Accounts receivable, net of allowances	434,153			413,926
Accrued utility revenue	35,800			77,200
Income taxes receivable	26,611			14,653
Deferred purchased gas costs	49,804			4,928
Prepaid and other current assets	190,554			243,701
Total current assets	765,402			839,769
Noncurrent assets:
Goodwill	339,948			359,045
Deferred income taxes	896			1,264
Deferred charges and other assets	429,716			440,862
Total noncurrent assets	770,560			801,171
Total assets	$	7,840,211		$	7,357,729
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock, $1 par (authorized - 120,000,000 shares; issued and outstanding - 54,624,090 and 53,026,848 shares)	$	56,254		$	54,656
Additional paid-in capital	1,437,733			1,305,769
Accumulated other comprehensive income (loss), net	(47,775		)	(52,668		)
Retained earnings	977,498			944,285
Total Southwest Gas Holdings, Inc. equity	2,423,710			2,252,042
Noncontrolling interest	—			(452		)
Total equity	2,423,710			2,251,590
Redeemable noncontrolling interest	84,354			81,831
Long-term debt, less current maturities	2,462,116			2,107,258
Total capitalization	4,970,180			4,440,679
Current liabilities:
Current maturities of long-term debt	38,165			33,060
Short-term debt	30,000			152,000
Accounts payable	188,896			248,993
Customer deposits	68,897			67,940
Income taxes payable	1,319			1,083
Accrued general taxes	52,361			43,560
Accrued interest	34,745			21,369
Deferred purchased gas costs	88,030			79,762
Other current liabilities	279,931			290,878
Total current liabilities	782,344			938,645
Deferred income taxes and other credits:
Deferred income taxes and investment tax credits	577,928			529,201
Accumulated removal costs	392,000			383,000
Other deferred credits and other long-term liabilities	1,117,759			1,066,204
Total deferred income taxes and other credits	2,087,687			1,978,405
Total capitalization and liabilities	$	7,840,211		$	7,357,729

The accompanying notes are an integral part of these statements.



	3



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

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
   SEPTEMBER 30, SEPTEMBER 30, SEPTEMBER 30,
   2017 2016 2017 2016 2017 2016
Operating revenues:

Gas operating revenues
   $ 213,059 $ 200,179 $ 935,823 $ 980,927 $ 1,276,308 $ 1,376,388
Construction revenues
   380,094 339,790 872,536 838,038 1,173,576 1,127,982


Total operating revenues
   593,153 539,969 1,808,359 1,818,965 2,449,884 2,504,370


Operating expenses:

Net cost of gas sold
   45,539 39,056 261,839 324,072 334,888 460,836
Operations and maintenance
   102,278 102,438 314,488 301,979 414,233 400,222
Depreciation and amortization
   58,529 69,845 189,089 217,764 260,457 286,977
Taxes other than income taxes
   14,046 12,480 43,325 39,480 56,221 51,810
Construction expenses
   342,629 300,611 806,586 757,919 1,073,090 1,009,188


Total operating expenses
   563,021 524,430 1,615,327 1,641,214 2,138,889 2,209,033


Operating income
   30,132 15,539 193,032 177,751 310,995 295,337


Other income and (expenses):

Net interest deductions
   (19,494 ) (18,158 ) (56,863 ) (54,100 ) (76,423 ) (71,884 )
Other income (deductions)
   2,876 2,565 8,788 6,756 11,501 10,861


Total other income and (expenses)
   (16,618 ) (15,593 ) (48,075 ) (47,344 ) (64,922 ) (61,023 )


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


Net income
   10,420 2,907 97,546 87,361 163,240 154,059
Net income attributable to noncontrolling interests
   216 435 170 500 684 1,079


Net income attributable to Southwest Gas Holdings, Inc.
   $ 10,204 $ 2,472 $ 97,376 $ 86,861 $ 162,556 $ 152,980


Basic earnings per share
   $ 0.21 $ 0.05 $ 2.05 $ 1.83 $ 3.42 $ 3.22


Diluted earnings per share
   $ 0.21 $ 0.05 $ 2.03 $ 1.82 $ 3.39 $ 3.20


Dividends declared per share
   $ 0.495 $ 0.450 $ 1.485 $ 1.350 $ 1.935 $ 1.755


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



	Three Months Ended September 30,						Nine Months Ended September 30,						Twelve Months Ended September 30,
	2019			2018			2019			2018			2019			2018
Operating revenues:
Gas operating revenues	$	209,980		$	217,523		$	989,368		$	987,515		$	1,359,581		$	1,354,000
Utility infrastructure services revenues	515,250			450,623			1,282,412			1,105,844			1,698,853			1,479,792
Total operating revenues	725,230			668,146			2,271,780			2,093,359			3,058,434			2,833,792
Operating expenses:
Net cost of gas sold	35,068			49,903			292,854			319,101			393,141			412,307
Operations and maintenance	109,652			105,508			321,190			313,294			414,289			406,137
Depreciation and amortization	75,370			62,156			223,251			185,941			286,522			247,803
Taxes other than income taxes	15,308			15,036			46,640			44,959			61,579			59,580
Utility infrastructure services expenses	451,574			395,862			1,154,238			1,007,485			1,534,442			1,349,862
Total operating expenses	686,972			628,465			2,038,173			1,870,780			2,689,973			2,475,689
Operating income	38,258			39,681			233,607			222,579			368,461			358,103
Other income and (expenses):
Net interest deductions	(27,434		)	(24,548		)	(80,662		)	(70,831		)	(106,502		)	(92,032		)
Other income (deductions)	(1,158		)	889			6,827			(6,151		)	(4,448		)	(6,401		)
Total other income and (expenses)	(28,592		)	(23,659		)	(73,835		)	(76,982		)	(110,950		)	(98,433		)
Income before income taxes	9,666			16,022			159,772			145,597			257,511			259,670
Income tax expense	3,141			3,691			35,031			33,421			63,294			51,098
Net income	6,525			12,331			124,741			112,176			194,217			208,572
Net income (loss) attributable to noncontrolling interests	1,172			—			2,523			(797		)	2,695			(866		)
Net income attributable to Southwest Gas Holdings, Inc.	$	5,353		$	12,331		$	122,218		$	112,973		$	191,522		$	209,438
Basic earnings per share	$	0.10		$	0.25		$	2.26		$	2.31		$	3.60		$	4.30
Diluted earnings per share	$	0.10		$	0.25		$	2.26		$	2.31		$	3.59		$	4.29
Average number of common shares	54,670			49,493			53,996			48,916			53,219			48,728
Average shares (assuming dilution)	54,748			49,553			54,063			48,968			53,287			48,781

The accompanying notes are an integral part of these statements.



	4



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

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
   SEPTEMBER 30, SEPTEMBER 30, SEPTEMBER 30,
   2017 2016 2017 2016 2017 2016
Net income
   $ 10,420 $ 2,907 $ 97,546 $ 87,361 $ 163,240 $ 154,059


Other comprehensive income (loss), net of tax

Defined benefit pension plans:

Net actuarial gain (loss)
   —   —   —   —   (14,118 ) (18,922 )
Amortization of prior service cost
   207 207 621 621 828 828
Amortization of net actuarial loss
   3,944 4,196 11,832 12,586 16,027 17,915
Regulatory adjustment
   (3,555 ) (3,796 ) (10,667 ) (11,388 ) (2,741 ) (404 )


Net defined benefit pension plans
   596 607 1,786 1,819 (4 ) (583 )


Forward-starting interest rate swaps:

Amounts reclassified into net income
   518 518 1,554 1,556 2,073 �� 2,073


Net forward-starting interest rate swaps
   518 518 1,554 1,556 2,073 2,073


Foreign currency translation adjustments
   1,012 (238 ) 1,861 614 1,408 233


Total other comprehensive income, net of tax
   2,126 887 5,201 3,989 3,477 1,723


Comprehensive income
   12,546 3,794 102,747 91,350 166,717 155,782
Comprehensive income attributable to noncontrolling interests
   198 427 181 521 679 1,089


Comprehensive income attributable to Southwest Gas Holdings, Inc.
   $ 12,348 $ 3,367 $ 102,566 $ 90,829 $ 166,038 $ 154,693



	Three Months Ended September 30,						Nine Months Ended September 30,						Twelve Months Ended September 30,
	2019			2018			2019			2018			2019			2018
Net income	$	6,525		$	12,331		$	124,741		$	112,176		$	194,217		$	208,572
Other comprehensive income (loss), net of tax
Defined benefit pension plans:
Net actuarial gain (loss)	—			—			—			—			(15,524		)	(32,701		)
Amortization of prior service cost	241			254			724			762			977			969
Amortization of net actuarial loss	4,442			6,387			13,325			19,161			19,713			23,105
Regulatory adjustment	(4,065		)	(5,746		)	(12,193		)	(17,236		)	(1,214		)	6,021
Net defined benefit pension plans	618			895			1,856			2,687			3,952			(2,606		)
Forward-starting interest rate swaps (“FSIRS”):
Amounts reclassified into net income	635			636			1,906			1,907			2,540			2,426
Net forward-starting interest rate swaps	635			636			1,906			1,907			2,540			2,426
Foreign currency translation adjustments	(447		)	599			1,131			(1,002		)	(877		)	(1,092		)
Total other comprehensive income (loss), net of tax	806			2,130			4,893			3,592			5,615			(1,272		)
Comprehensive income	7,331			14,461			129,634			115,768			199,832			207,300
Comprehensive income (loss) attributable to noncontrolling interests	1,172			—			2,523			(797		)	2,695			(866		)
Comprehensive income attributable to Southwest Gas Holdings, Inc.	$	6,159		$	14,461		$	127,111		$	116,565		$	197,137		$	208,166

The accompanying notes are an integral part of these statements.



	5



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of dollars)

(Unaudited)

   NINE MONTHS ENDED TWELVE MONTHS ENDED
   SEPTEMBER 30 SEPTEMBER 30
   2017 2016 2017 2016
CASH FLOW FROM OPERATING ACTIVITIES:

Net income
   $ 97,546 $ 87,361 $ 163,240 $ 154,059
Adjustments to reconcile net income to net cash provided by operating activities:

Depreciation and amortization
   189,089 217,764 260,457 286,977
Deferred income taxes
   49,409 43,702 74,439 86,526
Changes in current assets and liabilities:

Accounts receivable, net of allowances
   (15,330 ) 28,531 (13,765 ) (17,889 )
Accrued utility revenue
   42,100 41,700 (1,100 ) (800 )
Deferred purchased gas costs
   (79,127 ) 81,389 (114,658 ) 79,460
Accounts payable
   (26,771 ) (24,942 ) 19,866 10,445
Accrued taxes
   4,689 (7,055 ) 38,084 (11,033 )
Other current assets and liabilities
   43,044 12,022 3,590 22,034
Gains on sale
   (1,452 ) (4,117 ) (4,483 ) (4,200 )
Changes in undistributed stock compensation
   9,199 4,347 10,308 5,142
AFUDC
   (2,077 ) (1,893 ) (2,473 ) (2,890 )
Changes in other assets and deferred charges
   (14,470 ) 3,926 (1,436 ) 4,183
Changes in other liabilities and deferred credits
   3,395 (4,813 ) (10,239 ) 702


Net cash provided by operating activities
   299,244 477,922 421,830 612,716


CASH FLOW FROM INVESTING ACTIVITIES:

Construction expenditures and property additions
   (449,998 ) (404,388 ) (575,141 ) (555,819 )
Acquisition of businesses, net of cash acquired
   —   (17,000 ) —   (17,000 )
Changes in customer advances
   (1,951 ) 5,445 504 9,445
Miscellaneous inflows
   9,160 7,965 14,234 4,726


Net cash used in investing activities
   (442,789 ) (407,978 ) (560,403 ) (558,648 )


CASH FLOW FROM FINANCING ACTIVITIES:

Issuance of common stock, net
   11,563 530 11,505 507
Dividends paid
   (68,503 ) (61,950 ) (89,870 ) (81,138 )
Centuri distribution to redeemable noncontrolling interest
   (204 ) (99 ) (544 ) (198 )
Issuance of long-term debt, net
   104,308 408,946 119,308 420,946
Retirement of long-term debt
   (100,240 ) (196,351 ) (159,162 ) (240,999 )
Change in credit facility and commercial paper
   145,000 (150,000 ) 150,000 (97,000 )
Change in short-term debt
   110,500 (18,000 ) 110,500 —
Principal payments on capital lease obligations
   (796 ) (1,125 ) (1,025 ) (1,449 )
Redemption of Centuri shares from noncontrolling parties
   (23,000 ) —   (23,000 ) —
Withholding remittance—share-based compensation
   (3,176 ) (2,119 ) (3,176 ) (2,164 )
Other
   (1,104 ) (605 ) (2,068 ) (60 )


Net cash provided by (used in) financing activities
   174,348 (20,773 ) 112,468 (1,555 )


Effects of currency translation on cash and cash equivalents
   283 (14 ) 103 (318 )


Change in cash and cash equivalents
   31,086 49,157 (26,002 ) 52,195
Cash and cash equivalents at beginning of period
   28,066 35,997 85,154 32,959


Cash and cash equivalents at end of period
   $ 59,152 $ 85,154 $ 59,152 $ 85,154


Supplemental information:

Interest paid, net of amounts capitalized
   $ 45,771 $ 47,134 $ 66,077 $ 68,445
Income taxes paid (received)
   3,687 6,530 (21,875 ) 9,899



	Nine Months Ended September 30,						Twelve Months Ended September 30,
	2019			2018			2019			2018
CASH FLOW FROM OPERATING ACTIVITIES:
Net income	$	124,741		$	112,176		$	194,217		$	208,572
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	223,251			185,941			286,522			247,803
Deferred income taxes	46,099			36,210			60,930			50,190
Changes in current assets and liabilities:
Accounts receivable, net of allowances	(19,615		)	(1,659		)	(33,818		)	(27,276		)
Accrued utility revenue	41,400			43,600			(1,200		)	(500		)
Deferred purchased gas costs	(36,608		)	100,763			(54,797		)	84,282
Accounts payable	(46,079		)	(48,618		)	14,317			(1,886		)
Accrued taxes	(2,841		)	(9,840		)	(4,956		)	(12,417		)
Other current assets and liabilities	74,048			1,245			18,730			(50,002		)
Gains on sale	(3,157		)	(997		)	(3,863		)	(3,741		)
Changes in undistributed stock compensation	6,067			4,686			7,492			6,375
Equity AFUDC	(3,179		)	(1,034		)	(5,772		)	(1,253		)
Changes in other assets and deferred charges	(15,855		)	(10,497		)	(11,096		)	(18,296		)
Changes in other liabilities and deferred credits	(9,786		)	(4,583		)	33,243			(3,747		)
Net cash provided by operating activities	378,486			407,393			499,949			478,104
CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions	(719,386		)	(560,165		)	(925,135		)	(733,816		)
Acquisition of businesses, net of cash acquired	(19,533		)	(4,209		)	(266,697		)	(98,413		)
Changes in customer advances	15,049			11,051			17,461			13,325
Miscellaneous inflows	12,862			3,827			13,376			11,312
Net cash used in investing activities	(711,008		)	(549,496		)	(1,160,995		)	(807,592		)
CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net	129,341			92,234			391,509			121,826
Dividends paid	(86,345		)	(74,535		)	(112,050		)	(98,162		)
Issuance of long-term debt, net	482,614			480,993			566,793			783,748
Retirement of long-term debt	(127,175		)	(143,757		)	(221,176		)	(382,486		)
Change in short-term debt	(122,000		)	(183,000		)	(1,500		)	(79,000		)
Principal payments on finance lease obligations	(161		)	(422		)	(387		)	(606		)
Withholding remittance - share-based compensation	(1,858		)	(2,880		)	(2,088		)	(2,880		)
Other	1,167			(1,121		)	(456		)	(3,091		)
Net cash provided by financing activities	275,583			167,512			620,645			339,349
Effects of currency translation on cash and cash equivalents	58			139			(289		)	157
Change in cash and cash equivalents	(56,881		)	25,548			(40,690		)	10,018
Cash and cash equivalents at beginning of period	85,361			43,622			69,170			59,152
Cash and cash equivalents at end of period	$	28,480		$	69,170		$	28,480		$	69,170
Supplemental information:
Interest paid, net of amounts capitalized	$	62,165		$	49,568		$	99,159		$	75,740
Income taxes paid (received)	$	371		$	18,261		$	(16,669	)	$	20,247

The accompanying notes are an integral part of these statements.



	6



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

SOUTHWEST GAS ~~CORPORATION~~HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED ~~BALANCE SHEETS~~

STATEMENTS OF EQUITY

(~~Thousands of dollars)~~

In thousands, except per share amounts)

(Unaudited)

   SEPTEMBER 30, DECEMBER 31,
   2017 2016
ASSETS

Utility plant:

Gas plant
   $ 6,440,547 $ 6,193,564
Less: accumulated depreciation
   (2,218,796 ) (2,172,966 )
Acquisition adjustments, net
   81 196
Construction work in progress
   164,030 111,177


Net utility plant
   4,385,862 4,131,971


Other property and investments
   115,841 108,569


Current assets:

Cash and cash equivalents
   46,467 19,024
Accounts receivable, net of allowances
   68,028 111,845
Accrued utility revenue
   34,100 76,200
Income taxes receivable, net
   6,440 4,455
Deferred purchased gas costs
   6,230 2,608
Prepaids and other current assets
   118,587 126,363


Total current assets
   279,852 340,495


Noncurrent assets:

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


Total noncurrent assets
   404,037 1,000,091


Total assets
   $ 5,185,592 $ 5,581,126


CAPITALIZATION AND LIABILITIES
Capitalization:

Common stock
   $ 49,112 $ 49,112
Additionalpaid-in capital
   917,581 897,346
Accumulated other comprehensive income (loss), net
   (42,299 ) (45,639 )
Retained earnings
   606,007 767,061


Total Southwest Gas Corporation equity
   1,530,401 1,667,880
Discontinued operations—construction servicesnon-owner equity
   —   15,983
Long-term debt, less current maturities
   1,520,790 1,375,080


Total capitalization
   3,051,191 3,058,943


Current liabilities:

Current maturities of long-term debt
   —   25,000
Short-term debt
   83,000 —
Accounts payable
   92,257 138,229
Customer deposits
   70,162 72,296
Accrued general taxes
   48,998 42,921
Accrued interest
   24,406 17,395
Deferred purchased gas costs
   14,971 90,476
Payable to parent
   2,560 —
Other current liabilities
   109,705 95,999


Total current liabilities
   446,059 482,316


Deferred income taxes and other credits:

Deferred income taxes and investment tax credits, net
   853,682 806,109
Accumulated removal costs
   312,000 308,000
Other deferred credits and other long-term liabilities
   522,660 545,143
Discontinued operations—construction services—liabilities
   —   380,615


Total deferred income taxes and other credits
   1,688,342 2,039,867


Total capitalization and liabilities
   $ 5,185,592 $ 5,581,126



			Three Months Ended September 30,						Nine Months Ended September 30,
			2019			2018			2019			2018
Common stock shares
	Beginning balances		54,321			49,126			53,026			48,090
		Common stock issuances	303			297			1,598			1,333
	Ending balances		54,624			49,423			54,624			49,423
Common stock amount
	Beginning balances		$	55,951		$	50,756		$	54,656		$	49,720
		Common stock issuances	303			297			1,598			1,333
	Ending balances		56,254			51,053			56,254			51,053
Additional paid-in capital
	Beginning balances		1,409,923			1,021,508			1,305,769			955,332
		Common stock issuances	27,810			24,332			132,416			93,218
		Change in ownership of noncontrolling interest	—			—			(452		)	(2,710		)
	Ending balances		1,437,733			1,045,840			1,437,733			1,045,840
Accumulated other comprehensive income (loss)
	Beginning balances		(48,581		)	(55,520		)	(52,668		)	(47,682		)
		Foreign currency exchange translation adjustment	(447		)	599			1,131			(1,002		)
		Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax	618			895			1,856			2,687
		FSIRS amounts reclassified to net income, net of tax	635			636			1,906			1,907
		Reclassification of excess deferred taxes	—			—			—			(9,300		)
	Ending balances		(47,775		)	(53,390		)	(47,775		)	(53,390		)
Retained earnings
	Beginning balances		1,002,070			916,275			944,285			857,398
		Net income	5,353			12,331			122,218			112,973
		Dividends declared	(29,925		)	(25,876		)	(89,005		)	(76,941		)
		Reclassification of excess deferred taxes	—			—			—			9,300
	Ending balances		977,498			902,730			977,498			902,730
Total Southwest Gas Holdings, Inc. equity ending balances			2,423,710			1,946,233			2,423,710			1,946,233
Noncontrolling interest
	Beginning balances		—			(452		)	(452		)	(2,365		)
		Net income (loss)	—			—			—			(797		)
		Change in ownership of noncontrolling interest	—			—			452			2,710
	Ending balances		—			(452		)	—			(452		)
Total equity ending balances			$	2,423,710		$	1,945,781		$	2,423,710		$	1,945,781
Dividends declared per common share			$	0.545		$	0.52		$	1.635		$	1.56

The accompanying notes are an integral part of these statements.



	7



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED ~~STATEMENTS OF INCOME~~

BALANCE SHEETS

(~~In thousands)~~

Thousands of dollars)

(Unaudited)

   THREE MONTHS ENDED NINE MONTHS ENDED TWELVE MONTHS ENDED
   SEPTEMBER 30, SEPTEMBER 30, SEPTEMBER 30,
   2017 2016 2017 2016 2017 2016
Continuing operations:

Gas operating revenues
   $ 213,059 $ 200,179 $ 935,823 $ 980,927 $ 1,276,308 $ 1,376,388


Operating expenses:

Net cost of gas sold
   45,539 39,056 261,839 324,072 334,888 460,836
Operations and maintenance
   102,215 102,438 313,395 301,979 413,140 400,222
Depreciation and amortization
   46,194 56,436 153,643 174,413 212,693 228,609
Taxes other than income taxes
   14,046 12,480 43,325 39,480 56,221 51,810


Total operating expenses
   207,994 210,410 772,202 839,944 1,016,942 1,141,477


Operating income (loss)
   5,065 (10,231 ) 163,621 140,983 259,366 234,911


Other income and (expenses):

Net interest deductions
   (17,421 ) (16,364 ) (51,622 ) (49,155 ) (69,464 ) (65,146 )
Other income (deductions)
   3,081 2,521 8,744 6,712 10,308 9,615


Total other income and (expenses)
   (14,340 ) (13,843 ) (42,878 ) (42,443 ) (59,156 ) (55,531 )


Income (loss) from continuing operations before income taxes
   (9,275 ) (24,074 ) 120,743 98,540 200,210 179,380
Income tax expense (benefit)
   (5,251 ) (11,669 ) 38,307 31,004 65,887 59,544


Income (loss) from continuing operations
   (4,024 ) (12,405 ) 82,436 67,536 134,323 119,836


Discontinued operations—construction services:

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


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


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


Net income (loss)
   $ (4,024 ) $ 2,472 $ 82,436 $ 86,861 $ 147,616 $ 152,980



	September 30, 2019			December 31, 2018
ASSETS
Utility plant:
Gas plant	$	7,550,855		$	7,134,239
Less: accumulated depreciation	(2,303,864		)	(2,234,029		)
Construction work in progress	288,573			193,028
Net utility plant	5,535,564			5,093,238
Other property and investments	127,774			116,146
Current assets:
Cash and cash equivalents	16,811			31,962
Accounts receivable, net of allowances	73,530			140,057
Accrued utility revenue	35,800			77,200
Income taxes receivable	26,663			13,444
Deferred purchased gas costs	49,804			4,928
Prepaid and other current assets	171,402			229,562
Total current assets	374,010			497,153
Noncurrent assets:
Goodwill	10,095			10,095
Deferred charges and other assets	410,512			424,952
Total noncurrent assets	420,607			435,047
Total assets	$	6,457,955		$	6,141,584
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock	$	49,112		$	49,112
Additional paid-in capital	1,194,745			1,065,242
Accumulated other comprehensive income (loss), net	(45,287		)	(49,049		)
Retained earnings	731,036			717,155
Total equity	1,929,606			1,782,460
Long-term debt, less current maturities	2,115,870			1,818,669
Total capitalization	4,045,476			3,601,129
Current liabilities:
Short-term debt	30,000			152,000
Accounts payable	94,130			184,982
Customer deposits	68,897			67,940
Accrued general taxes	52,361			43,560
Accrued interest	34,623			20,243
Deferred purchased gas costs	88,030			79,762
Payable to parent	270			472
Other current liabilities	114,893			94,136
Total current liabilities	483,204			643,095
Deferred income taxes and other credits:
Deferred income taxes and investment tax credits, net	527,544			490,458
Accumulated removal costs	392,000			383,000
Other deferred credits and other long-term liabilities	1,009,731			1,023,902
Total deferred income taxes and other credits	1,929,275			1,897,360
Total capitalization and liabilities	$	6,457,955		$	6,141,584

The accompanying notes are an integral part of these statements.



	8



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

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
   SEPTEMBER 30, SEPTEMBER 30, SEPTEMBER 30,
   2017 2016 2017 2016 2017 2016
Continuing operations:

Net income (loss) from continuing operations
   $ (4,024 ) $ (12,405 ) $ 82,436 $ 67,536 $ 134,323 $ 119,836


Other comprehensive income (loss), net of tax

Defined benefit pension plans:

Net actuarial gain (loss)
   —   —   —   —   (14,118 ) (18,922 )
Amortization of prior service cost
   207 207 621 621 828 828
Amortization of net actuarial loss
   3,944 4,196 11,832 12,586 16,027 17,915
Regulatory adjustment
   (3,555 ) (3,796 ) (10,667 ) (11,388 ) (2,741 ) (404 )


Net defined benefit pension plans
   596 607 1,786 1,819 (4 ) (583 )


Forward-starting interest rate swaps:

Amounts reclassified into net income
   518 518 1,554 1,556 2,073 2,073


Net forward-starting interest rate swaps
   518 518 1,554 1,556 2,073 2,073


Total other comprehensive income, net of tax from continuing operations
   1,114 1,125 3,340 3,375 2,069 1,490


Comprehensive income (loss) from continuing operations
   (2,910 ) (11,280 ) 85,776 70,911 136,392 121,326


Discontinued operations—construction services:

Net income
   —   14,877 —   19,325 13,293 33,144
Foreign currency translation adjustments
   —   (238 ) —   614 (453 ) 233


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


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


Comprehensive income (loss)
   $ (2,910 ) $ 3,367 $ 85,776 $ 90,829 $ 149,248 $ 154,693



	Three Months Ended September 30,						Nine Months Ended September 30,						Twelve Months Ended September 30,
	2019			2018			2019			2018			2019			2018
Gas operating revenues	$	209,980		$	217,523		$	989,368		$	987,515		$	1,359,581		$	1,354,000
Operating expenses:
Net cost of gas sold	35,068			49,903			292,854			319,101			393,141			412,307
Operations and maintenance	109,039			104,657			319,572			312,055			412,330			404,549
Depreciation and amortization	52,372			47,924			159,327			145,549			205,594			193,828
Taxes other than income taxes	15,308			15,036			46,640			44,959			61,579			59,580
Total operating expenses	211,787			217,520			818,393			821,664			1,072,644			1,070,264
Operating income (loss)	(1,807		)	3			170,975			165,851			286,937			283,736
Other income and (expenses):
Net interest deductions	(23,619		)	(20,399		)	(70,063		)	(59,803		)	(92,000		)	(77,914		)
Other income (deductions)	(1,353		)	836			6,185			(5,861		)	(5,194		)	(6,425		)
Total other income and (expenses)	(24,972		)	(19,563		)	(63,878		)	(65,664		)	(97,194		)	(84,339		)
Income (loss) before income taxes	(26,779		)	(19,560		)	107,097			100,187			189,743			199,397
Income tax expense (benefit)	(6,767		)	(5,890		)	20,351			20,886			43,456			45,714
Net income (loss)	$	(20,012	)	$	(13,670	)	$	86,746		$	79,301		$	146,287		$	153,683

The accompanying notes are an integral part of these statements.



	9



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF ~~CASH FLOWS~~

COMPREHENSIVE INCOME

(Thousands of dollars)

(Unaudited)

   NINE MONTHS ENDED TWELVE MONTHS ENDED
   SEPTEMBER 30 SEPTEMBER 30
   2017 2016 2017 2016
CASH FLOW FROM OPERATING ACTIVITIES:

Net Income
   $ 82,436 $ 87,361 $ 148,130 $ 154,059
Income (loss) from discontinued operations
   —   19,825 13,807 34,223


Income from continuing operations
   82,436 67,536 134,323 119,836
Adjustments to reconcile net income to net cash provided by operating activities:

Depreciation and amortization
   153,643 174,413 212,693 228,609
Deferred income taxes
   44,621 39,953 72,627 76,837
Changes in current assets and liabilities:

Accounts receivable, net of allowances
   43,818 91,680 (7,131 ) 8,543
Accrued utility revenue
   42,100 41,700 (1,100 ) (800 )
Deferred purchased gas costs
   (79,127 ) 81,389 (114,658 ) 79,460
Accounts payable
   (45,972 ) (47,060 ) 17,271 1,467
Accrued taxes
   4,092 (5,660 ) 29,143 4,567
Other current assets and liabilities
   32,453 (819 ) (224 ) 9,135
Changes in undistributed stock compensation
   7,999 4,347 9,108 5,142
AFUDC
   (2,077 ) (1,893 ) (2,473 ) (2,890 )
Changes in other assets and deferred charges
   (14,861 ) 3,664 (1,914 ) 3,834
Changes in other liabilities and deferred credits
   2,883 (4,813 ) (10,751 ) 702


Net cash provided by operating activities
   272,008 444,437 336,914 534,442


CASH FLOW FROM INVESTING ACTIVITIES:

Construction expenditures and property additions
   (395,463 ) (337,921 ) (514,661 ) (485,665 )
Changes in customer advances
   (1,951 ) 5,445 504 9,445
Miscellaneous inflows
   2,407 2,464 2,925 3,506
Dividends received
   —   2,801 9,660 5,602


Net cash used in investing activities
   (395,007 ) (327,211 ) (501,572 ) (467,112 )


CASH FLOW FROM FINANCING ACTIVITIES:

Issuance of common stock, net
   —   530 (58 ) 507
Contributions from parent
   11,659 —   11,659 —
Dividends paid
   (60,497 ) (61,950 ) (81,864 ) (81,138 )
Issuance of long-term debt, net
   —   296,469 —   296,469
Retirement of long-term debt
   (25,000 ) (124,855 ) (25,000 ) (124,855 )
Change in credit facility and commercial paper
   145,000 (150,000 ) 150,000 (97,000 )
Change in short-term debt
   83,000 (18,000 ) 83,000 —
Withholding remittance—share-based compensation
   (3,176 ) (2,119 ) (3,176 ) (2,164 )
Other
   (544 ) (605 ) (1,508 ) (9 )


Net cash provided by (used in) financing activities
   150,442 (60,530 ) 133,053 (8,190 )


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


Change in cash and cash equivalents
   27,443 49,157 (29,645 ) 52,195
Change in cash and cash equivalents of discontinued operations included in discontinued operations construction services assets
   —   7,539 (1,960 ) 6,945


Change in cash and cash equivalents of continuing operations
   27,443 56,696 (31,605 ) 59,140
Cash and cash equivalents at beginning of period
   19,024 21,376 78,072 18,932


Cash and cash equivalents at end of period
   $ 46,467 $ 78,072 $ 46,467 $ 78,072


Supplemental information:

Interest paid, net of amounts capitalized
   $ 40,751 $ 42,804 $ 59,448 $ 63,031


Income taxes paid (received)
   $ 4 $ (3,055 ) $ (27,952 ) $ (16,600 )



	Three Months Ended September 30,						Nine Months Ended September 30,						Twelve Months Ended September 30,
	2019			2018			2019			2018			2019			2018
Net income (loss)	$	(20,012	)	$	(13,670	)	$	86,746		$	79,301		$	146,287		$	153,683
Other comprehensive income (loss), net of tax
Defined benefit pension plans:
Net actuarial gain (loss)	—			—			—			—			(15,524		)	(32,701		)
Amortization of prior service cost	241			254			724			762			977			969
Amortization of net actuarial loss	4,442			6,387			13,325			19,161			19,713			23,105
Regulatory adjustment	(4,065		)	(5,746		)	(12,193		)	(17,236		)	(1,214		)	6,021
Net defined benefit pension plans	618			895			1,856			2,687			3,952			(2,606		)
Forward-starting interest rate swaps (“FSIRS”):
Amounts reclassified into net income	635			636			1,906			1,907			2,540			2,426
Net forward-starting interest rate swaps	635			636			1,906			1,907			2,540			2,426
Total other comprehensive income (loss), net of tax	1,253			1,531			3,762			4,594			6,492			(180		)
Comprehensive income (loss)	$	(18,759	)	$	(12,139	)	$	90,508		$	83,895		$	152,779		$	153,503

The accompanying notes are an integral part of these statements.



	10



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of dollars)

(Unaudited)



	Nine Months Ended September 30,						Twelve Months Ended September 30,
	2019			2018			2019			2018
CASH FLOW FROM OPERATING ACTIVITIES:
Net Income	$	86,746		$	79,301		$	146,287		$	153,683
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	159,327			145,549			205,594			193,828
Deferred income taxes	35,899			33,239			45,659			55,787
Changes in current assets and liabilities:
Accounts receivable, net of allowances	66,527			49,654			(3,436		)	(2,066		)
Accrued utility revenue	41,400			43,600			(1,200		)	(500		)
Deferred purchased gas costs	(36,608		)	100,763			(54,797		)	84,282
Accounts payable	(77,311		)	(53,217		)	(686		)	(2,700		)
Accrued taxes	(4,419		)	(16,026		)	(7,125		)	(9,735		)
Other current assets and liabilities	87,869			(35,154		)	31,579			(81,333		)
Changes in undistributed stock compensation	4,710			4,269			5,796			5,558
Equity AFUDC	(3,179		)	(1,034		)	(5,772		)	(1,253		)
Changes in other assets and deferred charges	(21,098		)	(11,025		)	(17,122		)	(19,082		)
Changes in other liabilities and deferred credits	(10,357		)	7,550			19,762			8,208
Net cash provided by operating activities	329,506			347,469			364,539			384,677
CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions	(587,405		)	(486,037		)	(784,237		)	(651,022		)
Changes in customer advances	15,049			11,051			17,461			13,325
Miscellaneous inflows (outflows)	(51		)	1,316			(1,353		)	1,650
Net cash used in investing activities	(572,407		)	(473,670		)	(768,129		)	(636,047		)
CASH FLOW FROM FINANCING ACTIVITIES:
Contributions from parent	126,186			90,644			149,091			120,344
Dividends paid	(71,000		)	(65,000		)	(93,000		)	(86,000		)
Issuance of long-term debt, net	297,222			297,495			297,222			297,495
Change in short-term debt	(122,000		)	(182,000		)	21,000			(74,000		)
Withholding remittance - share-based compensation	(1,857		)	(2,880		)	(2,087		)	(2,880		)
Other	(801		)	(939		)	(890		)	(991		)
Net cash provided by financing activities	227,750			137,320			371,336			253,968

Change in cash and cash equivalents	(15,151		)	11,119			(32,254		)	2,598
Cash and cash equivalents at beginning of period	31,962			37,946			49,065			46,467
Cash and cash equivalents at end of period	$	16,811		$	49,065		$	16,811		$	49,065
Supplemental information:
Interest paid, net of amounts capitalized	$	51,720		$	42,986		$	82,539		$	67,025
Income taxes paid (received)	$	(22	)	$	11,286		$	(17,164	)	$	3,428

The accompanying notes are an integral part of these statements.



	11



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

(In thousands)

(Unaudited)



			Three Months Ended September 30,						Nine Months Ended September 30,
			2019			2018			2019			2018
Common stock shares
	Beginning and ending balances		47,482			47,482			47,482			47,482
Common stock amount
	Beginning and ending balances		$	49,112		$	49,112		$	49,112		$	49,112
Additional paid-in capital
	Beginning balances		1,169,549			1,006,065			1,065,242			948,767
		Share-based compensation	1,102			1,197			3,317			1,899
		Contributions from Southwest Gas Holdings, Inc.	24,094			34,048			126,186			90,644
	Ending balances		1,194,745			1,041,310			1,194,745			1,041,310
Accumulated other comprehensive income (loss)
	Beginning balances		(46,540		)	(53,310		)	(49,049		)	(47,073		)
		Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax	618			895			1,856			2,687
		FSIRS amounts reclassified to net income, net of tax	635			636			1,906			1,907
		Reclassification of excess deferred taxes	—			—			—			(9,300		)
	Ending balances		(45,287		)	(51,779		)	(45,287		)	(51,779		)
Retained earnings
	Beginning balances		776,101			717,126			717,155			659,193
		Net income (loss)	(20,012		)	(13,670		)	86,746			79,301
		Share-based compensation	(153		)	(172		)	(465		)	(510		)
		Dividends declared to Southwest Gas Holdings, Inc.	(24,900		)	(22,000		)	(72,400		)	(66,000		)
		Reclassification of excess deferred taxes	—			—			—			9,300
	Ending balances		731,036			681,284			731,036			681,284
Total Southwest Gas Corporation equity ending balances			$	1,929,606		$	1,719,927		$	1,929,606		$	1,719,927

The accompanying notes are an integral part of these statements.



	12



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Note 1 – ~~Nature~~Background, Organization, and Summary of ~~Operations and Basis of Presentation~~

Significant Accounting Policies

Nature of Operations. Southwest Gas Holdings, Inc. is a holding company, owning all of the shares of common stock of Southwest Gas Corporation (“Southwest” or the “natural gas operations” segment) and ~~prior to August 2017, 96.6%~~all of the shares of common stock of Centuri ~~Construction~~ Group, Inc. ~~During August 2017, Southwest Gas Holdings, Inc. acquired~~(“Centuri,” or the ~~remaining 3.4% equity interest in Centuri Construction Group, Inc. that was held by~~“utility infrastructure services” segment). At 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 dateannual meeting of ~~the reorganization, existing shareholders of Southwest Gas Corporation became~~ shareholders of Southwest Gas Holdings, Inc., held on a~~one-for-one~~ ~~basis, with~~May 2, 2019, shareholders voted to approve changing the ~~same number~~state of ~~shares and same ownership percentage as they held immediately prior to the reorganization. At the same time,~~incorporation for Southwest Gas ~~Corporation and Centuri Construction Group,~~Holdings, Inc. ~~(“Centuri” or the “construction services” segment) each~~from California to Delaware. The reincorporation became ~~subsidiaries of the publicly traded holding company; whereas, historically, Centuri had been a direct subsidiary of~~ effective September 20, 2019.

Southwest ~~Gas Corporation.~~

~~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~~utility infrastructure services enterprise dedicated to ~~meeting the growing demands~~delivering a diverse array of solutions to North ~~American utilities, energy~~America’s gas and ~~industrial markets.~~electric providers. Centuri derives revenue from installation, replacement, repair, and maintenance of energy distribution systems, and developing industrial construction solutions. Centuri operations are generally conducted under the business names of NPL Construction Co. (“NPL”), NPL Canada Ltd. (“NPL Canada”~~, formerly Link-Line Contractors Ltd.~~), ~~W.S. Nicholls Construction,~~New England Utility Constructors, Inc. (“~~W.S. Nicholls”~~Neuco”), and ~~Brigadier Pipelines Inc.~~Linetec Services, LLC (“~~Brigadier”~~Linetec”). ~~Typically, Centuri revenues~~Utility infrastructure services activity is seasonal in most of Centuri’s operating areas. Peak periods 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.~~

months in colder climate areas, such as the northeastern and midwestern United States (“U.S.”) and in Canada. In warmer climate areas, such as the southwestern and southeastern U.S., utility infrastructure services activity continues year round. In November 2017, Centuri acquired Neuco, thereby expanding its core services in the northeast region of the U.S. Additionally, in November 2018, Centuri expanded its operations in the southeast region of the U.S. through the acquisition of an 80% interest in Linetec. See Note 12 – Business Acquisitions for more information.

Basis of Presentation. The condensed consolidated financial statements ~~for~~of Southwest Gas Holdings, Inc. and subsidiaries (the “Company”) and Southwest included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). The year-end condensed balance sheet data was derived from audited financial statements. Certain information and footnote disclosures normally included in financial statements prepared in accordance with ~~United States~~U.S. generally accepted accounting principles (“U.S. GAAP”) have been condensed or omitted pursuant to such rules and regulations. As indicated above, in connection with the holding company reorganization, 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 this~~Form 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. Centuri operations continue to be part~~acquisitions of ~~continuing operations~~Neuco and ~~included in the consolidated financial statements of Southwest Gas Holdings, Inc.~~

Linetec.

The preparation of the condensed consolidated financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period.


~~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~~depiction 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~~2018 Annual Report to Shareholders, which is incorporated by reference into the ~~2016~~2018 Form 10-K.

~~Prepaids~~

Fair Value Measurements. Certain assets and ~~other current assets.~~ ~~Prepaids and other current assets includes gas pipe materials and operating supplies of $36 million~~liabilities are reported at ~~September 30, 2017 and $30 million at December 31, 2016 (carried at weighted average cost) and $24 million at September 30, 2017 and $953,000 at December 31, 2016 related~~fair value, which is defined as the price that would be received to ~~a regulatory~~sell an asset ~~associated with the Arizona decoupling mechanism (an alternative revenue program).~~

~~Other current liabilities~~~~. Other current liabilities of Southwest Gas Corporation include $21 million of dividends declared but not yet~~or paid to ~~Southwest Gas Holdings, Inc.~~transfer a liability in an orderly transaction between market participants at ~~September 30, 2017.~~

~~Cash~~the measurement date.

U.S. GAAP states that a fair value measurement should be based on the assumptions that market participants would use in pricing the asset or liability and ~~Cash Equivalents.~~ ~~For purposes of reporting consolidated cash flows, cash and cash equivalents include cash on hand and financial instruments with~~establishes 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~~The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and ~~cash equivalents at September 30, 2017~~the lowest priority to fair values derived from unobservable inputs (Level 3 measurements). Financial assets and ~~December 31, 2016 also includes money market fund investments~~liabilities are categorized in their entirety based on the lowest level of ~~approximately $19.8 million and $5.3 million, respectively, which fall within Level 2 (significant other observable inputs)~~input that is significant to the fair value measurement. The three levels of the fair value hierarchy ~~due~~are as follows:

Level 1 – quoted prices (unadjusted) in active markets for identical assets or liabilities that a company has the ability to access at the measurement date.

Level 2 – inputs other than quoted prices included within Level 1 that are observable for similar assets or liabilities, either directly or indirectly.

Level 3 – unobservable inputs for the asset or liability. Unobservable inputs are used to measure fair value to the ~~asset valuation methods used by money~~extent that observable inputs are not available, thereby allowing for situations in which there is little, if any, market ~~funds.~~

~~Significantnon-cash~~ investing and financing activities included the following: Upon contract expiration, customer advances of approximately $1.9 million and $3.6 million, during the first nine months of 2017 and 2016, 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~~asset or liability at 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.

measurement date.



	13



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

~~Amendments related to~~

The Company primarily used quoted market prices and other observable market pricing information in valuing cash and cash equivalents, derivatives, long-term debt outstanding, and assets of the ~~timing of when excess tax benefits are recognized, minimum statutory withholding requirements, forfeitures,~~qualified pension plan and ~~intrinsic value are~~postretirement benefit plans 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 each year for impairment (required annually by U.S. GAAP),~~ recorded and/or otherwise, if circumstances indicate 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 leveldisclosed at ~~which goodwill is assessed for impairment. No impairment was deemed to have occurred in the first nine months of 2017.~~

(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

~~Intercompany Transactions~~~~. Centuri recognizes revenues generated from contracts with Southwest (see~~~~Note 3—~~~~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

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.

fair value.

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 30, 2017~~

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

   Three Months Ended Nine Months Ended Twelve Months Ended
   September 30 September 30 September 30
   2017 2016 2017 2016 2017 2016
Southwest Gas Corporation—natural gas operations segment:

Change in COLI policies
   $ 2,100 $ 2,300 $ 6,800 $ 5,400 $ 8,800 $ 7,500
Interest income
   670 522 1,848 1,279 2,417 1,664
Equity AFUDC
   968 611 2,077 1,893 2,473 2,890
Miscellaneous income and (expense)
   (657 ) (912 ) (1,981 ) (1,860 ) (3,382 ) (2,439 )


Southwest Gas Corporation—total other income (deductions)
   3,081 2,521 8,744 6,712 10,308 9,615


Construction services segment:

Interest income
   1 —   2 1 2 414
Foreign transaction gain (loss)
   (442 ) (3 ) (640 ) (22 ) (640 ) 28
Miscellaneous income and (expense)
   231 47 676 65 1,825 804


Centuri—total other income (deductions)
   (210 ) 44 38 44 1,187 1,246


Corporate and administrative
   5 —   6 —   6 —


Consolidated Southwest Gas Holdings, Inc.—total other income (deductions)
   $ 2,876 $ 2,565 $ 8,788 $ 6,756 $ 11,501 $ 10,861



	September 30, 2019			December 31, 2018
Southwest Gas Corporation:
Net cash surrender value of COLI policies	$	126,142		$	114,405
Other property	1,632			1,741
Total Southwest Gas Corporation	127,774			116,146
Centuri property, equipment, and intangibles	968,013			792,191
Centuri accumulated depreciation/amortization	(345,113		)	(298,939		)
Other property	18,011			14,153
Total Southwest Gas Holdings, Inc.	$	768,685		$	623,551

Included in the table above isare the ~~change in~~net cash surrender values of company-owned life insurance (“COLI”) ~~policies (including net death benefits recognized).~~policies. These life insurance policies on members of management and other key employees are used by Southwest to indemnify itself against the loss of talent, expertise, and knowledge, as well as to provide indirect funding for certain nonqualified benefit plans.

Cash and Cash Equivalents. For purposes of reporting consolidated cash flows, cash and cash equivalents include cash on hand and financial instruments with original maturities of three months or less. Such investments are carried at cost, which approximates market value. Cash and cash equivalents for Southwest and the Company also include money market fund investments totaling approximately $1.5 million and $10.2 million, respectively, at September 30, 2019, and $18 million and $59.9 million, respectively, at December 31, 2018, which fall within Level 2 of the fair value hierarchy, due to the asset valuation methods used by money market funds.

Typical non-cash investing activities for Southwest include customer advances applied as contributions toward utility construction activity and capital expenditures that were not paid as of quarter end that are included in accounts payable. Amounts related to such activities were immaterial for the periods presented herein. Non-cash investing activities for the twelve months ended September 30, 2019 included $26.2 million of purchase consideration related to the Linetec acquisition by Centuri, in the form of liabilities incurred that remained unpaid as of September 30, 2019; such amounts are included in Other current liabilities on the Condensed Consolidated Balance Sheets of the Company. Also, see Recent Accounting Standards Updates and Note 4 – Leases for information related to right-of-use assets obtained in exchange for lease liabilities, which are non-cash investing and financing activities.

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



	September 30, 2019		December 31, 2018
Centuri accounts receivable for services provided to Southwest	$	16,757	$	18,830

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

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

Prepaid and Other Current Assets. Prepaid and other current assets includes gas pipe materials and operating supplies of $59 million at September 30, 2019 and $56 million at December 31, 2018 (carried at weighted average cost), in addition to $47 million at September 30, 2019 and $74 million at December 31, 2018 related to a regulatory asset associated with the Arizona decoupling mechanism (an alternative revenue program).



	14



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Goodwill. Goodwill is assessed as of October 1st each year for impairment, or more frequently, if circumstances indicate an impairment to the carrying value of goodwill may have occurred. Management of the Company and Southwest considered its reporting units and segments and determined that its segments and reporting units remain consistent between periods presented below, and that no change was necessary with regard to the level at which goodwill is assessed for impairment. NaN impairment was deemed to have occurred in the first nine months of 2019.



(Thousands of dollars)	Natural Gas Operations		Utility Infrastructure Services			Total Company
December 31, 2018	$	10,095	$	348,950		$	359,045
Measurement-period adjustments - Linetec acquisition (a)	—		(22,179		)	(22,179		)
Foreign currency translation adjustment	—		3,082			3,082
September 30, 2019	$	10,095	$	329,853		$	339,948

(a) See Note 12 – Business Acquisitions for details regarding Linetec measurement-period adjustments.

Other Current Liabilities. Other current liabilities for Southwest include $24.9 million and $23.5 million of dividends declared by Southwest Gas Corporation, but not yet paid to Southwest Gas Holdings, Inc. at September 30, 2019 and December 31, 2018, respectively. In addition, the balances in both periods include amounts payable under regulatory mechanisms in the next twelve months and miscellaneous other accrued liabilities. Amounts included in the Condensed Consolidated Balance Sheets of Southwest Gas Holdings, Inc. for both periods reflect unremitted consideration then outstanding associated with the business acquisition of Linetec.

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



	Three Months Ended						Nine Months Ended						Twelve Months Ended
	September 30,						September 30,						September 30,
	2019			2018			2019			2018			2019			2018
Southwest Gas Corporation - natural gas operations segment:
Change in COLI policies	$	200		$	4,700		$	11,200		$	6,000		$	2,000		$	9,500
Interest income	1,521			1,506			4,940			4,301			6,659			5,237
Equity AFUDC	1,212			448			3,179			1,034			5,772			1,253
Other components of net periodic benefit cost	(3,765		)	(5,265		)	(11,295		)	(15,794		)	(16,560		)	(20,650		)
Miscellaneous income and (expense)	(521		)	(553		)	(1,839		)	(1,402		)	(3,065		)	(1,765		)
Southwest Gas Corporation - total other income (deductions)	(1,353		)	836			6,185			(5,861		)	(5,194		)	(6,425		)
Utility infrastructure services segment:
Interest income	—			4			—			6			82			7
Foreign transaction gain (loss)	(6		)	(91		)	546			258			66			144
Miscellaneous income and (expense)	177			125			23			(595		)	514			(175		)
Centuri - total other income (deductions)	171			38			569			(331		)	662			(24		)
Corporate and administrative	24			15			73			41			84			48
Consolidated Southwest Gas Holdings, Inc. - total other income (deductions)	$	(1,158	)	$	889		$	6,827		$	(6,151	)	$	(4,448	)	$	(6,401	)

Included in the table above is the change in cash surrender values of COLI policies (including net death benefits recognized). 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.

~~Recently Issued Accounting Standards Updates.~~ ~~In May 2014, the FASB issued the update “Revenue from Contracts with Customers (Topic 606).” The update replaces much~~ Refer also to Note 2 – Components 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)~~Net Periodic Benefit Cost. 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)



	15



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

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.),~~

Recent Accounting Standards Updates.

Accounting pronouncements adopted 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.

2019:

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

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

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

~~Under~~ The Company and Southwest adopted Topic 842 in the ~~new guidance, lessor accounting is largely unchanged. Certain targeted improvements were made to align, where necessary, lessor accounting with~~first quarter of 2019 through an optional transition method, which was elected, permitting the lessee accounting model and Topic 606, Revenue from Contracts with Customers. Though companies have historically been required to make disclosures regarding leases and of associated contractual obligations, leases (with terms longer than a year) will no longer exist~~off-balance~~ sheet. Lessees (for capital 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 beginningapplication 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. 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 would still be required to evaluate any new easements entered into after the effective dateprovisions of the standard at the adoption date, rather than to ~~determine if~~earlier comparative periods. As a result, the ~~arrangements should~~Company and Southwest have not recast prior periods to reflect the adoption of this standard. See Note 4 – Leases.

Accounting pronouncements that will be accounted for as leases. Management is currently evaluating the new and proposed guidance in light of its customary leasing arrangements (and other arrangements in association with the new guidance) to determine the effect the new standard will have on its financial position, results of operations, cash flows, and business processes.

effective after 2019:

In June 2016, the FASB issued ~~the~~Accounting Standards Update (“ASU”) 2016-13 update “Financial ~~Instruments—~~Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” The update ~~amends guidance on reporting~~requires the measurement of all expected credit losses for financial assets held at ~~amortized cost basis~~the reporting date based on historical experience, current conditions, and ~~available for sale debt securities. For assets held at amortized cost basis, the update eliminates the “probable” threshold for initial recognition of~~reasonable and supportable forecasts. The inputs currently used to estimate credit losses ~~in current U.S. GAAP and, instead, requires an entity~~will still be used; however, they may be adapted to reflect ~~its current estimate~~the full amount 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, 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~~the Company’s and Southwest’s 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—~~ASU 2017-04 “Intangibles – Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” ~~The~~Under the update, ~~eliminates Step 2 from~~an entity will apply a one-step quantitative test as opposed to a two-step test as currently required, and record the amount of goodwill impairment ~~test. The annual, or interim, goodwill impairment test is performed by comparing~~as the ~~fair value~~excess of a reporting ~~unit with its carrying amount. An impairment charge should be recognized for the amount by which the~~unit's carrying amount ~~exceeds the reporting unit’s~~


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

over its fair ~~value; however, the loss recognized should~~value, not to exceed the total amount of goodwill allocated to ~~that~~the reporting unit. ~~In addition, income tax effects~~The new guidance does not amend the optional qualitative assessment. The amount of any goodwill impairment calculated under the update could vary from ~~anytax-deductible~~ ~~goodwill on~~ the calculation under existing guidance, largely due to the consideration to be given to unrecognized differences between the fair value and carrying ~~amount~~values of the other assets and liabilities in the reporting unit ~~should be considered when measuring~~under 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.new guidance. The amendments should be applied on a prospective basis. The update is effective for fiscal and interim periods beginning after December 15, 2019. Early adoption ishas been permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. Management ~~has determined that~~is evaluating the impacts this update ~~would~~might have ~~had no impact~~ on the Company’s and Southwest’s consolidated financial statements ~~for the periods presented if it had been effective during those periods.~~

and disclosures.

In ~~March 2017,~~August 2018, the FASB issued ASU 2018-15 “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract.” The update generally aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement (that is a service contract) with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. Once capitalized, the update ~~“Compensation –~~ requires the entity to expense the amount capitalized over the term of the hosting arrangement, including reasonably certain renewal periods. The update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption of the amendments in this update is permitted for interim and related annual fiscal periods after December 15, 2018. Management is evaluating the impacts this update might have on the Company’s and Southwest’s consolidated financial statements and disclosures.

In August 2018, the FASB issued ASU 2018-14 “Compensation—Retirement ~~Benefits (Topic 715)~~Benefits—Defined Benefit Plans—General (Subtopic 715-20): ~~Improving~~Disclosure Framework—Changes to the ~~Presentation~~Disclosure Requirements for Defined Benefit Plans.” This update removes disclosures that are no longer considered cost-beneficial, clarifies the specific requirements of ~~Net Periodic Pension Cost~~disclosures, and ~~Net Periodic Postretirement Benefit Cost.”~~adds disclosure requirements identified as relevant. The update applies to all employers that ~~offer employee benefits under~~sponsor defined benefit pension ~~plans,~~or other postretirement ~~benefit plans, or other types of benefits accounted for under Topic 715, Compensation – Retirement Benefits.~~plans. The update ~~requires that an employer report~~is effective for fiscal years ending after December 15, 2020. Upon adoption, the ~~service cost component in~~Company and Southwest will modify their disclosures to conform to the ~~same line item or items as other compensation costs arising from services rendered by~~requirements of the ~~employees during~~update.

In August 2018, the ~~period. The other components of net benefit cost are required~~FASB issued ASU 2018-13 “Fair Value Measurement: Disclosure Framework—Changes 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.~~Disclosure Requirements for Fair Value Measurement.” The update ~~also allows only~~modifies the ~~service cost component (and not~~disclosure requirements on fair value measurements in Topic 820. The update is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. Upon adoption, the ~~other components of periodic benefit costs)~~Company and Southwest will modify their disclosures to ~~be eligible for capitalization when applicable, making no exception for specialized industries, includingrate-regulated~~ ~~industries.~~

~~Southwest is a rate-regulated utility offering pension and postretirement benefits~~conform to ~~retired employees. It is anticipated that Southwest would continue to request recovery~~the requirements 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.~~

applicable.



	16



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

Note 2 – Components of Net Periodic Benefit Cost

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

~~Net~~

The service cost component of net periodic benefit costs included in the table below are components of an overhead loading process associated with the cost of labor. The overhead process ultimately results in allocation of that portion of overall net periodic benefit costs to the same accounts to which productive labor is charged. As a result, ~~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.

   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

The other components of net periodic benefit cost are reflected in Other income (deductions) on the Condensed Consolidated Statements of Income of each entity.



	Qualified Retirement Plan
	Period Ended September 30,
	Three Months						Nine Months						Twelve Months
	2019			2018			2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	6,466		$	7,139		$	19,398		$	21,417		$	26,536		$	27,265
Interest cost	12,252			11,043			36,755			33,130			47,799			44,652
Expected return on plan assets	(15,061		)	(14,689		)	(45,183		)	(44,066		)	(59,872		)	(57,865		)
Amortization of net actuarial loss	5,589			8,029			16,767			24,086			24,796			30,087
Net periodic benefit cost	$	9,246		$	11,522		$	27,737		$	34,567		$	39,259		$	44,139

	SERP
	Period Ended September 30,
	Three Months						Nine Months						Twelve Months
	2019			2018			2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	66		$	61		$	199		$	183		$	261		$	260
Interest cost	440			415			1,320			1,244			1,734			1,714
Amortization of net actuarial loss	255			375			765			1,126			1,141			1,486
Net periodic benefit cost	$	761		$	851		$	2,284		$	2,553		$	3,136		$	3,460

	PBOP
	Period Ended September 30,
	Three Months						Nine Months						Twelve Months
	2019			2018			2019			2018			2019			2018
(Thousands of dollars)
Service cost	$	319		$	368		$	957		$	1,105		$	1,325		$	1,472
Interest cost	761			687			2,285			2,061			2,972			2,869
Expected return on plan assets	(789		)	(929		)	(2,367		)	(2,789		)	(3,296		)	(3,629		)
Amortization of prior service costs	318			334			953			1,002			1,286			1,336
Net periodic benefit cost	$	609		$	460		$	1,828		$	1,379		$	2,287		$	2,048



	17



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

Note 3 – ~~Segment Information~~

Revenue

The ~~Company has two reportable segments:~~following information about the Company’s revenues is presented by segment. Southwest encompasses 1 segment – 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 inoperations.

Natural Gas Operations Segment:

Gas operating revenues on the Condensed Consolidated Statements of Income ~~an Other column~~of both the Company and Southwest include revenue from contracts with customers, which is ~~included associated with~~shown below, disaggregated by customer type, and various categories of revenue:



	Three Months Ended				Nine Months Ended					Twelve Months Ended
	September 30,				September 30,					September 30,
(Thousands of dollars)	2019		2018		2019			2018		2019			2018
Residential	$	124,169	$	120,249	$	706,270		$	631,562	$	961,928		$	864,128
Small commercial	39,725		40,020		179,519			183,616		250,986			253,330
Large commercial	10,945		11,360		36,030			39,934		49,288			54,462
Industrial/other	3,837		5,390		15,728			17,391		21,826			23,899
Transportation	21,580		19,818		68,297			64,591		90,696			88,115
Revenue from contracts with customers	200,256		196,837		1,005,844			937,094		1,374,724			1,283,934
Alternative revenue program revenues (deferrals)	7,957		9,094		(23,196		)	46,696		(23,913		)	67,017
Other revenues (a)	1,767		11,592		6,720			3,725		8,770			3,049
Total Gas operating revenues	$	209,980	$	217,523	$	989,368		$	987,515	$	1,359,581		$	1,354,000

(a) Comprised of various other revenue impacts, including $(0.8) million during the three months, and $(3.7) million for the nine and twelve months ending September 30, 2019, respectively; and, $(1) million during the three months, and $(13.5) million in both the nine and twelve months ending September 30, 2018 related to ~~corporate and administrative activities related to Southwest Gas Holdings, Inc.~~ tax reform savings reserves/adjustments.

Utility Infrastructure Services Segment:

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



(Thousands of dollars)	Three Months Ended				Nine Months Ended				Twelve Months Ended
	September 30,				September 30,				September 30,
	2019		2018		2019		2018		2019		2018
Service Types:
Gas infrastructure services	$	364,241	$	355,721	$	885,950	$	849,615	$	1,160,017	$	1,145,629
Electric power infrastructure services	70,610		4,666		184,277		14,062		202,844		19,304
Other	80,399		90,236		212,185		242,167		335,992		314,859
Total Utility infrastructure services revenues	$	515,250	$	450,623	$	1,282,412	$	1,105,844	$	1,698,853	$	1,479,792



(Thousands of dollars)	Three Months Ended				Nine Months Ended				Twelve Months Ended
	September 30,				September 30,				September 30,
	2019		2018		2019		2018		2019		2018
Contract Types:
Master services agreement	$	410,283	$	348,274	$	1,021,798	$	832,813	$	1,291,397	$	1,101,216
Bid contract	104,967		102,349		260,614		273,031		407,456		378,576
Total Utility infrastructure services revenues	$	515,250	$	450,623	$	1,282,412	$	1,105,844	$	1,698,853	$	1,479,792

Unit price contracts	$	415,404	$	368,918	$	1,006,577	$	948,593	$	1,316,404	$	1,286,059
Fixed price contracts	37,539		45,461		80,503		44,911		152,890		31,487
Time and materials contracts	62,307		36,244		195,332		112,340		229,559		162,246
Total Utility infrastructure services revenues	$	515,250	$	450,623	$	1,282,412	$	1,105,844	$	1,698,853	$	1,479,792



	18



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

The following table provides information about contracts receivable and revenue earned on contracts in progress in excess of billings (contract asset), which are both included within Accounts receivable, net ~~income~~of allowances, as well as amounts billed in excess of revenue earned on contracts (contract liability), which are included in Other current liabilities as of September 30, 2019 and December 31, 2018 on the Company’s Condensed Consolidated Balance Sheets:



(Thousands of dollars)	September 30, 2019		December 31, 2018
Contracts receivable, net	$	238,678	$	186,249
Revenue earned on contracts in progress in excess of billings	121,854		87,520
Amounts billed in excess of revenue earned on contracts	6,136		4,211

The revenue earned on contracts in progress in excess of billings (contract asset) primarily relates to Centuri’s rights to consideration for work completed but not billed and/or approved at the reporting date. These contract assets are transferred to contracts receivable when the rights become unconditional. The amounts billed in excess of revenue earned (contract liability) primarily relates to the advance consideration received from customers for which work has not yet been completed. The change in this contract liability balance from December 31, 2018 to September 30, 2019 is due to revenue recognized of $4.2 million that was included in this item as of January 1, 2019, after which time it became earned and the balance was reduced, and to increases due to cash received, net of revenue recognized during the period related to contracts that commenced during the period.

For contracts that have an original duration of one year or less, Centuri uses the practical expedient applicable to such contracts and does not consider/compute an interest component based on the time value of money. Further, because of the short duration of these contracts, Centuri has not disclosed the transaction price for the remaining performance obligations as of the end of each reporting period or when the Company expects to recognize the revenue.

As of September 30, 2019, Centuri has 53 contracts with an original duration of more than one year. The aggregate amount of the transaction price allocated to the unsatisfied performance obligations of these contracts as of September 30, 2019 was $103.3 million. Centuri expects to recognize the remaining performance obligations over approximately the next two ~~reportable segments~~years; however, the timing of that recognition is largely within the control of the customer, including when the necessary equipment and materials required to complete the work are provided by the customer.

Utility infrastructure services contracts receivable consists of the following:



(Thousands of dollars)	September 30, 2019			December 31, 2018
Billed on completed contracts and contracts in progress	$	238,117		$	184,100
Other receivables	1,156			2,588
Contracts receivable, gross	239,273			186,688
Allowance for doubtful accounts	(595		)	(439		)
Contracts receivable, net	$	238,678		$	186,249



	19



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Note 4 – Leases

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

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

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

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

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

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

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

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

Southwest’s leases are comprised primarily of operating leases of buildings, land, and equipment. Southwest has no finance leases and no significant short-term leases. Southwest’s leases have a remaining term of 1 to 10 years, some of which include options to extend the lease up to 3 years. Southwest is currently not a lessor in any significant lease arrangements. Southwest’s ROU assets are included in Gas plant, and its lease liabilities are included in, depending upon maturity, Other current liabilities or Other deferred credits and other long-term liabilities on the Company’s and Southwest’s Condensed Consolidated Balance Sheets as of September 30, 2019.

Centuri has operating and finance leases for corporate and field offices, construction equipment, and transportation vehicles. Centuri is currently not a lessor in any significant lease arrangements. Centuri’s leases have remaining lease terms of up to 19 years. Some of these include options to extend the leases, generally for optional terms of up to 5 years, and some include options to terminate the leases within 1 year. Centuri’s equipment leases may include variable payment terms in addition to the fixed lease payments if machinery is used in excess of the standard work periods. These variable payments are not probable of occurring under the current operating environment and have not been included in consideration of lease payments. Short-term leases of Centuri are not accounted for under the provisions of Topic 842, as permitted. Due to the seasonality of Centuri’s business, expense for short-term leases will fluctuate throughout the year with higher expense incurred during the warmer months. As of September 30, 2019 Centuri executed lease agreements that had not yet commenced. These lease agreements primarily relate to real estate leases that have terms ranging from December 2019 through August 2032. Total future lease payments over the lease terms are approximately $13.2 million. Centuri’s ROU assets are included in Other property and investments, and its lease liabilities for operating and finance leases are included, depending upon maturity, in Other current liabilities or Other deferred credits and other long-term liabilities on the Company’s Condensed Consolidated Balance Sheet as of September 30, 2019.



	20



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

The components of lease expense were as follows:



(Thousands of dollars)	Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019
Southwest:
Operating lease cost	$	350	$	1,165

Centuri:
Operating lease cost	$	3,026	$	9,069

Finance lease cost:
Amortization of ROU assets	$	34	$	103
Interest on lease liabilities	10		24
Total finance lease cost	44		127
Short-term lease cost	5,017		10,949
Total lease cost	$	8,437	$	21,310

Supplemental cash flow information related to leases for the nine months ended September 30, 2019 is as follows:



(Thousands of dollars)	Southwest		Centuri		Consolidated Total
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	976	$	8,104	$	9,080
Operating cash flows from finance leases	—		24		24
Financing cash flows from finance leases	—		161		161

ROU assets obtained in exchange for lease obligations:
Operating leases	$	1,143	$	21,653	$	22,796
Finance leases	—		386		386



	21



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

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



(Thousands of dollars)	September 30, 2019
Southwest:
Operating leases:
Net Utility Plant	$	2,008

Other current liabilities	$	826
Other deferred credits and other long-term liabilities	1,209
Total operating lease liabilities	$	2,035

Weighted average remaining lease term (in years)	3.77
Weighted average discount rate	3.35		%

Centuri:
Operating leases:
Other property and investments	$	71,377

Other current liabilities	8,183
Other deferred credits and other long-term liabilities	65,791
Total operating lease liabilities	$	73,974

Finance leases:
Other property and investments	$	788

Other current liabilities	256
Other deferred credits and other long-term liabilities	400
Total finance lease liabilities	$	656

Weighted average remaining lease term (in years)
Operating leases	9.43
Finance leases	1.79

Weighted average discount rate
Operating leases	4.08		%
Finance leases	5.95		%



	22



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

The following are schedules of maturities of lease liabilities as of September 30, 2019:



(Thousands of dollars)	Operating leases
Southwest:
2020	$	946
2021	548
2022	244
2023	79
2024	79
Thereafter	267
Total lease payments	2,163
Less imputed interest	128
Total	$	2,035



(Thousands of dollars)	Operating leases		Finance leases
Centuri:
2020	$	11,336	$	289
2021	10,416		174
2022	9,675		165
2023	8,192		95
2024	6,973		3
Thereafter	45,564		—
Total lease payments	92,156		726
Less imputed interest	18,182		70
Total	$	73,974	$	656

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

   Natural Gas
Operations    Construction
Services    Other    Total
Three months ended September 30, 2017

Revenues from external customers
   $ 213,059    $ 351,850    $ —      $ 564,909
Intersegment revenues
   —      28,244    —      28,244








Total
   $ 213,059    $ 380,094    $ —      $ 593,153








Segment net income (loss)
   $ (4,024 )    $ 14,335    $ (107 )    $ 10,204








Three months ended September 30, 2016

Revenues from external customers
   $ 200,179    $ 312,531    $ —      $ 512,710
Intersegment revenues
   —      27,259    —      27,259








Total
   $ 200,179    $ 339,790    $ —      $ 539,969








Segment net income (loss)
   $ (12,405 )    $ 14,877    $ —      $ 2,472








   Natural Gas
Operations    Construction
Services    Other    Total
Nine months ended September 30, 2017

Revenues from external customers
   $ 935,823    $ 800,073    $ —      $ 1,735,896
Intersegment revenues
   —      72,463    —      72,463








Total
   $ 935,823    $ 872,536    $ —      $ 1,808,359








Segment net income (loss)
   $ 82,436    $ 15,717    $ (777 )    $ 97,376








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

Revenues from external customers
   $ 1,276,308    $ 1,078,195    $ —      $ 2,354,503
Intersegment revenues
   —      95,381    —      95,381








Total
   $ 1,276,308    $ 1,173,576    $ —      $ 2,449,884








Segment net income (loss)
   $ 134,323    $ 29,010    $ (777 )    $ 162,556








Twelve months ended September 30, 2016

Revenues from external customers
   $ 1,376,388    $ 1,022,416    $ —      $ 2,398,804
Intersegment revenues
   —      105,566    —      105,566








Total
   $ 1,376,388    $ 1,127,982    $ —      $ 2,504,370








Segment net income
   $ 119,836    $ 33,144    $ —      $ 152,980



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

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



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

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



	23



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

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 ~~utilizes~~has utilized fixed-for-floating swap contracts (“Swaps”) to supplement its fixed-price contracts. The fixed-price contracts, firm commitments to purchase a fixed amount of gas in the future at a fixed price, qualify for the normal purchases and normal sales exception that is allowed for contracts that are probable of delivery in the normal course of business, and are exempt from fair value reporting.


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

The variable-price contracts qualify as derivative instruments; however, because the contract prices are the prevailing prices at the future transaction dates, the contracts have no ~~significant market~~determinable fair value. The ~~Swaps~~Swap contract prices are determined at the beginning of each month to reflect that month’s published first of month index price and are recorded at fair value.

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

Southwest historically utilized 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 outstanding Swaps highly correlate to forecasted purchases of natural gas, ~~during time frames ranging from~~with the longest maturity date of the Swaps being October ~~2017 through March 2019. Under such contracts,~~2020. Management does not currently anticipate entering into new Swaps in the near term. Regarding existing Swap arrangements, 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

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



	September 30, 2019	December 31, 2018
Contract notional amounts	16,071	13,387

The following table ~~sets forth~~shows the ~~gains~~amounts Southwest paid to and ~~(losses) recognized on the Swaps (derivatives)~~received from counterparties for ~~the three-, nine-, and twelve-month periods ended September 30, 2017 and 2016 and their location in the Condensed Consolidated Statements~~settlements of ~~Income for both the Company and Southwest:~~

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

~~(Thousands of dollars)~~

      Three Months Ended Nine Months Ended Twelve Months Ended
   Location of Gain or (Loss)    September 30 September 30 September 30
Instrument

Recognized in Income on Derivative
   2017 2016 2017 2016 2017 2016
Swaps
   Net cost of gas sold    $ (546 ) $ (2,072 ) $ (6,851 ) $ 2,253 $ (4,098 ) $ (656 )
Swaps
   Net cost of gas sold    546 * 2,072 * 6,851 * (2,253 )* 4,098 * 656 *


Total
      $ —   $ —   $ —   $ —   $ —   $ —

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

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

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

~~Fair values of derivatives not designated as hedging instruments:~~

September 30, 2017
Instrument

Balance Sheet Location
   Asset
Derivatives    Liability
Derivatives    Net
Total
Swaps
   Prepaids and other current assets    $ 56    $ (22 )    $ 34
Swaps
   Other current liabilities    27    (1,899 )    (1,872 )
Swaps
   Other deferred credits    1    (768 )    (767 )






Total
      $ 84    $ (2,689 )    $ (2,605 )






December 31, 2016
Instrument

Balance Sheet Location
   Asset
Derivatives    Liability
Derivatives    Net
Total
Swaps
   Deferred charges and other assets    $ 899    $ (54 )    $ 845
Swaps
   Prepaids and other current assets    3,551    (19 )    3,532






Total
      $ 4,450    $ (73 )    $ 4,377


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

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.

matured Swaps:



(Thousands of dollars)	Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019		Twelve Months Ended September 30, 2019
Paid to counterparties	$	2,191	$	8,338	$	10,322
Received from counterparties	$	10	$	1,057	$	1,657

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~~purchase gas adjustment (“PGA”) mechanism in determining ~~its~~the deferred PGA balances. Neither changes in fair value nor settled amounts of Swaps have a direct effect on earnings or other comprehensive ~~income.~~

~~The~~income, since following ~~table shows~~settlement, amounts are reflected in Net cost of gas sold at the ~~amounts~~same time they are included in Gas operating revenues through updates to the PGA component of rates.

Previously, Southwest ~~paid~~entered into forward-starting interest rate swaps (“FSIRS”), the settled positions for which are immaterial and continue to ~~and received~~be amortized from ~~counterparties for settlements of matured Swaps.~~

   Three Months Ended    Nine Months Ended    Twelve Months Ended
(Thousands of dollars)    September 30, 2017    September 30, 2017    September 30, 2017
Paid to counterparties
   $ 143    $ 1,555    $ 2,655






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

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 )
Swaps    Prepaids and other current assets    1,872
Swaps    Deferred charges and other assets    767
December 31, 2016
Instrument

Balance Sheet Location
   Net Total
Swaps    Other deferred credits    $ (845 )
Swaps    Other current liabilities    (3,532 )

~~Fair Value Measurements.~~Accumulated other comprehensive income (loss) into interest expense.



	24



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

The estimated fair ~~values~~value of Southwest’s Swaps were determined at September 30, ~~2017~~2019 and December 31, ~~2016~~2018 using ~~New York Mercantile Exchange (“NYMEX”)~~ futures settlement prices 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~~and 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~~of the ~~inputs used to measure fair value by~~Swaps and their ~~reliability,~~location in the ~~financial assets and liabilities that were accounted~~Condensed Consolidated Balance Sheets for ~~at fair value by~~ both the Company and ~~Southwest:~~


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

~~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~~Southwest (thousands of dollars). It also sets forth the location of regulatory assets or liabilities offsetting, dollar-for-dollar, the fair value of the Swaps (pursuant to Southwest’s rate-regulation):

Fair values of derivatives not designated as hedging instruments:



September 30, 2019
Swap Position
Instrument	Balance Sheet Location	Asset Derivatives		Liability Derivatives			Net Total			Offsetting Balance Sheet Location (Regulatory Asset/(Liability))
Swaps	Deferred charges and other assets	$	48	$	(27	)	$	21		Other deferred credits
Swaps	Other current liabilities	103		(9,837		)	(9,734		)	Prepaid and other current assets
Swaps	Other deferred credits	—		(335		)	(335		)	Deferred charges and other assets
Total		$	151	$	(10,199	)	$	(10,048	)

December 31, 2018
Swap Position
Instrument	Balance Sheet Location	Asset Derivatives		Liability Derivatives			Net Total			Offsetting Balance Sheet Location (Regulatory Asset/(Liability))
Swaps	Prepaid and other current assets	$	243	$	(99	)	$	144		Other current liabilities
Swaps	Other current liabilities	1,595		(3,347		)	(1,752		)	Prepaid and other current assets
Swaps	Other deferred credits	141		(251		)	(110		)	Deferred charges and other assets
Total		$	1,979	$	(3,697	)	$	(1,718	)

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 0 outstanding collateral associated with the Swaps ~~which were accounted for at fair value, fell within Level 1 (quoted prices~~during either period shown in ~~active markets for identical financial assets) or Level 3 (significant unobservable inputs)~~the above table.

Note 6 – Common Stock

Only shares 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. Refer to Note 10 – Pension and Other Post Retirement Benefits in the 2016 Annual Report to Shareholders on Form~~10-K.~~

~~Note 5 – Common Stock~~

~~In January 2017, the holding company reorganization was made effective and each outstanding share of Southwest Gas Corporation~~Company’s common stock ~~was converted into a share of common stock in Southwest Gas Holdings, Inc.,~~are publicly traded on a~~one-for-one~~ ~~basis. The~~the New York Stock Exchange, under the ticker symbol ~~of the~~“SWX.” Share-based compensation related to Southwest and Centuri is based on stock ~~“SWX,” remained unchanged, and Southwest Gas Corporation became a wholly owned subsidiary~~awards to be issued in shares of Southwest Gas Holdings, Inc.

On ~~March 29, 2017,~~May 8, 2019, the Company filed with the ~~Securities Exchange Commission (“SEC”)~~SEC an automatic shelf registration statement on FormS-3 (FileNo. ~~333-217018)~~333-231297), which became effective upon filing, for the offer and sale of up to ~~$150~~$300 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,~~May 8, 2019, between the Company and BNY Mellon Capital Markets, LLC (the “Equity Shelf Program”). ~~During~~The following table provides the ~~three months~~activity under the Equity Shelf Program for the quarter and ~~nine months ending~~life-to-date ended September 30, 2017, the Company sold, through the continuous equity offering program with BNY Mellon Capital Markets, LLC as agent, an aggregate of 147,077 shares of the Company’s common stock in the open market at a weighted average price of $80.07 per share, resulting in proceeds to the Company of $11,659,104, net of $117,769 in agent commissions. 2019:



	Three Months Ended			Life-To-Date Ended
	September 30,
��	2019			2019
Gross proceeds	$	24,337,600		$	99,337,371
Less: agent commissions	(243,375		)	(993,373		)
Net proceeds	$	24,094,225		$	98,343,998

Number of shares sold	273,594			1,146,955
Weighted average price per share	$	88.96		$	86.61



	25



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

As of September 30, ~~2017,~~2019, the Company had up to ~~$138,223,127~~$200,662,629 of common stock available for sale under the program. Net proceeds from the ~~sale~~sales of shares of common stock under the Equity Shelf Program are intended for general corporate purposes, including the acquisition of property for the construction, completion, extension or improvement of pipeline systems and facilities located in and around the communities served by Southwest. ~~Commensurate with these intentions,~~Net proceeds during the 3^rd ~~quarter of 2017~~nine months ended September 30, 2019 were contributed to, and reflected in the records of, Southwest (as a capital contribution from Southwest Gas Holdings, Inc.).

During the ~~parent holding company).~~

quarter ended March 31, 2019, the Company sold approximately 278,000 shares of common stock under a previously effective equity shelf program. Those issuances reflected the remaining shares available under that previous program.

During the nine months ended September 30, ~~2017,~~2019, the Company issued approximately ~~103,000~~76,000 shares of common stock through the Restricted Stock/Unit Plan and Management Incentive Plan.

Also during the nine months ended September 30, 2019, the Company issued 96,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan (“DRSPP”), raising approximately $8.1 million.

On September 20, 2019, coincident with the reincorporation into Delaware, the Company increased the number of authorized shares of common stock available for issuance from 60,000,000 to 120,000,000.

Note 67 – Long-Term Debt

~~Carrying amounts of long-term~~

Long-term debt ~~and related estimated fair values as of September 30, 2017 and December 31, 2016 are disclosed~~is recognized in the ~~following table.~~ Company’s and Southwest’s Condensed Consolidated Balance Sheets generally at the carrying value of the obligations outstanding. However, details surrounding the fair value and individual carrying values of instruments are discussed below or provided in the table that follows.

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~~values. The revolving credit facility ~~borrowings)~~ and ~~have interest rates that reset frequently. These~~IDRBs 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. Additionally, the revolving credit facility is generally repaid quickly and the IDRBs have interest rates that reset frequently.

The fair values of Southwest’s debentures (which include senior ~~notes,~~ and ~~fixed-rate IDRBs~~medium-term notes) 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).~~ 2.

The Centuri secured revolving credit and term loan facility and ~~Centuri~~Centuri’s other debt obligations (not actively traded) are categorized as Level ~~3, based on significant unobservable inputs to their fair values.~~3. Because Centuri’s debt is not publicly traded, fair values for the secured revolving credit and term loan facility and its other debt obligations were based on a conventional discounted cash flow methodology and ~~utilized~~utilizing current market pricing yield curves, across Centuri’s debt maturity spectrum, of other industrial bonds with an assumed credit rating comparable to the Company’s.

   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



	26



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

~~In March 2017,~~



	September 30, 2019					December 31, 2018
	Carrying Amount			Market Value		Carrying Amount			Market Value
(Thousands of dollars)
Southwest Gas Corporation:
Debentures:
Notes, 4.45%, due 2020	$	125,000		$	126,763	$	125,000		$	126,213
Notes, 6.1%, due 2041	125,000			167,619		125,000			150,728
Notes, 3.875%, due 2022	250,000			257,930		250,000			254,195
Notes, 4.875%, due 2043	250,000			303,955		250,000			268,985
Notes, 3.8%, due 2046	300,000			316,383		300,000			267,030
Notes, 3.7%, due 2028	300,000			323,034		300,000			298,926
Notes, 4.15%, due 2049	300,000			334,680		—			—
8% Series, due 2026	75,000			97,769		75,000			93,827
Medium-term notes, 7.78% series, due 2022	25,000			27,655		25,000			27,497
Medium-term notes, 7.92% series, due 2027	25,000			32,250		25,000			30,016
Medium-term notes, 6.76% series, due 2027	7,500			9,218		7,500			8,651
Unamortized discount and debt issuance costs	(14,852		)			(11,807		)
	1,767,648					1,470,693
Revolving credit facility and commercial paper	150,000			150,000		150,000			150,000
Industrial development revenue bonds:
Variable-rate bonds:
Tax-exempt Series A, due 2028	50,000			50,000		50,000			50,000
2003 Series A, due 2038	50,000			50,000		50,000			50,000
2008 Series A, due 2038	50,000			50,000		50,000			50,000
2009 Series A, due 2039	50,000			50,000		50,000			50,000
Unamortized discount and debt issuance costs	(1,778		)			(2,024		)
	198,222					197,976
Less: current maturities	—					—
Long-term debt, less current maturities - Southwest Gas Corporation	$	2,115,870				$	1,818,669
Centuri:
Centuri term loan facility	$	248,043		$	257,475	$	255,959		$	260,135
Unamortized debt issuance costs	(1,171		)			(1,414		)
	246,872					254,545
Centuri secured revolving credit facility	89,140			89,175		—			—
Centuri other debt obligations	48,399			49,393		67,104			67,053
Less: current maturities	(38,165		)			(33,060		)
Long-term debt, less current maturities - Centuri	$	346,246				$	288,589
Consolidated Southwest Gas Holdings, Inc.:
Southwest Gas Corporation long-term debt	$	2,115,870				$	1,818,669
Centuri long-term debt	384,411					321,649
Less: current maturities	(38,165		)			(33,060		)
Long-term debt, less current maturities - Southwest Gas Holdings, Inc.	$	2,462,116				$	2,107,258



	27



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

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 30, ~~2017,~~2019, the applicable margin is 1% for loans bearing interest with reference to LIBOR and 0% for loans bearing interest with reference to the alternative base rate. At September 30, ~~2017,~~2019, $150 million was outstanding on the long-term portion (including $50 million under the commercial paper program, discussed below) and ~~$83~~$30 million ~~was~~of borrowings were outstanding on the short-term portion of this credit facility ~~(See~~(see Note 78 – Short-Term Debt).

Southwest has a $50 million commercial paper program. Any issuance under the commercial paper program is supported by Southwest’s current revolving credit facility and, therefore, does not represent additional borrowing capacity under the credit facility. Borrowings under the commercial paper program are designated as long-term debt. Interest rates for the program are calculated at the then current commercial paper rate. At September 30, ~~2017,~~2019, as noted above, $50 million of borrowings were outstanding under the commercial paper program.

In May 2019, Southwest issued $300 million in 4.15% Senior Notes at a discount of 0.051%. The notes will mature in June 2049. The net proceeds were used to repay a portion of amounts then outstanding under its credit facility and commercial paper program.

In November 2018, Centuri, ~~has a $300 million~~in association with the acquisition of Linetec, amended and restated its senior secured revolving credit and term loan facility, ~~that~~increasing the capacity from $450 million to $590 million; the amended facility is scheduled to expire in ~~October 2019.~~November 2023. This facility includes a revolving credit facility and a term loan facility. The line of credit portion of the facility is $325 million; amounts borrowed and repaid under the revolving line of credit facility are available to be re-borrowed. The term loan facility portion ~~had an initial~~has a limit of approximately ~~$150 million, which was reached in 2014 and had $107 million outstanding (after repayments) at September 30, 2017.~~$265 million. The ~~$300~~$590 million revolving credit and term loan facility is secured by substantially all of Centuri’s assets except those explicitly excluded under the terms of the agreement (including owned real estate and certain certificated vehicles). ~~Centuri~~Centuri’s assets securing the facility at September 30, ~~2017~~2019 totaled ~~$526 million.~~$1.3 billion. At September 30, ~~2017, $189~~2019, $337 million in borrowings were outstanding under the Centuri facility.

It is currently anticipated that LIBOR may be discontinued as a benchmark or reference rate after 2021. As of September 30, 2019, 0 borrowings were outstanding for the holding company under its credit facility (see Note 78 – Short-Term Debt

~~In March 2017, Southwest Gas Holdings, Inc. entered into a~~), and therefore, there was no related indebtedness with reference to LIBOR. However, $130 million of Southwest’s outstanding borrowings under its credit facility ~~with a borrowing capacity~~(other than from its commercial paper program) and $218 million of ~~$100 million that expires in March 2022. The Company intends to utilize this~~Centuri’s outstanding borrowings under its credit facility ~~for short-term financing needs. Interest~~have 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%~~maturity dates that extend beyond 2021. Southwest’s outstanding LIBOR referenced debt of $130 million is approximately 6% of Southwest’s total debt, and Southwest’s and Centuri’s combined outstanding LIBOR referenced debt of $348 million is approximately 14% of total debt (including current maturities) for the Company overall. In order to ~~0.5% for loans bearing interest with reference to~~mitigate the ~~alternative base rate. The Company is also required to pay a commitment fee~~impact of the discontinuation on the ~~unfunded portion~~Company’s financial condition and results of operations, Southwest and Centuri will continue to monitor developments with respect to alternative rates and work with lenders to determine the ~~commitments based on its senior unsecured long-term debt rating. The commitment fee ranges from 0.075%~~appropriate alternative reference rate for variable rate indebtedness.

Note 8 – Short-Term Debt

Southwest Gas Holdings, Inc. has a $100 million credit facility that is scheduled to ~~0.200% per annum. At September 30, 2017, $27.5 million was~~expire in March 2022. There were 0 borrowings outstanding under this ~~facility.~~

credit facility at September 30, 2019.

As discussed inNote 67 – Long-Term Debt,, Southwest has a $400 million credit facility that is scheduled to expire in March 2022, of which $250 million has been designated by management for working capital purposes. Southwest had ~~$83~~$30 million inof short-term borrowings outstanding at September 30, ~~2017~~2019 under this facility.



	28



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

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 months ended September 30, 2017.

Southwest Gas Holdings, Inc. Equity
Accumulated Redeemable
Additional Other Non- Noncontrolling
Common Stock Paid-in Comprehensive Retained controlling Interest
(In thousands, except per share amounts)
Shares Amount Capital Income (Loss) Earnings Interest Total (Temporary
Equity)
DECEMBER 31, 2016
47,482 $ 49,112 $ 903,123 $ (48,008 ) $ 759,263 $ (2,217 ) $ 1,661,273 $ 22,590
Common stock issuances
250 250 21,090 21,340
Net income (loss)
97,376 (78 ) 97,298 248
Redemption value adjustments
(355 ) (355 ) 355
Foreign currency exchange translation adj.
1,850 1,850 11
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
Amounts reclassified to net income, net of tax (FSIRS)
1,554 1,554
Centuri dividend to redeemable noncontrolling interest
(204 )
Dividends declared

Common: $1.485 per share
(71,350 ) (71,350 )

SEPTEMBER 30, 2017
47,732 $ 49,362 $ 924,213 $ (42,818 ) $ 784,934 $ (2,295 ) $ 1,713,396 $ —

The table below provides details of activity in equity for Southwest Gas Corporation during the nine months ended September 30, 2017. Effective in January 2017, Southwest became a subsidiary of Southwest Gas Holdings, Inc., and only equity shares of the latter 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

~~(a)~~

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


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

The following information provides insight into amounts impacting the Company’s Other ~~Comprehensive Income (Loss)~~comprehensive income (loss), both before and ~~after tax~~after-tax impacts, within the Condensed Consolidated Statements of Comprehensive Income, which also impact Accumulated ~~Other Comprehensive Income~~other comprehensive income (“AOCI”) in the Condensed Consolidated Balance Sheets and the ~~associated column in the equity table above, as well as the Redeemable Noncontrolling Interest.~~Condensed Consolidated Statements of Equity. See Note 45 – 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
September 30, 2017 Three 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:

Amortization of prior service cost
   $ 333 $ (126 ) $ 207 $ 333 $ (126 ) $ 207
Amortization of net actuarial (gain)/loss
   6,362 (2,418 ) 3,944 6,767 (2,571 ) 4,196
Regulatory adjustment
   (5,734 ) 2,179 (3,555 ) (6,122 ) 2,326 (3,796 )


Pension plans other comprehensive income (loss)
   961 (365 ) 596 978 (371 ) 607
FSIRS (designated hedging activities):

Amounts reclassifed into net income
   835 (317 ) 518 835 (317 ) 518


FSIRS other comprehensive income
   835 (317 ) 518 835 (317 ) 518


Total other comprehensive income (loss) - Southwest Gas Corporation
   1,796 (682 ) 1,114 1,813 (688 ) 1,125


Foreign currency translation adjustments:

Translation adjustments
   1,012 —   1,012 (238 ) —   (238 )


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


Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.
   $ 2,808 $ (682 ) $ 2,126 $ 1,575 $ (688 ) $ 887


   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



	Three Months Ended September 30, 2019									Three Months Ended September 30, 2018
	Before- Tax Amount			Tax (Expense) or Benefit (1)			Net-of- Tax Amount			Before- Tax Amount			Tax (Expense) or Benefit (1)			Net-of- Tax Amount
Defined benefit pension plans:
Amortization of prior service cost	$	318		$	(77	)	$	241		$	334		$	(80	)	$	254
Amortization of net actuarial (gain)/loss	5,844			(1,402		)	4,442			8,404			(2,017		)	6,387
Regulatory adjustment	(5,348		)	1,283			(4,065		)	(7,560		)	1,814			(5,746		)
Pension plans other comprehensive income	814			(196		)	618			1,178			(283		)	895
FSIRS (designated hedging activities):
Amounts reclassified into net income	836			(201		)	635			836			(200		)	636
FSIRS other comprehensive income	836			(201		)	635			836			(200		)	636
Total other comprehensive income - Southwest Gas Corporation	1,650			(397		)	1,253			2,014			(483		)	1,531
Foreign currency translation adjustments:
Translation adjustments	(447		)	—			(447		)	599			—			599
Foreign currency other comprehensive income (loss)	(447		)	—			(447		)	599			—			599
Total other comprehensive income - Southwest Gas Holdings, Inc.	$	1,203		$	(397	)	$	806		$	2,613		$	(483	)	$	2,130

	Nine Months Ended September 30, 2019									Nine Months Ended September 30, 2018
	Before- Tax Amount			Tax (Expense) or Benefit (1)			Net-of- Tax Amount			Before- Tax Amount			Tax (Expense) or Benefit (1)			Net-of- Tax Amount
Defined benefit pension plans:
Amortization of prior service cost	$	953		$	(229	)	$	724		$	1,002		$	(240	)	$	762
Amortization of net actuarial (gain)/loss	17,532			(4,207		)	13,325			25,212			(6,051		)	19,161
Regulatory adjustment	(16,043		)	3,850			(12,193		)	(22,679		)	5,443			(17,236		)
Pension plans other comprehensive income	2,442			(586		)	1,856			3,535			(848		)	2,687
FSIRS (designated hedging activities):
Amounts reclassified into net income	2,508			(602		)	1,906			2,509			(602		)	1,907
FSIRS other comprehensive income	2,508			(602		)	1,906			2,509			(602		)	1,907
Total other comprehensive income - Southwest Gas Corporation	4,950			(1,188		)	3,762			6,044			(1,450		)	4,594
Foreign currency translation adjustments:
Translation adjustments	1,131			—			1,131			(1,002		)	—			(1,002		)
Foreign currency other comprehensive income (loss)	1,131			—			1,131			(1,002		)	—			(1,002		)
Total other comprehensive income - Southwest Gas Holdings, Inc.	$	6,081		$	(1,188	)	$	4,893		$	5,042		$	(1,450	)	$	3,592



	29



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

   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



	Twelve Months Ended September 30, 2019									Twelve Months Ended September 30, 2018
	Before- Tax Amount			Tax (Expense) or Benefit (1)			Net-of- Tax Amount			Before- Tax Amount			Tax (Expense) or Benefit (1)			Net-of- Tax Amount
Defined benefit pension plans:
Net actuarial gain/(loss)	$	(20,426	)	$	4,902		$	(15,524	)	$	(43,027	)	$	10,326		$	(32,701	)
Amortization of prior service cost	1,286			(309		)	977			1,336			(367		)	969
Amortization of net actuarial (gain)/loss	25,937			(6,224		)	19,713			31,573			(8,468		)	23,105
Regulatory adjustment	(1,597		)	383			(1,214		)	6,865			(844		)	6,021
Pension plans other comprehensive income (loss)	5,200			(1,248		)	3,952			(3,253		)	647			(2,606		)
FSIRS (designated hedging activities):
Amounts reclassified into net income	3,344			(804		)	2,540			3,346			(920		)	2,426
FSIRS other comprehensive income	3,344			(804		)	2,540			3,346			(920		)	2,426
Total other comprehensive income (loss) - Southwest Gas Corporation	8,544			(2,052		)	6,492			93			(273		)	(180		)
Foreign currency translation adjustments:
Translation adjustments	(877		)	—			(877		)	(1,092		)	—			(1,092		)
Foreign currency other comprehensive income (loss)	(877		)	—			(877		)	(1,092		)	—			(1,092		)
Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	7,667		$	(2,052	)	$	5,615		$	(999	)	$	(273	)	$	(1,272	)

(1)

Tax amounts are calculated using a 24% rate following the December 22, 2017 enactment date of U.S. tax reform. For periods prior to the enactment date (and included in specific line items of the tables for the twelve months ended September 30, 2018), tax amounts were calculated using a 38% rate. The tax effect of before-tax amounts remaining in the balance of Accumulated other comprehensive income (loss) as of September 30, 2019 is computed using a 24% tax rate overall. With regard to foreign currency translation adjustments, the Company has elected to indefinitely reinvest the earnings of Centuri’s Canadian subsidiaries in Canada, thus preventing deferred taxes on such earnings. As a result of this assertion, and no repatriation of earnings anticipated, the Company is not recognizing ~~any~~a tax effect or presenting a tax expense or benefit for ~~the~~ currency translation ~~adjustment amount~~adjustments reported in Other ~~Comprehensive Income, as repatriation of earnings is not anticipated.~~

comprehensive income (loss).

Approximately ~~$2.1~~$2.5 million of realized losses (net of tax) related to the FSIRS, reported in Accumulated other comprehensive income ~~(“AOCI”)~~(loss) at September 30, ~~2017,~~2019, will be reclassified into interest expense within the next 12 months as the related interest payments on long-term debt occur.

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

~~AOCI—Rollforward~~

~~(Thousands~~Sheets (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 (4,5)			After-Tax (5)			Before-Tax			Tax (Expense) Benefit (4,5)			After-Tax (5)			Before-Tax			Tax (Expense) Benefit		After-Tax			AOCI
Beginning Balance AOCI December 31, 2018	$	(55,227	)	$	13,254		$	(41,973	)	$	(9,310	)	$	2,234		$	(7,076	)	$	(3,619	)	$	—	$	(3,619	)	$	(52,668	)
Translation adjustments	—			—			—			—			—			—			1,131			—		1,131			1,131
Other comprehensive income (loss) before reclassifications	—			—			—			—			—			—			1,131			—		1,131			1,131
FSIRS amounts reclassified from AOCI (1)	—			—			—			2,508			(602		)	1,906						—		—			1,906
Amortization of prior service cost (2)	953			(229		)	724			—			—			—			—			—		—			724
Amortization of net actuarial loss (2)	17,532			(4,207		)	13,325			—			—			—			—			—		—			13,325
Regulatory adjustment (3)	(16,043		)	3,850			(12,193		)	—			—			—			—			—		—			(12,193		)
Net current period other comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.	2,442			(586		)	1,856			2,508			(602		)	1,906			1,131			—		1,131			4,893
Ending Balance AOCI September 30, 2019	$	(52,785	)	$	12,668		$	(40,117	)	$	(6,802	)	$	1,632		$	(5,170	)	$	(2,488	)	$	—	$	(2,488	)	$	(47,775	)


(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).



	30



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019


(4)	Tax amounts are calculated using a ~~38%~~24% rate.


~~SOUTHWEST GAS HOLDINGS, INC.~~(5)		~~Form 10-Q~~
~~SOUTHWEST GAS CORPORATION~~		~~September 30, 2017~~The beginning balances depict amounts attributable to the individual components of AOCI (Defined Benefit Plans and FSIRS) following the adoption of ASU No. 2018-02, with no impact to the total balance of AOCI resulting from the depiction.

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

~~AOCI—Rollforward~~

~~(Thousands~~Sheets (thousands of dollars)

   Defined Benefit Plans FSIRS
   Before-Tax Tax
(Expense)
Benefit (8) After-Tax Before-Tax Tax
(Expense)
Benefit (8) After-Tax AOCI
Beginning Balance AOCI December 31, 2016
   $ (57,613 ) $ 21,893 $ (35,720 ) $ (15,999 ) $ 6,080 $ (9,919 ) $ (45,639 )


FSIRS amounts reclassified from AOCI (5)
   —   —   —   2,507 (953 ) 1,554 1,554
Amortization of prior service cost (6)
   1,001 (380 ) 621 —   —   —   621
Amortization of net actuarial loss (6)
   19,084 (7,252 ) 11,832 —   —   —   11,832
Regulatory adjustment (7)
   (17,204 ) 6,537 (10,667 ) —   —   —   (10,667 )


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


Ending Balance AOCI September 30, 2017
   $ (54,732 ) $ 20,798 $ (33,934 ) $ (13,492 ) $ 5,127 $ (8,365 ) $ (42,299 )



	Defined Benefit Plans									FSIRS
	Before-Tax			Tax (Expense) Benefit (9,10)			After-Tax (10)			Before-Tax			Tax (Expense) Benefit (9,10)			After-Tax (10)			AOCI
Beginning Balance AOCI December 31, 2018	$	(55,227	)	$	13,254		$	(41,973	)	$	(9,310	)	$	2,234		$	(7,076	)	$	(49,049	)
FSIRS amounts reclassified from AOCI (6)	—			—			—			2,508			(602		)	1,906			1,906
Amortization of prior service cost (7)	953			(229		)	724			—			—			—			724
Amortization of net actuarial loss (7)	17,532			(4,207		)	13,325			—			—			—			13,325
Regulatory adjustment (8)	(16,043		)	3,850			(12,193		)	—			—			—			(12,193		)
Net current period other comprehensive income attributable to Southwest Gas Corporation	2,442			(586		)	1,856			2,508			(602		)	1,906			3,762
Ending Balance AOCI September 30, 2019	$	(52,785	)	$	12,668		$	(40,117	)	$	(6,802	)	$	1,632		$	(5,170	)	$	(45,287	)

~~(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)	Tax amounts are calculated using a ~~38%~~24% rate.

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

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

~~Amounts Recognized in AOCI (Before Tax)~~

~~(Thousands~~cost (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.



	September 30, 2019			December 31, 2018
Net actuarial (loss) gain	$	(417,832	)	$	(435,364	)
Prior service cost	(2,080		)	(3,033		)
Less: amount recognized in regulatory assets	367,127			383,170
Recognized in AOCI	$	(52,785	)	$	(55,227	)



	31



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

Note 10 – Segment Information

The Company has 2 reportable segments: natural gas operations and utility infrastructure services. Southwest has a single reportable segment that is referred to herein as the natural gas operations segment of the Company. In order to reconcile to net income as disclosed in the Condensed Consolidated Statements of Income, an Other column is included associated with impacts of corporate and administrative activities related to Southwest Gas Holdings, Inc. The following tables present revenues from external customers, intersegment revenues, and segment net income for the 2 reportable segments (thousands of dollars):



	Natural Gas Operations			Utility Infrastructure Services		Other			Total
Three Months Ended September 30, 2019
Revenues from external customers	$	209,980		$	480,896	$	—		$	690,876
Intersegment revenues	—			34,354		—			34,354
Total	$	209,980		$	515,250	$	—		$	725,230
Segment net income (loss)	$	(20,012	)	$	25,838	$	(473	)	$	5,353

Three Months Ended September 30, 2018
Revenues from external customers	$	217,523		$	414,175	$	—		$	631,698
Intersegment revenues	—			36,448		—			36,448
Total	$	217,523		$	450,623	$	—		$	668,146
Segment net income (loss)	$	(13,670	)	$	26,798	$	(797	)	$	12,331

	Natural Gas Operations			Utility Infrastructure Services		Other			Total
Nine Months Ended September 30, 2019
Revenues from external customers	$	989,368		$	1,160,303	$	—		$	2,149,671
Intersegment revenues	—			122,109		—			122,109
Total	$	989,368		$	1,282,412	$	—		$	2,271,780
Segment net income (loss)	$	86,746		$	36,725	$	(1,253	)	$	122,218

Nine Months Ended September 30, 2018
Revenues from external customers	$	987,515		$	1,009,166	$	—		$	1,996,681
Intersegment revenues	—			96,678		—			96,678
Total	$	987,515		$	1,105,844	$	—		$	2,093,359
Segment net income (loss)	$	79,301		$	35,034	$	(1,362	)	$	112,973

	Natural Gas Operations			Utility Infrastructure Services		Other			Total
Twelve Months Ended September 30, 2019
Revenues from external customers	$	1,359,581		$	1,537,508	$	—		$	2,897,089
Intersegment revenues	—			161,345		—			161,345
Total	$	1,359,581		$	1,698,853	$	—		$	3,058,434
Segment net income (loss)	$	146,287		$	46,668	$	(1,433	)	$	191,522

Twelve Months Ended September 30, 2018
Revenues from external customers	$	1,354,000		$	1,358,418	$	—		$	2,712,418
Intersegment revenues	—			121,374		—			121,374
Total	$	1,354,000		$	1,479,792	$	—		$	2,833,792
Segment net income (loss)	$	153,683		$	57,677	$	(1,922	)	$	209,438



	32



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Note 11 – Redeemable Noncontrolling Interest

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

Significant changes in the value of the redeemable noncontrolling interest, above a floor established at the acquisition date, are recognized as they occur, and the carrying value is adjusted as necessary at each reporting date. The fair value is estimated using a market approach that utilizes certain financial metrics from guideline public companies of similar industry and operating characteristics. However, the carrying value of the redeemable noncontrolling interest was greater than its fair value as of September 30, 2019, and no previous upward redemption value adjustments were made following the acquisition date. SEC guidance indicates that a redemption value adjustment would not be made under these circumstances. The following depicts ~~changes~~the change to the balance of the redeemable noncontrolling interest:



(Thousands of dollars):	Redeemable Noncontrolling Interest
Balance, December 31, 2018	$	81,831
Net income attributable to redeemable noncontrolling interest	2,523
Balance, September 30, 2019	$	84,354

Note 12 – Business Acquisitions

In November 2018, the Company, through its subsidiaries, led principally by Centuri, completed the acquisition of an 80% interest ~~between~~in a privately held infrastructure services business, Linetec, with 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
   $ —

~~Note 10 – Reorganization Impacts – Discontinued Operations Solely Related~~remaining 20% retained by the seller. See the Company’s 2018 Form 10-K for additional information about this acquisition.

Assets acquired and liabilities assumed in the transaction were recorded, generally, at their estimated acquisition date fair values. During the measurement period, which may be up to ~~Southwest Gas Corporation~~

~~No substantive change has occurred with regard~~one year from the acquisition date, the Company may continue to record adjustments to the ~~Company’s business segments on~~fair value of tangible and intangible assets acquired and liabilities assumed. The Company continues to collect information and reevaluates these estimates and assumptions quarterly. Upon the ~~whole,~~conclusion of the measurement period or final determination of the fair value of assets acquired or liabilities assumed, whichever comes first, any subsequent adjustments may be recognized in the ~~primary businesses comprising those segments (Centuri operations continue to be part~~Company’s Consolidated Statement of ~~continuing operations~~Income.

The Company’s allocation of the ~~controlled group~~purchase price was based on an evaluation of ~~companies),~~the appropriate fair values and ~~financial information~~represented management’s best estimate based on available data (including market data, data regarding customers of the acquired business, terms of acquisition-related agreements, analysis of historical and projected results, and other types of data). The analysis included consideration of types of intangibles that were acquired, including customer relationships, trade names, and customer contracts. Certain payments were estimated as of the acquisition date and are adjusted when paid or as estimates change based on available data; the final purchase accounting has not yet been completed. Further adjustments may occur, including potential changes to final purchase consideration payments held back, such as the remaining amounts associated with unbilled customer accounts receivable balances recorded at their estimated realizable values as of the acquisition date. Subsequent to the acquisition date and through September 30, 2019, Centuri recorded a net reduction to the overall purchase price of $25.2 million related to ~~Centuri continues to be included in condensed consolidated financial statements~~the combined effects 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 this~~Form 10-Q,~~ ~~depict Centuri-related~~mutual tax election under Internal Revenue Code Section 338(h)(10), working capital adjustments, amounts ~~as discontinued operations for periods prior to January 2017.~~

~~Due~~associated with certain unbilled customer receivable balances, and other refinements to the ~~discontinued operations accounting reflection,~~valuation, which impacted the ~~following disclosures provide additional information regarding~~remaining unremitted consideration. Approximately $19.5 million of previously unremitted consideration was paid during the ~~assets, liabilities, equity, revenues, and expenses~~nine months ending September 30, 2019. As 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:

that date, remaining unpaid consideration was $26.2 million.


~~(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~~


	33



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

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



	Acquisition Date		Measurement Period Adjustments			Revised Acquisition Date
Cash and cash equivalents	$	3.9	$	—		$	3.9
Accounts receivable	32.8		(0.5		)	32.3
Revenue earned on contracts in progress in excess of billings	21.6		(0.2		)	21.4
Prepaid expenses and other current assets	1.1		0.1			1.2
Property and equipment	89.4		(0.8		)	88.6
Intangible assets	89.3		—			89.3
Goodwill	188.5		(22.2		)	166.3
Total assets acquired	426.6		(23.6		)	403.0

Accounts payable	8.0		—			8.0
Accrued liabilities	6.9		1.6			8.5
Deferred compensation and related accrued taxes	3.4		—			3.4
Redeemable noncontrolling interest	81.7		—			81.7
Total liabilities assumed and noncontrolling interest	100.0		1.6			101.6
Net assets acquired	$	326.6	$	(25.2	)	$	301.4

The Company incurred and expensed acquisition costs of $6.9 million which are included in Utility infrastructure services expenses on the ~~components~~Company’s Consolidated Statement of Income for the year ended December 31, 2018. NaN acquisition-related costs were incurred during the three and nine months ended September 30, 2019, and no significant impacts to earnings resulted from the measurement-period adjustments reflected above.

The preliminary allocation of the ~~Discontinued~~purchase price of Linetec was accounted for in accordance with applicable accounting guidance. Goodwill consists of the value associated with the assembled workforce, consolidation of operations, ~~– construction servicesnon-owner~~ ~~equity amount shown~~and the estimated economic value attributable to future opportunities related to the transaction. As the business of Linetec was deemed an asset purchase for tax purposes, the tax-basis goodwill is expected to be deductible for tax purposes. During 2019, values at the acquisition date were adjusted, as reflected in the ~~Southwest Gas Corporation~~table above, on the Company’s 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 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
Construction revenues
   $ 339,790    $ 838,038    $ 301,040    $ 1,127,982
Operating expenses:

Construction expenses
   300,611    757,919    266,504    1,009,188
Depreciation and amortization
   13,409    43,351    12,318    58,368








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








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








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








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


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

Sheets.

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

Southwest Gas Holdings, Inc. is a holding company that owns all of the shares of common stock of Southwest Gas Corporation (“Southwest” or the “natural gas operations” segment) and ~~prior to August 2017, 96.6%~~all of the shares of common stock of Centuri ~~Construction~~ Group, Inc. (“~~Centuri”~~Centuri,” or the ~~“construction~~“utility infrastructure services” segment). 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 part of the holding company reorganization effective January 2017, Centuri and Southwest are now subsidiaries of Southwest Gas Holdings, Inc.; whereas historically, Centuri had been a direct subsidiary of Southwest. Southwest Gas Holdings, Inc. and its subsidiaries ~~(the “Company”) have two business segments (natural gas operations and construction services)~~are collectively referred to as the “Company.” At the annual meeting of shareholders of Southwest Gas Holdings, Inc., ~~which are discussed below.~~

held on May 2, 2019, shareholders voted to approve changing the state of incorporation of Southwest Gas Holdings, Inc. from California to Delaware. The reincorporation was effective as of September 20, 2019.

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

As of September 30, ~~2017 (on a seasonally adjusted basis),~~2019, Southwest had ~~1,999,000~~2,066,000 residential, commercial, industrial, and other natural gas customers, of which ~~1,065,000~~1,101,000 customers were located in Arizona, ~~741,000~~768,000 in Nevada, and ~~193,000~~197,000 in California. Residential and small commercial customers represented over 99% of the total customer base. During the twelve months ended September 30, ~~2017, 54%~~2019, 53% of operating margin (gas operating revenues less the net cost of gas sold) was earned in Arizona, ~~35%~~36% in Nevada, and 11% in California. During this same period, Southwest earned ~~85%~~84% of its operating margin ~~(gas operating revenues less the net cost of gas sold)~~ from residential and small commercial customers, 3% from other



	34



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

sales customers, and ~~12%~~13% from transportation customers. These general patterns are expected to remain materially consistent for the foreseeable future.

Southwest recognizes operating revenues from the distribution and transportation of natural gas (and related services) to customers. Operating margin is a financial measure defined by management as gas operating revenues less the net cost of gas sold. However, operating margin is not specifically defined in accounting principles generally accepted in the United States (“U.S. GAAP”). Thus operating margin is considered 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 adollar-for-dollar basis, but do not impact operating margin or operating income. Therefore, management believes operating margin provides investors and other interested parties with useful and relevant information to analyze Southwest’s financial performance in a rate-regulated environment. The principal factors affecting changes in operating margin are general rate relief (including impacts of infrastructure trackers) and customer growth.

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

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

Centuri is a comprehensive ~~construction~~utility infrastructure services enterprise dedicated to ~~meeting the growing demands~~delivering a diverse array of solutions to North ~~American utilities, energy~~America’s gas and ~~industrial markets.~~electric providers. Centuri derives revenue from installation, replacement, repair, and maintenance of energy distribution systems, and developing industrial construction solutions. Centuri operates in ~~24 major markets~~50 primary locations across 40 states and provinces in the United States ~~(primarily~~(“U.S.”) and Canada. In November 2017, Centuri expanded its operations in the northeast region of the U.S. through the acquisition of New England Utility Constructors, Inc. (“Neuco”), and again in November 2018, in the southeast region of the U.S. through the acquisition of an 80% interest in Linetec Services, LLC (“Linetec”). Both companies were privately owned utility infrastructure services businesses prior to their acquisition. Centuri operates in the U.S. primarily as ~~NPL)~~NPL, Neuco, and Linetec, and in ~~3 major markets in~~ Canada ~~(as~~primarily as NPL ~~Canada (formerly Link-Line Contractors Ltd.), and W.S. Nicholls).~~

~~Construction~~Canada.

Utility infrastructure services 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~~infrastructure replacement programs of utilities, weather, 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~~system 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~~utility system replacement projects throughout the U.S. Generally, Centuri revenues are lowest during the first quarter of the year due to less favorable winter weather conditions. Revenues typically improve as more favorable weather conditions occur during the summer and fall months. ~~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 awarded, by individual large customers can significantly impact operating results.

This Management’s Discussion and Analysis (“MD&A”) of Financial Condition and Results of Operations should be read in conjunction with the unaudited consolidated financial statements and the notes thereto included in this Quarterly Report on Form 10-Q and the audited financial statements and the notes thereto, as well as MD&A, included in the ~~2016~~2018 Annual Report to Shareholders, which is incorporated by reference into the ~~2016~~2018 Form10-K.



	35



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Executive Summary

The items discussed in this Executive Summary are intended to provide an overview of the results of the Company’s and Southwest’s operations. As needed, certain items are covered in greater detail in later sections of ~~management’s discussion and analysis.~~MD&A. As reflected in the table below, the natural gas operations segment accounted for an average of ~~81%~~75% oftwelve-month-to-date consolidated net income over the past two years. As such, ~~management’s discussion and analysis~~MD&A is primarily focused on that segment. Natural gas sales are seasonal, peaking during the winter months; therefore, results of operations for interim periods are not necessarily indicative of results for a full year.

Summary Operating Results

   Period Ended September 30,
   Three Months Nine Months    Twelve Months
   2017 2016 2017 2016    2017 2016
   (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
Construction services
   14,335 14,877 15,717 19,325    29,010 33,144
Corporate and administrative
   (107 ) —   (777 ) —      (777 ) —




Net income
   $ 10,204 $ 2,472 $ 97,376 $ 86,861    $ 162,556 $ 152,980




Average number of common shares outstanding
   47,628 47,481 47,577 47,464    47,553 47,442




Basic earnings per share

Consolidated
   $ 0.21 $ 0.05 $ 2.05 $ 1.83    $ 3.42 $ 3.22




Natural Gas Operations

Gas operating revenues
   $ 213,059 $ 200,179 $ 935,823 $ 980,927    $ 1,276,308 $ 1,376,388
Net cost of gas sold
   45,539 39,056 261,839 324,072    334,888 460,836




Operating margin
   $ 167,520 $ 161,123 $ 673,984 $ 656,855    $ 941,420 $ 915,552



	Period Ended September 30,
	Three Months						Nine Months						Twelve Months
	2019			2018			2019			2018			2019			2018
	(In thousands, except per share amounts)
Contribution to net income
Natural gas operations	$	(20,012	)	$	(13,670	)	$	86,746		$	79,301		$	146,287		$	153,683
Utility infrastructure services	25,838			26,798			36,725			35,034			46,668			57,677
Corporate and administrative	(473		)	(797		)	(1,253		)	(1,362		)	(1,433		)	(1,922		)
Net income	$	5,353		$	12,331		$	122,218		$	112,973		$	191,522		$	209,438

Average number of common shares	54,670			49,493			53,996			48,916			53,219			48,728
Basic earnings per share
Consolidated	$	0.10		$	0.25		$	2.26		$	2.31		$	3.60		$	4.30
Natural Gas Operations
Reconciliation of Revenue to Operating Margin (Non-GAAP measure)
Gas operating revenues	$	209,980		$	217,523		$	989,368		$	987,515		$	1,359,581		$	1,354,000
Less: Net cost of gas sold	35,068			49,903			292,854			319,101			393,141			412,307
Operating margin	$	174,912		$	167,620		$	696,514		$	668,414		$	966,440		$	941,693

3rd Quarter 2019 Overview

Natural gas operations highlights:

34,000 net new customers (1.7% growth rate) during the last 12 months

Filed California rate case (requesting a revenue increase of $12.8 million)

In October, S&P upgraded Southwest’s issuer debt rating from BBB+ (with a negative outlook) to A- (outlook unchanged)

Utility infrastructure services highlights:

Utility infrastructure services revenues increased $65 million ($70.3 million from Linetec)

Utility infrastructure services expenses increased $56 million ($55.8 million from Linetec)

Southwest Gas Holdings highlights:

Completed reincorporation from California into Delaware

Increased the number of authorized shares of common stock available for issuance from 60,000,000 to 120,000,000



	36



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

~~3rd Quarter 2017 Overview~~

~~Natural gas operations highlights:~~

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

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

~~Depreciation and amortization expense declined $10 million compared to the prior-year quarter~~

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

~~Targeting $27 million of vintage steel pipe replacement in Arizona during 2017~~

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

~~Construction services highlights:~~

~~Revenues increased $40.3 million compared to the prior-year quarter~~

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

~~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 30, 2017~~

Results of Natural Gas Operations

   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 )

Quarterly Analysis



	Three Months Ended
	September 30,
	2019			2018
	(Thousands of dollars)
Gas operating revenues	$	209,980		$	217,523
Net cost of gas sold	35,068			49,903
Operating margin	174,912			167,620
Operations and maintenance expense	109,039			104,657
Depreciation and amortization	52,372			47,924
Taxes other than income taxes	15,308			15,036
Operating income (loss)	(1,807		)	3
Other income (deductions)	(1,353		)	836
Net interest deductions	23,619			20,399
Loss before income taxes	(26,779		)	(19,560		)
Income tax benefit	(6,767		)	(5,890		)
Contribution to consolidated net income (loss)	$	(20,012	)	$	(13,670	)

Contribution from natural gas operations to consolidated net income decreased $6.3 million between the third quarters of 2019 and 2018. The decline was primarily due to increases in Operations and maintenance expense, Depreciation and amortization, and Net interest deductions, as well as reductions in Other income, partially offset by an increase in rate relief and customer growth.

Operating margin increased ~~$6 million between quarters. Rate relief in Arizona (effective April 2017) and California provided $4 million in operating margin (see~~~~Rates and Regulatory Proceedings~~).$7 million. Approximately $2 million ~~in increased operating~~of incremental margin was attributable to customer growth, as ~~32,000~~34,000 net new customers were added during the last twelve months.

Rate relief, primarily in California and Nevada, contributed $2 million in incremental operating margin in the current period. Miscellaneous service revenue and revenue outside the decoupling mechanisms also increased between periods. Regulatory surcharge recoveries for California cap and trade and public purpose programs and Nevada infrastructure replacement programs (collectively, having an offsetting impact in amortization expense), compose the residual increase.

Operations and maintenance expense ~~was relatively flat~~increased $4.4 million, or 4%, between quarters. ~~Decreases in employee-related benefit~~Higher general cost increases and legal costs ~~more than offset increases in other general costs.~~

of $2.5 million contributed to the increase between periods.

Depreciation and amortization expense increased $4.4 million, or 9%, between quarters, primarily due to a $602 million, or 9%, increase in average gas plant in service compared to the corresponding quarter a year ago, and to an increase in regulatory account amortization, as discussed above. The increase in gas plant was attributable to pipeline capacity reinforcement work, franchise requirements, scheduled and accelerated pipe replacement activities, and new infrastructure.

Other income decreased ~~$10~~$2.2 million between quarters primarily due to ~~reduced depreciation rates~~a decline in ~~Arizona,~~income from company-owned life insurance (“COLI”) policies. The current quarter reflects a ~~result~~$200,000 increase in COLI policy cash surrender values, while the prior-year quarter reflected $4.7 million of ~~the recent Arizona general rate case decision.~~COLI-related income. Partially offsetting these impacts were the ~~decline~~non-service-related components of employee pension and other postretirement benefit costs, which decreased $1.5 million between quarters.

Net interest deductions increased $3.2 million in the third quarter of 2019, as compared to the prior-year quarter, primarily due to the issuance of $300 million of Senior Notes in May 2019.



	37



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Results of Natural Gas Operations

Nine-Month Analysis



	Nine Months Ended
	September 30,
	2019		2018
	(Thousands of dollars)
Gas operating revenues	$	989,368	$	987,515
Net cost of gas sold	292,854		319,101
Operating margin	696,514		668,414
Operations and maintenance expense	319,572		312,055
Depreciation and amortization	159,327		145,549
Taxes other than income taxes	46,640		44,959
Operating income	170,975		165,851
Other income (deductions)	6,185		(5,861		)
Net interest deductions	70,063		59,803
Income before income taxes	107,097		100,187
Income tax expense	20,351		20,886
Contribution to consolidated net income	$	86,746	$	79,301

Contribution from natural gas operations to consolidated net income increased $7.4 million between the first nine months of 2019 and 2018. The increase was primarily due to rate relief, customer growth, and higher Other income, partially offset by increases in Operations and maintenance expense, Depreciation and amortization, and Net interest deductions.

Operating margin increased ~~depreciation associated with a $317~~$28 million, including an $8 million increase attributable to customer growth. Rate relief, primarily in California and Nevada, contributed an additional $8 million in operating margin. Regulatory surcharge recoveries, including for those programs in California and Nevada noted earlier, were $5.5 million higher overall in the current period, after giving effect for climate credits returned to California customers from the cap and trade program. Other changes in operating margin included miscellaneous revenues and margin from customers outside the decoupling mechanisms and reductions for the regulatory impacts of U.S. tax reform in the current period.

Operations and maintenance expense increased $7.5 million, or 5%2%, between periods. Higher pipeline integrity management and damage prevention programs, as well as other general cost increases, contributed to the increase. Lower service-related pension and other postretirement benefit costs mitigated the increases from the other items.

Depreciation and amortization expense increased $13.8 million, or 9%, between periods primarily due to a $568 million, or 8%, increase in average gas plant in service for the ~~current quarter~~period as compared to the corresponding ~~quarter~~period 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~~ Regulatory account surcharges, as noted above, also resulted in ~~Arizona, including~~increases in amortization expense in the ~~impact of a property tax tracking mechanism enacted as part of the recently settled Arizona general rate case.~~

current period.

Other income ~~increased $560,000~~(deductions) improved $12 million overall between ~~quarters primarily due to~~periods. The current period included income from COLI policy cash surrender value changes and net death benefits of $11.2 million, while the prior-year period reflected $6 million of COLI-related income. The non-service cost components of employee pension and other postretirement benefit costs were $4.5 million lower between periods. Additionally, an improvement in income of $2.1 million resulted from an increase in the equity ~~portion~~component of the allowance for funds used during construction (“AFUDC”) ~~associated with~~, due to both a higher ~~construction expenditures. The equity portion~~rate and level of ~~AFUDC represents~~capital expenditures in the cost of equity funds used to finance utility construction. The equity AFUDC improvement was partially offset by a decline between quarters in 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.

period.

Net interest deductions increased ~~$1.1~~$10.3 million between ~~quarters,~~periods, primarily due to the ~~September 2016~~ issuance of $300 million of ~~senior notes, partially offset by reductions associated with~~Senior Notes in March 2018 and $300 million in May 2019, in addition to higher interest rates and borrowings outstanding under the ~~redemption~~revolving credit and term-loan facility throughout much of ~~debt ($24.9 million of 4.75% IDRBs in September 2016) and lower interest expense associated with PGA balances as compared to~~ the ~~prior-year quarter.~~

current period.



	38



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

Results of Natural Gas Operations

~~Nine-Month~~

Twelve-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~~



	Twelve Months Ended
	September 30,
	2019			2018
	(Thousands of dollars)
Gas operating revenues	$	1,359,581		$	1,354,000
Net cost of gas sold	393,141			412,307
Operating margin	966,440			941,693
Operations and maintenance expense	412,330			404,549
Depreciation and amortization	205,594			193,828
Taxes other than income taxes	61,579			59,580
Operating income	286,937			283,736
Other income (deductions)	(5,194		)	(6,425		)
Net interest deductions	92,000			77,914
Income before income taxes	189,743			199,397
Income tax expense	43,456			45,714
Contribution to consolidated net income	$	146,287		$	153,683

Contribution to consolidated net income from natural gas operations ~~increased $14.9~~decreased by $7.4 million between the ~~first nine months of 2017~~twelve-month periods ended September 2019 and ~~2016.~~September 2018. The ~~improvement~~decrease was primarily due to higher Operations and maintenance expense, Depreciation and amortization expense, and Net interest deductions, partially offset by increases in operating margin and ~~lower depreciation expense, partially offset by an increase in operations and maintenance expenses.~~

Other income.

Operating margin increased ~~$17~~$25 million between ~~the comparative nine-month~~ periods. ~~Rate~~Customer growth provided $11 million, and combined rate relief, primarily in ~~the Arizona~~Nevada and California, ~~jurisdictions~~ provided ~~$10~~$9 million inof incremental operating ~~margin (see~~~~Rates and Regulatory Proceedings~~).margin. The remaining ~~$7 million~~net increase ~~was attributable to customer growth.~~

resulted from recoveries of regulatory assets, net of the return of California climate credits from the cap and trade program, infrastructure replacement mechanisms, customers outside the decoupling mechanisms, and other miscellaneous revenues, net of the regulatory impacts of U.S. tax reform.

Operations and maintenance expense increased ~~$11.4~~$7.8 million, or 4%2%, 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~~higher general costs and expenditures for pipeline damage prevention programs, offset by a reduction in ~~Arizona, a result~~the service-related component of ~~the recent Arizona general rate case decision. The depreciation decrease also included a decline of approximately $3.7 million in~~pension and other postretirement benefit costs.

Depreciation and amortization ~~related to the recovery of regulatory assets. Partially offsetting these declines was depreciation associated with a $325~~expense increased $11.8 million, or 5%6%, between periods primarily due to a $550 million, or 8%, increase in average gas plant in service for the current period as compared to the prior period. The expense increase reflects an offsetting reduction in ~~gas plant was attributable~~regulatory amortization between periods, including the impacts of climate credits returned to ~~pipeline capacity reinforcement work, franchise requirements, scheduled~~California customers under the cap and ~~accelerated pipe replacement activities, and new infrastructure.~~

trade program.

Taxes other than income taxes increased ~~$3.8~~$2 million, or 3%, between periods primarily due to higher property taxes associated with net plant additions, Nevada commerce taxes, and ~~increased property taxes in Arizona, including the impact of the Arizona property tax tracking mechanism.~~

California franchise taxes.

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 million between periods, primarily due to the September 2016 issuance of $300 million of senior notes, partially offset by reductions associated with debt redemptions ($100 million 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 to the prior-year period.


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

~~Results of Natural Gas Operations~~

~~Twelve-Month Analysis~~

   Twelve Months Ended September 30,
   2017    2016
   (Thousands of dollars)
Gas operating revenues
   $ 1,276,308    $ 1,376,388
Net cost of gas sold
   334,888    460,836




Operating margin
   941,420    915,552
Operations and maintenance expense
   413,140    400,222
Depreciation and amortization
   212,693    228,609
Taxes other than income taxes
   56,221    51,810




Operating income
   259,366    234,911
Other income (deductions)
   10,308    9,615
Net interest deductions
   69,464    65,146




Income before income taxes
   200,210    179,380
Income tax expense
   65,887    59,544




Contribution to consolidated net income
   $ 134,323    $ 119,836

~~Contribution to consolidated net income from natural gas operations increased by $14.5~~(deductions) improved $1.2 million between the twelve-month periods ended September 2019 and September 2018. Equity AFUDC contributed $4.5 million as a result of ~~2017~~increased construction expenditures and ~~2016. The improvement~~higher underlying rates. Additionally, the non-service components of employee pension and other postretirement benefits costs improved in the current period by $4 million. Offsetting these increases was ~~primarily due to higher operating margin and lower depreciation expense, partially offset by an increase in operations and maintenance expenses and interest expense.~~

~~Operating margin increased $26~~a decline of $7.5 million between periods including a combined $13 million of rate relief in the Arizona and California jurisdictions, as well as Paiute Pipeline Company. Customer growth provided $9 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 million.

~~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~~the combined effects of ~~the incremental costs recognized were associated with the amount~~changes in cash surrender values of COLI policies and ~~timing of employee incentive plan grants (including accelerated recognition for retirement-eligible employees). Pipeline integrity management and damage prevention programs collectively~~net death benefits.

Net interest deductions increased ~~$500,000.~~

Depreciation and amortization expense decreased $15.9 million between periods primarily due to reduced depreciation rates in Arizona, a result of the recent Arizona general rate case decision. Partially offsetting the decline was depreciation associated with a $335 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~~$14.1 million between periods primarily due to higher ~~property taxes~~interest associated ~~primarily~~ with ~~net plant additions and increased property taxes in Arizona, including~~ the ~~impact of a property tax regulatory tracking mechanism resulting from the recent Arizona general rate case.~~

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

~~Net interest deductions increased $4.3 million between periods, primarily due to the September 2016~~ issuance of $300 million of ~~senior notes. The increase was partially offset by reductions associated with the redemption of debt ($100~~Senior Notes in March 2018 and $300 million ~~of 4.85% IDRBs~~ in ~~July 2016~~May 2019, higher interest rates and ~~$24.9 million of 4.75% IDRBs in September 2016)~~average outstanding balances under Southwest’s credit facility, and ~~lower interest expense associated with~~carrying costs on PGA balances ~~as compared to~~in the ~~prior-year~~current period.



	39



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

Results of ~~Construction~~Utility Infrastructure Services

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~~



	Three Months Ended
	September 30,
	2019		2018
	(Thousands of dollars)
Utility infrastructure services revenues	$	515,250	$	450,623
Operating expenses:
Utility infrastructure services expenses	451,574		395,862
Depreciation and amortization	22,998		14,232
Operating income	40,678		40,529
Other income (deductions)	171		38
Net interest deductions	3,788		3,945
Income before income taxes	37,061		36,622
Income tax expense	10,051		9,824
Net income	27,010		26,798
Net income attributable to noncontrolling interest	1,172		—
Contribution to consolidated net income attributable to Centuri	$	25,838	$	26,798

In November 2018, Centuri acquired Linetec. The table above, therefore, includes results for Linetec in the 2019 period only, including $70.3 million of revenue and approximately $3.7 million of net income ~~from construction~~attributable to Linetec during the three months ended September 30, 2019.

Utility infrastructure services revenues increased $64.6 million in the ~~current~~third quarter ~~decreased by $542,000~~of 2019 when compared to the prior-year ~~quarter. The decrease is~~quarter, primarily due to ~~higher construction costs relative to increased~~the incremental revenues ~~resulting from apre-tax~~ ~~loss on a project described below, partially~~contributed by Linetec. These increases were offset by the July 2019 expiration of a ~~decline in depreciation and amortization.~~

Revenues increased $40.3 million, or 12%, between quarters primarily due to an increase 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~~multi-year water pipe replacement project ~~for~~ which ~~Centuri has requested~~was not renewed. The prior-year quarter also included revenue from certain non-routine customer-requested support during a strike-related event.

Utility infrastructure services expenses 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$55.7 million ~~for~~in the third ~~quarters~~quarter of ~~2017~~2019 when compared to the prior-year quarter, due primarily to $55.8 million of Linetec expenses. Implementation of new regulatory requirements for operating locations within certain eastern states in the U.S. resulted in lower revenues and ~~2016, respectively.~~

productivity inefficiencies totaling an estimated $4 million during the current quarter as Centuri works with customers to adopt the new requirements. Efforts to complete an industrial construction project in Canada resulted in additional costs of approximately $2 million during the current quarter as a result of delays in commissioning the project. Additionally, changes in the mix of work requested in 2019 by certain customers under unit-priced multi-year master services contracts resulted in higher labor and equipment costs compared to the work anticipated.

Depreciation and amortization ~~decreased $1.1~~expense increased $8.8 million between ~~quarters, primarily due to a $2~~quarters. Approximately $7.5 million ~~reduction associated with the extension~~ of the ~~estimated useful lives~~increase was attributable to the Linetec acquisition, including amortization of ~~certain depreciable~~finite-lived intangible assets ($1.2 million) and depreciation of property and equipment ($6.3 million) during the ~~past 12 months, partially offset by an~~third quarter of 2019. The remaining increase ~~in depreciation for~~was attributable to additional equipment purchased to support the growing volume of work being performed.



	40



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

Results of ~~Construction~~Utility Infrastructure Services

Nine-Month 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~~



	Nine Months Ended
	September 30,
	2019		2018
	(Thousands of dollars)
Utility infrastructure services revenues	$	1,282,412	$	1,105,844
Operating expenses:
Utility infrastructure services expenses	1,154,238		1,007,485
Depreciation and amortization	63,924		40,392
Operating income	64,250		57,967
Other income (deductions)	569		(331		)
Net interest deductions	10,514		10,448
Income before income taxes	54,305		47,188
Income tax expense	15,057		12,951
Net income	39,248		34,237
Net income (loss) attributable to noncontrolling interest	2,523		(797		)
Contribution to consolidated net income attributable to Centuri	$	36,725	$	35,034

As noted earlier, in November 2018, Centuri acquired Linetec. The table above, therefore, includes results for Linetec in the 2019 period only, including $174.6 million of revenue and approximately $8.5 million of net income ~~from construction services for~~attributable to Linetec during the first nine months of ~~2017 declined by $3.6~~2019.

Utility infrastructure services revenues increased $176.6 million ~~when compared to the prior-year period. The decrease is primarily due to higher construction costs relative to increased revenues, partially offset by a decline in depreciation and amortization.~~

~~Revenues increased $34.5 million, or 4%, in~~during the first nine months of ~~2017~~2019 when compared to the ~~prior-year~~same period in the prior year, primarily due to ~~increased~~the incremental revenues contributed by Linetec. These increases were offset by the July 2019 expiration of a multi-year water pipe replacement ~~work. Partially offsetting increases in revenues~~project which was ~~a temporary work stoppage by a significant customer that began in~~not renewed. During the first ~~quarter~~nine months of ~~2017 and continued through part~~2018, Centuri recorded revenue of $9 million on a negotiated settlement of an outstanding dispute under this contract. The prior-year period also included revenue from certain non-routine customer-requested support during a strike-related event.

Utility infrastructure services expenses increased $146.8 million during the ~~second quarter~~first nine months of ~~2017 resulting in a $26.3 million reduction in revenues,~~2019 when compared to the ~~prior-year~~same period in the prior year, due primarily to $139.7 million of Linetec expenses. Additionally, inclement weather conditions impacted costs, as well as the mix of work requested in 2019 by certain customers under unit-priced multi-year master services contracts, as previously discussed. Efforts to complete an industrial construction project in Canada resulted in additional costs during the current period. Net gains on sale of equipment (reflected as an offset to Utility infrastructure services expenses) were $3.2 million and ~~a $3.7~~$1 million~~pre-tax~~ ~~loss~~ for the nine-month periods of 2019 and 2018, respectively.

Depreciation and amortization expense increased $23.5 million between periods. Approximately $19.3 million of the increase is due to the Linetec acquisition, including amortization of finite-lived intangible assets ($3 million) and depreciation of property and equipment ($16 million) in the current ~~nine-month~~ period. The ~~temporary~~remaining increase in depreciation was attributable to additional equipment purchased to support the growing volume of work ~~stoppage was initiated~~being performed.



	41



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Results of Utility Infrastructure Services

Twelve-Month Analysis



	Twelve Months Ended
	September 30,
	2019		2018
	(Thousands of dollars)
Utility infrastructure services revenues	$	1,698,853	$	1,479,792
Operating expenses:
Utility infrastructure services expenses	1,534,442		1,349,862
Depreciation and amortization	80,928		53,975
Operating income	83,483		75,955
Other income (deductions)	662		(24		)
Net interest deductions	14,256		13,339
Income before income taxes	69,889		62,592
Income tax expense	20,526		5,781
Net income	49,363		56,811
Net income (loss) attributable to noncontrolling interest	2,695		(866		)
Contribution to consolidated net income attributable to Centuri	$	46,668	$	57,677

Results for Linetec have been included in the table above during the period following the November 2018 acquisition date, including $188.7 million of revenue and approximately $9.2 million of net income reflected in the twelve-month period ended September 2019.

Utility infrastructure services revenues increased $219.1 million overall in the twelve-month period ended September 2019 compared to the twelve-month period ended September 2018, primarily due to ~~state-mandated requalification~~incremental revenue noted above for Linetec. The remaining revenue increase is due to a higher volume 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 revenuespipe replacement work under new and ~~reduced productivity~~existing blanket and bid contracts, primarily in the ~~first quarter~~central U.S., and certain non-routine projects (including customer-requested support during strike-related and emergency response situations). Revenue for the twelve-month period in 2018 included a $9 million negotiated settlement of ~~2017.~~

~~Construction~~an outstanding contract dispute from 2017 associated with a water pipe replacement project.

Utility infrastructure services expenses increased ~~$48.7~~$184.6 million ~~or 6%,~~ between ~~periods. The increase in construction~~periods, primarily due to related expenses ~~is disproportionate to revenues noted above due in part to logistics surrounding the timing~~for Linetec of $149.8 million and ~~length of the temporary work stoppage with the significant customer~~additional labor and ~~to higher labor~~equipment costs incurred to complete work during inclement weather conditions in the ~~first quarter. In addition, results were negatively impacted by higher~~current period. The industrial construction ~~andstart-up~~project in Canada also resulted in additional costs ~~related~~during the current period. The mix of work requested to be completed in the current period, as discussed earlier, also contributed to the ~~water pipe replacement project, for~~increase in costs overall. Included in total Utility infrastructure services expenses are general and administrative costs, which ~~Centuri is pursuing cost recovery. Gains~~increased $12.3 million in the current period, including $6.9 million of deal costs from the acquisition of Linetec. Net gains on sale of equipment (reflected as an offset to ~~construction~~Utility infrastructure services expenses) were ~~approximately $1.5~~$3.9 million and ~~$4.1~~$3.7 million for the ~~first nine months~~twelve-month periods of ~~2017~~2019 and ~~2016,~~2018, respectively.

Depreciation and amortization ~~decreased $7.9~~expense increased $27 million between ~~periods, primarily due~~the current and prior-year periods. Approximately $22 million of this increase was attributable to ~~an $8.2 million reduction in~~Linetec amortization of finite-lived asset amortization ($4.1 million) and property and equipment depreciation ~~associated with the extension of the estimated useful lives of certain depreciable equipment during the past 12 months, partially offset by an~~($17.8 million). The remaining increase in depreciation ~~for~~was attributable to additional equipment purchased to support the growing volume of work being performed.

Net interest deductions increased $917,000 between periods due primarily to interest expense associated with incremental borrowings, and amortization of debt issue costs, related to the $590 million secured revolving credit and term loan facility (largely resulting from the Linetec acquisition). Lower rates on variable-rate debt mitigated the increases.

Income tax expense during the twelve-month period ended September 30, 2018 was favorably impacted by approximately $12 million of one-time tax benefits related to the remeasurement of Centuri’s deferred tax liabilities when U.S. tax reform was enacted in December 2017.



	42



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

~~Results of Construction Services~~

~~Twelve-Month Analysis~~

   Twelve Months Ended
September 30,
   2017    2016
   (Thousands of dollars)
Construction revenues
   $ 1,173,576    $ 1,127,982
Operating expenses:

Construction expenses
   1,073,090    1,009,188
Depreciation and amortization
   47,764    58,368




Operating income
   52,722    60,426
Other income (deductions)
   1,187    1,246
Net interest deductions
   6,813    6,738




Income before income taxes
   47,096    54,934
Income tax expense
   17,402    20,711




Net income
   29,694    34,223
Net income attributable to noncontrolling interests
   684    1,079




Contribution to consolidated net income attributable to Centuri
   $ 29,010    $ 33,144

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

Revenues increased $45.6 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 and higher labor costs incurred to complete work during inclement weather conditions in the first quarter of 2017 resulted in costs disproportionate to revenues. Results were negatively impacted by higher~~start-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. Gains on sale of equipment (reflected as an offset to construction expenses) were $4.5 million and $4.2 million for the twelve-month periods ended September 30, 2017 and 2016, respectively.

Depreciation and amortization decreased $10.6 million between the current and prior-year periods primarily due to an $11.1 million reduction associated with the extension of the estimated useful lives of certain depreciable equipment over the last twelve months, partially offset by an increase in depreciation for additional equipment purchased to support the growing volume of work being performed.


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

Rates and Regulatory Proceedings

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

General Rate Relief and Rate Design

Rates charged to customers vary according to customer class and rate jurisdiction and are set by the individual state and federal regulatory commissions that govern Southwest’s service territories. Southwest makes periodic filings for rate adjustments as the cost of providing service (including the cost of natural gas purchased) changes, and as additional investments in new or replacement pipeline and related facilities are made. Rates are intended to provide for recovery of all commission-approved costs and a reasonable return on investment. The mix of fixed and variable components in rates assigned to various customer classes (rate design) can significantly impact cash flows of Southwest. Management has worked with its regulatory commissions in designing rate structures that strive to provide affordable and reliable service to its customers while mitigating the volatility in prices to them and that endeavor to stabilize returns to investors. Such rate structures were in place in all of Southwest’s operating areas during all periods for which results of natural gas operations are disclosed above.

Arizona Jurisdiction

Arizona General Rate Case. On May 1, 2019, Southwest filed a general rate case application requesting to increase revenue by approximately $57 million to update the cost of service to reflect recent U.S. tax reform changes, including the return of excess deferred income taxes to customers, and to reflect capital investments of approximately $670 million, including certain post-test year additions, which include the southern Arizona LNG facility discussed below. At the time of the filing, the Company estimated the return of approximately $20.6 million of excess deferred income taxes. Since then, the Company finalized its 2018 tax return which allowed it to calculate the actual amortization amount of $5.7 million based on the prescribed methodology for calculating the excess amount to be returned to customers. The difference in estimated deferred taxes of $20.6 million and the actual amortization of $5.7 million would result in an increase in revenue and income tax expense, thereby having no impact to earnings. The revenue increase included a proposed 10.3% return on equity relative to a capital structure of 51.1% equity. The request also includes the retention of a fully decoupled rate design, other previously approved regulatory mechanisms, and a new infrastructure tracking mechanism for specific plastic pipe. The request includes a proposal for a renewable natural gas program that authorizes Southwest to purchase renewable natural gas for its customers and to recover the cost as part of its purchased gas adjustment mechanism. In October, Southwest filed a supplement to its post-test year plant request to include an additional $124.5 million of investments associated with its COYL and VSP programs. If approved, this could result in additional margin of approximately $17 million. A hearing in this matter is scheduled for February 2020.

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

Tax Reform. In February 2018, the ACC directed all Arizona utilities to address tax savings from the enactment of U.S. tax reform beginning January 1, 2018, through one of various means. In April 2018, Southwest filed an application with the ~~Arizona Corporation Commission (“ACC”)~~ACC, requesting approval for a tax refund process or, in ~~May 2016 requesting an increase in authorized annual operating revenues of approximately $32 million, or 4.2%,~~the alternative, the authority to file a general rate case to reflect ~~existing levels~~tax reform. Ultimately, Southwest was instructed to refund customers a one-time credit to reflect the tax savings from January through July 2018, effective with Southwest’s August 2018 billing cycles. In addition, effective August 2018, per-therm surcredits were established and are effective until new cost-of-service rates are implemented following the conclusion of ~~expense and requested returns, in addition to reflecting capital investments made by Southwest since June 2010. The application requested an overall~~the general rate of return of 7.82% on an original cost rate base of $1.336 billion, a 10.25% 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,case, 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~~May 2019. These undertakings are expected to refund $20 million annually, as compared to rate levels established in ~~February 2017, and~~ the ~~ACC approved the settlement agreement in~~previously concluded general rate case effective 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~~Through September 2019, Southwest has reflected relevant proportional amounts associated with the ~~exception of the return on common equity, which was set at 9.50%. Depreciation expense~~annualized $20 million as a reduction in revenue and is tracking monthly differences between amounts expected to be ~~reduced by $44.7 million, for a combined net annual operating income increase~~returned and amounts actually returned to customers, which has resulted in an asset balance of ~~$60.7 million. Other key elements~~approximately $287,000 as of September 30, 2019. See related discussion above with regard to 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 replacement program, and a continuation of the current decoupled rate design, excluding a 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 to defer changes in property tax expense for recovery or return in the next general rate case. New rates were effective April 2017. The settlement also includes a three-year rate case moratorium prohibiting a new application to adjust base rates from being filed prior to May 2019.

~~LNG (“~~DCA.

Liquefied Natural ~~Gas”~~Gas (“LNG”) Facility. In January 2014, Southwest filed an application with the ACC seeking preapproval to construct, operate, and maintain a 233,000 dekatherm LNG facility in southern Arizona. This facility is intended to enhance service reliability and flexibility inrelated to natural gas deliveries in the southern Arizona area by providing a local storage option, to be operated by Southwest and connected directly to its distribution system. InA modified ACC order in December ~~2014, Southwest received an order from the ACC grantingpre-approval~~ ~~of Southwest’s application to construct the LNG facility~~2016, following land purchase and the deferral of costs, up to $50 million. Following the December 2014 preapproval, Southwest purchased the site for the facility and completed detailed engineering design specifications for the purpose of soliciting bidsbid solicitation for the engineering, procurement, and construction ~~(“EPC”)~~ of the ~~facility. Southwest solicited requests~~facility, granted approval for ~~proposals for~~construction



	43



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

and deferral of costs not to exceed $80 million. Construction began during the ~~EPC phase~~third quarter of 2017 and the structures were completed in the third quarter of 2019. Testing of the ~~project,~~facility is in progress and ~~in October 2016 made a filing with~~is expected to be completed during the ~~ACC to modify the previously issued Order to update thepre-approved~~ ~~costs to reflect anot-to-exceed~~ ~~amount~~winter of ~~$80 million, which was approved by the ACC in December 2016.~~2019/2020. Through September ~~2017,~~2019, Southwest has incurred approximately ~~$21.7~~$72 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.~~

COYL Program. Southwest received approval, in connection with ~~an earlier~~its 2010 Arizona general rate case, to implement a program to conduct leak surveys, and if leaks were present, to replace and relocate service lines and meters for Arizona customers whose meters were set off from the customer’s home, ~~which is not~~representing a ~~traditional~~non-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~~ ~~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.~~non-leaking COYLs. The surcharge is designed to be 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,~~2019, Southwest requested to ~~establish an annual~~increase its surcharge ~~to collect $1.8~~revenue by $3.2 million (to $6.7 million overall) related to the revenue requirement associated with ~~$12.1~~$26.6 million in capital projects completed under both ~~Phase I~~phases during 2018. The Staff issued a report and ~~Phase II during 2016. In June 2017,~~recommendation to the ACC ~~issued a decision approving~~that the current COYL program surcharge ~~application. All capital work completed~~revenue be suspended, and that the program be reviewed in ~~earlier years was incorporated in~~conjunction with Southwest’s ~~Arizona rate base in connection with the recently completed~~pending general rate case, ~~proceeding,~~resolution of which is expected in the second quarter of 2020. The ACC issued an Order in October authorizing Southwest to retain the existing annual surcharge revenue of $3.5 million and to review the program as part of the pending rate case. ACC review of the $26.6 million of capital investment from 2018, including potential cost recovery, will now occur as part of the pending general rate case. With the supplemental filing discussed ~~above.~~


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

earlier, Southwest is proposing to have the ACC review the estimated $21.1 million of COYL capital projects scheduled to be completed in 2019, including any decision regarding potential cost recovery, as part of the pending rate case as well.

Vintage Steel Pipe ~~Program~~.(“VSP”) Program. Southwest received approval, in connection with its ~~most recent~~2016 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~~is made in February of each year. The surcharge is designed to be revised annually as the program progresses. ~~A Plan~~Southwest replaced approximately 119 miles of ~~Administration (“POA”), which was filed in March of 2017~~vintage steel pipe during 2018 totaling approximately $100 million. In the February 2019 VSP filing, Southwest requested to increase its surcharge revenue by $9.5 million (to $11.9 million) related to 2018 expenditures. The Staff issued a report and ~~was approved~~recommendation to the ACC that the current VSP program surcharge revenue be suspended and that the program be reviewed in conjunction with ~~the~~Southwest’s pending general rate case, ~~outlined~~resolution of which is expected in the ~~VSP~~second quarter of 2020. The ACC issued an Order in October authorizing Southwest to retain the current annual surcharge revenue of $2.4 million and to review the program ~~requirements and established~~as part of the ~~timeline for future project plans and surcharge requests.~~pending rate case. ACC review of the $100 million of capital investment from 2018, including consideration of potential cost recovery, will now occur as part of the pending general rate case. With the supplemental filing discussed earlier, Southwest is ~~currently targeting~~proposing to have the ~~replacement of nearly 40 miles~~ACC review the estimated $103.4 million of VSP ~~during~~capital projects scheduled to be completed in 2019, including potential cost recovery, as part of the pending rate case.

Customer Data Modernization Initiative. Southwest is embarking on an initiative to replace its customer service system and its gas transaction system, each of which is utilized to support all Southwest service territories. Combined, these undertakings are referred to as the Customer Data Modernization Initiative (the “CDMI”). In March 2019, Southwest filed an application with the ACC seeking an accounting order which, if approved, would authorize Southwest to track and defer all costs associated with the CDMI to mitigate adverse financial implications associated with this multi-year initiative. The total cost for the CDMI is estimated at $174 million, approximately $96 million of which would be allocable to the Arizona rate jurisdiction. The initiative is currently expected to be completed in the first half of 2021. A hearing in this matter is scheduled in the first quarter of 2020.

California Jurisdiction

California General Rate Case. Southwest’s existing rates became effective June 2014, and included a Post-Test Year (“PTY”) Ratemaking Mechanism, which allowed for attrition increases of 2.75% annually for 2015 through 2018, after which new rates from a subsequent rate case cycle would have been expected to be in effect. In December 2016, Southwest filed to modify the earlier (2014) general rate case decision to extend the rate case cycle by two years, and received CPUC approval in June 2017, ~~totaling approximately $27~~including extension of the annual 2.75% PTY attrition adjustments for 2019 and 2020.

On August 30, 2019 Southwest filed the previously deferred California general rate case, based on a test year of 2021, seeking authority to increase rates in its California rate jurisdictions. The proposed combined revenue increase of $12.8 million is net of a $10.9 million revenue reduction associated with changes from recent U.S. tax reform, which includes the amortization of $9.8 million (approximately $2 million annually over five years) associated with the difference in authorized income tax expense and actual incurred income tax expense for years 2019 and 2020, which when returned will impact cash flows but is not expected to have an impact on earnings overall. The overall revenue request also includes $1.6 million of excess accumulated deferred income taxes that are proposed to be returned to customers each year until the amount is reset as part of a future rate case. Southwest’s proposal includes a return on common equity of 10.5%, relative to a 53% equity ratio; continuation of the post-test year margin adjustments of 2.75%; implementation of various safety-related programs including a targeted pipe replacement ~~projects during 2018~~program, a meter protection program, including a combination of ~~approximately $100 million.~~

~~California Jurisdiction~~

measures, such as snow sheds, excess flow valves, upgraded meter set piping and



	44



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

upgraded Encoder Receiver Transmitter (“ERT”) protocol; as well as an expansion of the COYL replacement program. The case will be processed throughout 2020, with rates requested to be effective January 2021.

Tax Reform. In its 2017 decision approving Southwest’s request to extend the filing date of its next general rate case, the CPUC also directed Southwest to track income tax expenses resulting from mandatory or elective changes in tax law, procedure, or policy as a result of the extension. The purpose is to identify differences between Southwest’s authorized income tax expenses and its actual incurred income tax expenses. Through the third quarter of 2019, Southwest reflected $3.7 million as a reserve for amounts attributable to the impact of U.S. tax reform on the ratemaking revenue requirement.

Attrition Filing. In November ~~2016,~~2018, Southwest made its latest annual ~~post-test year (“PTY”)~~PTY attrition filing, ~~with the California Public Utilities Commission (“CPUC”),~~ requesting annual revenue increases of ~~$2.1~~$2 million in southern California, ~~$513,000~~$542,000 in northern California, and ~~$256,000~~$271,000 for South Lake Tahoe. This filing was approved in December ~~2016~~2018 and rates were made effective in January ~~2017.~~2019. At the same time, rates were updated to recover the regulatory asset associated with the revenue decoupling mechanism, or margin tracker.

Greenhouse Gas (“GHG”) Compliance. California Assembly Bill Number 32 and the regulations promulgated by the California Air Resources Board, require Southwest, as a covered entity, to comply with all applicable requirements associated with California GHG emissions reporting and the California Cap and Trade Program. The CPUC issued a decision in March 2018 adopting an allocation methodology to distribute the net revenues or costs for years 2015-2017 beginning in the second quarter of 2018. Southwest began amortizing its then existing net cost balance over a 12-month period with recovery rates effective July 2018 for all applicable rate schedules. In addition, for years 2019-2020, the decision directed the adoption of an allocation methodology to distribute the revenue proceeds through a California Climate Credit to active residential customers in April of each year, following initial required credits in October 2018. GHG compliance costs recovered through rates (including transportation customer rates) have no impact on earnings overall.

Customer Data Modernization Initiative. On April 26, 2019, Southwest filed an application with the CPUC seeking authority to establish a two-way, interest bearing balancing account to record costs associated with the CDMI to mitigate adverse financial implications associated with this multi-year project. Approximately $19 million of the total cost for the CDMI would be allocable to the California rate jurisdiction. Southwest filed a separate request to establish a memorandum account while the CPUC considers its application request to establish a two-way balancing account. Effective October 2019, the CPUC granted Southwest’s request, which will allow Southwest to track costs, including operations and maintenance costs and capital-related costs, such as depreciation, taxes, and return associated with California’s portion of the CMDI. The balance tracked will be recorded in a two-way balancing account if Southwest’s original application is approved. Resolution of the application request is expected in the fourth quarter of 2019.

Nevada Jurisdiction

Nevada General Rate ~~Case~~~~. In December 2016,~~Case. Southwest filed ~~to modify the~~its most recent general rate case ~~decision to extend~~with the ~~current rate case cycle by two years, including extension~~PUCN in May 2018 and updated the request following the certification period ending in July 2018. The filing requested a statewide overall revenue increase of ~~the annual PTY attrition adjustments through 2020 from 2018. That latest~~approximately $29.7 million.

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

The rate relief was lower than the amounts requested due to several factors, including the 9.25% granted return on equity, as opposed to a requested 10.3%, and the exclusion from rates at this time of costs attributable to several software applications, albeit allowing the Company to request recovery in its next general rate ~~application by September 2017. Expedited consideration was requested and~~case filing. In response to the PUCN’s decision, management filed a Petition for Reconsideration (the “Petition”) of several rate case issues in ~~June 2017, the CPUC approved the request, thereby extending~~January 2019. The PUCN Staff also filed a Petition for Reconsideration requesting several technical clarifications on the rate case decision with respect to how to calculate the intended results of the decision. The PUCN, in turn, issued a decision regarding both petitions in February 2019 that modified certain parts of the original order, but granted no further rate relief. The modified final decision resulted in a revenue increase of $9.2 million in southern Nevada and a revenue decrease in northern Nevada of $2.1 million. The decision included a reduction in depreciation expense of $800,000 and overall, resulted in a net increase in revenues of $7.1 million and an increase in operating income of $7.9 million. The resulting modified rates became effective March 2019. Management decided to seek judicial review of the PUCN’s rate order, the resolution of which is expected by the end of 2019.

General Revenues Adjustment. As part of the Annual Rate Adjustment (“ARA”) filing ~~deadline. Southwest believes this extension is~~ in 2018, the ~~public interest as it provides~~PUCN authorized rate ~~stability to customers for two additional years consistent~~adjustments associated with the ~~current reasonable rates approved~~General Revenues Adjustment (“GRA”), to recover $5.6 million from customers during 2019. The continuation of the GRA was affirmed as part of the ~~last general~~December 2018 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).~~

~~Nevada Jurisdiction~~

~~General Revenues Adjustment.~~In June 2016, Southwest requested authorization from the Public Utilities Commission of Nevada (“PUCN”) to adjust rates associated with its revenue decoupling mechanism (General Revenues Adjustment, or “GRA”). The filing was approved in December 2016, 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 result in a decrease in collections from customers of $15.4 million, based on the over-recovered balance in the account at the end of April 2017.decision. While there is no impact to net income overall from this rate adjustment, operating cash flows will ~~be reduced~~increase as the associated regulatory ~~liability~~asset balance is ~~refunded.~~

recovered. In



	45



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

June 2019, Southwest made its 2019 ARA filing in which it requested to update the GRA to reflect the current over-collected balances in both southern and northern Nevada. The proposal would provide a decrease in cash flows of approximately $8 million in southern Nevada and an increase of approximately $2 million in northern Nevada, but have no impact to operating margin or earnings overall. Proposed changes related to the 2019 ARA will be considered by the PUCN during the fourth quarter 2019, with rates expected to be effective January 2020.

Infrastructure Replacement ~~Mechanisms.~~Mechanism.In ~~January~~ 2014, the PUCN approved final rules for athe GIR mechanism ~~to defer~~which defers and ~~recover~~recovers certain costs associated with accelerated replacement of qualifying infrastructure that ~~does~~would not otherwise currently provide incremental revenues. Associated with ~~such~~the replacement of various types of pipe infrastructure under the mechanism ~~each year,~~(Early Vintage Plastic Pipe (“EVPP”), COYL, and VSP), generally on an annual basis, Southwest files a ~~Gas Infrastructure Replacement (“GIR”)~~GIR “Advance Application” in May and a “Rate Application,” generally in October. In June 2018, Southwest filed its Advance Application requesting ~~authority~~authorization to replace qualifying infrastructure ~~and files separately as part~~with projects totaling $228 million to be completed over a three-year period (2019-2021), 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 ~~GIR filing~~basis; however, it requested to move to a multi-year approval process for projects to improve operational flexibility and enhance coordination with contractors and governmental agencies. The PUCN issued a decision limiting its approval to the 2019 projects, resulting in an approval of $34.3 million for projects to be completed in 2019 (EVPP $9.3 million, COYL $1.3 million, and VSP $23.7 million).

The Rate Application is generally filed each October to reset the GIR recovery surcharge related to previously approved and completed ~~projects. For~~ projects, ~~approved in 2015 and completed in 2016,~~with new rates becoming effective each January. During the ~~annualized revenue was approximately $4.5 million. In September 2016, Southwest filed~~third quarter of 2018, management proposed to adjust the GIR surcharge ~~to recover~~rate as part of the ~~annual revenue requirement for amounts previously deferred. This~~rate case in lieu of filing a separate application, which was approved and implemented in ~~December 2016 and new rates became effective~~ January 2017. In June 2016, Southwest filed an Advance Application for projects 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. The PUCN issued an Order on the Advance Application in October 2016, approving approximately $57.3 million of replacement work with an annualized revenue requirement estimated at approximately $5.3 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 to be completed. In September 2017, Southwest filed to adjust the GIR surcharge to recover the annual revenue requirement for amounts previously deferred. For projects approved in 2016 and completed by July of 2017


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

~~, the deferred annualized revenue requirement is approximately $8.7 million. This filing~~2019. It is expected to ~~be approved~~result in ~~December 2017 with rates becoming effective January 2018.~~

~~In May 2017,~~incremental annual margin of approximately $6 million. On October 1, 2019, Southwest filed a ~~GIR Advance~~Rate Application ~~with~~to reset the ~~PUCN for projects totaling approximately $66 million that are~~recovery surcharge to include cumulative deferrals through August 31, 2019. This surcharge rate is expected to ~~be completed during 2018. Similar to previous years, the proposed projects consist~~become effective January 2020 and result in a reduction in annual margin 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 be approved as filed and that Southwest be authorized to start replacing COYLsapproximately $7.6 million in southern Nevada and $35,000 in certain situations, and to recover costs through 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 southernnorthern 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.

Conservation and Energy Efficiency (“CEE”). ~~In June 2015, Southwest requested recovery~~ The PUCN allows deferral (and later recovery) of approved conservation and energy efficiency ~~and conservation development and implementation~~ costs, ~~including promotions and incentives~~recovery rates for ~~various programs, as originally approved for deferral by~~which are adjusted in the ~~PUCN effective November 2009. While recovery of initial program costs was approved as~~annual rate adjustment filing. 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 the2018 ARA filing, ~~approved in December 2016,~~ Southwest requested and received modified rates, effective January ~~2017,~~2019, which are expected to result in annualized margin decreases of ~~$1.4 million in northern Nevada and $1.3~~$4.1 million in southern Nevada ~~to return over-collected balances.~~and $58,000 in northern Nevada. There is, however, no anticipated impact to net income overall from these ~~decreases~~changes as amortization expense is reduced by approximately the same amounts. In June 2019, Southwest made its 2019 ARA filing which proposes annualized margin increases of $3.2 million and $880,000 in southern and northern Nevada, respectively. Southwest recently entered into a stipulation and agreement to modify these amounts to $6.2 million and $1.1 million in southern and northern Nevada, respectively, which reflect the recovery of a related but separate program balance to be rolled into customer rates with the effective date. These changes, if approved, would have no impact on earnings overall, as described above. Proposed changes related to the 2019 ARA will ~~also~~ be ~~reduced.~~

considered by the PUCN during the fourth quarter 2019, with rates expected to be effective in January 2020.

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. This includes providing gas~~to provide 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~~Ultimately, the ~~extension of existing facilities~~PUCN issued an order approving Southwest’s proposal to expand natural gas infrastructure to Mesquite, ~~at an estimated cost~~including 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~~approximately $2.8 million. Southwest conducted preliminary design work and began serving certain customers with an approved virtual pipeline network in February 2019, which provides temporary natural gas supply using portions of the approved distribution system and compressed natural gas tanks. It is estimated that permitting and construction of the approach main to ~~convert existing homes~~bring the permanent supply to Mesquite and construction of the remaining approved distribution system could take approximately two years to complete.

In June 2019, Southwest filed for preapproval to construct the infrastructure necessary to expand natural gas service ~~which will~~to Spring Creek, Nevada, and implement a cost recovery methodology to timely recover the associated revenue requirement consistent with the SB 151 regulations. Proposed expansion to the Spring Creek area near Elko, Nevada, consists of an approach main, two regulator stations, and interior backbone plus the extension of the distribution system from the interior backbone system. This area has a population of approximately 16,500, with approximately 20% of the existing 5,000 potential customers expressing interest in taking natural gas service, if available. The total capital investment is estimated to be ~~charged as~~$61.9 million. Resolution of this request is expected in the first quarter of 2020.



	46



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Customer Data Modernization Initiative. In March 2019, Southwest filed a ~~separate surcharge~~request seeking authority to ~~Mesquite customers only.~~establish a regulatory asset to defer the revenue requirement related to the CDMI to mitigate the financial attrition associated with this multi-year project. Of the total estimated cost of the CDMI, approximately $59 million would be allocable to the Nevada rate jurisdictions. A ~~decision~~hearing on this ~~proposal~~matter was held in August 2019 and the PUCN issued its decision in September 2019 denying the Company’s request for regulatory asset treatment, finding that a general rate case is ~~expected within~~ the ~~required210-day~~ ~~time period~~most appropriate venue to address such costs. In response to the PUCN’s decision, Southwest filed a Petition for ~~filings of this type.~~

Reconsideration in October 2019 for which the PUCN has 40 days to issue a decision; otherwise, the petition is deemed denied.

Federal Energy Regulatory Commission (“FERC”) Jurisdiction

~~2018 Expansion.~~ ~~In response to growing demand in the Carson City and South Lake Tahoe areas of northern California and northern Nevada,~~

General Rate Case. Paiute Pipeline Company (“Paiute”) ~~evaluated shipper interest in acquiring additional transportation capacity and executed precedent agreements for incremental transportation capacity with~~, a wholly owned subsidiary of Southwest, ~~during the third quarter of 2016. In October 2016, Paiute initiated~~filed a~~pre-filing~~ ~~review process~~ general rate case application with the FERC ~~for an expansion project, which was approved during~~on May 31, 2019 to update the same month. In July 2017, a certificate application was filed, which included an applicant environmental assessment. The project is anticipated to consist of 8.5 miles of additional transmission pipeline infrastructure at an approximate cost of ~~$18 million. If~~service to reflect recent U.S. tax reform changes, capital investments and other changes in its cost of service since its last general rate case. The request includes an increase in revenue of approximately $7 million, including a proposed 14.84% return on equity relative to a hypothetical capital structure of 56% equity. Paiute is also proposing to continue its current rate structure for its customer categories. Paiute requested rates associated with this filing to be made effective on July 1, 2019; however, the ~~process progresses as planned, a decision should be received by April 2018~~rate increase request was suspended until December 2019. It is not uncommon for suspension/delay to occur related to requests for increases, in order to permit the FERC time to review the proposed changes. Rate decreases associated with the Elko Incremental Facilities Charge; 2010 Expansion Incremental Facilities Surcharge; and the ~~additional facilities could be in place by~~2015 Elko Area Expansion Incremental Facilities Surcharge were placed into effect July 1, 2019. Hearings have been scheduled for June 2020, with a final decision expected before the end of ~~2018.~~


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

2020.

PGA Filings

The rate schedules in all of Southwest’s service territories contain provisions that permit ~~adjustments~~adjustment to rates as the cost of purchased gas changes. These deferred energy provisions and purchased gas adjustment clauses are collectively referred to as “PGA” clauses. Differences between gas costs recovered from customers and amounts paid for gas by Southwest result in over- or under-collections. At September 30, ~~2017,~~2019, under-collections in ~~Arizona~~northern and ~~Northern~~southern Nevada resulted in an asset of ~~approximately $6.2~~$49.8 million and over-collections in ~~Southern Nevada~~Arizona and California resulted in a liability of ~~$15~~$88.0 million on the Company’s and Southwest’s ~~condensed consolidated~~Condensed Consolidated Balance Sheets. The balance ~~sheets. Gas cost rates paid to suppliers have been higher than amounts recovered from customers~~in Arizona reflects the majority (portion associated with interstate transmission into Arizona) of a $49 million refund received during the ~~first nine months~~third quarter of ~~2017, resulting~~2018 by Southwest from El Paso Natural Gas, L.L.C. (“EPNG”), as part of a rate case settlement. Effective May 2019, the ACC approved the return of the EPNG rate case settlement dollars as a special per-therm PGA credit, which resulted in ~~fluctuations~~$12.6 million in credits to Arizona customers since ~~December 31, 2016. Tariff rates have been adjusted~~its establishment and is expected to be in ~~all jurisdictions during this period.~~ place for approximately twelve months.

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

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

   September 30, 2017    December 31, 2016    September 30, 2016
Arizona
   $ 1,324    $ (20,349 )    $ (34,425 )
Northern Nevada
   4,906    (3,339 )    (10,326 )
Southern Nevada
   (13,711 )    (66,788 )    (77,402 )
California
   (1,260 )    2,608    (1,246 )






   $ (8,741 )    $ (87,868 )    $ (123,399 )



	September 30, 2019			December 31, 2018			September 30, 2018
Arizona	$	(84,438	)	$	(72,878	)	$	(70,863	)
Northern Nevada	11,909			4,928			(1,287		)
Southern Nevada	37,895			(5,951		)	(16,125		)
California	(3,592		)	(933		)	(4,748		)
	$	(38,226	)	$	(74,834	)	$	(93,023	)

Capital Resources and Liquidity

~~Cash~~

Historically, cash on hand and cash flows from operations ~~in the past twelve months~~ have ~~generally~~ provided ~~the majority~~a substantial portion of cash used in investing activities (primarily for construction expenditures and property additions). In recent years, ~~certain~~the Company has accelerated pipe replacement ~~has been accelerated to take advantage of bonus depreciation tax incentives and~~activities 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~~previously. This accelerated activity has necessitated the issuance of both debt and equity securities to supplement cash flows from ~~debt refinancing and strategic debt redemptions.~~operations. The ~~Company’s capitalization strategy is~~Company endeavors to maintain an appropriate balance of equity and debt to maintain strong investment-grade credit ratings, which should minimize interest costs.



	47



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Cash Flows

Southwest Gas Holdings, Inc.:

Operating Cash Flows.Cash flows provided by consolidated operating activities decreased ~~$179~~$29 million in the first nine months of ~~2017~~2019 as compared to the same period of ~~2016.~~2018. The decline in ~~operating~~ cash flows ~~was~~ primarily ~~attributable to the change in deferred~~resulted from a reduction/return of amounts under purchased gas ~~costs noted above. Refer to~~~~Results~~adjustment mechanisms, offset by increases in net income, benefits from depreciation, and impacts of ~~Natural Gas Operations~~ ~~and~~~~Rates and Regulatory Proceedings~~working capital components overall (including regulatory balances, such as the Arizona DCA, that are recovered or returned over twelve months or less).

Investing Cash Flows.Cash used in consolidated investing activities increased ~~$35~~$162 million in the first nine months of ~~2017~~2019 as compared to the same period of ~~2016.~~2018. 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~~activity, as well as the remittance of ~~$17 million to facilitate~~ a ~~construction services acquisition.~~

portion of purchase consideration previously held back in association with the acquisition of Linetec (see Note 12 – Business Acquisitions).

Financing Cash Flows.Net cash provided by consolidated financing activities increased ~~$195~~$108 million in the first nine months of ~~2017~~2019 as compared to the same period of ~~2016.~~2018. 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~~common stock under both an earlier equity registration and a recent Equity Shelf Program initiated in May 2019, in addition to higher payments in the prior year by Southwest of short-term balances under its revolving credit facility. Additionally, retirements of long-term debt arrangements were higher in the prior period; whereas, dividends were higher in the current period due to both an increase in the dividend rate and the number of shares outstanding in the current period. See Note 6 – Common Stock and Note 7 – Long-Term Debt.

The Company received approximately $121 million in ~~senior notes. The Company also issued approximately $12 million~~stock proceeds during ~~2017 in stock under its Equity Shelf Program. See also~~~~Note 5 – 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 months of ~~2017 as compared to the same period of 2016 as a result of an increase in the quarterly dividend rate~~2019 under its Equity Shelf programs and ~~an increase in the number of shares outstanding.~~

~~The Company~~ issued approximately ~~103,000 additional~~96,000 shares of common stock ~~collectively~~ through the ~~Restricted Stock/Unit~~Dividend Reinvestment and Stock Purchase Plan ~~and the Management Incentive Plan.~~

~~Southwest Gas Corporation:~~

~~Operating Cash Flows.~~Cash flows provided by operating activities decreased $172 million in the first nine months of 2017 as compared to the same period of 2016. The decline in operating cash flows was primarily attributable to the change in deferred purchased gas costs as discussed above. Refer to~~Results of Natural Gas Operations~~ ~~and~~~~Rates and Regulatory Proceedings~~.

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

~~Financing Cash Flows.~~Net cash provided by financing activities increased $211 million in the first nine months of 2017 as compared to the same period of 2016. 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(“DRSPP”), from ~~the issuance of $300 million in senior notes as discussed above. The current period included capital contributions from Southwest Gas Holdings, Inc.~~

which it raised approximately $8.1 million.

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

However, the holding company may raise funds through stock issuance or other external financing sources in support of each business segment, as discussed in Note 6 – Common Stock.

Southwest Gas Corporation:

Operating Cash Flows. Cash flows provided by operating activities decreased $18 million in the first nine months of 2019 as compared to the same period of 2018. The decline in operating cash flows was attributable to impacts related to deferred purchased gas costs noted above, offset by an increase in net income, benefits from depreciation, and the impacts of working capital components overall.

Investing Cash Flows. Cash used in investing activities increased $99 million in the first nine months of 2019 as compared to the same period of 2018. The change was primarily due to additional construction expenditures, as indicated above.

Financing Cash Flows. Net cash provided by financing activities increased $90 million in the first nine months of 2019 as compared to the same period of 2018. The increase was primarily due to an increase in capital contributions from Southwest Gas Holdings, Inc. compared to the prior period, and higher payments in the prior year related to short-term balances under Southwest’s revolving credit facility. As indicated above, Southwest utilized funds from the $300 million of Senior Notes issued in May 2019 to reduce amounts then outstanding under its revolving credit facility and commercial paper program. Dividends to the parent holding company were greater in the current period.

Gas Segment Construction Expenditures and Financing

During the twelve-month period ended September 30, ~~2017,~~2019, construction expenditures for the natural gas operations segment were ~~$515~~$784 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~~$365 million during this time, and provided approximately ~~57%~~42% of construction expenditures and dividend requirements.

~~Southwest~~

Management estimates natural gas segment construction expenditures during the three-year period ending December 31, ~~2019~~2021 will be ~~between $1.6 billion and $1.8~~approximately $2.1 billion. Of this amount, approximately ~~$570~~$730 million is ~~expected~~scheduled to be incurred in ~~2017.~~2019. Southwest plans to continue ~~as appropriate,~~ to request regulatory support as necessary and appropriate 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~~Significant replacement activities are expected to continue well beyond the next few years. See alsoRates and Regulatory Proceedings for discussion of Nevada infrastructure, Arizona COYL and anVSP programs, the Arizona LNG ~~facility.~~facility, and Spring Creek in Nevada. During the three-year period, cash flows from operating activities of Southwest are expected to provide approximately ~~60%~~45% to ~~70%~~50% of the funding for gas operations total construction expenditures and dividend requirements.



	48



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Any additional cash requirements are expected to be provided by existing credit facilities, equity contributions from the Company, and/or other external financing sources. The timing, types, and amounts of any additional external financings will be dependent on a number of factors, including the cost of gas purchases, conditions in the capital markets, timing and amounts of rate relief, timing differences between U.S. federal taxes embedded in customer rates and amounts implemented under tax reform, as well as growth levels in Southwest’s service areas and earnings. External financings could include the issuance of debt securities, bank and other short-term borrowings, and other forms of financing.

In ~~March 2017,~~May 2019, Southwest issued $300 million in 4.15% Senior Notes at a discount of 0.051%. The notes will mature in June 2049. A portion of the proceeds were used to repay amounts then outstanding under Southwest’s credit facility and commercial paper program.

In May 2019, the Company filed with the ~~Securities Exchange Commission (“SEC”)~~SEC an automatic shelf registration statement for the offer and sale of up to ~~$150~~$300 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,~~May 8, 2019, between the Company and BNY Mellon Capital Markets, LLC (the ~~“Equity~~Equity Shelf ~~Program”)~~Program discussed above). ~~Sales~~The Company issued $99.3 million under this multi-year program during the second and third quarters 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.~~2019. Net proceeds from the ~~sale~~sales of shares of common stock under the Equity Shelf Program are intended for general corporate purposes, including the acquisition of property for the construction, completion, extension or improvement of pipeline systems and facilities located in and around the communities served by Southwest.

In March 2018, Southwest ~~serves.~~

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 an earlier automatic shelf registration statement with the SEC for the offer and sale of up to $150 million of common stock from time to time in at-the-market offerings under the related prospectus and sales agency agreement. The Company issued the full capacity of this equity program, concluding during the quarter ended March 31, 2019.

During the ~~nine~~twelve months ended September 30, ~~2017, 147,077~~2019, 1,424,784 shares were issued inat-the-market offerings at an average price of ~~$80.07~~$85.92 per share with gross proceeds of ~~$11.8~~$122.4 million, agent commissions of ~~$118,000,~~$1.2 million, and net proceeds of ~~$11.7 million.~~$121.2 million under the Company’s equity shelf programs noted above. SeeNote 56 – Common Stock for more information.

Bonus Depreciation

In ~~December 2015,~~2017, with the ~~Protecting Americans from Tax Hikes Act~~enactment of ~~2015 (“PATH Act”) was enacted extending~~U.S. tax reform, 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 most public utility property. The Company estimates bonus depreciation will defer the payment of approximately ~~$29~~$30 million ($4 million of which relates to utility operations) of federal income taxes for ~~2017, resulting in a minimal amount of federal income tax being paid.~~

2019.

Dividend Policy

Dividends are payable on the Company’s common stock at the discretion of the Board of Directors ~~(“Board”~~(the “Board”). In setting the dividend rate, the Board currently targets a payout ratio of 55% to 65% of consolidated earnings per share and considers, among other factors, current and expected future earnings levels, our ongoing capital expenditure plans and expected external funding needs, ~~our payout ratio, and~~in addition to our ability to maintain strong credit ratings and liquidity. The Company has paid dividends on its common stock since 1956 and has increased that dividend each year since 2007. In February ~~2017,~~2019, the Board elected to increase the quarterly dividend from ~~$0.45~~$0.52 to ~~$0.495~~$0.545 per share, representing a ~~10%~~4.8% increase, effective with the June ~~2017~~2019 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, as well as plant investment, have historically had the most significant impact on liquidity.

On an interim basis, Southwest defers over- or under-collections of gas costs to PGA balancing accounts. In addition, Southwest uses this mechanism to either refund amounts over-collected or recoup amounts under-collected as compared to the price paid for natural gas during the period since the last PGA rate change went into effect. At September 30, ~~2017,~~2019, the combined balance in the PGA accounts totaled an over-collection of ~~$8.7~~$38 million. SeePGA Filingsfor more information.

~~In March 2017,~~



	49



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Southwest Gas Holdings, Inc. ~~entered into~~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 30, ~~2017, $27.5 million was~~2019, no borrowings were outstanding onunder 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~~which 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 long-term portion of the credit facility (including a commercial paper program, as noted below) during the first nine months of ~~2017~~2019 was $150 million. AtAs of September 30, ~~2017,~~2019, $150 million was outstanding under the long-term portion of the facility. The maximum amount outstanding on the ~~long-term and $83~~short-term portion of the credit facility during the first nine months of 2019 was $216 million. As of September 30, 2019, $30 million ~~was~~of borrowings were outstanding on the short-term portion of this credit facility. The credit facility can be used as necessary to meet liquidity requirements, including temporarily financing under-collected PGA balances, if any, or meeting the refund needs of over-collected balances. ~~This credit facility~~It 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.

As indicated, any additional cash requirements would include the existing credit facility, equity contributions from the Company, and/or other external financing sources.

Southwest has a $50 million commercial paper program. Any issuance under the commercial paper program is supported by Southwest’s current revolving credit facility and, therefore, does not represent additional borrowing capacity. Any borrowing under the commercial paper program during 2019 will be designated as long-term debt. Interest rates for the commercial paper program are calculated at the current commercial paper rate during the borrowing term. At September 30, ~~2017, no borrowings were~~2019, there was $50 million outstanding under this program.

Centuri has a ~~$300 million~~senior secured revolving credit and term loan facility ~~that~~with borrowing capacity of $590 million (refer to Note 7 – Long-Term Debt). 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$325 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 $265 million. The $590 million credit and term loan facility expires in November 2023. It is secured by substantially all of Centuri’s assets except those explicitly excluded under the terms of the agreement (including owned real estate and certain certificated vehicles). Centuri assets securing the facility at September 30, 2019 totaled $1.3 billion. The maximum amount outstanding on the revolving credit facility during the first nine months of ~~2017~~2019 was ~~$104~~$99 million. AtAs of September 30, ~~2017, $81.3~~2019, $89 million was outstanding on the ~~secured~~ revolving credit facility. As of September 30, 2019, there was $248 million outstanding on the term loan portion of the facility. Also at September 30, ~~2017,~~2019, there was approximately ~~$52~~$215 million, net of letters of credit, available under the line of credit.

~~The following table sets forth the ratios~~

It is currently anticipated that LIBOR may be discontinued as a benchmark or reference rate after 2021. As of ~~earnings to fixed charges~~September 30, 2019, no borrowings were outstanding for the ~~Company. Due~~holding company under its credit facility (see Note 8 – Short-Term Debt), and therefore, there was no related indebtedness with reference to LIBOR. However, all of Southwest’s outstanding borrowings of $130 million under its credit facility (other than from its commercial paper program) and $218 million of Centuri’s indebtedness under its facility have interest rates with reference to LIBOR and maturity dates that extend beyond 2021. The outstanding amounts reflect approximately 6% of Southwest’s total debt and 14% of total debt (including current maturities) for the Company overall. In order to mitigate the impact of the discontinuation on the Company’s financial condition and results of operations, Southwest and Centuri will continue to monitor developments with respect to alternative rates and work with lenders to determine the appropriate alternative reference rate for variable rate indebtedness. However, at this time the Company and Southwest can provide no assurances as to the ~~seasonal nature~~impact a LIBOR discontinuation will have on their financial condition or results 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

~~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.~~

operations. Any alternative rate may be less predictable or less attractive than LIBOR.



	50



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

Forward-Looking Statements

This quarterly report contains statements which constitute “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 (“Reform Act”). All statements other than statements of historical fact included or incorporated by reference in this quarterly report are forward-looking statements, including, without limitation, statements regarding the Company’s plans, objectives, goals, intentions, projections, strategies, future events or performance, negotiations, and underlying assumptions. The words “may,” “if,” “will,” “should,” “could,” “expect,” “plan,” “anticipate,” “believe,” “estimate,” “predict,” “project,” “continue,” “forecast,” “intend,” “endeavor,” “promote,” “seek,” and similar words and expressions are generally used and intended to identify forward-looking statements. For example, statements regarding operating margin patterns, customer growth, the composition of our customer base, price volatility, seasonal patterns, payment of debt, ~~interest savings,~~ the Company’s COLI strategy, replacement market and new construction market, expected impacts of valuation adjustments associated with the redeemable noncontrolling interest in Linetec, the impacts of the U.S. tax reform including disposition in regulatory proceedings and bonus depreciation tax deductions, ~~amount~~the impact of recent PHMSA rulemaking, the amounts and timing for completion of estimated future construction expenditures, including the LNG facility in southern Arizona, ~~the cost of the 2018 Paiute expansion project in northern Nevada and northern California,~~plans to pursue infrastructure programs or programs under SB151 legislation, forecasted operating cash flows and results of operations, net earnings impacts from gas infrastructure replacement surcharges, funding sources of cash requirements, amounts generally expected to be reflected in ~~2017~~2019 or future period revenues from regulatory rate proceedings including amounts ~~resulting~~requested from the ~~settled~~recently filed Arizona general rate case, the approved recovery of the Arizona DCA balance, the outcome of judicial review of the recently concluded Nevada rate case, 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~~various financing instruments and stock under the Equity Shelf Program or otherwise, future dividend increases and the Board’s current target dividend payout ratio, pension and ~~post-retirement~~postretirement 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,~~programs, statements regarding future gas prices, gas purchase contracts and derivative financial instruments, recoverability of regulatory assets, the impact of certain legal proceedings, and the timing and results of future rate hearings, including final resolution for recovery of the CDMI in all jurisdictions, 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, governmental or regulatory policy regarding natural gas or alternative energy, the regulatory support for ongoing infrastructure programs, the timing and amount of rate relief, the timing and methods determined by regulators to refund amounts to customers resulting from U.S. tax reform, changes in rate design, variability in volume of gas or transportation service sold to customers, changes in gas procurement practices, changes in capital requirements and funding, the impact of conditions in the capital markets on financing costs, the impact of variable rate indebtedness associated with a discontinuance of LIBOR including in relation to amounts of indebtedness then outstanding, changes in construction expenditures and financing, changes in operations and maintenance expenses, effects of pension expense forecasts, accounting changes and regulatory treatment related thereto, currently unresolved and future liability claims, changes in pipeline capacity for the transportation of gas and related costs, results of Centuri bid work, the impact of weather on Centuri’s operations, Centuri’s projections about the acquired business’ earnings (including accretion within the first twelve months) and future acquisition-related costs, impacts of changes in value of the redeemable noncontrolling interest if at other than fair value, resolution of events subject to cash consideration held back associated with representations, warranties, and other estimates including working capital adjustments related to the Linetec acquisition and impacts from final purchase accounting related thereto, Centuri ~~construction~~utility infrastructure expenses, differences between actual and originally expected outcomes of Centuri bid or other fixed-price construction agreements, outcomes from contract and change order negotiations, ~~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 work stoppages or reduction, the ~~recent work stoppage,~~result of productivity inefficiencies from regulatory requirements or otherwise, delays in commissioning individual projects, acquisitions, and management’s plans related thereto, competition, our ability to raise capital in external financings, our ability to continue to remain within the ratios and other limits subject to our debt covenants, and ongoing evaluations in regard to goodwill and other intangible assets. In addition, the Company can provide no assurance that its discussions regarding certain trends relating to its financing and operating expenses will continue or cease to continue in future periods. For additional information on the risks associated with the Company’s business, seeItem 1A. Risk Factors andItem 7A. Quantitative and Qualitative Disclosures About Market Risk in the Annual Report onForm ~~10-K~~10‑K for the year ended December 31, ~~2016.~~

2018.



	51



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

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~~2018 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 30, ~~2017,~~2019, management of Southwest Gas Holdings, Inc., including the Chief Executive Officer and Chief Financial Officer, ~~believe~~believes 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 quarter of ~~2017~~2019 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 30, ~~2017,~~2019, management of Southwest Gas Corporation, including the Chief Executive Officer and Chief Financial Officer, ~~believe~~believes Southwest’s disclosure controls and procedures are effective at attaining the level of reasonable assurance noted above.

There have been no changes in Southwest’s internal ~~controls~~control over financial reporting (as defined in Rules13a-15(f) and15d-15(f) of the Exchange Act) during the third quarter of ~~2017~~2019 that have materially affected, or are likely to materially affect Southwest’s internal ~~controls~~control over financial reporting.

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.

ITEM 4. MINE SAFETY DISCLOSURES Not applicable.

ITEM 5. OTHER INFORMATION None.

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

	52

~~ITEM 4.~~
	~~MINE SAFETY DISCLOSURES~~~~Not applicable.~~
SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2019

~~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)~~2.01	-	Agreement and Plan of Merger entered into on September 20, 2019 by Southwest Gas Holdings, Inc., a California corporation and Southwest Gas Holdings, Inc., a Delaware corporation. Incorporated herein by reference to Exhibit 2.1 to Form 8-K12B dated September 20, 2019, File No. 001-37976.
		—
Exhibit 3.01	-	~~Amendment to Articles~~Certificate of Incorporation of Southwest Gas Holdings, Inc., a Delaware corporation. Incorporated herein by reference to Exhibit 3.1 to Form 8-K12B dated September 20, 2019, File No. 001-37976.

Exhibit ~~3(ii)~~3.02	-	—		~~Amended and Restated~~ Bylaws of Southwest Gas Holdings, Inc., a Delaware corporation. Incorporated herein by reference to Exhibit 3.2 to Form 8-K12B dated September 20, 2019, File No. 001-37976.

Exhibit 10.01*4.01	-	—		~~Centuri 2017 Short-Term Incentive Plan.~~
~~Exhibit 12.01~~		—		~~Computation~~Form of ~~Ratios of Earnings to Fixed Charges –~~ Southwest Gas Holdings, Inc. Common Stock Certificate. Incorporated herein by reference to Exhibit 4.1 to Form 8-K12B dated September 20, 2019, File No. 001-37976.

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

Exhibit 31.02	-	—		Section 302 Certifications–Southwest Gas ~~Corporation.~~Corporation

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

Exhibit 32.02	-	—		Section 906 Certifications–Southwest Gas ~~Corporation.~~Corporation

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

Exhibit 101SCH		—	-	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

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

~~Management Incentive Plan~~


	53



SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, ~~2017~~2019

SIGNATURES

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

Southwest Gas Holdings, Inc.

(Registrant)

Date: November ~~7, 2017~~

6, 2019

~~/s/ GREGORY J. PETERSON~~

~~Gregory J. Peterson~~

/s/ LORI L. COLVIN

Lori L. Colvin

Vice President/Controller and Chief Accounting Officer

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

Southwest Gas Corporation

(Registrant)

Date: November ~~7, 2017~~

6, 2019

~~/s/ GREGORY J. PETERSON~~

~~Gregory J. Peterson~~

/s/ LORI L. COLVIN

Lori L. Colvin

Vice President/Controller and Chief Accounting Officer



	54


	SEPTEMBER 30, 2017			DECEMBER 31, 2016
ASSETS
Utility plant:
Gas plant	$	6,440,547		$	6,193,564
Less: accumulated depreciation		(2,218,796	)		(2,172,966	)
Acquisition adjustments, net		81			196
Construction work in progress		164,030			111,177

Net utility plant		4,385,862			4,131,971

Other property and investments		369,303			342,343

Current assets:
Cash and cash equivalents		59,152			28,066
Accounts receivable, net of allowances		301,792			285,145
Accrued utility revenue		34,100			76,200
Income taxes receivable, net		5,462			4,455
Deferred purchased gas costs		6,230			2,608
Prepaids and other current assets		132,182			136,833

Total current assets		538,918			533,307

Noncurrent assets:
Goodwill		147,865			139,983
Deferred income taxes		1,467			1,288
Deferred charges and other assets		411,655			432,234

Total noncurrent assets		560,987			573,505

Total assets	$	5,855,070		$	5,581,126

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
Additionalpaid-in capital		924,213			903,123
Accumulated other comprehensive income (loss), net		(42,818	)		(48,008	)
Retained earnings		784,934			759,263

Total Southwest Gas Holdings, Inc. equity		1,715,691			1,663,490
Noncontrolling interest		(2,295	)		(2,217	)

Total equity		1,713,396			1,661,273
Redeemable noncontrolling interest		—			22,590
Long-term debt, less current maturities		1,731,981			1,549,983

Total capitalization		3,445,377			3,233,846

Current liabilities:
Current maturities of long-term debt		28,453			50,101
Short-term debt		110,500			—
Accounts payable		159,382			184,669
Customer deposits		70,162			72,296
Income taxes payable		1,543			1,909
Accrued general taxes		48,998			42,921
Accrued interest		24,543			17,939
Deferred purchased gas costs		14,971			90,476
Other current liabilities		197,854			168,064

Total current liabilities		656,406			628,375

Deferred income taxes and other credits:
Deferred income taxes and investment tax credits		894,011			840,653
Accumulated removal costs		312,000			308,000
Other deferred credits and other long-term liabilities		547,276			570,252

Total deferred income taxes and other credits		1,753,287			1,718,905


Total capitalization and liabilities	$	5,855,070		$	5,581,126


	NINE MONTHS ENDED						TWELVE MONTHS ENDED
	SEPTEMBER 30						SEPTEMBER 30
	2017			2016			2017			2016
CASH FLOW FROM OPERATING ACTIVITIES:
Net income	$	97,546		$	87,361		$	163,240		$	154,059
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		189,089			217,764			260,457			286,977
Deferred income taxes		49,409			43,702			74,439			86,526
Changes in current assets and liabilities:
Accounts receivable, net of allowances		(15,330	)		28,531			(13,765	)		(17,889	)
Accrued utility revenue		42,100			41,700			(1,100	)		(800	)
Deferred purchased gas costs		(79,127	)		81,389			(114,658	)		79,460
Accounts payable		(26,771	)		(24,942	)		19,866			10,445
Accrued taxes		4,689			(7,055	)		38,084			(11,033	)
Other current assets and liabilities		43,044			12,022			3,590			22,034
Gains on sale		(1,452	)		(4,117	)		(4,483	)		(4,200	)
Changes in undistributed stock compensation		9,199			4,347			10,308			5,142
AFUDC		(2,077	)		(1,893	)		(2,473	)		(2,890	)
Changes in other assets and deferred charges		(14,470	)		3,926			(1,436	)		4,183
Changes in other liabilities and deferred credits		3,395			(4,813	)		(10,239	)		702

Net cash provided by operating activities		299,244			477,922			421,830			612,716

CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions		(449,998	)		(404,388	)		(575,141	)		(555,819	)
Acquisition of businesses, net of cash acquired		—			(17,000	)		—			(17,000	)
Changes in customer advances		(1,951	)		5,445			504			9,445
Miscellaneous inflows		9,160			7,965			14,234			4,726

Net cash used in investing activities		(442,789	)		(407,978	)		(560,403	)		(558,648	)

CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net		11,563			530			11,505			507
Dividends paid		(68,503	)		(61,950	)		(89,870	)		(81,138	)
Centuri distribution to redeemable noncontrolling interest		(204	)		(99	)		(544	)		(198	)
Issuance of long-term debt, net		104,308			408,946			119,308			420,946
Retirement of long-term debt		(100,240	)		(196,351	)		(159,162	)		(240,999	)
Change in credit facility and commercial paper		145,000			(150,000	)		150,000			(97,000	)
Change in short-term debt		110,500			(18,000	)		110,500			—
Principal payments on capital lease obligations		(796	)		(1,125	)		(1,025	)		(1,449	)
Redemption of Centuri shares from noncontrolling parties		(23,000	)		—			(23,000	)		—
Withholding remittance—share-based compensation		(3,176	)		(2,119	)		(3,176	)		(2,164	)
Other		(1,104	)		(605	)		(2,068	)		(60	)

Net cash provided by (used in) financing activities		174,348			(20,773	)		112,468			(1,555	)

Effects of currency translation on cash and cash equivalents		283			(14	)		103			(318	)

Change in cash and cash equivalents		31,086			49,157			(26,002	)		52,195
Cash and cash equivalents at beginning of period		28,066			35,997			85,154			32,959

Cash and cash equivalents at end of period	$	59,152		$	85,154		$	59,152		$	85,154

Supplemental information:
Interest paid, net of amounts capitalized	$	45,771		$	47,134		$	66,077		$	68,445
Income taxes paid (received)		3,687			6,530			(21,875	)		9,899


	SEPTEMBER 30,			DECEMBER 31,
	2017			2016
ASSETS
Utility plant:
Gas plant	$	6,440,547		$	6,193,564
Less: accumulated depreciation		(2,218,796	)		(2,172,966	)
Acquisition adjustments, net		81			196
Construction work in progress		164,030			111,177

Net utility plant		4,385,862			4,131,971

Other property and investments		115,841			108,569

Current assets:
Cash and cash equivalents		46,467			19,024
Accounts receivable, net of allowances		68,028			111,845
Accrued utility revenue		34,100			76,200
Income taxes receivable, net		6,440			4,455
Deferred purchased gas costs		6,230			2,608
Prepaids and other current assets		118,587			126,363

Total current assets		279,852			340,495

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

Total noncurrent assets		404,037			1,000,091

Total assets	$	5,185,592		$	5,581,126

CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock	$	49,112		$	49,112
Additionalpaid-in capital		917,581			897,346
Accumulated other comprehensive income (loss), net		(42,299	)		(45,639	)
Retained earnings		606,007			767,061

Total Southwest Gas Corporation equity		1,530,401			1,667,880
Discontinued operations—construction servicesnon-owner equity		—			15,983
Long-term debt, less current maturities		1,520,790			1,375,080

Total capitalization		3,051,191			3,058,943

Current liabilities:
Current maturities of long-term debt		—			25,000
Short-term debt		83,000			—
Accounts payable		92,257			138,229
Customer deposits		70,162			72,296
Accrued general taxes		48,998			42,921
Accrued interest		24,406			17,395
Deferred purchased gas costs		14,971			90,476
Payable to parent		2,560			—
Other current liabilities		109,705			95,999

Total current liabilities		446,059			482,316

Deferred income taxes and other credits:
Deferred income taxes and investment tax credits, net		853,682			806,109
Accumulated removal costs		312,000			308,000
Other deferred credits and other long-term liabilities		522,660			545,143
Discontinued operations—construction services—liabilities		—			380,615

Total deferred income taxes and other credits		1,688,342			2,039,867

Total capitalization and liabilities	$	5,185,592		$	5,581,126


(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


September 30, 2017 Instrument	Balance Sheet Location	Asset Derivatives		Liability Derivatives			Net Total
Swaps	Prepaids and other current assets	$	56	$	(22	)	$	34
Swaps	Other current liabilities		27		(1,899	)		(1,872	)
Swaps	Other deferred credits		1		(768	)		(767	)

Total		$	84	$	(2,689	)	$	(2,605	)


December 31, 2016 Instrument	Balance Sheet Location	Asset Derivatives		Liability Derivatives			Net Total
Swaps	Deferred charges and other assets	$	899	$	(54	)	$	845
Swaps	Prepaids and other current assets		3,551		(19	)		3,532

Total		$	4,450	$	(73	)	$	4,377


	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. Equity
							Accumulated												Redeemable
					Additional		Other						Non-						Noncontrolling
	Common Stock				Paid-in		Comprehensive			Retained			controlling						Interest
(In thousands, except per share amounts)	Shares		Amount		Capital		Income (Loss)			Earnings			Interest			Total			(Temporary Equity)
DECEMBER 31, 2016		47,482	$	49,112	$	903,123	$	(48,008	)	$	759,263		$	(2,217	)	$	1,661,273		$	22,590
Common stock issuances		250		250		21,090											21,340
Net income (loss)											97,376			(78	)		97,298			248
Redemption value adjustments											(355	)					(355	)		355
Foreign currency exchange translation adj.								1,850									1,850			11
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
Amounts reclassified to net income, net of tax (FSIRS)								1,554									1,554
Centuri dividend to redeemable noncontrolling interest																				(204	)
Dividends declared
Common: $1.485 per share											(71,350	)					(71,350	)

SEPTEMBER 30, 2017		47,732	$	49,362	$	924,213	$	(42,818	)	$	784,934		$	(2,295	)	$	1,713,396		$	—


	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


	Three Months Ended September 30, 2017									Three 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:
Amortization of prior service cost	$	333		$	(126	)	$	207		$	333		$	(126	)	$	207
Amortization of net actuarial (gain)/loss		6,362			(2,418	)		3,944			6,767			(2,571	)		4,196
Regulatory adjustment		(5,734	)		2,179			(3,555	)		(6,122	)		2,326			(3,796	)

Pension plans other comprehensive income (loss)		961			(365	)		596			978			(371	)		607
FSIRS (designated hedging activities):
Amounts reclassifed into net income		835			(317	)		518			835			(317	)		518

FSIRS other comprehensive income		835			(317	)		518			835			(317	)		518

Total other comprehensive income (loss) - Southwest Gas Corporation		1,796			(682	)		1,114			1,813			(688	)		1,125

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

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

Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	2,808		$	(682	)	$	2,126		$	1,575		$	(688	)	$	887


	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


	Defined Benefit Plans									FSIRS
	Before-Tax			Tax (Expense) Benefit (8)			After-Tax			Before-Tax			Tax (Expense) Benefit (8)			After-Tax			AOCI
Beginning Balance AOCI December 31, 2016	$	(57,613	)	$	21,893		$	(35,720	)	$	(15,999	)	$	6,080		$	(9,919	)	$	(45,639	)

FSIRS amounts reclassified from AOCI (5)		—			—			—			2,507			(953	)		1,554			1,554
Amortization of prior service cost (6)		1,001			(380	)		621			—			—			—			621
Amortization of net actuarial loss (6)		19,084			(7,252	)		11,832			—			—			—			11,832
Regulatory adjustment (7)		(17,204	)		6,537			(10,667	)		—			—			—			(10,667	)

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

Ending Balance AOCI September 30, 2017	$	(54,732	)	$	20,798		$	(33,934	)	$	(13,492	)	$	5,127		$	(8,365	)	$	(42,299	)


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


	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		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
Construction revenues	$	339,790	$	838,038	$	301,040	$	1,127,982
Operating expenses:
Construction expenses		300,611		757,919		266,504		1,009,188
Depreciation and amortization		13,409		43,351		12,318		58,368

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

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

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

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


	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


	Twelve Months Ended September 30,
	2017		2016
	(Thousands of dollars)
Gas operating revenues	$	1,276,308	$	1,376,388
Net cost of gas sold		334,888		460,836

Operating margin		941,420		915,552
Operations and maintenance expense		413,140		400,222
Depreciation and amortization		212,693		228,609
Taxes other than income taxes		56,221		51,810

Operating income		259,366		234,911
Other income (deductions)		10,308		9,615
Net interest deductions		69,464		65,146

Income before income taxes		200,210		179,380
Income tax expense		65,887		59,544

Contribution to consolidated net income	$	134,323	$	119,836


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