UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

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

2018



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

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

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~~49,431,933 shares as of October ~~27, 2017.~~

31, 2018.

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

SOUTHWEST GAS CORPORATION MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION (H)(1)(a) and (b) 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~~2018

FILING FORMAT

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

Part I—Financial information in this Quarterly Report on Form10-Q includes separate financial statements (i.e., balance sheets, statements of income, statements of comprehensive income, and statements of cash flows) for Southwest Gas Holdings, Inc. and Southwest Gas Corporation, in that order. The Notes to 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~~2018

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Thousands of dollars, except par value)

(Unaudited)

   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, 2018			December 31, 2017
ASSETS
Utility plant:
Gas plant	$	6,928,471		$	6,629,644
Less: accumulated depreciation	(2,275,376		)	(2,231,242		)
Construction work in progress	216,735			125,248
Net utility plant	4,869,830			4,523,650
Other property and investments	466,500			428,180
Current assets:
Cash and cash equivalents	69,170			43,622
Accounts receivable, net of allowances	347,571			347,375
Accrued utility revenue	34,600			78,200
Income taxes receivable	49,603			7,960
Deferred purchased gas costs	—			14,581
Prepaids and other current assets	220,249			165,294
Total current assets	721,193			657,032
Noncurrent assets:
Goodwill	176,059			179,314
Deferred income taxes	1,185			1,480
Deferred charges and other assets	419,829			447,410
Total noncurrent assets	597,073			628,204
Total assets	$	6,654,596		$	6,237,066
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock, $1 par (authorized - 60,000,000 shares; issued and outstanding - 49,422,938 and 48,090,470 shares)	$	51,053		$	49,720
Additional paid-in capital	1,045,840			955,332
Accumulated other comprehensive income (loss), net	(53,390		)	(47,682		)
Retained earnings	902,730			857,398
Total Southwest Gas Holdings, Inc. equity	1,946,233			1,814,768
Noncontrolling interest	(452		)	(2,365		)
Total equity	1,945,781			1,812,403
Long-term debt, less current maturities	2,123,641			1,798,576
Total capitalization	4,069,422			3,610,979
Current liabilities:
Current maturities of long-term debt	33,429			25,346
Short-term debt	31,500			214,500
Accounts payable	172,237			228,315
Customer deposits	68,100			69,781
Income taxes payable	2,572			5,946
Accrued general taxes	51,734			43,879
Accrued interest	30,594			17,870
Deferred purchased gas costs	93,023			6,841
Other current liabilities	229,521			203,403
Total current liabilities	712,710			815,881
Deferred income taxes and other credits:
Deferred income taxes and investment tax credits	519,146			476,960
Accumulated removal costs	322,000			315,000
Other deferred credits and other long-term liabilities	1,031,318			1,018,246
Total deferred income taxes and other credits	1,872,464			1,810,206
Total capitalization and liabilities	$	6,654,596		$	6,237,066

The accompanying notes are an integral part of these statements.



	3



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

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(In thousands, except per share amounts)

(Unaudited)

   THREE MONTHS ENDED NINE MONTHS ENDED TWELVE MONTHS ENDED
   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,
	2018			2017			2018			2017			2018			2017
Operating revenues:
Gas operating revenues	$	217,523		$	213,059		$	987,515		$	935,823		$	1,354,000		$	1,276,308
Construction revenues	450,623			380,094			1,105,844			872,536			1,479,792			1,173,576
Total operating revenues	668,146			593,153			2,093,359			1,808,359			2,833,792			2,449,884
Operating expenses:
Net cost of gas sold	49,903			45,539			319,101			261,839			412,307			334,888
Operations and maintenance	105,508			97,422			313,294			299,920			406,137			394,725
Depreciation and amortization	62,156			58,529			185,941			189,089			247,803			260,457
Taxes other than income taxes	15,036			14,046			44,959			43,325			59,580			56,221
Construction expenses	395,862			342,629			1,007,485			806,586			1,349,862			1,073,090
Total operating expenses	628,465			558,165			1,870,780			1,600,759			2,475,689			2,119,381
Operating income	39,681			34,988			222,579			207,600			358,103			330,503
Other income and (expenses):
Net interest deductions	(24,548		)	(19,494		)	(70,831		)	(56,863		)	(92,032		)	(76,423		)
Other income (deductions)	889			(1,980		)	(6,151		)	(5,780		)	(6,401		)	(8,007		)
Total other income and (expenses)	(23,659		)	(21,474		)	(76,982		)	(62,643		)	(98,433		)	(84,430		)
Income before income taxes	16,022			13,514			145,597			144,957			259,670			246,073
Income tax expense	3,691			3,094			33,421			47,411			51,098			82,833
Net income	12,331			10,420			112,176			97,546			208,572			163,240
Net income (loss) attributable to noncontrolling interest	—			216			(797		)	170			(866		)	684
Net income attributable to Southwest Gas Holdings, Inc.	$	12,331		$	10,204		$	112,973		$	97,376		$	209,438		$	162,556
Basic earnings per share	$	0.25		$	0.21		$	2.31		$	2.05		$	4.30		$	3.42
Diluted earnings per share	$	0.25		$	0.21		$	2.31		$	2.03		$	4.29		$	3.39
Dividends declared per share	$	0.520		$	0.495		$	1.560		$	1.485		$	2.055		$	1.935
Average number of common shares	49,493			47,628			48,916			47,577			48,728			47,553
Average shares (assuming dilution)	49,553			47,986			48,968			47,912			48,781			47,896

The accompanying notes are an integral part of these statements.



	4



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

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Thousands of dollars)

(Unaudited)

   THREE MONTHS ENDED NINE MONTHS ENDED TWELVE MONTHS ENDED
   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,
	2018			2017			2018			2017			2018			2017
Net income	$	12,331		$	10,420		$	112,176		$	97,546		$	208,572		$	163,240
Other comprehensive income (loss), net of tax
Defined benefit pension plans:
Net actuarial gain (loss)	—			—			—			—			(32,701		)	(14,118		)
Amortization of prior service cost	254			207			762			621			969			828
Amortization of net actuarial loss	6,387			3,944			19,161			11,832			23,105			16,027
Regulatory adjustment	(5,746		)	(3,555		)	(17,236		)	(10,667		)	6,021			(2,741		)
Net defined benefit pension plans	895			596			2,687			1,786			(2,606		)	(4		)
Forward-starting interest rate swaps:
Amounts reclassified into net income	636			518			1,907			1,554			2,426			2,073
Net forward-starting interest rate swaps	636			518			1,907			1,554			2,426			2,073
Foreign currency translation adjustments	599			1,012			(1,002		)	1,861			(1,092		)	1,408
Total other comprehensive income (loss), net of tax	2,130			2,126			3,592			5,201			(1,272		)	3,477
Comprehensive income	14,461			12,546			115,768			102,747			207,300			166,717
Comprehensive income (loss) attributable to noncontrolling interests	—			198			(797		)	181			(866		)	679
Comprehensive income attributable to Southwest Gas Holdings, Inc.	$	14,461		$	12,348		$	116,565		$	102,566		$	208,166		$	166,038

The accompanying notes are an integral part of these statements.



	5



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

SOUTHWEST GAS HOLDINGS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of dollars)

(Unaudited)

   NINE MONTHS ENDED TWELVE MONTHS ENDED
   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,
	2018			2017			2018			2017
CASH FLOW FROM OPERATING ACTIVITIES:
Net income	$	112,176		$	97,546		$	208,572		$	163,240
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	185,941			189,089			247,803			260,457
Deferred income taxes	36,210			49,409			50,190			74,439
Changes in current assets and liabilities:
Accounts receivable, net of allowances	(1,659		)	(15,330		)	(27,276		)	(13,765		)
Accrued utility revenue	43,600			42,100			(500		)	(1,100		)
Deferred purchased gas costs	100,763			(79,127		)	84,282			(114,658		)
Accounts payable	(48,618		)	(26,771		)	(1,886		)	19,866
Accrued taxes	(9,840		)	4,689			(12,417		)	38,084
Other current assets and liabilities	1,245			43,044			(50,002		)	3,590
Gains on sale	(997		)	(1,452		)	(3,741		)	(4,483		)
Changes in undistributed stock compensation	4,686			9,199			6,375			10,308
AFUDC	(1,034		)	(2,077		)	(1,253		)	(2,473		)
Changes in other assets and deferred charges	(10,497		)	(14,470		)	(18,296		)	(1,436		)
Changes in other liabilities and deferred credits	(4,583		)	3,395			(3,747		)	(10,239		)
Net cash provided by operating activities	407,393			299,244			478,104			421,830
CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions	(560,165		)	(449,998		)	(733,816		)	(575,141		)
Acquisition of businesses, net of cash acquired	(4,209		)	—			(98,413		)	—
Changes in customer advances	11,051			(1,951		)	13,325			504
Miscellaneous inflows	3,827			9,160			11,312			14,234
Net cash used in investing activities	(549,496		)	(442,789		)	(807,592		)	(560,403		)
CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net	92,234			11,563			121,826			11,505
Dividends paid	(74,535		)	(68,503		)	(98,162		)	(89,870		)
Centuri distribution to redeemable noncontrolling interest	—			(204		)	—			(544		)
Issuance of long-term debt, net	480,993			104,308			783,748			119,308
Retirement of long-term debt	(143,757		)	(100,240		)	(382,486		)	(159,162		)
Change in credit facility and commercial paper	—			145,000			—			150,000
Change in short-term debt	(183,000		)	110,500			(79,000		)	110,500
Principal payments on capital lease obligations	(422		)	(796		)	(606		)	(1,025		)
Redemption of Centuri shares from noncontrolling parties	—			(23,000		)	—			(23,000		)
Withholding remittance - share-based compensation	(2,880		)	(3,176		)	(2,880		)	(3,176		)
Other	(1,121		)	(1,104		)	(3,091		)	(2,068		)
Net cash provided by financing activities	167,512			174,348			339,349			112,468
Effects of currency translation on cash and cash equivalents	139			283			157			103
Change in cash and cash equivalents	25,548			31,086			10,018			(26,002		)
Cash and cash equivalents at beginning of period	43,622			28,066			59,152			85,154
Cash and cash equivalents at end of period	$	69,170		$	59,152		$	69,170		$	59,152
Supplemental information:
Interest paid, net of amounts capitalized	$	49,568		$	45,771		$	75,740		$	66,077
Income taxes paid (received)	$	18,261		$	3,687		$	20,247		$	(21,875	)

The accompanying notes are an integral part of these statements.



	6



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

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Thousands of dollars)

(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



	September 30, 2018			December 31, 2017
ASSETS
Utility plant:
Gas plant	$	6,928,471		$	6,629,644
Less: accumulated depreciation	(2,275,376		)	(2,231,242		)
Construction work in progress	216,735			125,248
Net utility plant	4,869,830			4,523,650
Other property and investments	125,204			119,114
Current assets:
Cash and cash equivalents	49,065			37,946
Accounts receivable, net of allowances	70,094			119,748
Accrued utility revenue	34,600			78,200
Income taxes receivable	46,250			—
Deferred purchased gas costs	—			14,581
Prepaids and other current assets	202,705			153,771
Total current assets	402,714			404,246
Noncurrent assets:
Goodwill	10,095			10,095
Deferred charges and other assets	403,505			425,564
Total noncurrent assets	413,600			435,659
Total assets	$	5,811,348		$	5,482,669
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock	$	49,112		$	49,112
Additional paid-in capital	1,041,310			948,767
Accumulated other comprehensive income (loss), net	(51,779		)	(47,073		)
Retained earnings	681,284			659,193
Total Southwest Gas Corporation equity	1,719,927			1,609,999
Long-term debt, less current maturities	1,818,621			1,521,031
Total capitalization	3,538,548			3,131,030
Current liabilities:
Short-term debt	9,000			191,000
Accounts payable	98,956			158,474
Customer deposits	68,100			69,781
Income taxes payable	—			4,971
Accrued general taxes	51,734			43,879
Accrued interest	30,481			17,171
Deferred purchased gas costs	93,023			6,841
Payable to parent	380			194
Other current liabilities	111,658			108,785
Total current liabilities	463,332			601,096
Deferred income taxes and other credits:
Deferred income taxes and investment tax credits, net	485,072			445,243
Accumulated removal costs	322,000			315,000
Other deferred credits and other long-term liabilities	1,002,396			990,300
Total deferred income taxes and other credits	1,809,468			1,750,543
Total capitalization and liabilities	$	5,811,348		$	5,482,669

The accompanying notes are an integral part of these statements.



	7



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

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(~~In thousands)~~

Thousands of dollars)

(Unaudited)

   THREE MONTHS ENDED NINE MONTHS ENDED TWELVE MONTHS ENDED
   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



	Three Months Ended September 30,						Nine Months Ended September 30,						Twelve Months Ended September 30,
	2018			2017			2018			2017			2018			2017
Continuing operations:
Gas operating revenues	$	217,523		$	213,059		$	987,515		$	935,823		$	1,354,000		$	1,276,308
Operating expenses:
Net cost of gas sold	49,903			45,539			319,101			261,839			412,307			334,888
Operations and maintenance	104,657			97,359			312,055			298,827			404,549			393,632
Depreciation and amortization	47,924			46,194			145,549			153,643			193,828			212,693
Taxes other than income taxes	15,036			14,046			44,959			43,325			59,580			56,221
Total operating expenses	217,520			203,138			821,664			757,634			1,070,264			997,434
Operating income	3			9,921			165,851			178,189			283,736			278,874
Other income and (expenses):
Net interest deductions	(20,399		)	(17,421		)	(59,803		)	(51,622		)	(77,914		)	(69,464		)
Other income (deductions)	836			(1,775		)	(5,861		)	(5,824		)	(6,425		)	(9,200		)
Total other income and (expenses)	(19,563		)	(19,196		)	(65,664		)	(57,446		)	(84,339		)	(78,664		)
Income (loss) from continuing operations before income taxes	(19,560		)	(9,275		)	100,187			120,743			199,397			200,210
Income tax expense (benefit)	(5,890		)	(5,251		)	20,886			38,307			45,714			65,887
Income (loss) from continuing operations	(13,670		)	(4,024		)	79,301			82,436			153,683			134,323
Discontinued operations - construction services:
Income before income taxes	—			—			—			—			—			21,649
Income tax expense	—			—			—			—			—			7,842
Income	—			—			—			—			—			13,807
Noncontrolling interests	—			—			—			—			—			514
Income - discontinued operations	—			—			—			—			—			13,293
Net income (loss)	$	(13,670	)	$	(4,024	)	$	79,301		$	82,436		$	153,683		$	147,616

The accompanying notes are an integral part of these statements.



	8



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

SOUTHWEST GAS CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(~~In thousands)~~

Thousands of dollars)

(Unaudited)

   THREE MONTHS ENDED NINE MONTHS ENDED TWELVE MONTHS ENDED
   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,
	2018			2017			2018			2017			2018			2017
Continuing operations:
Net income (loss) from continuing operations	$	(13,670	)	$	(4,024	)	$	79,301		$	82,436		$	153,683		$	134,323
Other comprehensive income (loss), net of tax
Defined benefit pension plans:
Net actuarial gain (loss)	—			—			—			—			(32,701		)	(14,118		)
Amortization of prior service cost	254			207			762			621			969			828
Amortization of net actuarial loss	6,387			3,944			19,161			11,832			23,105			16,027
Regulatory adjustment	(5,746		)	(3,555		)	(17,236		)	(10,667		)	6,021			(2,741		)
Net defined benefit pension plans	895			596			2,687			1,786			(2,606		)	(4		)
Forward-starting interest rate swaps:
Amounts reclassified into net income	636			518			1,907			1,554			2,426			2,073
Net forward-starting interest rate swaps	636			518			1,907			1,554			2,426			2,073
Total other comprehensive income (loss), net of tax from continuing operations	1,531			1,114			4,594			3,340			(180		)	2,069
Comprehensive income (loss) from continuing operations	(12,139		)	(2,910		)	83,895			85,776			153,503			136,392
Discontinued operations - construction services:
Net income	—			—			—			—			—			13,293
Foreign currency translation adjustments	—			—			—			—			—			(453		)
Comprehensive income	—			—			—			—			—			12,840
Comprehensive income (loss) attributable to noncontrolling interests	—			—			—			—			—			(16		)
Comprehensive income attributable to discontinued operations - construction services	—			—			—			—			—			12,856
Comprehensive income (loss)	$	(12,139	)	$	(2,910	)	$	83,895		$	85,776		$	153,503		$	149,248

The accompanying notes are an integral part of these statements.



	9



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

SOUTHWEST GAS CORPORATION 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
   $ 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 )



	Nine Months Ended September 30,						Twelve Months Ended September 30,
	2018			2017			2018			2017
CASH FLOW FROM OPERATING ACTIVITIES:
Net Income	$	79,301		$	82,436		$	153,683		$	148,130
Income from discontinued operations	—			—			—			13,807
Income from continuing operations	79,301			82,436			153,683			134,323
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	145,549			153,643			193,828			212,693
Deferred income taxes	33,239			44,621			55,787			72,627
Changes in current assets and liabilities:
Accounts receivable, net of allowances	49,654			43,818			(2,066		)	(7,131		)
Accrued utility revenue	43,600			42,100			(500		)	(1,100		)
Deferred purchased gas costs	100,763			(79,127		)	84,282			(114,658		)
Accounts payable	(53,217		)	(45,972		)	(2,700		)	17,271
Accrued taxes	(16,026		)	4,092			(9,735		)	29,143
Other current assets and liabilities	(35,154		)	32,453			(81,333		)	(224		)
Changes in undistributed stock compensation	4,269			7,999			5,558			9,108
AFUDC	(1,034		)	(2,077		)	(1,253		)	(2,473		)
Changes in other assets and deferred charges	(11,025		)	(14,861		)	(19,082		)	(1,914		)
Changes in other liabilities and deferred credits	7,550			2,883			8,208			(10,751		)
Net cash provided by operating activities	347,469			272,008			384,677			336,914
CASH FLOW FROM INVESTING ACTIVITIES:
Construction expenditures and property additions	(486,037		)	(395,463		)	(651,022		)	(514,661		)
Changes in customer advances	11,051			(1,951		)	13,325			504
Miscellaneous inflows	1,316			2,407			1,650			2,925
Dividends received	—			—			—			9,660
Net cash used in investing activities	(473,670		)	(395,007		)	(636,047		)	(501,572		)
CASH FLOW FROM FINANCING ACTIVITIES:
Issuance of common stock, net	—			—			—			(58		)
Contributions from parent	90,644			11,659			120,344			11,659
Dividends paid	(65,000		)	(60,497		)	(86,000		)	(81,864		)
Issuance of long-term debt, net	297,495			—			297,495			—
Retirement of long-term debt	—			(25,000		)	—			(25,000		)
Change in credit facility and commercial paper	—			145,000			—			150,000
Change in short-term debt	(182,000		)	83,000			(74,000		)	83,000
Withholding remittance - share-based compensation	(2,880		)	(3,176		)	(2,880		)	(3,176		)
Other	(939		)	(544		)	(991		)	(1,508		)
Net cash provided by financing activities	137,320			150,442			253,968			133,053
Net cash provided by discontinued operating activities	—			—			—			57,680
Net cash used in discontinued investing activities	—			—			—			(11,049		)
Net cash used in discontinued financing activities	—			—			—			(44,491		)
Effects of currency translation on cash and cash equivalents	—			—			—			(180		)
Change in cash and cash equivalents	11,119			27,443			2,598			(29,645		)
Change in cash and cash equivalents of discontinued operations included in discontinued operations construction services assets	—			—			—			(1,960		)
Change in cash and cash equivalents of continuing operations	11,119			27,443			2,598			(31,605		)
Cash and cash equivalents at beginning of period	37,946			19,024			46,467			78,072
Cash and cash equivalents at end of period	$	49,065		$	46,467		$	49,065		$	46,467
Supplemental information:
Interest paid, net of amounts capitalized	$	42,986		$	40,751		$	67,025		$	59,448
Income taxes paid (received)	$	11,286		$	4		$	3,428		$	(27,952	)

The accompanying notes are an integral part of these statements.



	10



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

Note 1 – Nature of Operations and Basis of Presentation

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

In January 2017, a previously contemplated and approved reorganization under a holding company structure was made effective. The reorganization was designed to provide further separation between regulated and unregulated businesses, and to provide additional financing flexibility. Coincident with the effective date of the reorganization, existing shareholders of owners.

Southwest Gas Corporation ~~became shareholders of Southwest Gas Holdings, Inc., on aone-for-one~~ basis, with the same number of shares and same ownership percentage as they held immediately prior to the reorganization. At the same time, Southwest Gas Corporation and Centuri Construction Group, Inc. (“Centuri” or the “construction services” segment) each became subsidiaries of the publicly traded holding company; whereas, historically, Centuri had been a direct subsidiary of Southwest Gas Corporation.

~~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~~infrastructure services enterprise dedicated to meeting the growing demands of North American utilities, energy, and industrial markets. Centuri derives revenue from installation, replacement, repair, and maintenance of energy distribution systems, and developing industrial ~~construction~~infrastructure solutions. Centuri operations are generally conducted under the business names of NPL Construction Co. (“NPL”), Canyon Pipeline Construction, Inc. (“Canyon”), NPL Canada Ltd. (“NPL Canada”~~, formerly Link-Line Contractors Ltd.~~), W.S. Nicholls Construction, Inc. (“W.S. Nicholls”), and Canyon Special Projects, Inc. (“Special Projects,” formerly Brigadier Pipelines Inc. ~~(“Brigadier”~~). Typically, Centuri revenues are lowest during the first quarter of the year due to unfavorable winter weather conditions. Operating revenues typically improve as more favorable weather conditions occur during the summer and fall months.

In November 2017, Centuri acquired New England Utility Constructors, Inc. (“Neuco”) for $99 million, less assumed debt, thereby expanding its core services in the Northeast region of the United States. See the Southwest Gas Holdings, Inc. March 31, 2018 Form 10-Q for additional information about this acquisition, including final purchase accounting.

Basis of Presentation. The condensed consolidated financial statements for Southwest Gas Holdings, Inc. and subsidiaries (the “Company”) and Southwest included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Certain information and footnote disclosures normally included in financial statements prepared in accordance with United States generally accepted accounting principles (“U.S. GAAP”) have been condensed or omitted pursuant to such rules and regulations. ~~As indicated above, in~~In connection with ~~the~~a holding company reorganization in January 2017, Centuri ceased to be a subsidiary of Southwest and became a subsidiary of Southwest Gas Holdings, Inc. To give effect to this change, the separate condensed consolidated financial statements related to Southwest Gas Corporation, which are included in thisForm 10-Q, depict Centuri-related amounts for periods prior to January 1, 2017 as discontinued operations. Because the transfer of Centuri from Southwest Gas Corporation to Southwest Gas Holdings, Inc. was effectuated as an equity transaction and not a sale, assets and liabilities subject to the discontinued operations presentation have been reflected as noncurrent on the Southwest Gas Corporation Condensed Consolidated Balance Sheet. Those assets and liabilities are detailed in~~Note~~ ~~10 – Reorganization Impacts – Discontinued Operations Solely Related to Southwest Gas Corporation~~~~,and include both current andnon-current~~ ~~amounts.~~

No substantive change has occurred with regard to the Company’s business segments on the whole, or in the primary businesses comprising those segments as a result of the foregoing organizational ~~changes.~~changes, or due to the acquisition of Neuco. Following the organizational changes, Centuri operations continue to be part of continuing operations and included in the consolidated financial statements of ~~Southwest Gas Holdings, Inc.~~

the Company.

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


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

Actual results could differ from those estimates. In the opinion of management, all adjustments, consisting of normal recurring items and estimates necessary for a fair statement of results for the interim periods, have been made. It is suggested that these condensed consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the ~~2016~~2017 Annual Report to Shareholders, which is incorporated by reference into the ~~2016~~2017 Form 10-K.



	11



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

Early Adoption of Accounting Standards Update (“ASU”) No. 2018-02.

In January 2018, the Financial Accounting Standards Board (the “FASB”) issued ASU No. 2018-02 “Income Statement—Reporting Comprehensive Income—Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.” Early adoption of the amendments in this update was permitted, including adoption in any interim period. Therefore, the Company and Southwest chose to adopt the update early, as permitted, as of January 1, 2018. The adoption of this update is considered a change in accounting principle. The update addressed issues resulting from the December 22, 2017 enactment of the Tax Cuts and Jobs Act (the “TCJA”). Stakeholders raised a narrow-scope financial reporting issue that arose as a consequence of the TCJA related to the fact that when deferred tax balances were remeasured in December 2017, those deferred tax balances were to be reduced, but related amounts historically accumulated in Accumulated other comprehensive income (“AOCI”) prior to the enactment of the TCJA, were required to be recognized as income tax expense rather than being relieved from AOCI. The amendments in this update allowed a reclassification from AOCI to retained earnings for those otherwise “stranded” tax effects in AOCI following enactment of the TCJA. Accordingly, approximately $9.3 million of previously stranded tax effects resulting from the TCJA were reclassified to retained earnings from AOCI on the Condensed Consolidated Balance Sheets of Southwest and the Company effective with the early adoption date. Also in association with the adoption, the Company and Southwest elected an accounting policy for releasing income tax effects from AOCI, such that the release of any income tax effects from AOCI will occur as individual items in AOCI are sold or liquidated, to the extent that the related income tax effects are material. See Note 9 – Equity, Other Comprehensive Income, and Accumulated Other Comprehensive Income for more information.

Prepaids and other current assets. Prepaids and other current assets includes gas pipe materials and operating supplies of ~~$36~~$53 million at September 30, ~~2017~~2018 and ~~$30~~$33 million at December 31, ~~2016~~2017 (carried at weighted average cost) ~~and $24~~, as well as $73 million at September 30, ~~2017~~2018 and ~~$953,000~~$40 million at December 31, ~~2016~~2017 related to a regulatory asset associated with the Arizona decoupling mechanism (an alternative revenue program).

Income Taxes. On December 22, 2017, as indicated above, the TCJA legislation was enacted. Substantially all of the provisions of the TCJA are effective for taxable years beginning after December 31, 2017. The TCJA includes extensive changes which significantly impact the taxation of business entities, including specific provisions related to regulated public utilities. A significant change that impacts the Company and Southwest includes the reduction in the corporate federal income tax rate from 35% to 21%. The tax rate reduction created excess deferred taxes, resulting in the required remeasurement of deferred tax balances, which when remeasured during the fourth quarter of 2017, reduced income tax expense. The regulated operations of Southwest experienced other impacts due to the applicable rate-regulation and the accounting treatment prescribed by U.S. GAAP to reflect the economics of that regulation. The remeasurement for Southwest reduced the net deferred income tax liability and caused the creation of a regulatory liability with appropriate tax gross-up. Both the deferred tax liabilities and excess deferred tax liabilities (included within regulatory liabilities) reduce utility rate base. The TCJA includes provisions that stipulate how these excess deferred taxes are to be passed back to customers, and ultimate facilitation will occur in conjunction with appropriate regulatory commissions. During the nine months ended September 30, 2018, tax expense for the Company and Southwest reflects the lower U.S. federal income tax rate now in effect (as applicable to earnings in 2018). Amounts recorded by the Company and Southwest associated with the measurement and accounting for the effects of the TCJA are provisional reasonable estimates. Management is continuing to evaluate and finalize all provisional items during the measurement period permitted by the SEC and the FASB, and will complete its assessment in the fourth quarter of 2018.

In July 2018, the Arizona Corporation Commission (the “ACC”) staff issued a recommended opinion and order, and the ACC issued a decision (the “Decision”) based on the staff recommendation, requiring Southwest to return the difference in excess cost-of-service rates due to tax reform. The Decision required Southwest to provide a bill credit in August 2018 for excess taxes collected from January through July 2018. Also as required by the Decision, Southwest began tracking, in a regulatory account, the difference between amounts expected to be returned and the actual amounts returned by these means. As of September 30, 2018, this difference of $2.4 million is reflected in Other current liabilities on the balance sheets of both Southwest and the Company.

Other current liabilities. Other current liabilities offor Southwest ~~Gas Corporation~~ include ~~$21~~$22 million of dividends declared by Southwest Gas Corporation, but not yet paid to Southwest Gas Holdings, Inc. at September 30, ~~2017.~~

2018.

Cash and Cash Equivalents. For purposes of reporting consolidated cash flows, cash and cash equivalents include cash on hand and financial instruments with a purchase-date maturity of three months or less. In general, cash and cash equivalents fall within Level 1 (quoted prices for identical financial instruments) of the three-level fair value hierarchy that ranks the inputs used to measure fair value by their reliability. However, cash and cash equivalents ~~at September 30, 2017~~for Southwest and ~~December 31, 2016~~the Company also ~~includes~~include money market fund investments oftotaling approximately ~~$19.8~~$38.8 million and ~~$5.3~~$39.6 million, respectively, which fall within Level 2 (significant other observable inputs) of the fair value hierarchy, due to the asset valuation methods used by money market funds.

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

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

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

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



	12



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

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

Goodwill. Goodwill is assessed as of October 1steach year for impairment, ~~(required annually by U.S. GAAP),~~ or ~~otherwise,~~more frequently, if circumstances indicate an impairment to the carrying value of goodwill may have occurred. In consideration of the holding company reorganization, management of the Company considered its reporting units and segments and determined that historic judgments regarding its segments and reporting units continue to apply, and that no change was necessary with regard to the level at which goodwill is assessed for impairment. No impairment was deemed to have occurred in the first nine 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

2018.

(Thousands of dollars)
Natural Gas
Operations

Infrastructure
Services
Consolidated
December 31, 2017 $ 10,095
$ 169,219
$ 179,314
Additional goodwill from Neuco acquisition —
182
182
Foreign currency translation adjustment —
(3,437 ) (3,437 )
September 30, 2018 $ 10,095
$ 165,964
$ 176,059

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

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



	September 30, 2018		December 31, 2017
Centuri accounts receivable for services provided to Southwest	$	13,566	$	12,987

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



	13



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

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~~

September 30, 2018 December 31, 2017
Southwest Gas Corporation:
Net cash surrender value of COLI policies $ 123,476
$ 117,341
Other property 1,728
1,773
Total Southwest Gas Corporation 125,204
119,114
Centuri property, equipment, and intangibles 613,365
554,730
Centuri accumulated depreciation/amortization (287,396 ) (258,906 )
Other property 15,327
13,242
Total Southwest Gas Holdings, Inc. $ 466,500
$ 428,180

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

   Three Months Ended Nine Months Ended Twelve Months Ended
   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



	Three Months Ended						Nine Months Ended						Twelve Months Ended
	September 30,						September 30,						September 30,
	2018			2017			2018			2017			2018			2017
Southwest Gas Corporation - natural gas operations segment:
Change in COLI policies	$	4,700		$	2,100		$	6,000		$	6,800		$	9,500		$	8,800
Interest income	1,506			670			4,301			1,848			5,237			2,417
Equity AFUDC	448			968			1,034			2,077			1,253			2,473
Other components of net periodic benefit cost	(5,265		)	(4,856		)	(15,794		)	(14,568		)	(20,650		)	(19,508		)
Miscellaneous income and (expense)	(553		)	(657		)	(1,402		)	(1,981		)	(1,765		)	(3,382		)
Southwest Gas Corporation - total other income (deductions)	836			(1,775		)	(5,861		)	(5,824		)	(6,425		)	(9,200		)
Infrastructure services segment:
Interest income	4			1			6			2			7			2
Foreign transaction gain (loss)	(91		)	(442		)	258			(640		)	144			(640		)
Miscellaneous income and (expense)	125			231			(595		)	676			(175		)	1,825
Centuri - total other income (deductions)	38			(210		)	(331		)	38			(24		)	1,187
Corporate and administrative	15			5			41			6			48			6
Consolidated Southwest Gas Holdings, Inc. - total other income (deductions)	$	889		$	(1,980	)	$	(6,151	)	$	(5,780	)	$	(6,401	)	$	(8,007	)

Included in the table above is the change in cash surrender values of company-owned life insurance (“COLI”) policies (including net death benefits recognized). These life insurance policies on members of management and other key employees are used by Southwest to indemnify itself against the loss of talent, expertise, and knowledge, as well as to provide indirect funding for certain nonqualified benefit plans. Current tax regulations provide fortax-free treatment of life insurance (death benefit) proceeds. Therefore, changes in the cash surrender values of COLI policies, as they progress towards the ultimate death benefits, are also recorded without tax consequences.

Refer also to Note 2 – Components of Net Periodic Benefit Cost.

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

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


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

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

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

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

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

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

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

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

Under the new guidance, lessor accounting is largely unchanged. Certain targeted improvements were made to align, where necessary, lessor accounting with the lessee accounting model and Topic 606, ~~Revenue~~“Revenue from Contracts with Customers.” Though companies have historically been required to make disclosures regarding leases and of associated contractual obligations, leases ~~(with~~with terms longer than a ~~year)~~year will no longer existoff-balance sheet. Lessees (for capital 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 beginningEarly application 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~~update is permitted. Management ~~currently plans to~~will 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~~2019 (the required adoption date). In July 2018,



	14



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

the FASB issued narrow-scope improvements to the standard, which include, among other things, guidance on lease classification reassessment and certain circumstances surrounding remeasurement. Also included was clarification that lessor-controlled options to terminate a lease are considered in the ~~process~~lease term.

Management expects to elect various practical expedients and accounting policies regarding the transition method used to implement Topic 842. The Company and Southwest plan to elect the new optional transition method included within the recent FASB update “Leases—Targeted Improvements”, also issued in July 2018, which allows for comparative periods not to be restated. In conjunction with this decision, management currently expects that no retained earnings adjustment will be necessary due to the adoption of ~~evaluating other types~~Topic 842. At a minimum, management expects the following regarding Topic 842 practical expedients and accounting policy elections:

To elect to use the “package”, which is a set of ~~arrangements~~three practical expedients that ~~have~~must be elected as a package and applied consistently to all of the ~~potential to meet~~Company’s and Southwest’s leases. These include: not reassessing whether any expired or existing contracts are or contain leases; not reassessing the ~~definition of a~~ 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 ~~new standard,~~updated guidance); and ~~is also in~~not reassessing initial direct costs for any existing leases.

To elect to adopt 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~~exclude all easements in place prior to ~~existing easement contracts that were not previously assessed as leases~~January 1, 2019 from treatment under ~~historic guidance.~~Topic 842. However, the Company ~~would still be required to~~and Southwest will evaluate any 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.

Management is ~~currently evaluating~~continuing to implement new software systems (one for Southwest and one for Centuri) to facilitate compliance with Topic 842. Management continues to evaluate 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, and amendments, will have on its financial position, results of operations, cash flows, and business processes.

In June 2016, the FASB issued the update “Financial Instruments—Credit ~~Losses (Topic 326):~~Losses: Measurement of Credit Losses on Financial Instruments.” The update amends guidance on reporting credit losses for financial assets held at amortized cost basis and available for sale debt securities. For assets held at amortized cost basis, the update eliminates the “probable” threshold for initial recognition of credit losses in current U.S. GAAP and, instead, requires an entity to reflect its current estimate of all expected credit losses. The allowance for credit losses is a valuation account that is deducted from the amortized cost basis of the financial asset to present the net amount expected to be collected. For available for sale debt securities, credit losses should be measured in a manner similar to current U.S. ~~GAAP,~~GAAP; however, the update will require that credit losses be presented as an allowance rather than as a write-down. This update affects entities holding financial assets and net investment in leases that are not accounted for at fair value through net income. The update affects loans, debt securities, trade receivables, net investments in leases,off-balance sheet credit exposures, reinsurance receivables, and any other financial assets not excluded from the scope that have the contractual right to receive cash. The update is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. ~~All entities may adopt~~Early adoption of the amendments in this update ~~earlier as of~~is permitted for interim and related annual fiscal ~~years beginning~~periods after December 15, ~~2018, including interim periods within those fiscal years.~~2018. Management is evaluating what impact, if any, this update might have on its consolidated financial statements and disclosures.

In August ~~2016,~~2018, the FASB issued the update ~~“Classification~~“Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract.” The update generally aligns the requirements for capitalizing implementation costs incurred in a hosting arrangement (that is a service contract) with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. The update also requires the entity to expense the capitalized implementation costs of ~~Certain Cash Receipts and Cash Payments.” This update addresses~~such hosting arrangements over the ~~following specific cash flow issues: debt prepayment or debt extinguishment costs; settlement ofzero-coupon~~ ~~debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate~~term 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,hosting arrangement, including ~~identification of the predominant nature in cases where cash receipts and payments have aspects of more than one class of cash flows.~~reasonably certain renewal periods. The update is effective for fiscal years beginning after December 15, ~~2017,~~2019, including interim periods within those fiscal years. Early adoption ~~is permitted. Management believes~~of the amendments in this update ~~will not~~is permitted for interim and related annual fiscal periods after December 15, 2018. Management is evaluating the impacts this update might have ~~a material impact~~ on its consolidated ~~cash flow~~financial statements and disclosures.



	15



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

In ~~October 2016,~~August 2018, the FASB issued the update ~~“Accounting~~“Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for ~~Income Taxes: Intra-Entity Asset Transfers of Assets Other than Inventory.~~Defined Benefit Plans.” This update ~~eliminates~~removes disclosures that are no longer considered cost-beneficial, clarifies the ~~current U.S. GAAP exception for~~specific requirements of disclosures, and adds disclosure requirements identified as relevant. The update applies to all ~~intra-entity sales of assets~~employers that sponsor defined benefit pension or 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 thepre-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.~~post-retirement plans. The update is effective for fiscal years ~~beginning~~ending after December 15, ~~2017, including interim periods within those fiscal years.~~2020. Early adoption is ~~permitted; however,~~permitted. Management is evaluating 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 believesimpacts this update ~~will not~~might have ~~a material impact~~ on its ~~consolidated financial statements and~~ disclosures.

In ~~January 2017,~~August 2018, the FASB issued the update ~~“Intangibles—Goodwill and Other (Topic 350): Simplifying~~“Fair Value Measurement: Disclosure Framework—Changes to the ~~Test~~Disclosure Requirements for ~~Goodwill Impairment.~~Fair Value Measurement.” The update ~~eliminates Step~~is intended to improve the effectiveness of fair value measurement disclosures and removes the following disclosure requirements: the amount of and reasons for transfers between Level 1 and Level 2 ~~from the goodwill impairment test. The annual, or interim, goodwill impairment test is performed by comparing~~of the fair value hierarchy; the policy for timing of transfers between levels; and the valuation processes for Level 3 fair value measurements. The update also modifies or clarifies for investments in certain entities that calculate net asset value, a ~~reporting unit with its carrying amount. An impairment charge should be recognized for~~requirement to disclose the ~~amount by which~~timing of liquidation of an investee’s assets and the ~~carrying amount exceeds~~date when restrictions from redemption might lapse (in cases when the timing has been communicated or announced publicly). It also clarifies communication requirements about measurement uncertainty as of the reporting ~~unit’s~~

date. Furthermore, the update added requirements to disclose changes in unrealized gains/losses included in other comprehensive income for recurring Level 3 fair value measurements held at the end of the reporting period, as well as the range and weighted average value of significant unobservable inputs used to develop Level 3 fair value measurements. For certain unobservable inputs, an entity may disclose other quantitative information in lieu of the weighted average if it would be a more reasonable and rational method to reflect the distribution of inputs to the measurements. Management is evaluating the impacts this update might have on its disclosures.



	16



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

~~fair value; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. In addition, income tax effects from anytax-deductible~~ goodwill on the carrying amount of the reporting unit should be considered when measuring the goodwill impairment loss, if applicable. The update also eliminates the requirements for any reporting unit with a zero or negative carrying amount to perform a qualitative assessment and, if it fails that qualitative test, to perform Step 2 of the goodwill impairment test. An entity still has the option to perform the qualitative assessment for a reporting unit to determine if the quantitative impairment test is necessary. The amendments should be applied on a prospective basis. The update is effective for fiscal and interim periods beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. Management has determined that this update would have had no impact on the consolidated financial statements for the periods presented if it had been effective during those periods.

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

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


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

Note 2 – Components of Net Periodic Benefit Cost

As of January 1, 2018, the Company and Southwest adopted “Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.” The update requires that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and be appropriately described. The update also allows only the service cost component (and not the other components of periodic benefit costs) to be eligible for capitalization when applicable, making no exception for specialized industries, including rate-regulated industries. This guidance is required to be applied on a retrospective basis for the presentation of the service cost and other components of net benefit cost, and on a prospective basis for the capitalization of only the service cost component of net benefit cost. Amounts capitalized as part of assets prior to the date of adoption were not adjusted through a cumulative effect adjustment. The guidance allows a practical expedient for the retrospective application that permits use of the amounts disclosed for the various components of net benefit cost in the pension and other postretirement benefit plans footnote as the basis for the retrospective application. This is in lieu of determining how much of the various components of net benefit cost were actually reflected in the income statement each period as a result of capitalization of certain costs into assets and their subsequent amortization. The Company and Southwest have elected to utilize the practical expedient.

Therefore, upon adoption, amounts presented in the Condensed Consolidated Statements of Income for operations and maintenance for the three-, nine-, and twelve-month periods ended September 30, 2017 were reclassified. The Operations and maintenance line item of the Company’s Condensed Consolidated Statements of Income was revised from $102.3 million to $97.4 million for the three months ended September 30, 2017, from $314.5 million to $299.9 million for the nine months ended September 30, 2017, and from $414.2 million to $394.7 million for the twelve months ended September 30, 2017. The Operations and maintenance line item of Southwest’s Condensed Consolidated Statements of Income was revised from $102.2 million to $97.4 million for the three months ended September 30, 2017, from $313.4 million to $298.8 million for the nine months ended September 30, 2017, and from $413.1 million to $393.6 million for the twelve months ended September 30, 2017. The Other income (deductions) line item of the Company’s Condensed Consolidated Statements of Income was revised from $2.9 million to $(2.0) million for the three months ended September 30, 2017, from $8.8 million to $(5.8) million for the nine months ended September 30, 2017, and from $11.5 million to $(8.0) million for the twelve months ended September 30, 2017. The Other income (deductions) line item of Southwest’s Condensed Consolidated Statements of Income was revised from $3.1 million to $(1.8) million for the three months ended September 30, 2017, from $8.7 million to $(5.8) million for the nine months ended September 30, 2017, and from $10.3 million to $(9.2) million for the twelve months ended September 30, 2017. Net income overall was not impacted by this reclassification for either the Company or Southwest.

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

~~Net~~

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

The service cost component of net periodic benefit costs included in the table below are components of an overhead loading process associated with the cost of ~~labor.~~labor (refer to discussion above related to the update to Topic 715). The overhead process ultimately results in allocation of that portion of overall net periodic benefit costs to the same accounts to which productive labor is charged. As a result, ~~net periodic benefit~~service costs become components of various accounts, primarily operations and maintenance expense, net utility plant, and deferred charges and other assets for both the Company and Southwest.

   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

Refer also to the practical expedient elected related to amounts capitalized as part of assets prior to the adoption date.



	17



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



	Qualified Retirement Plan
	Period Ended September 30,
	Three Months						Nine Months						Twelve Months
	2018			2017			2018			2017			2018			2017
(Thousands of dollars)
Service cost	$	7,139		$	5,848		$	21,417		$	17,544		$	27,265		$	23,252
Interest cost	11,043			11,520			33,130			34,561			44,652			46,068
Expected return on plan assets	(14,689		)	(13,799		)	(44,066		)	(41,397		)	(57,865		)	(55,536		)
Amortization of net actuarial loss	8,029			6,001			24,086			18,003			30,087			24,319
Net periodic benefit cost	$	11,522		$	9,570		$	34,567		$	28,711		$	44,139		$	38,103

	SERP
	Period Ended September 30,
	Three Months						Nine Months						Twelve Months
	2018			2017			2018			2017			2018			2017
(Thousands of dollars)
Service cost	$	61		$	77		$	183		$	232		$	260		$	315
Interest cost	415			471			1,244			1,413			1,714			1,878
Amortization of net actuarial loss	375			361			1,126			1,081			1,486			1,426
Net periodic benefit cost	$	851		$	909		$	2,553		$	2,726		$	3,460		$	3,619

	PBOP
	Period Ended September 30,
	Three Months						Nine Months						Twelve Months
	2018			2017			2018			2017			2018			2017
(Thousands of dollars)
Service cost	$	368		$	367		$	1,105		$	1,101		$	1,472		$	1,476
Interest cost	687			808			2,061			2,424			2,869			3,218
Expected return on plan assets	(929		)	(839		)	(2,789		)	(2,518		)	(3,629		)	(3,305		)
Amortization of prior service costs	334			333			1,002			1,001			1,336			1,335
Amortization of net actuarial loss	—			—			—			—			—			105
Net periodic benefit cost	$	460		$	669		$	1,379		$	2,008		$	2,048		$	2,829

Note 3 – Revenue

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

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

Natural Gas Operations Segment:

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



	18



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

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

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

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

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

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



	19



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

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



	Three Months Ended				Nine Months Ended				Twelve Months Ended
	September 30,				September 30,				September 30,
(Thousands of dollars)	2018		2017		2018		2017		2018		2017
Residential	$	120,249	$	123,459	$	631,562	$	624,638	$	864,128	$	854,840
Small commercial	40,020		41,656		183,616		173,799		253,330		237,430
Large commercial	11,360		11,475		39,934		37,851		54,462		50,397
Industrial/other	5,390		5,024		17,391		15,518		23,899		20,946
Transportation	19,818		20,545		64,591		64,235		88,115		86,528
Revenue from contracts with customers	196,837		202,159		937,094		916,041		1,283,934		1,250,141
Alternative revenue program revenues (deferrals)	9,094		9,123		46,696		15,026		67,017		21,300
Other revenues (a)	11,592		1,777		3,725		4,756		3,049		4,867
Total Gas operating revenues	$	217,523	$	213,059	$	987,515	$	935,823	$	1,354,000	$	1,276,308

(a)

Includes various other revenues, and during the first six months of 2018, included $12.5 million as a reserve against revenue associated with a tax reform savings adjustment. During the third quarter of 2018, amounts previously recognized were reclassified to the various categories of revenue from contracts with customers when incorporated in tariff rates. Refer to Income Taxes in Note 1 – Nature of Operations and Basis of Presentation.

Infrastructure Services Segment:

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

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

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

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

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



	20



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

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

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

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

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

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

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



(Thousands of dollars)	Three Months Ended				Nine Months Ended				Twelve Months Ended
	September 30,				September 30,				September 30,
	2018		2017		2018		2017		2018		2017
Service Types:
Replacement gas construction	$	305,177	$	238,957	$	718,598	$	540,907	$	965,757	$	765,068
New gas construction	50,544		43,216		131,017		116,521		179,872		180,093
Other construction	94,902		97,921		256,229		215,108		334,163		228,415
Total Construction revenues	$	450,623	$	380,094	$	1,105,844	$	872,536	$	1,479,792	$	1,173,576



	21



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



(Thousands of dollars)	Three Months Ended				Nine Months Ended				Twelve Months Ended
	September 30,				September 30,				September 30,
	2018		2017		2018		2017		2018		2017
Contract Types:
Master services agreement	$	348,274	$	261,576	$	832,813	$	617,129	$	1,101,216	$	831,465
Bid contract	102,349		118,518		273,031		255,407		378,576		342,111
Total Construction revenues	$	450,623	$	380,094	$	1,105,844	$	872,536	$	1,479,792	$	1,173,576

Unit priced contracts	$	368,918	$	332,462	$	948,593	$	782,560	$	1,286,059	$	993,294
Fixed priced contracts	81,705		47,632		157,251		89,976		193,733		180,282
Total Construction revenues	$	450,623	$	380,094	$	1,105,844	$	872,536	$	1,479,792	$	1,173,576

The following table provides information about contracts receivable and revenue earned on contracts in progress in excess of billings (contract asset), which are both included within Accounts receivable, net of allowances, and amounts billed in excess of revenue earned on contracts (contract liability), which are included in Other current liabilities as of September 30, 2018 and December 31, 2017 on the Company’s Condensed Consolidated Balance Sheets:



(Thousands of dollars)	September 30, 2018		December 31, 2017
Contracts receivable, net	$	191,923	$	221,859
Revenue earned on contracts in progress in excess of billings	85,554		5,768
Amounts billed in excess of revenue earned on contracts	7,192		9,602

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. Upon adoption of Topic 606, the Company reclassified $51.7 million to revenue earned on contracts in progress in excess of billings, and during the nine months ended September 30, 2018, recognized an increase of $33.8 million, excluding the impact from the adoption, primarily related to normal operating and billing activities. 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 January 1, 2018 to September 30, 2018 is due to revenue recognized of $9.6 million that was included in this item as of January 1, 2018, and to increases due to cash received, net of revenue recognized during the period related to contracts that commenced during the period.

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

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

Centuri has sixteen contracts that had an original duration of more than one year. The aggregate amount of the transaction price allocated to the unsatisfied performance obligations of these contracts as of September 30, 2018 is $71 million. Centuri expects to recognize the remaining performance obligations over the next four years; however, the timing of that recognition is largely within the control of the customer, including when the necessary equipment and materials required to complete the work are provided by the customer.



	22



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

Construction services contracts receivable consists of the following:




(Thousands of dollars)	September 30, 2018
Billed on completed contracts and contracts in progress	$	189,619
Other receivables	2,424

Contracts receivable, gross	192,043
Allowance for doubtful accounts	(120		)

Contracts receivable, net	$	191,923



	23



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

Note 34 – Segment Information

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

   Natural Gas
Operations    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



	Natural Gas Operations			Infrastructure Services		Other			Total
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
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

	Natural Gas Operations			Infrastructure Services		Other			Total
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
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

	Natural Gas Operations			Infrastructure Services		Other			Total
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
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



	24



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

Note 45 – Derivatives and Fair Value Measurements

Derivatives. In managing its natural gas supply portfolios, Southwest has historically entered into fixed- and variable-price contracts, which qualify as derivatives. Additionally, Southwest utilizesfixed-for-floating swap contracts (“Swaps”) to supplement its fixed-price contracts. The fixed-price contracts, firm commitments to purchase a fixed amount of gas in the future at a fixed price, qualify for the normal purchases and normal sales exception that is allowed for contracts that are probable of delivery in the normal course of business, and are exempt from fair value reporting.


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

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

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

The fixed-price contracts and Swaps are utilized by Southwest under its volatility mitigation programs to effectively fix the price on a portion (up to 25% in the Arizona and California jurisdictions) of its natural gas supply portfolios. The maturities of the Swaps highly correlate to forecasted purchases of natural gas, during time frames ranging from October ~~2017~~31, 2018 through ~~March~~October 31, 2019. Under such contracts, Southwest pays the counterparty a fixed rate and receives from the counterparty a floating rate per MMBtu (“dekatherm”) of natural gas. Only the net differential is actually paid or received. The differential is calculated based on the notional amounts under the contracts, which are detailed in the table below (thousands of dekatherms):

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

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



	September 30, 2018	December 31, 2017
Contract notional amounts	14,157	10,929

The following table sets forth the gains and (losses) recognized on the Swaps (derivatives) for the three-, nine-, and twelve-month periods ended September 30, ~~2017~~2018 and ~~2016~~2017 and their location in the Condensed Consolidated Statements of Income for both the Company and Southwest:

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

~~(Thousands of dollars)~~

      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
      $ —   $ —   $ —   $ —   $ —   $ —



(Thousands of dollars)
		Three Months Ended								Nine Months Ended								Twelve Months Ended
	Location of Gain or (Loss) Recognized in Income on Derivative	September 30,								September 30,								September 30,
Instrument		2018				2017				2018				2017				2018				2017
Swaps	Net cost of gas sold	$	511			$	(546	)		$	(3,815	)		$	(6,851	)		$	(8,536	)		$	(4,098	)
Swaps	Net cost of gas sold	(511		)	*	546			*	3,815			*	6,851			*	8,536			*	4,098			*
Total		$	—			$	—			$	—			$	—			$	—			$	—



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

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



	25



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

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~~



September 30, 2018		Asset		Liability
Instrument	Balance Sheet Location	Derivatives		Derivatives			Net Total
Swaps	Deferred charges and other assets	$	24	$	—		$	24
Swaps	Other current liabilities	1,038		(5,735		)	(4,697		)
Swaps	Other deferred credits and other long-term liabilities	57		(188		)	(131		)
Total		$	1,119	$	(5,923	)	$	(4,804	)

December 31, 2017		Asset		Liability
Instrument	Balance Sheet Location	Derivatives		Derivatives			Net Total
Swaps	Other current liabilities	$	11	$	(4,468	)	$	(4,457	)
Swaps	Other deferred credits and other long-term liabilities	19		(1,342		)	(1,323		)
Total		$	30	$	(5,810	)	$	(5,780	)

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

Pursuant to regulatory deferral accounting treatment for rate-regulated entities, unrealized gains and losses in fair value of the Swaps are recorded as a regulatory asset and/or liability. When the Swaps mature, any prior positions held are reversed and the settled position is recorded as an increase or decrease of purchased gas under the related ~~purchased~~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 following table shows the amounts Southwest paid to and received from counterparties for settlements of matured Swaps.

   Three Months Ended    Nine Months Ended    Twelve Months Ended
(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



	Three Months Ended		Nine Months Ended		Twelve Months Ended
(Thousands of dollars)	September 30, 2018		September 30, 2018		September 30, 2018
Paid to counterparties	$	866	$	4,797	$	6,343
Received from counterparties	$	—	$	6	$	6

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

September 30, 2017
Instrument

Balance Sheet Location
   Net Total
Swaps    Other current liabilities    $ (34 )
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 )

September 30, 2018
Instrument Balance Sheet Location Net Total
Swaps Other deferred credits and other long-term liabilities $ (24 )
Swaps Prepaids and other current assets 4,697
Swaps Deferred charges and other assets 131

December 31, 2017
Instrument Balance Sheet Location Net Total
Swaps Prepaids and other current assets $ 4,457
Swaps Deferred charges and other assets 1,323



	26



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

Fair Value Measurements. The estimated fair values of Southwest’s Swaps were determined at September 30, ~~2017~~2018 and December 31, ~~2016~~2017 using ~~New York Mercantile Exchange (“NYMEX”)~~ futures settlement prices, published by the CME Group, for the delivery of natural gas at Henry Hub adjusted by the price of ~~NYMEX ClearPort basis Swaps,~~future settlement bases, which reflect the difference between the price of natural gas at a given delivery basin and the Henry Hub pricing points. These Level 2 inputs (inputs, other than quoted prices, for similar assets or liabilities) are observable in the marketplace throughout the full term of the Swaps, but have been credit-risk adjusted with no significant impact to the overall fair value measurement.

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


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

Level 2—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



(Thousands of dollars)	September 30, 2018			December 31, 2017
Assets at fair value:
Deferred charges and other assets - Swaps	$	24		$	—
Liabilities at fair value:
Other current liabilities - Swaps	(4,697		)	(4,457		)
Other deferred credits and other long-term liabilities - Swaps	(131		)	(1,323		)
Net Assets (Liabilities)	$	(4,804	)	$	(5,780	)

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

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

Note 56 – Common Stock

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

On March 29, 2017, the Company filed with the ~~Securities Exchange Commission (“SEC”)~~SEC an automatic shelf registration statement on FormS-3 (FileNo. 333-217018), which became effective upon filing, for the offer and sale of up to $150 million of common stock from time to time inat-the-market offerings under the prospectus included therein and in accordance with the Sales Agency Agreement, dated March 29, 2017, between the Company and BNY Mellon Capital Markets, LLC (the “Equity Shelf Program”). During the three months ~~and nine months ending~~ended September 30, ~~2017,~~2018, the Company sold, through the ~~continuous equity offering program with BNY Mellon Capital Markets, LLC as agent,~~Equity Shelf Program, an aggregate of ~~147,077~~259,473 shares of the Company’s common stock in the open market at a weighted average price of ~~$80.07~~$78.83 per share, resulting in proceeds to the Company of ~~$11,659,104,~~$20,250,309 net of ~~$117,769~~$204,549 in agent commissions. During the nine months ended September 30, 2018, the Company sold, through the Equity Shelf Program, an aggregate of 1,145,705 shares of the Company’s common stock in the open market at a weighted average price of $74.32 per share, resulting in proceeds to the Company of $84,298,476 net of $851,500 in agent commissions. During the twelve months ended September 30, 2018, the Company sold, through the Equity Shelf Program, an aggregate of 1,504,335 shares of the Company’s common stock in the open market at a weighted average price of $76.55 per share, resulting in proceeds to the Company of $113,998,400, net of $1,151,499 in agent commissions. As of September 30, ~~2017,~~2018, the Company had up to ~~$138,223,127~~$23,073,229 of common stock available for sale under the program. Net proceeds from the sale of shares of common stock under the Equity Shelf Program are intended for general corporate purposes, including the acquisition of property for the construction, completion, extension, or improvement of pipeline systems and facilities located in and around the communities served by Southwest. ~~Commensurate with these intentions, proceeds during the 3~~^rd ~~quarter of 2017 were contributed to, and reflected in the records of, Southwest (as a capital contribution from the parent holding company).~~

During the nine months ended September 30, ~~2017,~~2018, the Company issued approximately ~~103,000~~78,000 shares of common stock through the Restricted Stock/Unit Plan and Management Incentive Plan.

Also during the nine months ended September 30, 2018, the Company issued 109,000 shares of common stock through the Dividend Reinvestment and Stock Purchase Plan (“DRSPP”), raising approximately $7.8 million.



	27



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

Note 67 – Long-Term Debt

Carrying amounts of long-term debt and related estimated fair values as of September 30, ~~2017~~2018 and December 31, ~~2016~~2017 are disclosed in the following table. Southwest’s revolving credit facility (including commercial paper) and the variable-rate Industrial Development Revenue Bonds (“IDRBs”) approximate their carrying values, as they are repaid quickly (in the case of credit facility borrowings) and have interest rates that reset frequently. These are categorized as Level 1 due to Southwest’s ability to access similar debt arrangements at measurement dates with comparable terms, including variable/market rates. The fair values of Southwest’s debentures, senior notes, and fixed-rate IDRBs were determined utilizing a market-based valuation approach, where fair values are determined based on evaluated


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

pricing data, such as broker quotes and yields for similar securities adjusted for observable differences. Significant inputs used in the valuation generally include benchmark yield curves, credit ratings and issuer spreads. The external credit rating, coupon rate, and maturity of each security are considered in the valuation, as applicable. The fair values of debentures and fixed-rate IDRBs are categorized as Level 2 (observable market inputs based on market prices of similar securities). The Centuri secured revolving credit and term loan facility and Centuri other debt obligations (not actively traded) are categorized as Level 3, based on significant unobservable inputs to their fair values. Because Centuri’s debt is not publicly traded, fair values for the secured revolving credit and term loan facility and other debt obligations were based on a conventional discounted cash flow methodology and utilized current market pricing yield curves, across Centuri’s debt maturity spectrum, of other industrial bonds with an assumed credit rating comparable to the Company’s.

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

Southwest Gas Corporation:

Debentures:

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





   1,173,002       1,197,569





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





Industrial development revenue bonds:

Variable-rate bonds:

Tax-exempt Series A, due 2028
   50,000    50,000    50,000    50,000
2003 Series A, due 2038
   50,000    50,000    50,000    50,000
2008 Series A, due 2038
   50,000    50,000    50,000    50,000
2009 Series A, due 2039
   50,000    50,000    50,000    50,000
Unamortized discount and debt issuance costs
   (2,212 )       (2,489 )





   197,788       197,511





Less: current maturities
   —         (25,000 )





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





Centuri:

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





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





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





Consolidated Southwest Gas Holdings, Inc.:

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





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



	28



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

~~In March 2017,~~



	September 30, 2018					December 31, 2017
	Carrying Amount			Fair Value		Carrying Amount			Fair Value
(Thousands of dollars)
Southwest Gas Corporation:
Debentures:
Notes, 4.45%, due 2020	$	125,000		$	126,808	$	125,000		$	129,273
Notes, 6.1%, due 2041	125,000			147,874		125,000			158,304
Notes, 3.875%, due 2022	250,000			251,003		250,000			256,163
Notes, 4.875%, due 2043	250,000			262,023		250,000			283,243
Notes, 3.8%, due 2046	300,000			273,843		300,000			302,970
Notes, 3.7%, due 2028	300,000			293,304		—			—
8% Series, due 2026	75,000			93,836		75,000			96,063
Medium-term notes, 7.78% series, due 2022	25,000			27,686		25,000			28,714
Medium-term notes, 7.92% series, due 2027	25,000			29,693		25,000			31,542
Medium-term notes, 6.76% series, due 2027	7,500			8,596		7,500			8,882
Unamortized discount and debt issuance costs	(12,037		)			(9,350		)
	1,470,463					1,173,150
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	(1,842		)			(2,119		)
	198,158					197,881
Less: current maturities	—					—
Long-term debt, less current maturities - Southwest Gas Corporation	$	1,818,621				$	1,521,031
Centuri:
Centuri term loan facility	$	189,002		$	195,247	$	199,578		$	207,588
Unamortized debt issuance costs	(941		)			(1,111		)
	188,061					198,467
Centuri secured revolving credit facility	78,217			78,277		56,472			56,525
Centuri other debt obligations	72,171			71,966		47,952			48,183
Less: current maturities	(33,429		)			(25,346		)
Long-term debt, less current maturities - Centuri	$	305,020				$	277,545
Consolidated Southwest Gas Holdings, Inc.:
Southwest Gas Corporation long-term debt	$	1,818,621				$	1,521,031
Centuri long-term debt	338,449					302,891
Less: current maturities	(33,429		)			(25,346		)
Long-term debt, less current maturities - Southwest Gas Holdings, Inc.	$	2,123,641				$	1,798,576



	29



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

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,~~2018, the applicable margin is 1% for loans bearing interest with reference to LIBOR and 0% for loans bearing interest with reference to the alternative base rate. At September 30, ~~2017,~~2018, $150 million was outstanding on the long-term portion (including the commercial paper program, discussed below) and ~~$83~~$9 million was 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. 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,~~ 2018, as noted above, $50 million was outstanding under the commercial paper program.

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

Centuri has a ~~$300~~$450 million senior secured revolving credit and term loan facility that is scheduled to expire in ~~October 2019.~~November 2022. This facility includes a revolving credit facility and a term loan facility. The line of credit portion of the facility is $250 million; amounts borrowed and repaid under the revolving credit facility are available to be re-borrowed. The term loan facility portion ~~had an initial~~has a limit of approximately ~~$150 million, which~~$200 million. The limit on the term loan facility was reached in ~~2014 and had $107 million outstanding (after repayments) at September 30, 2017.~~November 2017; therefore, no further borrowing is permitted under this term loan facility. The ~~$300~~$450 million revolving credit and term loan facility is secured by substantially all of Centuri’s assets except those explicitly excluded under the terms of the agreement (including owned real estate and certain certificated vehicles). Centuri assets securing the facility at September 30, ~~2017~~2018 totaled ~~$526~~$675 million. At September 30, ~~2017, $189~~2018, $267 million in borrowings were outstanding under the Centuri facility.

Additionally, for the nine months ended September 30, 2018, Centuri entered into equipment loans for approximately $40 million with a maturity date of May 2023 under an existing agreement.

Note 78 – Short-Term Debt

~~In March 2017, Southwest Gas Holdings, Inc. entered into~~

The Company has a $100 million credit facility ~~with a borrowing capacity of $100 million~~ that ~~expires~~is scheduled to expire in March 2022. The Company ~~intends to utilize this facility for~~had $22.5 million in short-term ~~financing needs. Interest rates for this facility are calculated~~borrowings outstanding at either the LIBOR or the “alternate base rate,” plus in each case an applicable margin that is determined based on the Company’s senior unsecured debt rating. The applicable margin ranges from 0.75% to 1.50% for loans bearing interest with reference to LIBOR and from 0% to 0.5% for loans bearing interest with reference to the alternative base rate. The Company is also required to pay a commitment fee on the unfunded portion of the commitments based on its senior unsecured long-term debt rating. The commitment fee ranges from 0.075% to 0.200% per annum. At September 30, ~~2017, $27.5 million was outstanding~~2018 under this facility.

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~~$9 million in short-term borrowings outstanding at September 30, ~~2017~~2018 under this facility.



	30



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

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.~~the Company 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 $ —

2018.



	Southwest Gas Holdings, Inc. Equity
	Common Stock			Additional Paid-in Capital			Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Non-controlling Interest
(In thousands, except per share amounts)	Shares	Amount		Additional Paid-in Capital			Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Non-controlling Interest			Total
December 31, 2017	48,090	$	49,720	$	955,332		$	(47,682	)	$	857,398		$	(2,365	)	$	1,812,403
Common stock issuances	1,333	1,333		93,218			—			—			—			94,551
Net income (loss)	—	—		—			—			112,973			(797		)	112,176
Foreign currency exchange translation adjustment	—	—		—			(1,002		)	—			—			(1,002		)
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax	—	—		—			2,687			—			—			2,687
Amounts reclassified to net income, net of tax (FSIRS)	—	—		—			1,907			—			—			1,907
Reclassification of excess deferred taxes (a)	—	—		—			(9,300		)	9,300			—			—
Change in ownership of noncontrolling interest (b)	—	—		(2,710		)	—			—			2,710			—
Dividends declared
Common: $1.56 per share	—	—		—			—			(76,941		)	—			(76,941		)
September 30, 2018	49,423	$	51,053	$	1,045,840		$	(53,390	)	$	902,730		$	(452	)	$	1,945,781


(a)	Release of excess deferred taxes accumulated prior to December 22, 2017 (date of enactment of the TCJA), as a result of the adoption of ASU 2018-02, which permitted such release.

(b)

Centuri, through its subsidiary, NPL, has historically held a 65% ownership interest in IntelliChoice Energy, LLC (“ICE”). A residual interest of 35% has been held by a third party. During the second quarter of 2018, an additional $1 million of capital was contributed by NPL, thereby increasing NPL’s ownership interest to 95%. The carrying amount of the noncontrolling interest has been adjusted with a corresponding charge to Additional paid-in capital on the Company’s Condensed Consolidated Balance Sheet.

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

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

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








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



	Southwest Gas Corporation Equity
	Common Stock			Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings
(In thousands)	Shares	Amount		Additional Paid-in Capital		Accumulated Other Comprehensive Income (Loss)			Retained Earnings			Total
December 31, 2017	47,482	$	49,112	$	948,767	$	(47,073	)	$	659,193		$	1,609,999
Net income	—	—		—		—			79,301			79,301
Other comprehensive income (loss):
Net actuarial gain (loss) arising during period, less amortization of unamortized benefit plan cost, net of tax	—	—		—		2,687			—			2,687
Amounts reclassified to net income, net of tax (FSIRS)	—	—		—		1,907			—			1,907
Reclassification of excess deferred taxes (a)	—	—		—		(9,300		)	9,300			—
Stock-based compensation (b)	—	—		1,899		—			(510		)	1,389
Dividends declared to Southwest Gas Holdings, Inc.	—	—		—		—			(66,000		)	(66,000		)
Contributions from Southwest Gas Holdings, Inc.	—	—		90,644		—			—			90,644
September 30, 2018	47,482	$	49,112	$	1,041,310	$	(51,779	)	$	681,284		$	1,719,927


(a)	Release of excess deferred taxes accumulated prior to December 22, 2017 (date of enactment of the TCJA), as a result of the adoption of ASU 2018-02, which permitted such release.

(b)

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



	31



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

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 in the Condensed Consolidated Balance Sheets and the associated column in the equity table ~~above, as well as the Redeemable Noncontrolling Interest.~~above. 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									Three Months Ended
	September 30, 2018									September 30, 2017
	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	$	334		$	(80	)	$	254		$	333		$	(126	)	$	207
Amortization of net actuarial (gain)/loss	8,404			(2,017		)	6,387			6,362			(2,418		)	3,944
Regulatory adjustment	(7,560		)	1,814			(5,746		)	(5,734		)	2,179			(3,555		)
Pension plans other comprehensive income	1,178			(283		)	895			961			(365		)	596
FSIRS (designated hedging activities):
Amounts reclassified into net income	836			(200		)	636			835			(317		)	518
FSIRS other comprehensive income	836			(200		)	636			835			(317		)	518
Total other comprehensive income - Southwest Gas Corporation	2,014			(483		)	1,531			1,796			(682		)	1,114
Foreign currency translation adjustments:
Translation adjustments	599			—			599			1,012			—			1,012
Foreign currency other comprehensive income (loss)	599			—			599			1,012			—			1,012
Total other comprehensive income - Southwest Gas Holdings, Inc.	$	2,613		$	(483	)	$	2,130		$	2,808		$	(682	)	$	2,126

	Nine Months Ended									Nine Months Ended
	September 30, 2018									September 30, 2017
	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	$	1,002		$	(240	)	$	762		$	1,001		$	(380	)	$	621
Amortization of net actuarial (gain)/loss	25,212			(6,051		)	19,161			19,084			(7,252		)	11,832
Regulatory adjustment	(22,679		)	5,443			(17,236		)	(17,204		)	6,537			(10,667		)
Pension plans other comprehensive income	3,535			(848		)	2,687			2,881			(1,095		)	1,786
FSIRS (designated hedging activities):
Amounts reclassified into net income	2,509			(602		)	1,907			2,507			(953		)	1,554
FSIRS other comprehensive income	2,509			(602		)	1,907			2,507			(953		)	1,554
Total other comprehensive income - Southwest Gas Corporation	6,044			(1,450		)	4,594			5,388			(2,048		)	3,340
Foreign currency translation adjustments:
Translation adjustments	(1,002		)	—			(1,002		)	1,861			—			1,861
Foreign currency other comprehensive income (loss)	(1,002		)	—			(1,002		)	1,861			—			1,861
Total other comprehensive income - Southwest Gas Holdings, Inc.	$	5,042		$	(1,450	)	$	3,592		$	7,249		$	(2,048	)	$	5,201



	32



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

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

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


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

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


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


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


Foreign currency translation adjustments:

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


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


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



	Twelve Months Ended									Twelve Months Ended
	September 30, 2018									September 30, 2017
	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)	$	(43,027	)	$	10,326		$	(32,701	)	$	(22,770	)	$	8,652		$	(14,118	)
Amortization of prior service cost	1,336			(367		)	969			1,335			(507		)	828
Amortization of net actuarial (gain)/loss	31,573			(8,468		)	23,105			25,850			(9,823		)	16,027
Regulatory adjustment	6,865			(844		)	6,021			(4,420		)	1,679			(2,741		)
Pension plans other comprehensive income (loss)	(3,253		)	647			(2,606		)	(5		)	1			(4		)
FSIRS (designated hedging activities):
Amounts reclassified into net income	3,346			(920		)	2,426			3,344			(1,271		)	2,073
FSIRS other comprehensive income	3,346			(920		)	2,426			3,344			(1,271		)	2,073
Total other comprehensive income (loss) - Southwest Gas Corporation	93			(273		)	(180		)	3,339			(1,270		)	2,069
Foreign currency translation adjustments:
Translation adjustments	(1,092		)	—			(1,092		)	1,408			—			1,408
Foreign currency other comprehensive income (loss)	(1,092		)	—			(1,092		)	1,408			—			1,408
Total other comprehensive income (loss) - Southwest Gas Holdings, Inc.	$	(999	)	$	(273	)	$	(1,272	)	$	4,747		$	(1,270	)	$	3,477

(1)

Tax amounts are calculated using a 24% rate following the December 22, 2017 enactment date of the TCJA. For periods prior to the enactment date (and included in specific line items of the tables for the twelve months ended September 30, 2018 and 2017), 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, 2018 is effectively computed using a 24% tax rate overall after the reclassification of previously stranded excess deferred taxes existing as a result of the TCJA (see table for Accumulated other comprehensive income (loss), including the balance, below). With regard to foreign currency translation adjustments, the Company has elected to indefinitely reinvest the earnings of Centuri’s Canadian subsidiaries in Canada, thus preventing deferred taxes on such earnings. As a result of this assertion, the Company is not recognizing any tax effect or presenting a tax expense or benefit for the currency translation adjustment amount reported in Other ~~Comprehensive Income,~~comprehensive income (loss), as repatriation of earnings is not anticipated.

Approximately ~~$2.1~~$2.5 million of realized losses (net of tax) related to the FSIRS, reported in Accumulated other comprehensive income ~~(“AOCI”)~~(loss) at September 30, ~~2017,~~2018, will be reclassified into interest expense within the next 12 months as the related interest payments on long-term debt occur.



	33



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

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

~~AOCI—~~

AOCI - Rollforward

(Thousands of dollars)

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




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




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




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




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




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



	Defined Benefit Plans									FSIRS									Foreign Currency Items
	Before-Tax			Tax (Expense) Benefit (5)			After-Tax			Before-Tax			Tax (Expense) Benefit (5)			After-Tax			Before-Tax			Tax (Expense) Benefit		After-Tax			Other			AOCI
Beginning Balance AOCI December 31, 2017	$	(61,520	)	$	22,293		$	(39,227	)	$	(12,655	)	$	4,809		$	(7,846	)	$	(609	)	$	—	$	(609	)	$	—		$	(47,682	)
Translation adjustments	—			—			—			—			—			—			(1,002		)	—		(1,002		)	—			(1,002		)
Other comprehensive income (loss) before reclassifications	—			—			—			—			—			—			(1,002		)	—		(1,002		)	—			(1,002		)
FSIRS amounts reclassified from AOCI (1)	—			—			—			2,509			(602		)	1,907			—			—		—			—			1,907
Amortization of prior service cost (2)	1,002			(240		)	762			—			—			—			—			—		—			—			762
Amortization of net actuarial loss (2)	25,212			(6,051		)	19,161			—			—			—			—			—		—			—			19,161
Regulatory adjustment (3)	(22,679		)	5,443			(17,236		)	—			—			—			—			—		—			—			(17,236		)
Net current period other comprehensive income (loss) attributable to Southwest Gas Holdings, Inc.	3,535			(848		)	2,687			2,509			(602		)	1,907			(1,002		)	—		(1,002		)	—			3,592
Reclassification of excess deferred taxes (4)	—			—			—			—			—			—			—			—		—			(9,300		)	(9,300		)
Ending Balance AOCI September 30, 2018	$	(57,985	)	$	21,445		$	(36,540	)	$	(10,146	)	$	4,207		$	(5,939	)	$	(1,611	)	$	—	$	(1,611	)	$	(9,300	)	$	(53,390	)


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


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


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


(4)	Release of excess deferred taxes accumulated prior to December 22, 2017 (date of enactment of the TCJA), as a result of the adoption of ASU 2018-02, which permitted such release.


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



	34



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

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

~~AOCI—~~

AOCI - Rollforward

(Thousands of dollars)

   Defined Benefit Plans FSIRS
   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 (10)			After-Tax			Before-Tax			Tax (Expense) Benefit (10)			After-Tax			Other			AOCI
Beginning Balance AOCI December 31, 2017	$	(61,520	)	$	22,293		$	(39,227	)	$	(12,655	)	$	4,809		$	(7,846	)	$	—		$	(47,073	)
FSIRS amounts reclassified from AOCI (6)	—			—			—			2,509			(602		)	1,907			—			1,907
Amortization of prior service cost (7)	1,002			(240		)	762			—			—			—			—			762
Amortization of net actuarial loss (7)	25,212			(6,051		)	19,161			—			—			—			—			19,161
Regulatory adjustment (8)	(22,679		)	5,443			(17,236		)	—			—			—			—			(17,236		)
Net current period other comprehensive income attributable to Southwest Gas Corporation	3,535			(848		)	2,687			2,509			(602		)	1,907			—			4,594
Reclassification of excess deferred taxes (9)	—			—			—			—			—			—			(9,300		)	(9,300		)
Ending Balance AOCI September 30, 2018	$	(57,985	)	$	21,445		$	(36,540	)	$	(10,146	)	$	4,207		$	(5,939	)	$	(9,300	)	$	(51,779	)

~~(5)~~
(6)	The FSIRS reclassification amounts are included in ~~the~~ Net interest deductions ~~line item~~ on Southwest’s Condensed Consolidated Statements of Income.

~~(6)~~
(7)	These AOCI components are included in the computation of net periodic benefit cost (seeNote 2 – Components of Net Periodic Benefit Costfor additional details).

~~(7)~~
(8)	The regulatory adjustment represents the portion of the activity above that is expected to be recovered through rates in the future (the related regulatory asset is included in ~~the~~ Deferred charges and other assets ~~line item~~ on Southwest’s Condensed Consolidated Balance Sheets).

~~(8)~~
(9)	Release of excess deferred taxes accumulated prior to December 22, 2017 (date of enactment of the TCJA), as a result of the adoption of ASU 2018-02, which permitted such release.


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

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

Amounts Recognized in AOCI (Before Tax)

(Thousands of dollars)

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




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

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

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


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

~~The following depicts changes to the balance of the redeemable noncontrolling interest between the indicated periods.~~

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


Balance, September 30, 2017
   $ —



	September 30, 2018			December 31, 2017
Net actuarial (loss) gain	$	(423,343	)	$	(448,555	)
Prior service cost	(3,366		)	(4,368		)
Less: amount recognized in regulatory assets	368,724			391,403
Recognized in AOCI	$	(57,985	)	$	(61,520	)

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

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

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



	35



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

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

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


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

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

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

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


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

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

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


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

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

Results of ~~Construction~~Infrastructure 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~~



(Thousands of dollars)	Twelve Months Ended September 30, 2017
Construction revenues	$	301,040
Operating expenses:
Construction expenses	266,504
Depreciation and amortization	12,318

Operating income	22,218
Other income (deductions)	1,149
Net interest deductions	1,718

Income before income taxes	21,649
Income tax expense	7,842

Net income	13,807
Net income attributable to noncontrolling interests	514

Discontinued operations - construction services - income	$	13,293

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

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

Southwest is engaged in the business of purchasing, distributing, and transporting natural gas for customers in portions of Arizona, Nevada, and California. Southwest is the largest distributor of natural gas in Arizona, selling and transporting natural gas in most of central and southern Arizona, including the Phoenix and Tucson metropolitan areas. Southwest is also the largest distributor of natural gas in Nevada, serving the Las Vegas metropolitan area and 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),~~2018, Southwest had ~~1,999,000~~2,032,000 residential, commercial, industrial, and other natural gas customers, of which ~~1,065,000~~1,082,000 customers were located in Arizona, ~~741,000~~755,000 in Nevada, and ~~193,000~~195,000 in California. Residential and commercial customers represented over 99% of the total customer base. During the twelve months ended September 30, ~~2017,~~2018, 54% of operating margin (gas operating revenues less the net cost of gas sold) was earned in Arizona, 35% in Nevada, and 11% in California. During this same period, Southwest earned 85% of its operating margin ~~(gas operating revenues less the net cost of gas sold)~~ from residential and small commercial customers, 3% from other sales customers, and 12% from transportation customers. These general patterns are expected to remain materially consistent for the foreseeable future.



	36



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

Southwest recognizes operating revenues from the distribution and transportation of natural gas (and related services) to customers. ~~Operating margin~~Gas cost is a ~~financial measure~~tracked cost, which is passed through to customers without markup under purchased gas adjustment (“PGA”) mechanisms, impacting revenues and net cost of gas sold on a dollar-for-dollar basis, thereby having no impact on Southwest’s profitability. Therefore, management routinely uses operating margin, defined ~~by management~~ as ~~gas~~indicated, as operating revenues less the net cost of gas ~~sold. However, operating~~sold, in its analysis of Southwest’s financial performance. Operating margin also forms a basis for Southwest’s various regulatory decoupling mechanisms. Operating margin is not, however, specifically defined in accounting principles generally accepted in the United States (“U.S. GAAP”)~~. Thus, operating margin~~ and is considered anon-GAAP measure. Management uses this financial measure because natural gas operating revenues include the net cost of gas sold, which is a tracked cost that is passed through to customers without markup under purchased gas adjustment (“PGA”) mechanisms. Fluctuations in the net cost of gas sold impact revenues on a~~dollar-for-dollar~~ ~~basis, but do not impact operating margin or operating income. Therefore, management~~ believes operating margin provides investors and other interested parties with useful and relevant information to analyze Southwest’s financial performance in a rate-regulated environment. Refer to the Summary Operating Results table for a reconciliation of revenues to operating margin.

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

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

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

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


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

have implemented or modified pipeline integrity management programs to enhance safety pursuant to federal and state mandates. These programs ~~coupled with recent bonus depreciation tax deduction incentives,~~ have resulted in a significant increase in multi-year pipeline replacement projects throughout the U.S. Centuri has focused its efforts on obtaining pipe replacement work under both blanket contracts and incremental bid projects. For both the twelve months ended September 30, 2018 and 2017, revenues from replacement work provided over 65% of total revenues. Generally, Centuri revenues are lowest during the first quarter of the year due to less favorable winter weather conditions. Revenues typically improve as more favorable weather conditions occur during the summer and fall months. This is expected in both the U.S. and Canadian markets. In certain circumstances, such as with large bid contracts (especially those of a longer duration), or unit-price contracts with revenue caps, results may be impacted by differences between costs incurred and those anticipated when the work was originally bid. Work awarded or ~~failing to be~~not awarded by individual large customers can significantly impact operating results.

This Management’s Discussion and Analysis (“MD&A”) of Financial Condition and Results of Operations should be read in conjunction with the consolidated financial statements and the notes thereto, as well as MD&A included in the ~~2016~~2017 Annual Report to Shareholders, which is incorporated by reference into the ~~2016~~2017 Form10-K.

Executive Summary

The items discussed in this Executive Summary are intended to provide an overview of the results of the Company’s 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%~~77% 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



	37



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

Summary Operating Results

Period Ended September 30,
Three Months Nine Months Twelve Months
2018 2017 2018 2017 2018 2017
(In thousands, except per share amounts)
Contribution to net income
Natural gas operations $ (13,670 ) $ (4,024 ) $ 79,301
$ 82,436
$ 153,683
$ 134,323
Infrastructure services 26,798
14,335
35,034
15,717
57,677
29,010
Corporate and administrative (797 ) (107 ) (1,362 ) (777 ) (1,922 ) (777 )
Net income $ 12,331
$ 10,204
$ 112,973
$ 97,376
$ 209,438
$ 162,556

Average number of common shares 49,493
47,628
48,916
47,577
48,728
47,553
Basic earnings per share
Consolidated $ 0.25
$ 0.21
$ 2.31
$ 2.05
$ 4.30
$ 3.42
Natural Gas Operations
Reconciliation of Revenue to Operating Margin (Non-GAAP measure)
Gas operating revenues $ 217,523
$ 213,059
$ 987,515
$ 935,823
$ 1,354,000
$ 1,276,308
Less: Net cost of gas sold 49,903
45,539
319,101
261,839
412,307
334,888
Operating margin $ 167,620
$ 167,520
$ 668,414
$ 673,984
$ 941,693
$ 941,420

3rd Quarter ~~2017~~2018 Overview

Natural gas operations highlights:

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

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

~~Depreciation and amortization expense declined $10~~Received $49 million refund from El Paso Natural Gas rate settlement

Operating margin reflects regulatory impacts of tax reform

Infrastructure services highlights:

Record quarterly earnings

Revenues increased $71 million compared to the prior-year quarter

~~Operating income~~Construction expenses increased ~~$15.3~~$53 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~~



	38



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

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,
	2018			2017
	(Thousands of dollars)
Gas operating revenues	$	217,523		$	213,059
Net cost of gas sold	49,903			45,539
Operating margin	167,620			167,520
Operations and maintenance expense	104,657			97,359
Depreciation and amortization	47,924			46,194
Taxes other than income taxes	15,036			14,046
Operating income	3			9,921
Other income (deductions)	836			(1,775		)
Net interest deductions	20,399			17,421
Income (loss) before income taxes	(19,560		)	(9,275		)
Income tax expense (benefit)	(5,890		)	(5,251		)
Contribution to consolidated net income (loss)	$	(13,670	)	$	(4,024	)

Contribution from natural gas operations decreased $9.7 million between the third quarters of 2018 and 2017. The decline was primarily due to higher Operations and maintenance expense and Net interest deductions, partially offset by an increase in Other income (deductions) and customer growth. U.S. federal tax reform impacted both revenue and tax expense. The amounts above reflect a reclassification of $4.9 million for 2017 from Operations and maintenance expense to Other income (deductions) related to the non-service cost components of net periodic benefit costs, as a result of the adoption of the update to FASB Topic 715 (refer to Note 2 – Components of Net Periodic Benefit Cost to the condensed consolidated financial statements in this Form 10-Q), with no impact to net income overall. The reclassification in the 2017 period is intended to make that information comparable to the current period presentation.

Operating margin ~~increased $6 million between quarters. Rate relief in Arizona (effective April 2017) and California provided $4 million in operating margin (see~~~~Rates and Regulatory Proceedings~~~~). Approximately~~includes a $2 million ~~in increased operating margin was~~increase attributable to customer growth, as ~~32,000~~33,000 net new customers were added during the last twelve months.

Rate relief in California and other miscellaneous revenues added $1 million in operating margin. These increases were offset by a $3 million decrease in the current quarter related to U.S. tax reform.

Operations and maintenance expense ~~was relatively flat~~increased $7.3 million between quarters. ~~Decreases in employee-related benefit~~Approximately $2 million of the increase was due to higher pension and employee medical costs. Pipeline integrity management and damage prevention programs accounted for approximately $1 million of the increase. The remaining increase was primarily associated with higher information technology related costs ~~more than offset increases in other~~and general ~~costs.~~

cost increases.

Depreciation and amortization expense ~~decreased $10~~increased $1.7 million between quarters primarily due to ~~reduced depreciation rates in Arizona,~~ a ~~result of the recent Arizona general rate case decision. Partially offsetting the decline was increased depreciation associated with a $317~~$480 million, or 5%8%, increase in average gas plant in service for the current quarter as compared to the corresponding quarter a year ago. The increase in gas plant was attributable to pipeline capacity reinforcement work, franchise requirements, scheduled and accelerated pipe replacement activities, and new infrastructure.

~~Taxes other than~~ Increases in depreciation were mitigated by decreases in regulatory account amortization, notably related to Nevada Conservation and Energy Efficiency (“CEE”) programs.

Other income ~~taxes increased $1.6~~(deductions) improved $2.6 million between quarters primarily due to higher property taxes associated with net plant additions and increased property taxes in Arizona, including the impact of a property tax tracking mechanism enacted as part of the recently settled Arizona general rate case.

~~Other income increased $560,000 between quarters primarily due to~~ an increase in the equity portion of the allowance for funds used during construction (“AFUDC”) associated with higher construction expenditures. The equity portion of AFUDC represents the cost of equity funds used to finance utility construction. The equity AFUDC improvement was partially offset by a decline between quarters in income from company-owned life insurance (“COLI”) policies. The current quarter reflects ~~$2.1~~a $4.7 million ~~of income associated with~~increase in COLI policy cash surrender ~~value increases,~~values and incremental net death benefits, while the prior-year quarter reflected ~~$2.3~~$2.1 million of COLI-related income. ~~COLI amounts~~Amounts in ~~each quarter were greater than expected.~~

both periods reflect the non-service cost components of employee pension and other post-retirement benefits.

Net interest deductions increased ~~$1.1~~$3 million ~~between quarters,~~in the third quarter of 2018, as compared to the prior-year quarter, primarily due to the ~~September 2016~~ issuance of $300 million of senior notes ~~partially offset by reductions associated with the redemption of debt ($24.9 million of 4.75% IDRBs~~ in ~~September 2016) and lower interest expense associated with PGA balances as compared to the prior-year quarter.~~

March 2018.



	39



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

Income taxes were impacted in 2018 by the pre-tax earnings impacts discussed above as well as by the December 2017 enactment of tax reform. Among other things, tax reform reduced the corporate federal income tax rate from 35% to 21%, which provides a reduced benefit during periods when seasonal losses are encountered.



	40



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

Results of Natural Gas Operations

Nine-Month Analysis

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




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




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




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




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

~~The contribution~~



	Nine Months Ended
	September 30,
	2018			2017
	(Thousands of dollars)
Gas operating revenues	$	987,515		$	935,823
Net cost of gas sold	319,101			261,839
Operating margin	668,414			673,984
Operations and maintenance expense	312,055			298,827
Depreciation and amortization	145,549			153,643
Taxes other than income taxes	44,959			43,325
Operating income	165,851			178,189
Other income (deductions)	(5,861		)	(5,824		)
Net interest deductions	59,803			51,622
Income before income taxes	100,187			120,743
Income tax expense	20,886			38,307
Contribution to consolidated net income	$	79,301		$	82,436

Contribution to consolidated net income from natural gas operations ~~increased $14.9~~decreased $3.1 million between the first nine months of ~~2017~~2018 and ~~2016.~~2017. The ~~improvement~~decrease was primarily due to higher ~~operating margin~~Operations and ~~lower depreciation~~maintenance expense and Net interest deductions, partially offset by ~~an increase in operations~~customer growth and rate relief. The amounts above for Operations and maintenance ~~expenses.~~

expense and Other income (deductions) for the 2017 period reflect a $14.6 million reclassification related to the non-service cost components of employee pensions and other post-retirement benefits, as a result of the adoption of the update to FASB Topic 715. The reclassification is intended to make the prior period comparable to the current period, but did not impact net income overall.

Operating margin ~~increased $17~~declined $5.6 million between the comparative nine-month ~~periods. Rate~~periods, due to a $15 million decrease related to the enactment of U.S. tax reform in December 2017. The decrease relates to a reduction in rates to reflect the reduced cost of service during 2018 resulting from tax reform. The decline in applicable U.S. income tax rates also significantly reduced income tax expense. Operating margin was favorably impacted by rate relief in the Arizona and California jurisdictions, which collectively provided ~~$10~~$5 million in operating margin. Customer growth provided approximately $8 million in additional operating margin. The residual variance relates to the combined impacts of reduced surcharge recoveries including Nevada CEE programs (offset in Depreciation and amortization expense below), as well as variability in other miscellaneous revenues and margin ~~(see~~~~Rates and Regulatory Proceedings~~~~). The remaining $7 million increase was attributable to customer growth.~~

from customers outside the decoupling mechanisms.

Operations and maintenance expense increased ~~$11.4~~$13.2 million ~~or 4%,~~ between periods due primarily to $5 million associated with higher pension service cost and other employee benefit cost and $2.5 million in incremental expenditures for pipeline integrity management and damage prevention programs. Residual increases are attributable to higher information technology related costs and other 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~~$8.1 million between periods primarily due to reduced depreciation rates in Arizona, a result of the ~~recent~~April 2017 Arizona general rate case ~~decision.~~decision, and to the impacts of surcharge recoveries for regulatory mechanisms, as discussed above. Partially offsetting the decline was additional depreciation expense associated with a $456 million, or 7%, increase in average gas plant in service for the current period as compared to the prior period. The ~~depreciation decrease also~~increase 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 periods primarily due to higher property taxes associated with plant additions.



	41



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

Other income (deductions) was flat between periods. The current period included ~~a decline~~an increase in interest income of ~~approximately $3.7~~$2.5 million ~~in amortization~~ related to the ~~recovery~~Gas Infrastructure Replacement (“GIR”) mechanism in Nevada. (See the Rates and Regulatory Proceedings section for more information about the GIR mechanism.) This was offset by a $1 million decrease in equity AFUDC due to a lower rate in the current period as compared to the prior period, and an increase in non-service cost components of employee pension and post-retirement benefits costs of $1.3 million.

Net interest deductions increased $8.2 million between periods, primarily due to higher interest associated with credit facility borrowings during the current period and the issuance of $300 million of senior notes in the first quarter of 2018.

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



	42



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

Results of Natural Gas Operations

Twelve-Month Analysis



	Twelve Months Ended
	September 30,
	2018			2017
	(Thousands of dollars)
Gas operating revenues	$	1,354,000		$	1,276,308
Net cost of gas sold	412,307			334,888
Operating margin	941,693			941,420
Operations and maintenance expense	404,549			393,632
Depreciation and amortization	193,828			212,693
Taxes other than income taxes	59,580			56,221
Operating income	283,736			278,874
Other income (deductions)	(6,425		)	(9,200		)
Net interest deductions	77,914			69,464
Income before income taxes	199,397			200,210
Income tax expense	45,714			65,887
Contribution to consolidated net income	$	153,683		$	134,323

Contribution to consolidated net income from natural gas operations increased by $19.4 million between the twelve-month periods of 2018 and 2017. The improvement was primarily due to rate relief and Income tax expense, partially offset by increases in Operations and maintenance expense, Taxes other than income taxes, and Net interest deductions. The amounts above for Operations and maintenance expense and Other income (deductions) for the 2017 period reflect a $19.5 million reclassification related to the non-service cost components of employee pensions and other post-retirement benefits, as a result of the adoption of the update to FASB Topic 715. The reclassification is intended to make the prior period comparable to the current period, but did not impact net income overall.

Operating margin remained relatively flat between periods. Combined rate relief in the Arizona and California jurisdictions provided $11 million of operating margin. Customer growth provided another $10 million in operating margin, while operating margin associated with recoveries of regulatory ~~assets.~~assets, infrastructure replacement mechanisms, customers outside the decoupling mechanisms, and other miscellaneous revenues decreased $6 million. The impacts of tax reform, described earlier, decreased operating margin by $15 million in the current period. However, net income overall was not unfavorably impacted, as favorable impacts from tax reform are reflected in income tax expense.

Operations and maintenance expense increased $10.9 million, or 3%, between periods primarily due to a $4 million increase in service-cost-related pension expense and $3 million in expenditures for pipeline damage prevention programs.

Depreciation and amortization expense decreased $18.9 million between periods primarily due to reduced depreciation rates in Arizona, a result of the April 2017 Arizona general rate case decision, in addition to the impact from changes in regulatory surcharge recoveries on amortization. Partially offsetting ~~these declines~~the decline was depreciation associated with a ~~$325~~$430 million, or 5%7%, increase in average gas plant in service for the current period as compared to the prior period. The increase in gas plant was attributable to pipeline capacity reinforcement work, franchise requirements, scheduled and accelerated pipe replacement activities, and new infrastructure.

Taxes other than income taxes increased ~~$3.8~~$3.4 million, or 6%, between periods primarily due to higher property taxes associated with net plant ~~additions and increased property taxes in Arizona, including the impact of the Arizona property tax tracking mechanism.~~

additions.

Other income ~~which principally includes returns on~~(deductions) improved $2.8 million between the twelve-month periods of 2018 and 2017 primarily due to an increase in interest income related to the GIR mechanism in Nevada. Income resulting from increases in the cash surrender value of COLI policies and~~non-utility~~ ~~expenses, increased $2~~ net death benefits recognized was $9.5 million ~~between periods. The~~in the current period ~~reflects $6.8~~and $8.8 million ~~of income associated with COLI policy cash surrender value increases, while~~in the prior-year ~~period~~period. The non-service cost components of employee pension and post-retirement benefits are 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.

both periods.



	43



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

~~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~~

Net interest deductions increased ~~by $14.5~~$8.5 million between the ~~twelve-month periods of 2017~~current and ~~2016. The improvement was~~prior-year period 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 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 of the incremental costs recognized were associated with the amount and timing of employee incentive plan grants (including accelerated recognition for retirement-eligible employees). Pipeline integrity management and damage prevention programs collectively 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 million between periods primarily due to higher property taxes associated primarily with net plant additions and increased property taxes in Arizona, including the impact of 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~~credit facility borrowings during late 2017 and ~~2016. The current period reflects an $8.8 million increase in COLI policy cash surrender values, while~~early 2018 and the ~~prior-year period reflected $7.5 million~~issuance 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~~notes in the ~~redemption~~first quarter of ~~debt ($100~~2018.

Income taxes were favorably impacted during the twelve months ending September 30, 2018 due to the December 2017 enactment of tax reform, which reduced the corporate federal income tax rate from 35% to 21%, effective January 2018. Approximately $8 million 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~~one-time tax benefits related to the ~~prior-year period.~~

remeasurement of deferred tax liabilities were recorded in the fourth quarter of 2017, in addition to the lower rate utilized in 2018.



	44



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

Results of ~~Construction~~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 net income from construction services~~



	Three Months Ended
	September 30,
	2018		2017
	(Thousands of dollars)
Construction revenues	$	450,623	$	380,094
Operating expenses:
Construction expenses	395,862		342,629
Depreciation and amortization	14,232		12,335
Operating income	40,529		25,130
Other income (deductions)	38		(210		)
Net interest deductions	3,945		1,962
Income before income taxes	36,622		22,958
Income tax expense	9,824		8,407
Net income	26,798		14,551
Net income attributable to noncontrolling interest	—		216
Contribution to consolidated net income attributable to Centuri	$	26,798	$	14,335

In November 2017, Centuri acquired New England Utility Constructors, Inc. (“Neuco”). Line items in the ~~current~~table above reflect the results of Neuco only for the 2018 period due to the date of acquisition.

Construction revenues increased $70.5 million in the third quarter ~~decreased by $542,000~~of 2018 when compared to the prior-year ~~quarter. The decrease is~~quarter, primarily due to $50.4 million of revenues contributed by Neuco and a higher ~~construction costs relative to increased revenues, resulting from apre-tax~~ ~~loss on a project described below, partially offset by a decline in depreciation and amortization.~~

~~Revenues increased $40.3 million, or 12%, between quarters primarily due to an increase in~~volume of pipe replacement work ~~with existing customers. A significant portion of the increase relates to~~under blanket and bid ~~jobs that are expected to be substantially complete by year end.~~

contracts.

Construction expenses increased ~~$42~~$53.2 million ~~or 14%,~~ between quarters due to additional pipe replacement ~~work.~~ work and higher labor-related and operating expenses to support increased growth. Approximately $34.8 million of construction expenses associated with Neuco are included in the three months ended September 30, 2018.

Depreciation and amortization expense increased $1.9 million between quarters, primarily due to incremental amortization of finite-lived intangible assets recognized from the Neuco acquisition and to depreciation on additional equipment purchased to support the growing volume of work being performed, partially offset by a $1.6 million reduction in depreciation associated with an extension (in the first quarter of 2018) of the estimated useful lives of certain depreciable equipment.

Net interest deductions increased by $2 million between quarters due primarily to higher average debt outstanding under the existing $450 million secured revolving credit and term loan facility in 2018 and higher rates on variable-rate debt.

Income taxes increased $1.4 million between quarters; however, the 2018 quarter reflects lower U.S. federal income tax rates following tax reform applied to an increased level of earnings.



	45



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

Results ~~were negatively~~of Infrastructure Services

Nine-Month Analysis



	Nine Months Ended
	September 30,
	2018			2017
	(Thousands of dollars)
Construction revenues	$	1,105,844		$	872,536
Operating expenses:
Construction expenses	1,007,485			806,586
Depreciation and amortization	40,392			35,446
Operating income	57,967			30,504
Other income (deductions)	(331		)	38
Net interest deductions	10,448			5,095
Income before income taxes	47,188			25,447
Income tax expense	12,951			9,560
Net income	34,237			15,887
Net income (loss) attributable to noncontrolling interest	(797		)	170
Contribution to consolidated net income attributable to Centuri	$	35,034		$	15,717

Line items in the table above reflect the results of Neuco only for the 2018 period as the acquisition occurred in November 2017.

Construction revenues increased $233.3 million during the first nine months of 2018 when compared to the same period in the prior year due to an increased volume of replacement work for many natural gas distribution customers, the contribution of $98.6 million in revenue from Neuco in 2018, the resumption of work following a customer’s temporary work stoppage that impacted ~~by higher construction costs for~~prior-year performance, and the settlement of an outstanding contract dispute associated with a water pipe replacement ~~project, for which Centuri has requested~~project.

Construction expenses increased ~~cost recovery. No~~$200.9 million between periods. The increase is due to additional pipe replacement work ~~orders will be accepted on~~and higher labor costs incurred to complete work during inclement weather conditions during the ~~project pending resolution~~first quarter of ~~Centuri’s request.~~2018. Approximately $78.6 million of construction expenses associated with Neuco are included in the nine months ended September 30, 2018. Gains on sale of equipment (reflected as an offset to construction expenses) were approximately ~~$25,000~~$1 million and ~~$1.4~~$1.5 million for the ~~third quarters~~first nine months of 2018 and 2017, ~~and 2016,~~ respectively.

Depreciation and amortization ~~decreased $1.1~~increased $4.9 million between ~~quarters,~~periods, primarily due to incremental amortization of finite-lived intangible assets recognized from the Neuco acquisition and to depreciation on additional equipment purchased to support the growing volume of work being performed, partially offset by a $2$5.5 million reduction in depreciation expense associated with the extension of the estimated useful lives of certain depreciable ~~equipment during~~equipment.

Net interest deductions increased by $5.4 million between periods due primarily to higher average debt outstanding under the ~~past 12 months, partially offset by~~existing $450 million secured revolving credit and term loan facility in 2018 and higher rates on variable-rate debt.

Income taxes increased $3.4 million between periods; however, the 2018 period reflects lower U.S. federal income tax rates following tax reform applied to an ~~increase in depreciation for additional equipment purchased to support the growing volume~~increased level of ~~work being performed.~~

earnings.



	46



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

Results of Infrastructure Services

Twelve-Month Analysis



	Twelve Months Ended
	September 30,
	2018			2017
	(Thousands of dollars)
Construction revenues	$	1,479,792		$	1,173,576
Operating expenses:
Construction expenses	1,349,862			1,073,090
Depreciation and amortization	53,975			47,764
Operating income	75,955			52,722
Other income (deductions)	(24		)	1,187
Net interest deductions	13,339			6,813
Income before income taxes	62,592			47,096
Income tax expense	5,781			17,402
Net income	56,811			29,694
Net income (loss) attributable to noncontrolling interest	(866		)	684
Contribution to consolidated net income attributable to Centuri	$	57,677		$	29,010

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

Construction ~~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 net income from construction services for~~revenues increased $306.2 million in the ~~first nine months of 2017 declined by $3.6 million when~~current twelve-month period compared to the ~~prior-year period. The decrease is~~same period of 2017, primarily due to a higher ~~construction costs relative to~~volume of pipe replacement work under blanket contracts and the contribution of approximately $115.8 million in revenue from Neuco since the November 2017 acquisition date. In addition, Centuri performed work on a multi-year water pipe replacement program, which began in late 2016, that contributed incremental revenues of $61.7 million and $38.2 million during the twelve-month periods ended September 30, 2018 and 2017, respectively.

Construction expenses increased ~~revenues, partially offset by a decline in depreciation and amortization.~~

~~Revenues increased $34.5~~$276.8 million ~~or 4%, in the first nine months of 2017 when compared to the prior-year period~~between periods, primarily due to ~~increased~~additional pipe replacement ~~work. Partially offsetting increases~~work and greater operating expenses to support growth in revenues was a temporary work stoppage by a significant customer that began in the first quarter of 2017 and continued through part of the second quarter of 2017 resulting in a $26.3 million reduction in revenues, compared to the prior-year period, and a $3.7 million~~pre-tax~~ loss in the current nine-month period. The temporary work stoppage was initiated due to state-mandated requalification of employees of all contractors working within the jurisdictional boundary of one state. Operations resumed gradually following the requalification of Centuri’s employees during the second quarter of 2017. Additionally, inclement weather in several operating areas negatively impacted revenues and reduced productivity in the first quarter of 2017.

Construction expenses increased $48.7 million, or 6%, between periods. The increase in construction expenses is disproportionate to revenues noted above due in part to logistics surrounding the timing and length of the temporary work stoppage with the significant customer and to higher labor costs incurred to complete work during inclement weather conditions in the first quarter.operations. In addition, results were negatively impacted by higher construction ~~andstart-up~~costs related to the water pipe replacement ~~project, for which Centuri is pursuing cost recovery.~~program noted above. Approximately $94.6 million of construction expenses from Neuco are included in the twelve months ended September 30, 2018. Gains on sale of equipment (reflected as an offset to construction expenses) were ~~approximately $1.5~~$3.7 million and ~~$4.1~~$4.5 million for the ~~first nine months~~twelve-month periods of 2018 and 2017, ~~and 2016,~~ respectively.

Depreciation and amortization ~~decreased $7.9~~expense increased $6.2 million between the current and prior-year periods primarily due to ~~an $8.2~~incremental amortization of finite-lived intangible assets recognized from the Neuco acquisition and to depreciation on additional equipment purchased to support the growing volume of work being performed, partially offset by a $6.4 million reduction in depreciation associated with the extension of the estimated useful lives of certain depreciable ~~equipment during~~equipment.

Net interest deductions increased $6.5 million between periods due primarily to higher average debt outstanding under the ~~past 12 months, partially offset by an increase~~existing $450 million secured revolving credit and term loan facility in ~~depreciation for additional equipment purchased~~the current twelve-month period and higher rates on variable-rate debt.

Income tax expense decreased $11.6 million between periods, primarily due to ~~support~~approximately $12 million of one-time tax benefits related to the ~~growing volume~~remeasurement of ~~work being performed.~~

Centuri’s deferred tax liabilities that were recorded in the fourth quarter of 2017, and to lower income tax rates in effect in 2018. These impacts collectively resulted from U.S. tax reform.



	47



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

~~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

Arizona Jurisdiction

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

~~LNG (“~~

Tax Reform. In February 2018, the ACC directed all Arizona utilities to address tax savings from the enactment of tax reform pursuant to the Tax Cut and Jobs Act (the “TCJA”) beginning January 1, 2018 through a tax expense adjuster mechanism, a notice of intent to file a rate case, or through a separate application. In April 2018, Southwest filed an application with the ACC, requesting approval for a tax refund process or, in the alternative, the authority to file a general rate case to reflect tax reform. The requested tax refund process was designed to ensure customers receive the benefits from tax reform through an ACC-approved earnings test, whereby a tax refund application would be made annually to refund to customers any margin contributing to earnings above the ACC-authorized rate of return. The ACC staff (the “Staff”) recommended that Southwest refund customers a one-time credit to reflect the tax savings from January through July 2018, effective with Southwest’s August 2018 billing cycles and that, effective August 2018, surcredits be established on a per-therm basis until new cost-of-service rates become effective following the Company’s next general rate case. Other recommendations included supplemental compliance reports related to excess deferred income taxes and an annual true-up to account for differences between the actual tax savings and the amount authorized by the ACC. In July 2018, the ACC issued a decision (the “Decision”) approving the Staff’s recommendations. The Decision addressed current tax reductions due to tax reform through refunding customers approximately $20 million annually (as compared to rate levels established in the most recent general rate case effective April 2017) until new general rates are approved. However, it did not direct refunding to commence with regard to excess amounts from the remeasurement of deferred tax balances, which continue to be recognized as a regulatory liability beginning with the enactment date of tax reform (see Note 1 – Nature of Operations and Basis of Presentation). Through September 2018, Southwest reflected approximately $15 million of the $20 million annual amount as a reduction in revenue and is tracking monthly differences between amounts expected to be returned and amounts actually returned to customers, resulting in a liability balance of $2.4 million as of September 30, 2018.

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 in natural gas deliveries in the southern Arizona area by providing a local storage option, to be operated by Southwest and connected directly to its distribution system. In December 2014, Southwest received an order from the ACC granting~~pre-approval~~ preapproval of Southwest’s application to construct the LNG facility and the deferral of costs, up to $50 ~~million. Following the December 2014 preapproval, Southwest purchased the site for the facility~~million, which was later approved (December 2016) to be modified not to exceed $80 million, following land purchase and ~~completed detailed engineering design specifications for the purpose of soliciting bids~~bid solicitation for the engineering, procurement, and construction ~~(“EPC”)~~ of the facility. ~~Southwest solicited requests for proposals for the EPC phase of the project, and in October 2016 made a filing with the ACC to modify the previously issued Order to update thepre-approved~~ ~~costs to reflect anot-to-exceed~~ amount of $80 million, which was approved by the ACC in December 2016. Through September 2017, Southwest has incurred approximately $21.7 million in capital expenditures toward the project (including land acquisition costs). Construction commenced during the third quarter of 2017 and is expected to be completed by the end of 2019.

Through September 2018, Southwest has incurred approximately $51 million in capital expenditures toward the project (including land acquisition costs).

COYL Program. Southwest received approval, in connection with an earlier Arizona general rate case, to implement a program to conduct leak surveys, and if leaks were present, to replace and relocate service lines and meters for Arizona customers whose meters were set off from the customer’s home, which is not a traditional configuration. ~~Customers with this configuration were previously responsible for~~“Phase II” of the ~~cost~~COYL program included the replacement of ~~maintaining these lines and were subject to the immediate cessation of natural gas service iflow-pressure~~ ~~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 revised annually as the program progresses. In ~~2014, Southwest received approval to add a “Phase II” component to~~ the ~~COYL program to include the replacement ofnon-leaking~~ ~~COYLs. In the most recent~~ annual COYL filing made in February 2017, Southwest requested to establish an annual surcharge to collect $1.8 million related to the revenue requirement associated with $12.1 million in capital projects completed under both ~~Phase I and Phase II~~phases during 2016. In June 2017, the ACC issued a decision approving the surcharge application. All capital work completed in earlier years was incorporated in Southwest’s Arizona rate base in connection with the recently completed general rate case proceeding, as discussed above.

In the annual COYL filing made in February 2018, Southwest requested surcharge revenue of $4.2 million (an increase of $2.4 million from $1.8 million) related to 2017 expenditures of $18 million. In September 2018, the ACC approved the proposed surcharge application, while modifying the surcharge revenue to $3.5 million (an increase of $1.7 million) to reflect the impact of tax reform on the revenue requirement calculation.



	48



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

~~Vintage Steel Pipe Program~~.

VSP Program. Southwest received approval, in connection with its most recent Arizona general rate case, to implement a ~~vintage steel pipe (“VSP”)~~VSP replacement program. Southwest currently has approximately 6,000 miles ofpre-1970s vintage steel pipe in Arizona. Southwest proposed to start replacing the pipe on an accelerated basis and to recover the costs through an annual surcharge filing that will be made in February of each year. The surcharge is designed to be revised annually as the program progresses. A Plan of Administration (“POA”), which was filed in March of 2017 and was approved in conjunction with the general rate case, outlined the VSP program requirements and established the timeline for future project plans and surcharge requests. Southwest ~~is currently targeting the replacement of nearly~~replaced approximately 40 miles of VSP during 2017 totaling approximately $27 million and is targeting replacement projects during 2018 of approximately $100 million.

~~California Jurisdiction~~

~~Attrition Filing.~~ In ~~November 2016,~~the annual VSP filing made in February 2018, Southwest ~~made its latest annual post-test year (“PTY”) attrition filing with~~requested to establish a surcharge to collect $3.1 million related to 2017 expenditures. In September 2018, the ~~California Public Utilities Commission (“CPUC”), requesting annual~~ACC approved the proposed surcharge application, while modifying the surcharge revenue ~~increases~~to $2.4 million to reflect the impact of $2.1 million in southern California, $513,000 in northern California, and $256,000 for South Lake Tahoe. This filing was approved in December 2016 and rates were made effective in January 2017. At the same time, rates were updated to recover the regulatory asset associated withtax reform on the revenue ~~decoupling mechanism, or margin tracker.~~

requirement calculation.

California Jurisdiction

California General Rate ~~Case~~.Case. In December 2016, Southwest filed to modify the most recent general rate case decision to extend the current rate case cycle by two years, including extension of the annual ~~PTY~~post-test year (“PTY”) attrition adjustments through 2020 from 2018. That latest rate case decision would have otherwise required Southwest to file its next general rate application by September 2017. Expedited consideration was requested and in June 2017, the ~~CPUC~~California Public Utilities Commission (the “CPUC”) approved the request, thereby extending the rate case filing ~~deadline.~~deadline to September 2019. Southwest believes this extension is in the public interest as it provides rate stability to customers for two additional years consistent with the current reasonable rates approved as part of the last general rate case, and the ~~current revenue requirement and rate of return are not in need of adjustment (with the~~ continuation of the currently approved 2.75% PTY attrition adjustment for the two additional ~~years).~~

years. Also see Attrition Filing below.

Tax Reform. In its 2017 decision approving Southwest’s request to extend the filing date of its next general rate case, the CPUC directed Southwest to track income tax expense resulting from mandatory or elective changes in tax law, procedure, or policy during the period of the rate case extension. The purpose is to identify differences between Southwest’s authorized income tax expense and its actual incurred income tax expense during calendar years 2019 and 2020, the result of which would be reviewed in Southwest’s next general rate case. Southwest does not currently anticipate making an ad hoc filing in advance of the next general rate case filing to implement any changes resulting from tax reform.

Attrition Filing. In November 2017, Southwest made its latest annual PTY attrition filing, requesting annual revenue increases of $2 million in southern California, $527,000 in northern California, and $263,000 for South Lake Tahoe. This filing was approved in December 2017 and rates were made effective in January 2018. At the same time, rates were updated to recover the regulatory asset associated with the revenue decoupling mechanism, or margin tracker.

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

Nevada Jurisdiction

Nevada General ~~Revenues Adjustment.~~~~In June 2016, Southwest requested authorization~~Rate Case. The currently effective general rate case decision was received from the Public Utilities Commission of Nevada ~~(“PUCN”~~(the “PUCN”) in November 2012 as amended in a Rehearing Decision in April 2013. Southwest filed its most recent general rate case with the PUCN in May 2018 and updated the request following the certification period ending in July 2018. The filing requests a statewide overall general rate increase of approximately $29.7 million to account for changes in the cost of service ($12.1 million) since the last general rate case, including those resulting from the TCJA, and another $17.6 million associated with the inclusion in rate base of GIR projects previously approved by the PUCN under the ongoing program. The application also requests a return on common equity of 10.3%, and a capital structure utilizing a 49.3% equity ratio. In association with the proposed changes, depreciation expense is expected to increase by approximately $4 million, for a net operating income impact of approximately $25 million. Southwest also seeks to adjust the GIR rate as part of the rate case process in lieu of filing a separate GIR rate application later this year. That adjustment would result in estimated incremental operating margin of $6 million.



	49



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

In addition to the foregoing, Southwest is requesting to implement a pension tracker to account for the changes in pension expense between rate cases. Southwest also proposes to include two new tariff schedules (1) compression service and (2) biogas and renewable natural gas service. There are no changes to rate design overall, and a request to continue the general revenues adjustment (the “GRA”) mechanism (revenue decoupling mechanism) is included. The PUCN Staff and the Bureau of Consumer Protection (the “BCP”) each filed testimony requesting various changes to the proposed cost of service, including recommending a return on common equity of 9.4% and 9.3%, respectively. The PUCN Staff proposed an overall annual increase of approximately $13.9 million, but proposed to offset that with approximately $16.5 million of imputed revenue on contracts for service the Company has with several of its large customers. The BCP has proposed an annual increase of approximately $2.2 million, with a smaller offset for imputed revenues on the large customer contracts. Management cannot predict how these proposals will impact the ultimate decision of the PUCN, but currently expects that an order will be received during the fourth quarter of 2018 and that new rates will become effective no later than January 1, 2019. See also Tax Reform and Infrastructure Replacement Mechanisms below.

Tax Reform. The PUCN opened an investigation into the TCJA, requiring comments to be filed by April 2018. Southwest filed comments, whereby it described its plan to address the tax changes in its general rate case that was filed in May 2018. The PUCN issued a decision in October 2018 affirming that the pending Nevada rate case is the appropriate forum for addressing the impact of the TCJA on ratepayers, and recommended that the Company refrain from amortizing any excess accumulated deferred tax balances until the rate case is resolved.

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

reduced.

Infrastructure Replacement ~~Mechanisms.~~Mechanism.In January 2014, the PUCN approved final rules for a mechanism to defer and recover certain costs associated with accelerated replacement of infrastructure that ~~does~~would not otherwise currently provide incremental revenues. Associated with ~~such~~the replacement of various types of pipe infrastructure under the mechanism (Early Vintage Plastic Pipe (“EVPP”), COYL and VSP), each year Southwest files a ~~Gas Infrastructure Replacement (“GIR”) Advance Application~~GIR “Advance Application” requesting ~~authority~~authorization to replace qualifying infrastructure and files separately as part of an annual GIR filing to reset the recovery surcharge, related to previously approved and completed projects. For projects approved in 2015 and completed in 2016, the annualized revenue was approximately $4.5 million. In September 2016, Southwest filed to adjust the GIR surcharge to recover the annual revenue requirement for amounts previously deferred. This filing was approved in December 2016 and new rates became effective January 2017. In June 2016, Southwest filed 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 approximatelyinfrastructure. Approximately $57.3 million of replacement work was approved for 2017 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 is expected to be approved in December 2017 with rates becoming effective January 2018.~~

In May 2017, Southwest filed ~~a GIR~~its Advance Application ~~with the PUCN~~ for projects totaling approximately $66 million that are expected to be completed during 2018. Similar to previous years, the proposed projects consist of early vintage plastic and early vintage steel pipe, as well as the continuation of the previously approved COYL program in northern Nevada. Southwest entered into a settlement agreement with the intervening parties and filed a proposed stipulation requesting the Commission approve the settlement agreement. The settlement agreement proposed that the request be approved as filed and that Southwest be authorized to start replacing COYLs in southern Nevada in certain situations, and to recover costs through the GIR mechanism. The PUCN issued an ~~Order~~order on ~~the GIR~~that Advance Application in September 2017, approving approximately ~~$65.7~~$66 million of replacement work ~~(with~~with an annualized revenue requirement estimated at $6 million.

In June 2018, Southwest filed its Advance Application with projects totaling $228 million to be completed over a three-year period, with a total annualized revenue requirement (following the three-year replacement period) of approximately $6$21.7 million. Historically, Southwest has requested approval of projects on an annual basis; however, it requested to move to a multi-year approval process for projects to improve operational flexibility and enhance coordination with contractors and governmental agencies. The PUCN issued a decision limiting its approval to the 2019 projects, resulting in an annual approval of $35.3 million for projects to be completed in 2019 (EVPP $9.3 million, COYL $1.3 million, and VSP $24.7 million) ~~and the COYL provisions in southern Nevada.~~

~~Subsequent~~.

Filed separately, as part of each GIR filing, Southwest requests authorization to ~~three GIR rate applications,~~reset the GIR ~~regulations require Southwest~~recovery surcharge related to ~~either file~~previously approved and completed projects, with new rates becoming effective each January. In November 2017, for projects approved in 2016 and completed by July 2017, a deferred annualized revenue requirement of $8.7 million was approved to be recovered from customers through updated rates effective January 2018. Included as part of the 2018 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~~(noted above), management proposed to ~~these regulations, necessitating a request for waiver to permit Southwest to proceed with~~adjust the GIR ~~program without filing a general~~surcharge rate as part of the rate case in ~~2017. This waiver was approved by~~lieu of filing a separate application during the ~~PUCN~~third quarter, which would be expected to result in ~~January 2017; however, in order to continue~~incremental annual margin of approximately $6 million. A decision is expected during 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~~fourth quarter of 2018.

Conservation and Energy ~~Efficiency (“~~Efficiency(“CEE”). In June 2015, Southwest requested recovery of energy efficiency and conservation development and implementation costs, including promotions and incentives for various programs, as originally approved for deferral by the PUCN effective November 2009. While recovery of initial program costs was approved as part of the most ~~recent~~recently completed general rate case, amounts incurred subsequent to May 2012 (the related certification period) continued to be deferred. Approved rates for thepost-May 2012 costs deferred (including previously expected program expenditures for 2016) became



	50



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

effective January ~~2016 and resulted in annualized margin increases of $2 million in northern Nevada and $8.5 million in southern Nevada. Then, as part of the~~2016. The 2017 ARA filing approved in ~~December 2016, Southwest~~November 2017, with modified rates effective January ~~2017,~~2018, is expected to result in annualized margin decreases of $8.2 million in southern Nevada and $1.4 million in northern Nevada ~~and $1.3~~to return over-collected balances. As part of the 2018 ARA filing, Southwest requested modified rates, effective January 2019, which would authorize an annualized margin decrease of $4 million in southern Nevada ~~to return over-collected balances.~~and a $100,000 increase in northern Nevada. There is, however, no anticipated impact to net income overall from these ~~decreases~~changes as amortization expense will ~~also~~ be ~~reduced.~~

impacted directionally the same and by the same amounts.

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~~Hearings took place in April 2018, and in May, the ~~extension of existing facilities~~PUCN issued an order approving Southwest’s proposal to ~~Mesquite at an estimated cost~~expand natural gas infrastructure to Mesquite. The order approves a capital investment of approximately ~~$30 million.~~$28 million and the construction of approximately 37 miles of distribution pipeline (including the approach main). The cost is ~~proposed~~expected to be recovered through a volumetric ~~surcharge on~~rates from all southern Nevada ~~customers. A second phase~~customers (including new customers in Mesquite). The annual revenue requirement associated with the project is ~~then proposed~~$2.8 million. Southwest has begun preliminary design work and is currently targeting the first quarter of 2019 to ~~convert existing homes to~~start serving certain customers with an approved virtual pipeline network, which is a temporary natural gas ~~service, which will be charged as~~supply using a ~~separate surcharge~~limited distribution system and compressed natural gas tanks. It is estimated that permitting and construction of the approach main to bring the permanent supply to Mesquite ~~customers only. A decision on this proposal is expected within~~and construction of the ~~required210-day~~ ~~time period for filings of this type.~~

remaining approved distribution system could take up to two years to complete.

Federal Energy Regulatory Commission (“FERC”) Jurisdiction

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

2018 Expansion. In response to growing demand in the Carson City and South Lake Tahoe areas of northern California and northern Nevada, Paiute ~~Pipeline Company (“Paiute”)~~ evaluated shipper interest in acquiring additional transportation capacity and executed precedent agreements for incremental transportation capacity with Southwest during the third quarter of 2016. In October 2016, Paiute initiated apre-filing review process with the FERC for an expansion project, which was approved during the same month. In July 2017, a certificate application was filed, which included an applicant environmental assessment. ~~The~~In May 2018, the FERC issued a Certificate of Public Convenience and Necessity authorizing Paiute to construct the $18 million project. Following receipt of contractor pricing for the project, ~~is anticipated~~Paiute updated the project costs to reflect approximately $22 million and made a filing with FERC requesting to amend the certificate order to reflect the updated cost estimates. In October 2018, the FERC issued an order amending the certificate to reflect updated costs of the project. Construction work began in July 2018 and will consist of 8.5 miles of additional transmission pipeline ~~infrastructure at an approximate~~infrastructure. The project is expected to be completed and placed in service in November 2018.

Tax Reform. The FERC issued a Notice of Proposed Rulemaking (“NOPR”) on whether the federal income tax changes of the TCJA cause pipeline rates to no longer be just and reasonable. The NOPR provided for pipelines to file a FERC Form No. 501-G to evaluate the impact of tax reform on their revenue requirement. In addition to filing the form, pipelines would select one of the following four options: (1) make a limited “Section 4” filing to reduce its rates by the percentage reduction in its cost of ~~$18 million. If~~service shown in its FERC Form No. 501-G; (2) commit to file either a prepackaged uncontested rate settlement or a general Section 4 rate case; (3) file a statement explaining why no change in rates is necessary; or (4) file the ~~process progresses as planned,~~new FERC form without taking any other action. The FERC would also ultimately consider whether to initiate an investigation of any pipeline that would not have submitted a ~~decision should~~limited Section 4 rate reduction filing or committed to file a general rate case. In July 2018, the FERC issued a final rule (Order No. 849) adopting procedures for determining which jurisdictional pipelines may be ~~received by April 2018~~collecting unjust and unreasonable rates in light of tax reform. The rule became effective in September 2018. Paiute and Southwest Gas Transmission Company (“SGTC”), both of which are FERC-regulated subsidiaries of Southwest and the ~~additional facilities could be in place by~~Company, are each expected to file a Form No. 501-G during the ~~end~~fourth quarter of 2018.

In advance of its Form No. 501-G filing, Paiute has initiated discussions with its shippers regarding adjusting rates to reflect impacts of the TCJA as well as settlement of Paiute’s obligation to file a general rate case no later than May 31, 2019. SGTC has also initiated discussions with its shipper on adjusting its rates to reflect the impact of the TCJA.



	51



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

PGA Filings

The rate schedules in all of Southwest’s service territories contain provisions that permit adjustments to rates as the cost of purchased gas changes. These deferred energy provisions and purchased gas adjustment clauses are collectively referred to as “PGA” clauses. Differences between gas costs recovered from customers and amounts paid for gas by Southwest result in over- or under-collections. ~~At September 30, 2017, under-collections~~Over-collections in ~~Arizona and Northern Nevada resulted in an asset~~all jurisdictions, coupled with a refund of ~~approximately $6.2~~$49 million ~~and over-collections in Southern Nevada and California~~received during the third quarter of 2018 due to the El Paso Natural Gas, L.L.C. (“EPNG”) rate case settlement, resulted in a liability of ~~$15~~$93 million included in Deferred purchased gas costs on the Company’s and Southwest’s ~~condensed consolidated balance sheets. Gas cost rates paid to suppliers have been higher than amounts recovered from customers during the first nine months~~Condensed Consolidated Balance Sheets as of ~~2017, resulting in fluctuations since December 31, 2016. Tariff rates have been adjusted in all jurisdictions during this period.~~September 30, 2018. 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).

As the majority of the $49 million EPNG refund noted above related to Southwest’s transmission service into Arizona, in October 2018, Southwest filed an application with the ACC requesting an alternate methodology for refunding the EPNG funds allocated to the Arizona rate jurisdiction customers, which would involve offsetting sizable amounts currently receivable from Arizona customers under a different mechanism (the margin decoupling mechanism). A decision is expected during the fourth quarter of 2018.

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

   September 30, 2017    December 31, 2016    September 30, 2016
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, 2018			December 31, 2017			September 30, 2017
Arizona	$	(70,863	)	$	5,069		$	1,324
Northern Nevada	(1,287		)	8,189			4,906
Southern Nevada	(16,125		)	(6,841		)	(13,711		)
California	(4,748		)	1,323			(1,260		)
	$	(93,023	)	$	7,740		$	(8,741	)

Capital Resources and Liquidity

Cash on hand and cash flows from operations in the past twelve months have generally provided the majority of cash used in investing activities (primarily for construction expenditures and property additions). In recent years, certain pipe replacement has been accelerated to ~~take advantage of bonus depreciation tax incentives and to~~ fortify system integrity and reliability, notably in association with ~~new~~ gas infrastructure replacement programs as discussed ~~above.~~previously. During this same time, benefits were derived from ~~debt refinancing~~new borrowings and strategic debt redemptions. The Company’s capitalization strategy is to maintain an appropriate balance of equity and debt to maintain strong investment-grade credit ratings, which should minimize interest costs.

Cash Flows

Southwest Gas Holdings, Inc.:

Operating Cash Flows.Cash flows provided by consolidated operating activities ~~decreased $179~~increased $108 million in the first nine months of ~~2017~~2018 as compared to the same period of ~~2016. The decline~~2017. Changes in operating cash flows ~~was primarily attributable to~~are typically influenced significantly by the change in ~~deferred~~ purchased gas costs, ~~noted above. Refer~~including amounts incurred and deferred, as well as when amounts are incorporated in customer bills to~~Results~~ recover the deferred balances. For example, during the third quarter of ~~Natural Gas Operations~~ ~~and~~~~Rates and Regulatory Proceedings~~.

2018, EPNG refunded to Southwest, as ordered by the FERC, $49 million previously billed to Southwest for transmission services, subject to refund, in association with its 2010 rate case.

Investing Cash Flows.Cash used in consolidated investing activities increased ~~$35~~$107 million in the first nine months of ~~2017~~2018 as compared to the same period of ~~2016.~~2017. The change was primarily due to increased construction expenditures in the natural gas operations segment, including scheduled and accelerated replacement activity. ~~The prior period included an outflow of $17 million to facilitate a construction services acquisition.~~

Financing Cash Flows.Net cash provided by consolidated financing activities ~~increased $195~~decreased $7 million in the first nine months of ~~2017~~2018 as compared to the same period of ~~2016.~~2017. The ~~increase~~decrease was primarily due to activity under the credit facility and commercial paper program (an increase in borrowings in the current-year nine-month period and the repayment of borrowings in the prior-year nine-month period). The prior period included proceeds in utility operations from the issuance of $300 million in senior notes. The Company also issued approximately $12 million 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~~dividends paid, which increased in the first nine months of ~~2017~~2018 as compared to the same period of ~~2016~~2017 as a result of an increase in the quarterly dividend rate and ~~an increase~~ in the number of shares outstanding.

The Company issued approximately ~~103,000~~$84 million in stock during the first nine months of 2018 under its Equity Shelf Program and approximately 78,000 additional shares of common stock collectively through the Restricted Stock/Unit Plan and the Management



	52



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

Incentive Plan.

~~Southwest Gas Corporation:~~

~~Operating Cash Flows.~~~~Cash flows provided by operating activities decreased $172 million in~~ Also during the ~~first~~ nine months ended September 30, 2018, the Company issued 109,000 shares of ~~2017 as compared to~~common stock through 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~~Dividend Reinvestment 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 from the issuance of $300 million in senior notes as discussed above. The current period included capital contributions from Southwest Gas Holdings, Inc.

Stock Purchase Plan (“DRSPP”), raising approximately $7.8 million.

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

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

Southwest Gas Corporation:

Operating Cash Flows. Cash flows provided by operating activities increased $75 million in the first nine months of 2018 as compared to the same period of 2017. The increase in operating cash flows was primarily attributable to the change in Deferred purchased gas costs, including the EPNG refund as discussed above, net of other changes in working capital.

Investing Cash Flows. Cash used in investing activities increased $79 million in the first nine months of 2018 as compared to the same period of 2017. The change was primarily due to additional construction expenditures, as indicated above.

Financing Cash Flows. Net cash provided by financing activities decreased $13 million in the first nine months of 2018 as compared to the same period of 2017. The decrease was primarily due to repayment of the credit facility and commercial paper program borrowings following the issuance of $300 million in senior notes in March 2018 and to an increase in dividends paid. Capital contributions increased from Southwest Gas Holdings, Inc.

Gas Segment Construction Expenditures and Financing

During the twelve-month period ended September 30, ~~2017,~~2018, construction expenditures for the natural gas operations segment were ~~$515~~$651 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~~$385 million during this time and provided approximately ~~57%~~52% of construction expenditures and dividend requirements.

~~Southwest~~

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

See additional discussion in the Notes to financial statements (specifically, Note 6 – Common Stock and Note 7 – Long-Term Debt).

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

In March 2017, the Company filed with the Securities and Exchange Commission ~~(“SEC”~~(the “SEC”) an automatic shelf registration statement for the offer and sale of up to $150 million of common stock from time to time inat-the-market offerings under the prospectus included therein and in accordance with the Sales Agency Agreement, dated March 29, 2017, between the Company and BNY Mellon Capital Markets, LLC (the “Equity Shelf Program”). ~~Sales~~As the Company deems appropriate, sales of the shares will


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

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



	53



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

During the nine months ended September 30, ~~2017, 147,077~~2018, 1,145,705 shares were issued inat-the-market offerings at an average price of ~~$80.07~~$74.32 per share with gross proceeds of ~~$11.8~~$85.2 million, agent commissions of ~~$118,000,~~$851,500, and net proceeds of ~~$11.7~~$84.3 million. SeeNote 56 – Common Stock for more information.

See also discussion above regarding the Company’s issuances under the DRSPP.

Bonus Depreciation

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

2018.

Dividend Policy

Dividends are payable on the Company’s common stock at the discretion of the Board of Directors (“Board”). In setting the dividend rate, the Board currently targets a payout ratio of 55% to 65% of consolidated earnings per share and considers, among other factors, current and expected future earnings levels, our ongoing capital expenditure plans and expected external funding needs, ~~our payout ratio,~~ and our ability to maintain strong credit ratings and liquidity. The Company has paid dividends on its common stock since 1956 and has increased that dividend each year since 2007. In February ~~2017,~~2018, the Board elected to increase the quarterly dividend from ~~$0.45~~$0.495 to ~~$0.495~~$0.52 per share, representing a ~~10%~~5% increase, effective with the June ~~2017~~2018 payment. ~~The Board currently targets a payout ratio of 55% to 65% of consolidated earnings per share.~~

Liquidity

Liquidity refers to the ability of an enterprise to generate sufficient amounts of cash through its operating activities and external financing to meet its cash requirements. Several general factors (some of which are out of the control of the Company) that could significantly affect liquidity in future years include: variability of natural gas prices, changes in the ratemaking policies of regulatory commissions, regulatory lag, customer growth in the natural gas segment’s service territories, the ability to access and obtain capital from external sources, interest rates, changes in income tax laws, pension funding requirements, inflation, and the level of earnings. Natural gas prices and related gas cost recovery rates have historically had the most significant impact on liquidity.

On an interim basis, Southwest defers over- or under-collections of gas costs to PGA balancing accounts. In addition, Southwest uses this mechanism to either refund amounts over-collected or recoup amounts under-collected as compared to the price paid for natural gas during the period since the last PGA rate change went into effect. At September 30, ~~2017,~~2018, the combined balance in the PGA accounts totaled an over-collection of ~~$8.7~~$93 million, which included the EPNG rate case settlement of $49 million. SeePGA Filingsfor more ~~information.~~

~~In March 2017, Southwest Gas Holdings, Inc. entered into~~information, including a proposal to offset other amounts due from Arizona customers with proceeds from the EPNG refund.

The Company has a credit facility with a borrowing capacity of $100 million that expires in March 2022. The Company intends to utilize this facility for short-term financing needs. At September 30, ~~2017, $27.5~~2018, $22.5 million was outstanding on this facility.

~~In March 2017,~~

Southwest ~~Gas Corporation amended its~~has a credit facility, ~~increasing the~~with borrowing capacity ~~from $300 million to~~of $400 million, ~~and extended the term of the facility from March 2021 to~~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 credit facility (including a commercial paper program, as noted below) during the first nine months of ~~2017~~2018 was $150 million. At September 30, ~~2017,~~2018, $150 million was outstanding on the long-term portion (including the commercial paper program) and ~~$83~~$9 million was outstanding on the short-term portion of this credit facility. Commercial paper borrowings are discussed below. The credit facility can be used as necessary to meet liquidity requirements, including temporarily financing under-collected PGA balances, if any, or meeting the refund needs of over-collected balances. This credit facility has been


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

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

Southwest has a $50 million commercial paper program. Any issuance under the commercial paper program is supported by Southwest’s current revolving credit facility and, therefore, does not represent additional borrowing capacity. Any borrowing under the commercial paper program will be designated as long-term debt. Interest rates for the commercial paper program are calculated at the current commercial paper rate during the borrowing term. At September 30, ~~2017, no borrowings were~~2018, there was $50 million outstanding under this program.



	54



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

Centuri has a ~~$300 million~~senior secured revolving credit and term loan facility ~~that~~with borrowing capacity of $450 million. The line of credit portion of the facility is scheduled to expire in October 2019. The term loan facility portion had an initial limit of approximately $150 million, which was reached in 2014 and; $107 million was outstanding (after repayments) at September 30, 2017. The secured revolving credit facility portion also has a limit of $150$250 million; amounts borrowed and repaid under ~~this portion of~~ the revolving credit facility are available to bere-borrowed. The term loan facility portion, has a limit of approximately $200 million. The limit on the term loan facility was reached in November 2017; therefore, no further borrowing is permitted under this term loan facility. The $450 million credit and term loan facility expires in November 2022. The $450 million revolving credit and term loan facility is secured by substantially all of Centuri’s assets except those explicitly excluded under the terms of the agreement (including owned real estate and certain certificated vehicles). Centuri assets securing the facility at September 30, 2018 totaled $675 million. The maximum amount outstanding on the credit facility during the first nine months of ~~2017~~2018 was ~~$104~~$294 million. At September 30, ~~2017, $81.3~~2018, $78 million was outstanding on the secured revolving credit facility. Also at September 30, ~~2017,~~2018, there was approximately ~~$52~~$154 million, net of letters of credit, available under the line of credit.

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

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

~~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.~~



	55



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

Forward-Looking Statements

This quarterly report contains statements which constitute “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 (“Reform Act”). All statements other than statements of historical fact included or incorporated by reference in this quarterly report are forward-looking statements, including, without limitation, statements regarding the Company’s plans, objectives, goals, intentions, projections, strategies, future events or performance, negotiations, and underlying assumptions. The words “may,” “if,” “will,” “should,” “could,” “expect,” “plan,” “anticipate,” “believe,” “estimate,” “predict,” “project,” “continue,” “forecast,” “intend,” “promote,” “seek,” and similar words and expressions are generally used and intended to identify forward-looking statements. For example, statements regarding operating margin patterns, customer growth, the composition of our customer base, price volatility, seasonal patterns, payment of debt, interest savings, the Company’s COLI strategy, replacement market and new construction market, the impacts of the Tax Cuts and Jobs Act legislation including disposition as to both timing and amounts in regulatory proceedings, bonus depreciation tax deductions, amount and timing for completion of estimated future construction expenditures, including the LNG facility in southern Arizona, the ~~cost of~~Mesquite expansion in Nevada, and the Paiute 2018 ~~Paiute~~ expansion project in northern Nevada and northern California, forecasted operating cash flows and results of operations, ~~net earnings~~ impacts from gas infrastructure replacement programs and surcharges, funding sources of cash requirements, amounts generally expected to be reflected in ~~2017~~2018 or future period revenues from regulatory rate proceedings including amounts resulting from the settled Arizona general rate case, the recently filed Nevada general rate case, rates and surcharges, PGA, and other rate adjustments, sufficiency of working capital and current credit facilities, bank lending practices, the Company’s views regarding its liquidity position, ability to raise funds and receive external financing capacity and the intent and ability to issue common stock under the Equity Shelf Program, the intent and ability to issue various financing instruments and stock under the December 2017 shelf registration statement, future dividend increases and the Board’s current target dividend payout ratio, pension and post-retirement benefits, certain ~~benefits~~impacts of tax acts, ~~the effect of any rate changes or regulatory proceedings,~~ contract or construction change order negotiations, impacts of accounting standard updates, infrastructure replacement mechanisms and ~~the~~ COYL ~~program, statements regarding~~programs, future gas prices, gas purchase contracts and derivative financial instruments, recoverability of regulatory assets, the time period and means for returning to customers proceeds from the recent EPNG refund, the impact of certain legal proceedings, and the timing and results of future rate hearings and approvals are forward-looking


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

statements. All forward-looking statements are intended to be subject to the safe harbor protection provided by the Reform Act.

A number of important factors affecting the business and financial results of the Company could cause actual results to differ materially from those stated in the forward-looking statements. These factors include, but are not limited to, customer growth rates, conditions in the housing market, the ability to recover costs through the PGA mechanisms or other regulatory assets, the effects of regulation/deregulation, the impacts of alternative energy sources to natural gas, the timing and amount of rate relief, the timing, amount, and methods determined by regulators to refund amounts to customers resulting from tax reform, changes in rate design, variability in volume of gas or transportation service sold to customers, changes in gas procurement practices, changes in capital requirements and funding, the impact of conditions in the capital markets on financing costs, changes in construction expenditures and financing, changes in operations and maintenance expenses, effects of pension expense forecasts, accounting changes and regulatory treatment related thereto, currently unresolved and future liability claims, changes in pipeline capacity for the transportation of gas and related costs, results of Centuri bid work, results of Neuco (including the ability to be accretive to earnings over the first twelve months), Centuri construction expenses, differences between actual and originally expected outcomes of Centuri bid or other fixed-price construction agreements, outcomes from contract and change order negotiations, ~~and~~ ability to successfully procure new work, impacts from work awarded or failing to be awarded from significant customers, the mix of work awarded, the amount of work awarded to Centuri, ~~following the lifting of the recent work stoppage,~~ acquisitions and management’s plans related thereto, competition, our ability to raise capital in external financings, our ability to continue to remain within the ratios and other limits subject to our debt covenants, and ongoing evaluations in regard to goodwill and other intangible assets. In addition, the Company can provide no assurance that its discussions regarding certain trends relating to its financing and operating expenses will continue or cease to continue in future periods. For additional information on the risks associated with the Company’s business, seeItem 1A. Risk Factors andItem 7A. Quantitative and Qualitative Disclosures About Market Risk in the Annual Report onForm 10-K for the year ended December 31, ~~2016.~~

2017.

All forward-looking statements in this quarterly report are made as of the date hereof, based on information available to the Company as of the date hereof, and the Company assumes no obligation to update or revise any of its forward-looking statements even if experience or future changes show that the indicated results or events will not be realized.We caution you not to unduly rely on any forward-looking statement(s).



	56



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

~~ITEM 3.~~

~~QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK~~

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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

~~ITEM 4.~~

~~CONTROLS AND PROCEDURES~~

ITEM 4. CONTROLS AND PROCEDURES

Management of Southwest Gas Holdings, Inc. and Southwest Gas Corporation has established disclosure controls and procedures (as defined in Rules13a-15(e) and15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) that are designed to provide reasonable assurance that information required to be disclosed in their respective reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms and to provide reasonable assurance that such information is accumulated and communicated to management of each company, including each respective Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosures. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and benefits of controls must be considered relative to their costs. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or management override of the control. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and may not be detected.

Based on the most recent evaluation, as of September 30, ~~2017,~~2018, management of Southwest Gas Holdings, Inc., including the Chief Executive Officer and Chief Financial Officer, believe the Company’s disclosure controls and procedures are effective at attaining the level of reasonable assurance noted above.


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

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

Based on the most recent evaluation, as of September 30, ~~2017,~~2018, management of Southwest Gas Corporation, including the Chief Executive Officer and Chief Financial Officer, believe Southwest’s disclosure controls and procedures are effective at attaining the level of reasonable assurance noted above.

There have been no changes in Southwest’s internal ~~controls~~control over financial reporting (as defined in Rules13a-15(f) and15d-15(f) of the Exchange Act) during the third quarter of ~~2017~~2018 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.~~

	57

~~ITEM 4.~~
	~~MINE SAFETY DISCLOSURES~~~~Not applicable.~~
SOUTHWEST GAS HOLDINGS, INC.		Form 10-Q
SOUTHWEST GAS CORPORATION		September 30, 2018

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

Exhibit 101SCH		—	-	XBRL Schema Document

Exhibit 101.CAL		—	-	XBRL Calculation Linkbase Document

Exhibit 101.DEF		—	-	XBRL Definition Linkbase Document

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

~~Management Incentive Plan~~


	58



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

SIGNATURES

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

Southwest Gas Holdings, Inc.

(Registrant)

Date: November 7, ~~2017~~

2018

~~/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~~

2018

~~/s/ GREGORY J. PETERSON~~

~~Gregory J. Peterson~~

/s/ LORI L. COLVIN

Lori L. Colvin

Vice President/Controller and Chief Accounting Officer



	59


	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		$	—


	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	)


	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