~~Condensed~~

Dominion Energy South Carolina, Inc.

Consolidated Balance Sheets

(Unaudited)

(millions)	June 30, 2019			December 31, 2018
ASSETS
Utility plant in service	$	12,986		$	12,803
Accumulated depreciation and amortization		(4,750	)		(4,581	)
Construction work in progress		282			350
Nuclear fuel, net of accumulated amortization		193			211
Utility plant, net ($690 and $711 related to VIEs)		8,711			8,783
Nonutility Property and Investments:
Nonutility property, net of accumulated depreciation		71			72
Assets held in trust, net-nuclear decommissioning		206			190
Other investments		—			1
Nonutility property and investments, net		277			263
Current Assets:
Cash and cash equivalents		5			377
Restricted cash and equivalents		117			—
Receivables:
Customer, net of allowance for uncollectible accounts of $7 and $4		327			331
Affiliated and related party		19			359
Other		55			68
Inventories (at average cost):
Fuel		107			89
Materials and supplies		160			158
Prepayments		111			82
Regulatory assets		259			223
Other current assets		19			1
Total current assets ($133 and $96 related to VIEs)		1,179			1,688
Deferred Debits and Other Assets:
Regulatory assets		3,759			4,046
Other		357			183
Total deferred debits and other assets ($34 and $34 related to VIEs)		4,116			4,229
Total assets	$	14,283		$	14,963

~~(Unaudited)~~

Millions of dollars June 30,
2018 December 31,
2017
Assets
Utility Plant In Service $ 14,926
$ 14,370
Accumulated Depreciation and Amortization (4,995 ) (4,611 )
Construction Work in Progress 470
471
Nuclear Fuel, Net of Accumulated Amortization 193
208
Goodwill, net of writedown of $230 210
210
Utility Plant, Net 10,804
10,648
Nonutility Property and Investments:
     Nonutility property, net of accumulated depreciation of $138 and $133 267
270
Assets held in trust, net-nuclear decommissioning 136
136
Other investments 139
68
Nonutility Property and Investments, Net 542
474
Current Assets:
Cash and cash equivalents 238
409
     Receivables:
         Customer, net of allowance for uncollectible accounts of $6 and $6 517
665
    Income taxes 206
198
         Other 99
105
Inventories (at average cost):
Fuel and gas supply 119
143
Materials and supplies 167
161
Prepayments 134
99
     Other current assets 14
17
     Derivative financial instruments —
54
     Total Current Assets 1,494
1,851
Deferred Debits and Other Assets:
Regulatory assets 5,757
5,580
Other 304
186
Total Deferred Debits and Other Assets 6,061
5,766
Total $ 18,901
$ 18,739

See Notes to ~~Condensed~~ Consolidated Financial Statements.

Dominion Energy South Carolina, Inc.

Consolidated Balance Sheets—(Continued)

(Unaudited)

(millions)	June 30, 2019			December 31, 2018
CAPITALIZATION AND LIABILITIES
Common Stock - no par value, 40.3 million shares outstanding	$	3,635		$	2,860
Retained earnings		72			1,279
Accumulated other comprehensive loss		(4	)		(3	)
Total common equity		3,703			4,136
Noncontrolling interest		173			179
Total equity		3,876			4,315
Affiliated long-term debt		230			—
Long-term debt, net		3,934			5,132
Total long-term debt		4,164			5,132
Total capitalization		8,040			9,447
Current Liabilities:
Short-term borrowings		—			73
Current portion of long-term debt		7			14
Accounts payable		150			267
Affiliated and related party payables		368			347
Customer deposits and customer prepayments		75			73
Revenue subject to refund		14			77
Taxes accrued		163			228
Interest accrued		62			72
Regulatory liabilities		269			126
Reserves for litigation and regulatory proceedings		278			11
Other		62			42
Total current liabilities		1,448			1,330
Deferred Credits and Other Liabilities:
Deferred income taxes, net		555			989
Asset retirement obligations		498			542
Pension and other postretirement benefits		223			232
Regulatory liabilities		3,277			2,264
Other		227			143
Other affiliate		15			16
Total deferred credits and other liabilities		4,795			4,186
Commitments and Contingencies (see Note 11)
Total capitalization and liabilities	$	14,283		$	14,963

Millions of dollars June 30,
2018 December 31,
2017
Capitalization and Liabilities

Common Stock - no par value, 143 million shares outstanding $ 2,389
$ 2,390
Retained Earnings 2,987
2,915
Accumulated Other Comprehensive Loss (39 ) (50 )
Total Common Equity 5,337
5,255
Long-Term Debt, net 6,098
5,906
Total Capitalization 11,435
11,161
Current Liabilities:

Short-term borrowings 517
350
Current portion of long-term debt 568
727
Accounts payable 263
438
Customer deposits and customer prepayments 151
112
Revenue subject to refund 164
—
Taxes accrued 123
214
Interest accrued 88
87
Dividends declared 18
86
Derivative financial instruments 4
6
Other 69
93
Total Current Liabilities 1,965
2,113
Deferred Credits and Other Liabilities:

Deferred income taxes, net 1,333
1,261
Asset retirement obligations 578
568
Pension and other postretirement benefits 360
360
Unrecognized tax benefits 19
19
Regulatory liabilities 3,019
3,059
Other 192
198
Total Deferred Credits and Other Liabilities 5,501
5,465
Commitments and Contingencies (Note 10)

Total $ 18,901
$ 18,739

See Notes to ~~Condensed~~ Consolidated Financial Statements.

~~SCANA Corporation and Subsidiaries~~

~~Condensed Consolidated Statements of Income~~

~~(Unaudited)~~

Three Months Ended Six Months Ended
June 30, June 30,
Millions of dollars, except per share amounts 2018 2017 2018 2017
Operating Revenues:

Electric $ 552
$ 679
$ 1,098
$ 1,256
Gas - regulated 148
140
509
461
Gas - nonregulated 143
182
416
456
Total Operating Revenues 843
1,001
2,023
2,173
Operating Expenses:

Fuel used in electric generation 155
161
315
297
Purchased power 15
21
67
32
Gas purchased for resale 192
227
598
597
Other operation and maintenance 208
179
410
354
Impairment loss —
—
4
—
Depreciation and amortization 100
95
199
189
Other taxes 70
67
140
133
Total Operating Expenses 740
750
1,733
1,602
Operating Income 103
251
290
571
Other Income, net 4
14
133
27
Interest charges, net of allowance for borrowed funds used during construction of $3, $7, $6 and $14 (95 ) (88 ) (192 ) (175 )
Income Before Income Tax Expense 12
177
231
423
Income Tax Expense 4
56
54
131
Net Income $ 8
$ 121
$ 177
$ 292

Earnings Per Share of Common Stock $ 0.06
$ 0.85
$ 1.24
$ 2.04
Weighted Average Common Shares Outstanding (millions) 143
143
143
143
Dividends Declared Per Share of Common Stock $ 0.1237
$ 0.6125
$ 0.7362
$ 1.225

~~See Notes to Condensed Consolidated Financial Statements.~~

~~SCANA Corporation and Subsidiaries~~

~~Condensed~~

Dominion Energy South Carolina, Inc.

Consolidated Statements of Comprehensive Income (Loss)

(Unaudited)

	Three Months Ended June 30,					Six Months Ended June 30,
(millions)	2019			2018		2019			2018
Operating Revenues:
Electric⁽¹⁾	$	621		$	553	$	141		$	1,100
Gas		77			79		222			234
Total operating revenues		698			632		363			1,334
Operating Expenses:
Fuel used in electric generation⁽¹⁾		143			155		280			315
Purchased power⁽¹⁾		12			15		20			67
Gas purchased for resale⁽¹⁾		44			45		121			121
Other operations and maintenance		123			113		219			215
Other operations and maintenance - affiliated suppliers		72			51		120			95
Impairment of assets and other charges		100			—		371			4
Depreciation and amortization		115			81		217			161
Other taxes⁽¹⁾		72			65		141			129
Total operating expenses		681			525		1,489			1,107
Operating income (loss)		17			107		(1,126	)		227
Other income (expense), net		(9	)		2		(14	)		125
Interest charges, net of allowance for borrowed funds used during construction of $2, $3, $2 and $5⁽¹⁾		63			76		136			152
Income (loss) before income tax expense (benefit)		(55	)		33		(1,276	)		200
Income tax expense (benefit)		15			2		(103	)		41
Net Income (Loss) and Other Comprehensive Income (Loss)		(70	)		31		(1,173	)		159
Comprehensive Income Attributable to Noncontrolling Interest		8			5		14			9
Comprehensive Income (Loss) Available (Attributable) to Common Shareholder	$	(78	)	$	26	$	(1,187	)	$	150

~~(Unaudited)~~

(1)	See Note 14 for amounts attributable to affiliates.

Three Months Ended June 30, Six Months Ended June 30,
Millions of dollars 2018 2017 2018 2017
Net Income $ 8
$ 121
$ 177
$ 292
Other Comprehensive Income (Loss), net of tax:
Unrealized Gains (Losses) on Cash Flow Hedging Activities:
Arising during period, net of tax of $-, $(2), $1, and $(3) 1
(3 ) 4
(5 )
Reclassified as increases to interest expense, net of tax of $1, $1, 2, and $3 2
2
4
4
Reclassified as increases (decreases) to gas purchased for resale, net of tax of $-, $-, $1 and $(1) —
—
2
(2 )
Net unrealized gains (losses) on cash flow hedging activities 3
(1 ) 10
(3 )
Deferred cost of employee benefit plans, net of tax of $-, $-, $-, and $- —
—
1
—
Other Comprehensive Income (Loss) 3
(1 ) 11
(3 )
Total Comprehensive Income $ 11
$ 120
$ 188
$ 289

See Notes to ~~Condensed~~ Consolidated Financial Statements.

~~SCANA Corporation and Subsidiaries~~

~~Condensed~~

Dominion Energy South Carolina, Inc.

Consolidated Statements of Cash Flows

(Unaudited)

	Six Months Ended June 30,
(millions)	2019			2018
Operating Activities
Net income (loss)	$	(1,173	)	$	159
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Impairment of assets and other charges		371			4
Provision for refunds to customers		950			—
Deferred income taxes, net		(434	)		58
Depreciation and amortization		223			165
Amortization of nuclear fuel		27			27
Other adjustments		(4	)		(7	)
Changes in certain assets and liabilities:
Receivables - affiliated and related party		(3	)		(12	)
Income tax receivable		—			(8	)
Inventories		(48	)		(11	)
Prepayments		(29	)		(34	)
Regulatory assets		187			(9	)
Regulatory liabilities		195			(107	)
Accounts payable		(72	)		(19	)
Accounts payable - affiliated and related party		17			8
Revenue subject to refund		(63	)		156
Taxes accrued		(65	)		(93	)
Other assets		(138	)		(131	)
Other liabilities		59			55
Net cash provided by operating activities		—			201
Investing Activities
Property additions and construction expenditures		(226	)		(464	)
Proceeds from investments and sales of assets		12			31
Purchase of investments		(23	)		(17	)
Purchase of investments - affiliate		—			(113	)
Proceeds from interest rate derivative contract settlement		—			115
Investment in affiliate, net		343			(75	)
Net cash provided by (used in) investing activities		106			(523	)
Financing Activities
Proceeds from issuance of debt		—			100
Proceeds from issuance of affiliated debt		230			—
Repayment of long-term debt, including redemption premiums		(1,247	)		(170	)
Dividend to parent		(30	)		(156	)
Contribution from parent		775			20
Contribution returned to parent		(20	)		—
Money pool borrowings, net		4			150
Short-term borrowings, net		(73	)		205
Net cash provided by (used in) financing activities		(361	)		149
Net decrease in cash, restricted cash and equivalents		(255	)		(173	)
Cash, restricted cash and equivalents at beginning of period		377			395
Cash, restricted cash and equivalents at end of period	$	122		$	222
Supplemental Cash Flow Information
Noncash investing and financing activities:⁽¹⁾
Accrued construction expenditures	$	39		$	19
Leases⁽²⁾		5			—

~~(Unaudited)~~

(1)	See Note 1 for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements.

Six Months Ended June 30,
Millions of dollars 2018 2017
Cash Flows From Operating Activities:

Net income $ 177
$ 292
Adjustments to reconcile net income to net cash provided from operating activities:

Impairment loss 4
—
Deferred income taxes, net 69
93
Depreciation and amortization 215
200
Amortization of nuclear fuel 27
19
Allowance for equity funds used during construction (7 ) (18 )
Carrying cost recovery (3 ) (11 )
Changes in certain assets and liabilities:
Receivables 139
87
Income taxes receivable (8 ) 136
Inventories (18 ) (36 )
Prepayments (34 ) (47 )
Regulatory assets (18 ) (30 )
Regulatory liabilities (110 ) (1 )
Accounts payable (48 ) (31 )
Revenue subject to refund 164
—
Unrecognized tax benefits —
49
Taxes accrued (91 ) (87 )
Derivative financial instruments (1 ) (3 )
Other assets (138 ) (26 )
Other liabilities 29
(73 )
Net Cash Provided From Operating Activities 348
513
Cash Flows From Investing Activities:

Property additions and construction expenditures (597 ) (780 )
Proceeds from investments and sales of assets (including derivative collateral returned) 79
62
Purchase of investments (including derivative collateral posted) (136 ) (66 )
Proceeds upon interest rate derivative contract settlements 115
—
Net Cash Used For Investing Activities (539 ) (784 )
Cash Flows From Financing Activities:

Proceeds from issuance of long-term debt 200
150
Repayment of long-term debt (174 ) (14 )
Dividends (173 ) (170 )
Short-term borrowings, net 167
188
Net Cash Provided From Financing Activities 20
154
Net Decrease In Cash and Cash Equivalents (171 ) (117 )
Cash and Cash Equivalents, January 1 409
208
Cash and Cash Equivalents, June 30 $ 238
$ 91
Supplemental Cash Flow Information:

Cash for–Interest paid (net of capitalized interest of $6 and $14) $ 179
$ 168
–Income taxes paid 3
1
–Income taxes received —
123
Noncash Investing and Financing Activities:
Accrued construction expenditures 42
81
Capital leases 6
6

(2) Includes $3 million of financing leases and $2 million of operating leases.

See Notes to ~~Condensed~~ Consolidated Financial ~~Statements.~~

Statements.

~~SCANA Corporation and Subsidiaries~~

~~Condensed~~

Dominion Energy South Carolina, Inc.

Consolidated Statements of Changes in Common Equity

(Unaudited)

Quarter-To-Date

	Common Stock
(millions)	Shares		Amount		Retained Earnings			AOCI			Noncontrolling Interest			Total Equity
March 31, 2018		40	$	2,860	$	2,034		$	(4	)	$	144		$	5,034
Total comprehensive income available to common shareholder						26						5			31
Capital contribution from parent												20			20
June 30, 2018		40	$	2,860	$	2,060		$	(4	)	$	169		$	5,085

March 31, 2019		40	$	3,535	$	151		$	(4	)	$	185		$	3,867
Total comprehensive income (loss) available (attributable) to common shareholder						(78	)					8			(70	)
Capital contribution from parent				100											100
Capital contribution returned to parent												(20	)		(20	)
Other						(1	)								(1	)
June 30, 2019		40	$	3,635	$	72		$	(4	)	$	173		$	3,876

Year-To-Date

~~(Unaudited)~~

	Common Stock
(millions)	Shares		Amount		Retained Earnings			AOCI			Noncontrolling Interest			Total Equity
December 31, 2017		40	$	2,860	$	1,982		$	(4	)	$	142		$	4,980
Total comprehensive income available to common shareholder						150						9			159
Capital contribution from parent												20			20
Dividend to parent						(72	)					(2	)		(74	)
June 30, 2018		40	$	2,860	$	2,060		$	(4	)	$	169		$	5,085

December 31, 2018		40	$	2,860	$	1,279		$	(3	)	$	179		$	4,315
Cumulative-effect of change in accounting principle						1			(1	)					—
Total comprehensive income (loss) available (attributable) to common shareholder						(1,187	)					14			(1,173	)
Capital contribution from parent				775											775
Capital contribution returned to parent												(20	)		(20	)
Dividend to parent						(20	)								(20	)
Other						(1	)								(1	)
June 30, 2019		40	$	3,635	$	72		$	(4	)	$	173		$	3,876

Common Stock Accumulated Other Comprehensive Income (Loss)
Millions Shares Outstanding Amount Treasury Amount Retained Earnings Gains (Losses) from Cash Flow Hedges Deferred Employee Benefit Plans Total AOCI Total
Balance as of January 1, 2018 143
$ 2,402
$ (12 ) $ 2,915
$ (37 ) $ (13 ) $ (50 ) $ 5,255
Net Income 177
177
Other Comprehensive Income (Loss)
Gains arising during the period 4
—
4
4
Losses/amortization reclassified from AOCI 6
1
7
7
Total Comprehensive Income 177
10
1
11
188
Purchase of Treasury Stock —
—
(1 ) (1 )
Dividends Declared (105 ) (105 )
Balance as of June 30, 2018 143
$ 2,402

$ (13 )
$ 2,987
$ (27 )
$ (12 )
$ (39 ) $ 5,337

Balance as of January 1, 2017 143
$ 2,402
$ (12 ) $ 3,384
$ (36 ) $ (13 ) $ (49 ) $ 5,725
Net Income 292
292
Other Comprehensive Income (Loss)
Losses arising during the period (5 ) —
(5 ) (5 )
Losses/amortization reclassified from AOCI 2
—
2
2
Total Comprehensive Income 292
(3 ) —
(3 ) 289
Purchase of Treasury Stock —
—
(1 ) (1 )
Dividends Declared (175 ) (175 )
Balance as of June 30, 2017 143
$ 2,402
$ (13 ) $ 3,501
$ (39 ) $ (13 ) $ (52 ) $ 5,838

~~Dividends declared per share of common stock were $0.7362 for the six months ended June 30, 2018 and were $1.225 for the six months ended June 30, 2017.~~

See Notes to ~~Condensed~~ Consolidated Financial Statements.

Dominion Energy South Carolina, ~~Electric & Gas Company and Affiliates~~

~~Condensed Consolidated Balance Sheets~~

~~(Unaudited)~~

Millions of dollars June 30,
2018 December 31,
2017
Assets

Utility Plant In Service $ 12,650
$ 12,161
Accumulated Depreciation and Amortization (4,488 ) (4,124 )
Construction Work in Progress 322
375
Nuclear Fuel, Net of Accumulated Amortization 193
208
Utility Plant, Net ($690 and $711 related to VIEs) 8,677
8,620
Nonutility Property and Investments:

Nonutility property, net of accumulated depreciation 73
71
Assets held in trust, net-nuclear decommissioning 136
136
Other investments 1
2
Nonutility Property and Investments, Net 210
209
Current Assets:

     Cash and cash equivalents 222
395
     Receivables:
          Customer, net of allowance for uncollectible accounts of $4 and $4 390
390
          Affiliated companies 161
32
          Income taxes 206
198
          Other 69
85
     Inventories (at average cost):

     Fuel 72
90
     Materials and supplies 154
149
     Prepayments 116
82
     Derivative financial instrument —
54
     Other current assets 2
2
     Total Current Assets ($106 and $191 related to VIEs) 1,392
1,477
Deferred Debits and Other Assets:

Regulatory assets 5,644
5,476
Other 281
164
Other affiliate 71
—
     Total Deferred Debits and Other Assets ($36 and $50 related to VIEs) 5,996
5,640
Total $ 16,275
$ 15,946

~~See~~ Inc.

Notes to ~~Condensed Consolidated Financial Statements.~~

Millions of dollars June 30,
2018 December 31,
2017
Capitalization and Liabilities
Common Stock - no par value, 40.3 million shares outstanding $ 2,860
$ 2,860
Retained Earnings 2,060
1,982
Accumulated Other Comprehensive Loss (4 ) (4 )
Total Common Equity 4,916
4,838
Noncontrolling Interest 169
142
Total Equity 5,085
4,980
Long-Term Debt, net 4,536
4,441
Total Capitalization 9,621
9,421
Current Liabilities:
Short-term borrowings 457
252
Current portion of long-term debt 564
723
Accounts payable 123
251
Affiliated payables 260
102
Customer deposits and customer prepayments 119
70
Revenue subject to refund 156
—
Taxes accrued 115
208
Interest accrued 68
67
Dividends declared —
82
Derivative financial instruments 1
2
Other 32
47
Total Current Liabilities 1,895
1,804
Deferred Credits and Other Liabilities:
Deferred income taxes, net 1,231
1,173
Asset retirement obligations 538
529
Pension and other postretirement benefits 216
217
Unrecognized tax benefits 19
19
Regulatory liabilities 2,627
2,667
Other 110
97
Other affiliate 18
19
Total Deferred Credits and Other Liabilities 4,759
4,721
Commitments and Contingencies (Note 10)

Total $ 16,275
$ 15,946

~~See Notes to Condensed Consolidated Financial Statements.~~

~~South Carolina Electric & Gas Company and Affiliates~~

~~Condensed Consolidated Statements of Comprehensive Income~~

~~(Unaudited)~~

Three Months Ended Six Months Ended
June 30, June 30,
Millions of dollars 2018 2017 2018 2017
Operating Revenues:

Electric $ 552
$ 678
$ 1,098
$ 1,256
Electric - nonconsolidated affiliate 1
2
2
3
Gas 79
75
234
216
Gas - nonconsolidated affiliate —
1
—
1
Total Operating Revenues 632
756
1,334
1,476
Operating Expenses:

Fuel used in electric generation 126
126
255
239
Fuel used in electric generation - nonconsolidated affiliate 29
35
60
59
Purchased power 15
21
67
32
Gas purchased for resale 45
42
121
108
Other operation and maintenance 113
96
215
197
Other operation and maintenance - nonconsolidated affiliate 51
50
95
91
Impairment loss —
—
4
—
Depreciation and amortization 81
77
161
154
Other taxes 64
60
126
120
Other taxes - nonconsolidated affiliate 1
2
3
3
Total Operating Expenses 525
509
1,107
1,003
Operating Income 107
247
227
473
Other Income, net 2
8
125
15
Interest charges, net of allowance for borrowed funds used during construction of $3, $7, $5 and $13 (76 ) (69 ) (152 ) (138 )
Income Before Income Tax Expense 33
186
200
350
Income Tax Expense 2
60
41
112
Net Income and Total Comprehensive Income 31
126
159
238
Less Net Income and Total Comprehensive Income Attributable to Noncontrolling Interest 5
3
9
7
Earnings and Comprehensive Income Available to Common Shareholder $ 26
$ 123
$ 150
$ 231

Dividends Declared on Common Stock $ —
$ 81
$ 74
$ 160

~~See Notes to Condensed Consolidated Financial Statements.~~

~~South Carolina Electric & Gas Company and Affiliates~~

~~Condensed Consolidated Statements of Cash Flows~~

~~(Unaudited)~~

Six Months Ended June 30,
Millions of dollars 2018 2017
Cash Flows From Operating Activities:
Net income $ 159
$ 238
Adjustments to reconcile net income to net cash provided from operating activities:
Impairment loss 4
—
Deferred income taxes, net 58
65
Depreciation and amortization 165
157
Amortization of nuclear fuel 27
19
Allowance for equity funds used during construction (4 ) (16 )
Carrying cost recovery (3 ) (11 )
Changes in certain assets and liabilities:
Receivables —
(5 )
Receivables - affiliate (12 ) (1 )
Income tax receivable (8 ) 53
Inventories (11 ) (22 )
Prepayments (34 ) (38 )
Regulatory assets (9 ) (26 )
Regulatory liabilities (107 ) 1
Accounts payable (19 ) 4
Accounts payable - affiliate 8
(12 )
Revenue subject to refund 156
—
Taxes accrued (93 ) (83 )
Unrecognized tax benefit —
153
Other assets (131 ) (20 )
Other liabilities 55
(35 )
Net Cash Provided From Operating Activities 201
421
Cash Flows From Investing Activities:
Property additions and construction expenditures (464 ) (650 )
Proceeds from investments and sales of assets (including derivative collateral returned) 31
47
Purchase of investments (including derivative collateral posted) (17 ) (52 )
Purchase of investments - affiliate (113 ) —
Proceeds from interest rate derivative contract settlement 115
—
Proceeds from investments - affiliate 42
—
Investment in affiliate (117 ) —
Net Cash Used For Investing Activities (523 ) (655 )
Cash Flows From Financing Activities:
Proceeds from issuance of debt 100
—
Repayment of long-term debt (170 ) (10 )
Dividends (156 ) (158 )
Money pool borrowings, net 150
(1 )
Contribution from parent 20
—
Short-term borrowings, net 205
275
Net Cash Provided From Financing Activities 149
106
Net Decrease In Cash and Cash Equivalents (173 ) (128 )
Cash and Cash Equivalents, January 1 395
164
Cash and Cash Equivalents, June 30 $ 222
$ 36

Supplemental Cash Flow Information:
Cash for–Interest (net of capitalized interest of $5 and $13) $ 135
$ 129
– Income taxes paid —
3
– Income taxes received —
143
Noncash Investing and Financing Activities:
Accrued construction expenditures 19
61
Capital leases 6
6

~~See Notes to Condensed~~ Consolidated Financial Statements.

~~South Carolina Electric & Gas Company and Affiliates~~

~~Condensed Consolidated Statements of Changes in Common Equity~~

(Unaudited)

Common Stock
Millions Shares Amount Retained Earnings AOCI Noncontrolling Interest Total Equity
Balance at January 1, 2018 40
$ 2,860
$ 1,982
$ (4 ) $ 142
$ 4,980
Earnings available to common shareholder 150
9
159
Total Comprehensive Income 150
—
9
159
Contribution from Parent 20
20
Cash dividend declared (72 ) (2 ) (74 )
Balance at June 30, 2018 40
$ 2,860
$ 2,060
$ (4 ) $ 169
$ 5,085

Balance at January 1, 2017 40
$ 2,860
$ 2,481
$ (3 ) $ 134
$ 5,472
Earnings available to common shareholder 231
7
238
Total Comprehensive Income 231
—
7
238
Cash dividend declared (155 ) (5 ) (160 )
Balance at June 30, 2017 40
$ 2,860
$ 2,557
$ (3 ) $ 136
$ 5,550

~~See Notes to Condensed Consolidated Financial Statements.~~

~~SCANA Corporation and Subsidiaries~~

~~South Carolina Electric & Gas Company and Affiliates~~

~~Notes to Condensed Consolidated Financial Statements~~

~~(Unaudited)~~

The following unaudited notes to the condensed consolidated financial statements are a combined presentation. Except as otherwise indicated herein, each note applies to the Company and Consolidated SCE&G; however, Consolidated SCE&G makes no representation as to information relating solely to SCANA Corporation or its subsidiaries (other than Consolidated SCE&G).

~~The following condensed~~ notes should be read in conjunction with the Notes to Consolidated Financial Statements appearing in ~~each company's~~DESC's Annual Report on Form 10-K for the year ended December 31, ~~2017, which also were~~2018. DESC filed such annual report on a combined ~~presentation.~~ basis with SCANA. Accordingly, the information presented in such notes is presented on a combined basis and therefore some of the information may apply only to SCANA and not DESC. DESC makes no representation as to any such information.

These are interim financial statements and, due to the seasonality of ~~each company's~~DESC's business and matters that may occur during the rest of the year, ~~including the matters described in Note 10 under~~ ~~Impairment Considerations~~, the amounts reported in the ~~Condensed Consolidated Statements of Income and Condensed~~ Consolidated Statements of Comprehensive Income (Loss) are not necessarily indicative of amounts expected for the full year. In the opinion of management, ~~of the respective companies,~~ the information furnished herein reflects all adjustments which are necessary for a fair statement of the results for the interim periods reported, and such adjustments are of a normal recurring nature. In addition, the preparation of financial statements in conformity with GAAP 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 amount of revenues and expenses during the reporting period. Actual results could differ from those estimates.


1.	~~SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES~~

Certain amounts in DESC's 2018 Consolidated Financial Statements and Notes have been reclassified to conform to the 2019 presentation for comparative purposes; however, such reclassifications did not affect DESC's net income (loss) and other comprehensive income (loss), total assets, liabilities, equity or cash flows.

DESC is a wholly-owned subsidiary of SCANA which, effective January 2019, is a wholly-owned subsidiary of Dominion Energy.

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Consolidation and Variable Interest Entities

The condensed consolidated financial statements of the Company include, after eliminating intercompany balances and transactions, the accounts of the parent holding company and each of its subsidiaries, including Consolidated SCE&G. Accordingly, discussions regarding the Company's financial results necessarily include the results of Consolidated SCE&G.

~~SCE&G~~

DESC has determined that it has a controlling financial interest in each of GENCO and Fuel Company (which are considered to be VIEs) and, accordingly, DESC's Consolidated ~~SCE&G's condensed consolidated financial statements~~Financial Statements include, after eliminating intercompany balances and transactions, the accounts of ~~SCE&G,~~DESC, GENCO and Fuel Company. The equity interests in GENCO and Fuel Company are held solely by SCANA, ~~SCE&G’s~~DESC’s parent. As a result, ~~GENCO’s~~GENCO and Fuel Company’s equity and results of operations are reflected as noncontrolling interest in the Consolidated ~~SCE&G’s condensed consolidated financial statements.~~

Financial Statements.

GENCO owns a coal-fired electric generating station with a 605 MW net generating capacity (summer rating). GENCO’s electricity is sold, pursuant to a FERC-approved tariff, solely to ~~SCE&G~~DESC under the terms of a power purchase agreement and related operating agreement. The effects of these transactions are eliminated in consolidation. ~~Substantially all of~~ GENCO’s property (carrying value of ~~approximately~~ $497 million) ~~serves~~previously served as collateral for its long-term borrowings. In May 2019, GENCO redeemed its 5.49% senior secured notes and was able to release the first mortgage lien in June 2019 that had previously secured these notes. Fuel Company acquires, owns and provides financing for ~~SCE&G’s~~DESC’s nuclear fuel, certain fossil fuels and emission and other environmental allowances. See also Note 5.

~~Income Statement Presentation~~

~~Revenues~~

Additionally, DESC purchases shared services from DESS, an affiliated VIE that provides accounting, legal, finance and ~~expenses arising~~certain administrative and technical services to all SCANA subsidiaries, including DESC. DESC has determined that it is not the primary beneficiary of DESS as it does not have either the power to direct the activities that most significantly impact its economic performance or an obligation to absorb losses and benefits which could be significant to it. See Note 14 for amounts attributable to affiliates.

Significant Accounting Policies

There have been no significant changes from ~~regulated businesses~~Note 1 to the Consolidated Financial Statements in DESC's Annual Report on Form 10-K for the year ended December 31, 2018, with the exception of the item described below.

Leases

DESC leases certain assets including vehicles, real estate, office equipment and other assets under both operating and finance leases. For operating leases, rent expense is recognized on a straight-line basis over the term of the lease agreement, subject to regulatory framework. Rent expense associated with operating leases, short-term leases and variable leases is primarily recorded in other operations and maintenance expense in the ~~case~~Consolidated Statements of Comprehensive Income (Loss). Rent expense associated with finance leases results in the separate presentation of interest expense on the lease liability and amortization expense of the ~~Company,~~related right-of-use asset in the ~~retail natural gas marketing business (including those activities~~Consolidated Statements of ~~segments described~~Comprehensive Income (Loss). Amortization expense and interest charges associated with finance leases are recorded in ~~Note 11) are presented~~depreciation and amortization and interest charges, respectively, in the Consolidated Statements of Comprehensive Income (Loss) or deferred within ~~Operating Income,~~regulatory assets in the Consolidated Balance Sheets.

Certain leases include one or more options to renew, with renewal terms that can extend the lease from one to 70 years. The exercise of renewal options is solely at DESC's discretion and ~~other activities are presented within Other Income (Expense).~~

~~Asset Management~~is included in the lease term if the option is reasonably certain to be exercised. A right-of-use asset and ~~Supply Service Agreement~~

~~PSNC Energy, a subsidiary of SCANA, utilizes an asset management and supply service agreement~~corresponding lease liability for leases with a counterparty for certain natural gas storage facilities. Such counterparty held, through an agency relationship, 41% and 39% of PSNC Energy’s natural gas inventory at June 30, 2018 and December 31, 2017, respectively, with a carrying value of $9.8 million and $11.5 million, respectively. Under theoriginal lease terms of ~~this agreement, PSNC Energy receives storage asset management feesof which 75%~~one year or less are ~~credited to customers. This agreement expires on March 31, 2019.~~

~~Earnings Per Share~~

not included in the Consolidated Balance Sheets, unless such leases contain renewal options that DESC is reasonably certain will be exercised.

The Company computes basic earnings per share by dividing net income by the weighted average number of common shares outstanding for the period. When applicable, the Company computes diluted earnings per share using this same formula, after giving effect to securities considered to be dilutive potential common stock utilizing the treasury stock method.

~~Reclassifications~~

In the statement of operations, amounts reported for 2017 under the captions “Other income,” “Other expense” and “Allowance for equity funds used during construction” have been combined into a single caption titled “Other Income (Expense), Net.” Detailsdetermination of the ~~composition of this caption are described in Note 12. Also, the subtotal captioned “Total Other Expense” that previously appeared on the statements of operations~~discount rate utilized has ~~been eliminated.~~

~~New Accounting Matters~~

~~Recently Adopted~~

~~In the first quarter of 2018, the Company and Consolidated SCE&G adopted the following accounting guidance, as applicable, issued by the FASB. The adoption of this guidance had no impact or no~~a significant impact on ~~their respective financial statements except as indicated.~~

~~In January 2017,~~ the ~~FASB issued accounting guidance to simplify the accounting for goodwill impairment by removing Step 2~~calculation of the ~~goodwill impairment test. The guidance~~present value of the lease liability included in the Consolidated Balance Sheets. For DESC’s leased assets, the discount rate implicit in the lease is ~~effective for years beginning in 2020, though early adoption after January 1, 2017 is allowed. The Company adopted this guidance on January 1, 2018.~~

~~Effective January 1, 2018, the Company and Consolidated SCE&G adopted new accounting guidance for revenue arising~~generally unable to be determined from ~~contracts with customers. This guidance~~a lessee perspective. As such, DESC uses a five-step analysis in determining when and how revenue is recognized, and requires that revenue recognition depict the transfer of control of promised goods or services to customers in an amount that reflects the consideration a company expects to receive in exchange for those goods or services. As permitted, this guidance was adopted using the modified retrospective method whereby amounts and disclosures for prior periods are not restated. Revenue recognition patterns did not changeinternally-developed incremental borrowing rates as a ~~result of adopting this guidance, and no cumulative effect adjustment to Retained Earnings was required. For additional required disclosures, see Note 3.~~

Effective January 1, 2018, the Company and Consolidated SCE&G adopted accounting guidance that changed the required presentation of net periodic pension and postretirement benefit costs. As a result, net periodic pension and postretirement benefit costs have been separated into their service cost components and non-service cost components. Service cost components continue to be included within operating income and are presenteddiscount rate in the same line item as other compensation costs arising from services rendered by employees during the period. Non-service cost components are now excluded from operating income. This guidance has been applied on a retrospective basis for the presentationcalculation of the ~~service cost components and other components, and resulted in~~present value of the ~~following changes~~lease liability. The incremental borrowing rates are determined based on an analysis of DESC's publicly available secured borrowing rates over various lengths of time that most closely corresponds to ~~the amounts reported in 2017.~~

Increase (Decrease) Millions of dollars The Company Consolidated SCE&G
June 30, 2017 Three Months Ended Six Months Ended Three Months Ended Six Months Ended
Other operation and maintenance $ (2 ) $ (6 ) $ (1 ) $ (5 )
Total Operating Expenses (2 ) (6 ) (1 ) (5 )
Operating Income 2
6
1
5
Other Income (Expense), Net (2 ) (6 ) (1 ) (5 )

In addition, this guidance limits eligibility for capitalization of net periodic pension and postretirement benefit costs to only the service cost component, and requires this change to be applied prospectively. Accordingly, no reclassifications were made related to the capitalization of service costs, and the adoption of this guidance did not result in a material impact on the Company’s and Consolidated SCE&G’s respective financial statements. Amounts which otherwise would have been capitalized to plant accounts under prior guidance are now being deferred within regulatory assets.

~~Guidance issued in January 2016 changed how entities measure certain equity investments and financial liabilities, among other things.~~

Guidance issued in August 2016 is intended to reduce diversity in cash flow statement classification related to certain transactions, and entities must apply the guidance retrospectively to all periods presented.

~~Guidance issued in November 2016 clarified how restricted cash should be presented on the statement of cash flows, and entities were to apply the guidance retrospectively to all periods presented.~~

~~Pending Adoption~~

~~The Company and Consolidated SCE&G will adopt the following accounting guidance issued by the FASB when indicated below.~~

DESC's lease maturities.

Recently Adopted Accounting Standards

In February 2016, the ~~FASB~~Financial Accounting Standards Board issued revised accounting guidance ~~related to~~for the recognition, measurement, presentation and ~~presentation~~disclosure of ~~leases.~~leasing arrangements. The ~~guidance applies~~update requires that a liability and corresponding right-of-use ~~model and, for lessees, requires all leases with a duration over 12 months to be~~asset are recorded on the balance sheet ~~with~~for all leases, including those leases classified as operating leases, while also refining the ~~rights~~definition of ~~use treated as assets and the payment obligations treated as liabilities. Further,~~

~~depending primarily on the nature of the assets and the relative consumption of them, lease costs~~a lease. In addition, lessees will be ~~recognized either through~~required to disclose key information about the ~~separate amortization~~amount, timing, and uncertainty of ~~the right-of-use asset~~cash flows arising from leasing arrangements. Lessor accounting remains largely unchanged.

The guidance became effective for DESC's interim and the recognition of the interest cost related to the payment obligation, or through the recording of a combined straight-line rental expense. For lessors, the guidance calls for the recognition of income either through the derecognition of assets and subsequent recording of interest income on lease amounts receivable, or through the recognition of rental income on a straight-line basis, also depending on the nature of the assets and relative consumption. In the first quarter of 2018, FASB amendedannual reporting periods beginning January 1, 2019. DESC adopted this revised accounting guidance using a modified retrospective approach, which requires lessees and lessors to ~~clarify that land easements are within~~recognize and measure leases at the ~~scope~~date of adoption. Under this approach, DESC utilized the ~~new guidance and to provide an optional~~ transition practical expedient ~~that~~to maintain historical presentation for periods before January 1, 2019. DESC also applied the ~~Company~~other practical expedients, which required no reassessment of whether existing contracts are or contain leases, no reassessment of lease classification for existing leases and ~~Consolidated SCE&G intend to adopt, that allows adopters to not evaluate under the new guidance~~no evaluation of existing or expired land easements that were not previously accounted for as leases. ~~FASB also approved a new transition option in~~In connection with the ~~first quarter~~adoption of ~~2018, that the Company and Consolidated SCE&G intend to adopt, that will allow the new standard to be adopted without revising comparative period reporting or disclosures. The new~~this revised accounting guidance, is effective for years beginning in 2019, and the Company and Consolidated SCE&G do not anticipate that its adoption will have a material impact on their respective financial statements other than increasing amounts reported forDESC recorded $19 million of offsetting right-of-use assets and liabilities onfor operating leases in effect at the balance sheet and changing the location on their respective statements of operations where certain expenses are recorded. No impact on net income is expected. The identification and analysis of leasing and related contracts to which the guidance might apply continues. In addition, the Company and Consolidated SCE&G have begun implementation of a third party software tool that will assist with initial adoption ~~and ongoing compliance. Preliminary system configuration has been completed and data from certain leases are being entered.~~

~~In June 2016, the FASB issued accounting guidance requiring the use of a current expected credit loss impairment model~~date. See Note 12 for certain financial instruments. The new model is applicable to trade receivables and most debt instruments, among other financial instruments, and in certain instances may result in impairment losses being recognized earlier than under current guidance. The Company and Consolidated SCE&G must adopt this guidance beginning in 2020, including interim periods, though the guidance may be adopted in 2019. The Company and Consolidated SCE&G have not determined when this guidance will be adopted or what impact it will have on their respective financial statements.

In August 2017, the FASB issued accounting guidance intended to simplify the application of hedge accounting. Among other things, the new guidance will enable more hedging strategies to qualify for hedge accounting, will allow entities more time to perform an initial assessment of hedge effectiveness, and will permit an entity to perform a qualitative assessment of effectiveness for certain hedges instead of a quantitative one. For cash flow hedges that are highly effective, all changes in the fair value of the derivative hedging instrument will be recorded in other comprehensive income and will be reclassified to earnings in the same period that the hedged item impacts earnings. Fair value hedges will continue to be recorded in current earnings, and any ineffectiveness will impact the income statement. In addition, changes in the fair value of a derivative will be recorded in the same income statement line as the earnings effect of the hedged item, and additional disclosures will be required related to the effect of hedging on individual income statement line items. The guidance must be applied to all outstanding instruments using a modified retrospective method, with any cumulative effect adjustment recorded to opening retained earnings as of the beginning of the first period in which the guidance becomes effective. The Company and Consolidated SCE&G expect to adopt this guidance when required in the first quarter of 2019 and do not expect it to have a significant impact on their respective financial statements.

In February 2018, the FASB issued accounting guidance allowing entities to reclassify from AOCI to retained earnings any amounts for stranded tax effects resulting from the Tax Act. The guidance must be applied either in the period of adoption or retrospectively to each period in which the effect of the change was recognized. The Company and Consolidated SCE&G must adopt this guidance beginning in 2019, including interim periods, though the guidance may be adopted earlier. The Company and Consolidated SCE&G have not determined when this guidance will be adopted or what impact it will have on their respective statements of financial position. No impact is expected on statements of operations or cash flows.

information.

2.RATE AND OTHER REGULATORY MATTERS

~~Rate~~

Regulatory Matters

~~Tax Act Regulatory Proceedings~~

Involving Potential Loss Contingencies

As a result of issues generated in the ordinary course of business, DESC is involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for DESC to estimate a range of possible loss. For regulatory matters that DESC cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that DESC is able to estimate a range of possible loss. For regulatory matters that DESC is able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any estimated range is based on currently available information, involves elements of judgment and significant uncertainties and may not represent DESC’s maximum possible loss exposure. The ~~Tax Act contained~~circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on DESC’s financial position, liquidity or results of operations.

FERC

In June 2019, DESC submitted the 2015 Task Order as a stand-alone rate schedule, which governs DESC’s provision of retail service to the DOE at the Savannah River Site. The 2015 Task Order also includes provisions that ~~lowered~~govern the federal corporate tax rate from 35% to 21% effective January 1, 2018. In response, the SCPSC and the NCUC have sought information from utilities under their respective jurisdictions that would disclose the impact of the Tax Act on their individual company's operations and ~~would propose procedures for changing customer rates~~maintenance of certain transmission facilities, which DESC has determined to ~~reflect those impacts. SCE&G and PSNC Energy provided~~be services that are likely subject to ~~their respective commissions the requested information. The ORS filed a petition with the SCPSC that, among other things,~~FERC’s jurisdiction. DESC requested that the ~~SCPSC order that rates~~FERC accept the 2015 Task Order for filing to become effective in ~~effect as~~August 2019 and accept the refund analysis included in the filing. At June 30, 2019, DESC’s Consolidated Balance Sheets include reserves of ~~January 1, 2018, be~~$10 million included within revenue subject to refund so that ratepayers receive the benefit of the tax law changes as of January 1, 2018. The ORS has made subsequent filings with the SCPSC making specific recommendations for how it should direct SCE&G to account for the ~~effects~~potential refund of amounts collected under the ~~Tax Act~~2015 Task Order as well as under two prior task orders commencing in 1995 and ~~for~~each covering ten-year periods. During the ~~accrual~~second quarter of 2019, DESC recorded a $6 million ($4 million after-tax) charge primarily within interest on deferred amounts until new customer rates are made effective. On April 25, 2018, the SCPSC issued an order that requires utilities to track and defer as a regulatory liability the effects resulting from the Tax Act.

~~SCE&G and PSNC Energy expect their respective commissions will take further action on this~~charges in DESC’s Consolidated Statements of Comprehensive Income (Loss). This matter in 2018 but cannot determine what form those actions will take. As of June 30, 2018, estimates of income tax amounts charged through customer rates that relate to the effects of the Tax Act are being deferred as Revenue subject to refund on the condensed consolidated balance sheet. Such deferrals include the accrual of estimated carrying costs. Such estimates totaled $55.0 million for the Company, of which $46.2 million was attributable to Consolidated SCE&G. In addition, as further discussed under Regulatory Assets and Regulatory Liabilities below, certain accumulated deferred income taxes contained within regulatory liabilities represent excess deferred income taxes arising from the remeasurement of deferred income taxes upon the enactment of the Tax Act. Certain of these amounts are protected under normalization regulations and will be amortized over the remaining lives of related property, and certain of these amounts will be amortized to the benefit of customers over a prescribed period as instructed by regulators.

is pending.

Electric - BLRA ~~and Joint Petition~~

On January 12, 2018, SCE&G and Dominion Energy filed with the SCPSC the Joint Petition for review and approval of a proposed business combination whereby SCANA would become a wholly-owned subsidiary of Dominion Energy.

In the Joint Petition, approval of a customer benefits plan and a cost recovery plan for the Nuclear Project is also sought. Key provisions of this Joint Petition are summarized at Note 10. The SCPSC has scheduled a hearing on the Joint Petition and two other dockets related to the Nuclear Project, namely the Request by the ORS and a June 2017 complaint filed by the Friends of the Earth and the Sierra Club, to begin November 1, 2018. This hearing schedule was established in response to legislation described below.

~~On June 27,~~July 2018, the South Carolina ~~General Assembly adopted Act 258, which became law June 28, 2018, to temporarily reduce the amount SCE&G can collect~~Commission issued orders implementing a legislatively-mandated temporary reduction in revenues that could be collected by DESC from customers under the BLRA. ~~Act 258 requires the SCPSC to order a reduction in~~These orders reduced the portion of ~~SCE&G's~~DESC’s retail electric rates associated with the ~~Nuclear~~NND Project from approximately 18% of the average residential electric ~~customer’s~~customer's bill to approximately ~~3.2%~~3%, orwhich equates to a reduction in revenues of approximately $31 million per month, retroactive to April 1, 2018. ~~Absent an earlier ruling from~~As a result, in the ~~SCPSC, which could be issued only on the SCPSC’s own initiative, these lower rates are~~

second quarter of 2018 DESC recorded a charge of $109 million ($82 million after-tax) to ~~be effective until the SCPSC renders a final decision on the merits~~operating revenues in DESC’s Consolidated Statements of ~~the Joint Petition. On July 2 and 3, 2018, the SCPSC issued orders implementing the~~Comprehensive Income (Loss). The temporary rate reduction ~~required by Act 258. Unless~~remained in effect until February 2019 when rates pursuant to the ~~relief discussed~~SCANA Merger Approval Order became effective.

Other Regulatory Matters

Other than the following matter, there have been no significant developments regarding the pending regulatory matters disclosed in Note 2 to the ~~next paragraph is granted, the new rates and retroactive credits required by Act 258 are to be put into effect with the first billing cycle of August 2018. Retroactive credits~~Consolidated Financial Statements in DESC's Annual Report on Form 10-K for the ~~period April 1,~~year ended December 31, 2018 through June 30, 2018 total approximately $109.3 million, which amount has been deferred within Revenue subject to refund on the condensed consolidated balance sheet of the Company and Consolidated SCE&G. The initial recognition of such retroactive credits includes the effects of cycle billing on unbilled usage. In additionor Note 2 to the ~~reduction of electric rates (which rates had been previously approved by the SCPSC), Act 258~~

also alters various procedures previously applicable under the BLRA, including redefining the standard of care required by the BLRA and supplying definitions of key terms that would affect the evidence required to establish SCE&G’s ability to recover its costs associated with the Nuclear Project.

~~On June 29, 2018, SCE&G filed a lawsuit~~Consolidated Financial Statements in ~~the District Court challenging the constitutionality of Act 258 along with joint resolution S. 954, which became law~~DESC’s Quarterly Report on July 2, 2018. Among other things, S. 954 prohibits the SCPSC from holding a hearing on the merits of the Joint Petition before November 1, 2018, and requires it to issue an order on the merits of the Joint Petition by December 21, 2018. In the lawsuit, which was subsequently amended, SCE&G seeks a declaration that the new laws are unconstitutional and asks the court to issue an injunction prohibiting the SCPSC from implementing Act 258. A hearing on SCE&G’s motionForm 10-Q for the issuance of a preliminary injunction was held July 30-31, 2018. Dominion Energy and Sedona would not be obligated to complete the pending merger with SCANA if Act 258 remains in effect and is implemented.

~~Electric - Cost of Fuel~~

On April 25, 2018, the SCPSC approved SCE&G’s proposal to increase the total fuel cost component of retail electric rates. Specifically, the SCPSC approved SCE&G’s increase to certain environmental, avoided capacity and DER cost components and SCE&G’s agreement to maintain its base fuel component to produce a projected under-recovered balance of approximately $1.3 million at the end of the 12-month period beginning with the first billing cycle of May 2018. This projected under-recovered balance includes the effect of offsetting fuel cost recovery with the gains realized from the settlement of certain interest rate derivatives in early 2018. SCE&G also agreed to recover, over a 12-month period beginning with the first billing cycle of May 2018, projected DER program costs of approximately $29.3 million.

~~Electric - Other~~

On April 25, 2018, the SCPSC approved SCE&G's request to recover approximately $33.0 million of costs and net lost revenues associated with DSM Programs, along with an incentive to invest in such programs. Changes in rates became effective beginning with the first billing cycle of May 2018.

quarter ended March 31, 2019.

Gas ~~- SCE&G~~

In June ~~15, 2018, SCE&G~~2019, DESC filed with the ~~SCPSC~~South Carolina Commission its monitoring report for the 12-month period ended March 31, ~~2018 and proposed an approximately $22.6~~2019 with a total revenue requirement of $437 million. This represents a $7 million ~~or 5.29%,~~ overall ~~decrease~~increase to its natural gas rates under the terms of the RSA including the impact of the lower corporate tax rate resulting from the Tax Act. The ORS is expected to issue an audit report by September 1, 2018, and the SCPSC is expected to issue its order by October 15, 2018. If approved, the rate adjustment will beNatural Gas Rate Stabilization Act effective for the ~~first billing cycle of~~rate year beginning November ~~2018.~~

~~Gas - PSNC Energy~~

The NCUC has authorized PSNC Energy to use a tracker mechanism to recover the incurred capital investment and associated costs of complying with federal standards for pipeline integrity and safety requirements that are not in current base rates. PSNC Energy has filed biannual applications to adjust its rates for this purpose, and the NCUC has approved those applications for the incremental annual revenue requirements, as follows:



~~Rates Effective~~		~~Incremental Increase~~
~~March 1, 2017~~		~~$1.9 million~~
~~September 1, 2017~~		~~$0.7 million~~
~~March 1, 2018~~		~~$14.7 million~~

2019. This matter is pending.

Regulatory Assets and Regulatory Liabilities

Rate-regulated utilities recognize in their financial statements certain revenues and expenses in different periods than do other enterprises. As a result, ~~the Company and Consolidated SCE&G have~~DESC has recorded regulatory assets and regulatory liabilities which are summarized in the following tables. Except for ~~certain unrecovered nuclear project~~NND Project costs and certain other unrecovered plant costs, substantially all regulatory assets are either explicitly excluded from rate base or are effectively excluded from rate base due to their being offset by related liabilities.

	June 30,		December 31,
(millions)	2019		2018
Regulatory assets:
NND Project costs	$	138	$	127
Deferred employee benefit plan costs		16		16
Other unrecovered plant		14		14
DSM programs		16		14
Other		75		52
Regulatory assets - current		259		223
NND Project costs		2,572		2,641
AROs		324		380
Deferred employee benefit plan costs		230		256
Deferred losses on interest rate derivatives		308		442
Other unrecovered plant		73		79
DSM programs		53		51
Environmental remediation costs		21		24
Deferred storm damage costs		34		35
Deferred transmission operating costs		27		15
Other		117		123
Regulatory assets - noncurrent		3,759		4,046
Total regulatory assets	$	4,018	$	4,269
Regulatory liabilities:
Monetization of guaranty settlement	$	67	$	61
Income taxes refundable through future rates		48		52
Reserve for refunds to electric utility customers		136		—
Other		18		13
Regulatory liabilities - current		269		126
Monetization of guaranty settlement		1,003		1,037
Income taxes refundable through future rates		826		607
Asset removal costs		552		541
Deferred gains on interest rate derivatives		77		75
Reserve for refunds to electric utility customers		813		—
Other		6		4
Regulatory liabilities - noncurrent		3,277		2,264
Total regulatory liabilities	$	3,546	$	2,390

The Company Consolidated SCE&G
Millions of dollars June 30,
2018 December 31,
2017 June 30,
2018 December 31,
2017
Regulatory Assets:

Unrecovered Nuclear Project costs $ 4,142
$ 3,976
$ 4,142
$ 3,976
AROs and related funding 451
434
426
410
Deferred employee benefit plan costs 296
305
266
273
Deferred losses on interest rate derivatives 449
456
449
456
Other unrecovered plant 99
105
99
105
DSM Programs 59
59
59
59
Pipeline integrity management costs 61
51
9
8
Environmental remediation costs 29
30
24
25
Deferred storm damage costs 24
24
24
24
Other 147
140
146
140
Total Regulatory Assets $ 5,757
$ 5,580
$ 5,644
$ 5,476

Regulatory Liabilities:

Monetization of guaranty settlement $ 1,098
$ 1,095
$ 1,098
$ 1,095
Accumulated deferred income taxes 1,074
1,076
915
914
Asset removal costs 768
757
535
527
Deferred gains on interest rate derivatives 78
131
78
131
Other 1
—
1
—
Total Regulatory Liabilities $ 3,019

$ 3,059
$ 2,627
$ 2,667

Regulatory assets for unrecovered Nuclear Project costs have been recorded based on such amounts not being probable of loss in accordance with the accounting guidance on abandonments, whereas the other regulatory assets have been recorded based on the probability of their recovery. All regulatory assets represent incurred costs that may be deferred under ~~applicable~~ GAAP for regulated operations. The ~~SCPSC, the NCUC~~South Carolina Commission or the FERC has reviewed and approved through specific orders certain of the items shown as regulatory assets. In addition, regulatory assets include, but are not limited to, certain costs which have not been specifically approved for recovery by one of these regulatory agencies, including ~~unrecovered nuclear project~~deferred transmission operating costs that are the subject of regulatory proceedings ~~as further~~ discussed ~~above and~~ in Note ~~10. In recording~~11. While such costs ~~as regulatory assets,~~are not currently being recovered, management believes ~~the costs~~they would be allowable under existing rate-making concepts ~~that are~~ embodied in rate orders or ~~current~~applicable state ~~law. The~~law and expects to recover these costs ~~are currently not being recovered, but are expected to be recovered~~ through rates in future periods. In the future, as a result of deregulation, changes in state law, other changes in the regulatory environment or changes in accounting requirements or other adverse legislative or regulatory developments, ~~the Company or Consolidated SCE&G~~DESC could be required to write off all or a portion of its regulatory assets and liabilities. Such an event could have a material effect on ~~the Company's and Consolidated SCE&G's~~DESC's financial statements in the period the write-off would be recorded.

~~Unrecovered Nuclear~~

NND Project costs ~~represents~~reflects expenditures by SCE&G that have been reclassified from construction work in progress as a result of the decision to stop construction of Unit 2 and Unit 3 and to pursue recovery of costs under the abandonment provisions of the BLRA or through other regulatory means, net of an estimated impairment loss and of the cost of certain assets that have been or will be placed in service. See also Note 10.

~~AROs and related funding represents the regulatory asset~~ associated with the ~~legal obligation~~NND Project, which pursuant to ~~decommission~~the SCANA Merger Approval Order, will be recovered from electric service customers over a 20-year period ending in 2039. See Note 11 for more information.

AROs represent deferred depreciation and ~~dismantle Unit 1 and conditional AROs~~accretion expense related to legal obligations associated with the future retirement of generation, transmission and distribution ~~properties,~~properties. The AROs primarily relate to DESC’s electric generating facilities, including ~~gas pipelines. These regulatory assets~~Summer, and are expected to be recovered over the related property lives and periods of decommissioning which may range up to approximately ~~107~~106 years.

Employee benefit plan costs ~~of the regulated utilities~~ have historically been recovered as they have been recorded under GAAP. Deferred employee benefit plan costs represent amounts of pension and other postretirement benefit costs which were accrued as liabilities and treated as regulatory assets pursuant to FERC guidance, and costs deferred pursuant to specific ~~SCPSC~~South Carolina Commission regulatory orders. ~~SCE&G recovers~~DESC expects to recover deferred pension costs through utility rates ~~of approximately $2 million annually for electric operations, which will end in 2044, and approximately $1 million annually for gas operations, which will end in~~

~~2027. The remainder of the~~over periods through 2044. DESC expects to recover other deferred benefit costs ~~are expected to be recovered~~ through utility rates, primarily over average service periods of participating employees up to ~~approximately~~ 11 years.

Deferred losses or gains on interest rate derivatives represent (i) the ~~effective portions of~~ changes in fair value and payments made or received upon settlement of certain interest rate derivatives designated as cash flow hedges and (ii) the changes in fair value and payments made or received upon settlement of certain other interest rate derivatives not so designated. The amounts recorded with respect to (i) are expected to be amortized to interest expense over the lives of the underlying debt through 2043. The amounts recorded with respect to (ii) are expected to be similarly amortized to interest expense through 2065.

Other unrecovered plant represents the carrying value of coal-fired generating units, including related materials and supplies inventory, retired from service prior to being fully depreciated. ~~Pursuant to SCPSC approval, SCE&G~~DESC is amortizing these amounts through cost of service rates over the units' previous estimated remaining useful lives through ~~approximately~~ 2025. Unamortized amounts are included in rate base and are earning a current return.

DSM ~~Programs~~programs represent ~~SCE&G's~~ deferred costs associated with electric demand reduction programs, and such deferred costs are currently being recovered over ~~approximately~~ five years through an approved rate rider.

Pipeline integrity management costs represent operating costs incurred to comply with federal regulatory requirements related to natural gas pipelines. PSNC Energy is recovering costs totaling $4.1 million annually through 2021. PSNC Energy is continuing to defer pipeline integrity costs, and as of June 30, 2018 costs of $38.1 million have been deferred pending future approval of rate recovery. SCE&G amortizes $1.9 million of such costs annually.

Environmental remediation costs ~~represent costs~~are associated with the assessment and clean-up of sites currently or formerly owned by ~~SCE&G or PSNC Energy. SCE&G's~~DESC. Such remediation costs are expected to be recovered over periods of up to ~~approximately 17 years, and PSNC Energy's remediation costs of $4.5 million are being recovered over a period that will end in 2021.~~

16 years. See also Note 11.

Deferred storm damage costs represent ~~costs incurred in excess of amounts previously collected through SCE&G’s SCPSC-approved~~ storm ~~damage reserve, and~~restoration costs for which ~~SCE&G~~DESC expects to receive future recovery through customer rates.

Deferred transmission operating costs includes deferred depreciation and property taxes associated with certain transmission assets for which DESC expects recovery from customers through future rates. See also Note 11.

Various other regulatory assets are expected to be recovered through rates over varying periods through 2047.

Monetization of guaranty settlement represents proceeds ~~received under or arising from~~related to the monetization of the Toshiba Settlement. ~~The SCPSC is expected~~In accordance with the SCANA Merger Approval Order, this balance, net of amounts that may be required to ~~determine how SCE&G's~~satisfy certain liens, will be refunded to electric customers ~~will realize the value of these proceeds~~over a 20-year period ending in ~~connection with its consideration of the Request by the ORS and the Joint Petition (see above and~~2039. See Note ~~10).~~

~~Accumulated deferred income~~11.

Income taxes ~~contained within regulatory liabilities represent~~refundable through future rates includes (i) excess deferred income taxes arising from the remeasurement of deferred income taxes ~~upon~~in connection with the enactment of the 2017 Tax Reform Act (certain of which are protected under normalization ~~regulations~~rules and will be amortized over the remaining lives of related property, and certain of which will be amortized to the benefit of customers over a prescribed ~~period~~periods as instructed by regulators) and (ii) deferred income taxes arising from investment tax credits, offset by (iii) deferred income taxes that arise from utility operations that have not been included in customer rates (a portion of which relate to depreciation and are expected to be recovered over the remaining lives of the related property which may range up to ~~approximately~~ 85 years). See also Note 6.

Reserve for refunds to electric utility customers reflects amounts previously collected from retail electric customers of DESC for the NND Project to be credited to customers over an estimated 11-year period in connection with the SCANA Merger Approval Order. See Note 11.

Asset removal costs represent estimated net collections through depreciation rates of amounts to be ~~incurred~~expended for the removal of assets in the future.

3. REVENUE RECOGNITION

~~Identifying Revenue Streams and Related Performance Obligations~~

~~Operating Revenues~~

Operating revenues arise primarily from the sale and transmission of electricity and the sale and transportation of natural gas. Electric and Gas regulated revenues consist primarily of retail sales to residential, commercial and industrial customers under various tariff rates approved by state regulatory commissions. These tariff rates generally include charges for the energy consumed and a standard basic facilities or demand charge designed to recover certain fixed costs incurred to

provide service to the customer. Tariff rates also include commission-approved regulatory mechanisms in the form of adjustments or riders, such as for weather normalization, fuel and environmental cost recovery, energy conservation programs, interruptible service and real time pricing provisions, among others. Electric revenues also include wholesale sales and transmission service, primarily to municipal customers and other service providers, under contracts or tariffs approved by the FERC.

Gas nonregulated revenues arise from natural gas sales at market-based rates. Such sales to residential and certain commercial customers include charges for natural gas delivered, at either variable or fixed prices, together with any applicable customer service charges, charges originating from an interstate pipeline company, and other incidental charges. The Company

DESC has determined that its gas marketing subsidiary serves as an agent for distribution services provided by a nonaffiliated company in its retail market. Accordingly, the pass-through charges to customers related to such services are not considered revenues. Sales to other commercial and to industrial customers include commodity and transportation charges for natural gas delivered at contracted rates, together with applicable fees for storage, injection, demand, and charges originating from one or more interstate pipeline companies.

Performance obligations which have not been satisfied by the Company or Consolidated SCE&G relate primarily to demand or standby service for natural gas. Demand or standby charges for natural gas arise when an industrial customer reserves capacity on assets controlled by the service provider and may use that capacity to move natural gas it has acquired from other suppliers. For all periods presented, the amount of revenue recognized by the Company and Consolidated SCE&G for these charges is equal to the amount of consideration they have a right to invoice, and corresponds directly to the value transferred to the customer. As a result, amounts related to performance obligations that have not been fully satisfied are not disclosed.

Contracts governing the transactions above do not have a significant financing component. Also, due to the nature of the commodities underlying these transactions, no performance obligations arise for returns, refunds or warranties. In addition, taxes billed to customers are excluded from the transaction price. Such amounts are recorded as liabilities until they are remitted to the respective taxing authority and are not included in revenues or expenses in the statements of operations.

~~Non-Operating Revenues~~

Non-operating revenues are derived from the sale of appliances and water heaters, as well as from contracts covering the repair of certain appliances, wiring, plumbing and similar systems and fees received for such repairs from customers not under a repair contract. In addition, the portion of fees received under asset management agreements that regulators have recognized to be incentives for the Company and Consolidated SCE&G to engage in such transactions is recorded as non-operating revenues.

Revenues from sales are recorded when the appliance or water heater is delivered to the customer. Repair contract coverage fees are recorded when invoiced, generally on a monthly basis in advance of the period of coverage. Additional charges for service calls and non-covered repairs are billed and collected at the time service is rendered. Revenues from asset management agreements are recorded when the related fixed monthly amounts are due, which corresponds to timing of the value received by the customer.

The point at which the customer controls the use of a purchased product, or has obtained substantially all of the benefits from repair services, corresponds to when revenues are recorded and performance obligations are fulfilled. Contract assets arising from invoicing repair contract fees in advance of the coverage period are not material. Income earned from financing sales of appliances and other products is recorded within interest income. Any performance obligations arising from returns, refunds or warranties are not material.

Non-operating revenues also arise from sources unrelated to contracts with customers, such as carrying costs recorded on certain regulatory assets, gains from property sales and income from rentals and from equity method investments, among others. In 2018, such amounts include gains realized upon the settlement of certain interest rate swaps (see Note 12). Such revenues are outside the scope of revenues from contracts with customers.

Non-operating revenues are further described in Note 12. Such revenues arising from contracts with customers were not material for any period presented, and accordingly, detailed disclosures regarding these revenues are not provided.

~~Significant Judgments and Estimates~~

Electricity and natural gas are sold and delivered to the customer for immediate consumption and the customer controls the use of, and obtains substantially all of the benefits from, the energy and related services as they are delivered. As such, the related performance obligations are satisfied over time and revenue is recognized over the same period. The Company and Consolidated SCE&G have determined that their right to consideration from a customer directly corresponds to the value of the performance completed at the date each customer invoice is rendered. As a result, the Company and Consolidated SCE&G recognize revenue in the amounts for which they have a right to invoice. This includes estimated amounts unbilled at a balance sheet date but which are to be invoiced in the normal cycle.

~~Regulatory mechanisms exist within electric and gas tariffs or orders from regulators that result in adjustments to customer bills. These regulatory mechanisms are designed:~~

~~To recover costs related to fuel, pension, pipeline integrity and energy conservation, among others;~~

~~To recover carrying costs associated with debt-based financing;~~

~~To replace revenues lost as a result of the utility implementing DER programs and DSM Programs; and~~

~~For gas revenues, to achieve weather normalization or to decouple gas revenues from weather and other factors, such as through the WNA at SCE&G or the CUT at PSNC Energy.~~

Recovery of deferred costs and carrying costs and the replacement of lost revenues are components of approved tariffs, and therefore, adjustments to customer bills occur as electricity or natural gas is sold and delivered to the customer. As such, the Company and Consolidated SCE&G have concluded that performance obligations related to these adjustments are not capable of being distinct from the underlying tariff based sales. Accordingly, revenues arising from these adjustments are recorded within Operating Revenues - Electric or Gas - regulated on the statements of operations, consistent with revenues from underlying tariff based sales.

Adjustments for SCE&G’s WNA increase gas customer bills when weather is milder than normal and decrease gas customer bills when weather is colder than normal. These adjustments are made during the same period that the underlying natural gas is sold and delivered to the customer, and the performance obligations associated with these adjustments are not capable of being distinct from tariff based sales. Such adjustments are recorded within Operating Revenues - Gas - regulated on the statements of operations. When weather is significantly milder than normal, SCE&G limits such adjustments on a gas customer’s bill to an amount that would be added if weather were 50% milder than normal. Adjustments exceeding this limit, though still recorded as operating revenue, are deferred within regulatory assets until customers are subsequently billed for the excess with the approval of the SCPSC.

PSNC Energy’s CUT is a decoupling mechanism that adjusts bills for residential and commercial customers based on per customer average consumption. When average consumption exceeds actual usage, PSNC Energy records increased revenue associated with this undercollection and defers it within regulatory assets. Likewise, when actual usage exceeds average consumption, a decrement to revenue associated with this overcollection is recorded and deferred within regulatory liabilities. PSNC Energy’s tariff based rates are adjusted semiannually, with the approval of the NCUC, to collect or refund these deferred amounts over the subsequent 12 month period.

Amounts deferred for the WNA and the CUT arise under specific arrangements with regulators rather than customers. As a result, the Company and Consolidated SCE&G have concluded that these arrangements represent alternative revenue programs. Revenue from alternative revenue programs is included within Operating Revenues - Gas - regulated on the statements of operations in the month such adjustments are deferred within regulatory accounts, and is shown as Other operating revenues when disaggregated in the table below. As permitted, the Company and Consolidated SCE&G have elected to reduce the regulatory accounts in the period when such amounts are reflected on customer bills without affecting operating revenues.

~~Disaggregation of Revenues~~

The impact of several factors on the amount, timing and uncertainty of operating revenues and cash flows can vary significantly by customer class. For electric revenues and nonregulated gas revenues, which do not have weather normalization mechanisms in place, the impact of weather and conservation measures on energy usage typically affect residential and commercial customers to a greater degree than other customer classes. For utilities, revenue requirements result in increases or decreases in tariff rates approved by regulatory bodies and often vary by customer class. Also, certain cost recovery and other mechanisms may have an uneven impact on a particular customer class depending on the underlying tariffs affected. For nonregulated gas, revenues are impacted by competitive market rates tailored to appeal to specific customer classes. The Company and Consolidated SCE&G have disaggregated operating revenues by customer class as follows:

	Three Months Ended					Three Months Ended				Six Months Ended				Six Months Ended
	June 30, 2019					June 30, 2018				June 30, 2019				June 30, 2018
(millions)	Electric			Gas		Electric		Gas		Electric		Gas		Electric		Gas
Customer class:
Residential	$	281		$	31	$	243	$	34	$	10	$	109	$	495	$	120
Commercial		206			23		171		22		67		61		340		61
Industrial		100			19		106		21		18		45		191		45
Other		35			4		30		2		45		7		68		7
Revenues from contracts with customers		622			77		550		79		140		222		1,094		233
Other revenues		(1	)		—		3		—		1		—		6		1
Total Operating Revenues	$	621		$	77	$	553	$	79	$	141	$	222	$	1,100	$	234

The Company Consolidated SCE&G PSNC Energy Gas-nonregulated
Millions of dollars Electric Gas-regulated Gas-regulated
Total
Gas-regulated

Three months ended June 30, 2018
Customer class:
  Residential $ 243
$ 34
$ 38
$ 72
$ 30
  Commercial 171
22
18
40
16
  Industrial 106
21
4
25
91
  Other 30
2
7
9
6
Revenues from contracts with customers 550
79
67
146
143
Other operating revenues 3
—
2
2
—
Total Operating Revenues $ 553
$ 79
$ 69
$ 148
$ 143

Six months ended June 30, 2018
Customer class:
  Residential $ 495
$ 120
$ 183
$ 303
$ 136
  Commercial 340
61
66
127
50
  Industrial 191
45
10
55
211
  Other 68
7
15
22
19
Revenues from contracts with customers 1,094
233
274
507
416
Other operating revenues 6
1
1
2
—
Total Operating Revenues $ 1,100
$ 234
$ 275
$ 509
$ 416

Contract ~~Costs~~

~~Costs~~liabilities represent the obligation to ~~obtain contracts are generally expensed when incurred. In limited instances, SCE&G provides economic development grants intended~~transfer goods or services to ~~support economic growth within SCE&G’s electric service territory and defers such grants as regulatory assets on the condensed consolidated balance sheet. Whenever these grants are contingent on~~ a customer ~~entering into a long-term electric supply~~for which consideration has already been received from the customer. DESC had contract ~~with SCE&G, they~~liability balances of $5 million and $4 million at June 30, 2019 and December 31, 2018, respectively. During the six months ended June 30, 2019, DESC recognized revenue of $3 million from the beginning contract liability balances as DESC fulfilled its obligations to provide service to its customers. Contract liabilities are ~~considered costs to obtain that underlying contract. Such costs that exceed certain thresholds are deferred~~recorded in customer deposits and ~~amortized on a straight-line basis over~~customer prepayments in the ~~term of the related service contract, which generally ranges from ten to 15 years.~~

~~Balances and activity related to contract costs deferred as regulatory assets were as follows:~~

The Company and Consolidated SCE&G
Millions of dollars Regulatory Assets
January 1, 2018 $ 16.3
Additional costs —
Amortization (0.8 )
Impairment —
June 30, 2018 $ 15.5

Consolidated Balance Sheets.

4. ~~COMMON~~ EQUITY

SCANA shareholders approved the Merger Agreement at a special meeting on July 31, 2018. Certain regulatory approvals must be obtained and other conditions must be met before the merger may be consummated.

~~SCANA had 200 million~~

For all periods presented, DESC's authorized shares of common stock, ~~authorized as of June 30, 2018 and December 31, 2017.~~

~~Authorized shares of SCE&G common stock~~no par value, were 50 million, as of ~~June 30, 2018~~which 40.3 million were issued and ~~December 31, 2017. Authorized~~outstanding, and DESC's authorized shares of ~~SCE&G~~ preferred stock, no par value, were 20 million, of which 1,000 shares ~~no par value,~~ were issued and ~~outstanding as of June~~

~~30, 2018 and December 31, 2017.~~outstanding. All ~~issued and~~ outstanding shares of ~~SCE&G's~~ common and preferred stock are held by SCANA.

In ~~June 2018, SCANA made~~February 2019, DESC received an equity contribution of $675 million from its parent that was funded by Dominion Energy. DESC used these funds to ~~GENCO~~redeem long-term debt. See Note 5.

In June 2019, DESC received an equity contribution of ~~$20 million.~~

~~SCANA’s articles of incorporation do not limit the dividends~~$100 million from its parent that ~~may be paid on its common stock, and the articles of incorporation of each of SCANA's subsidiaries contain no such limitations on their respective common stock. SCANA has agreed~~was funded by Dominion Energy. DESC used these funds to ~~obtain the consent of~~repay intercompany credit agreement borrowings from Dominion ~~Energy, which consent cannot be unreasonably withheld, prior to making dividend payments to shareholders greater than $0.6125 per share for any quarter while the Merger Agreement is pending.~~

~~SCE&G’s~~Energy.

DESC’s bond indenture under which it issues ~~First Mortgage Bonds~~first mortgage bonds contains provisions that could limit the payment of cash dividends on its common stock. ~~SCE&G's~~DESC's bond indenture permits the payment of dividends on ~~SCE&G's~~DESC's common stock only either (1) out of its Surplus (as defined in the bond indenture) or (2) in case there is no Surplus, out of its net profits for the fiscal year in which the dividend is declared and/or the preceding fiscal year. In addition, the Federal Power Act requires the appropriation of a portion of certain earnings from hydroelectric projects. At June 30, ~~2018~~2019 and ~~2017,~~December 31, 2018, retained earnings of ~~approximately $97.6~~$126 million and ~~$82.3~~$115 million, respectively, were restricted by this requirement as to payment of cash dividends on ~~SCE&G’s~~DESC’s common stock.

~~PSNC Energy’s note purchase~~ In addition, pursuant to the SCANA Merger Approval Order, the amount of any DESC dividends paid must be reasonable and ~~debenture purchase agreements contain provisions that could limit~~consistent with the long-term payout ratio of the electric utility industry and gas distribution industry.

At June 30, 2019, DESC’s retained earnings are below the balance established by the Federal Power Act as a reserve on earnings attributable to hydroelectric generation plants. As a result, DESC is prohibited from the payment of ~~cash distributions, including~~ dividends without regulatory approval until the balance of its retained earnings increases. There have been no other significant changes to dividend restrictions affecting DESC described in Note 4 to the Consolidated Financial Statements in DESC’s Annual Report on ~~PSNC Energy's common stock. These agreements generally limit~~Form 10-K for the ~~sum of distributions to an amount that does not exceed $30 million~~ ~~plus~~ ~~85% of Consolidated Net Income (as therein defined) accumulated after~~year ended December 31, ~~2008~~ ~~plus~~ the net proceeds of issuances by PSNC Energy of equity or convertible debt securities (as therein defined). As of June 30, 2018, this limitation would permit PSNC Energy to pay cash distributions in excess of $100 million.

2018.

5. LONG-TERM AND SHORT-TERM DEBT AND LIQUIDITY

Long-term Debt

In ~~June 2018,~~February 2019, DESC launched tender offers for certain of its first mortgage bonds pursuant to which it purchased first mortgage bonds having an aggregate purchase price equal to $1.2 billion. DESC incurred a loss on reacquired debt of $187 million in connection with these tender offers, which is recorded in other deferred debits on the Consolidated Balance Sheets.

Long-term Debt - Affiliate

In May 2019, GENCO ~~redeemed~~issued a $230 million 3.05% promissory note due to Dominion Energy that matures in May 2024. The issuance by GENCO was approved by the South Carolina Commission. Proceeds from the issuance were used to redeem GENCO’s 5.49% senior secured notes due in 2024 at ~~maturity $160~~the remaining principal outstanding of $33 million ~~of 6.06% secured notes. The repayment was funded using a combination of utility~~plus accrued interest, repay money pool borrowings and ~~an equity contribution from SCANA.~~

~~In June 2018, PSNC Energy issued $100~~to return $20 million of ~~4.33% senior notes due June 15, 2028.~~ contributed equity capital to SCANA.

Liquidity

In ~~June 2017, PSNC~~March 2019, DESC became a co-borrower under Dominion Energy's $6 billion joint revolving credit facility. DESC's short-term financing is supported through its access to this joint revolving credit facility, which can be used for working capital, as support for the combined commercial paper programs of DESC, Dominion Energy ~~issued $150 million~~and certain other of ~~4.18% senior notes due~~its subsidiaries (co-borrowers), and for other general corporate purposes.

DESC's share of commercial paper and letters of credit outstanding under its joint credit facility with Dominion Energy, were as follows:

(millions)

Facility Limit

Outstanding

Commercial Paper

Outstanding

Letters of Credit

At June 30, 2019

1,000

—

A maximum of $1.0 billion of the facility is available to DESC, less any amounts outstanding to co-borrowers. A sub-limit for DESC is set within the facility limit but can be changed at the option of the co-borrowers multiple times per year. At June 30, ~~2047. Proceeds~~2019, the sub-limit for DESC was $500 million. If DESC has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term borrowings from ~~each of these sales were~~DESC's parent or from Dominion Energy. This credit facility matures in March 2023 and can be used to ~~repay short-term debt,~~support bank borrowings and the issuance of commercial paper, as well as to ~~finance capital expenditures, and for general corporate purposes.~~

~~Substantially all electric utility plant~~support up to $1.0 billion (or the sub-limit, whichever is ~~pledged as collateral~~less) of letters of credit.

Also in ~~connection~~March 2019, DESC canceled its previous committed long-term facility which was a revolving line of credit under a credit agreement with ~~long-term debt.~~

~~Liquidity~~

~~Credit agreements are~~a syndicate of banks. This previous credit agreement was used for general corporate purposes, including liquidity support for ~~each company's~~DESC's commercial paper program and working capital needs, and was set to expire in December 2020.

(millions)

Facility Limit⁽¹⁾

Outstanding

Commercial Paper

Outstanding

Letters of Credit

At December 31, 2018

1,200

—

(1)	Included $500 million related to Fuel Company. In February 2019, Fuel Company's commercial paper program and its credit facility were terminated.

The weighted-average interest rate of the case of Fuel Company, to finance or refinance the purchase of nuclear fuel, certain fossil fuels, and emission and other environmental allowances. Committed long-term facilities are revolving lines of credit under credit agreements with a syndicate of banks. Committed LOC, outstanding ~~LOC advances,~~ commercial paper ~~and LOC-supported letter of~~supported by this credit ~~obligations were as follows:~~

June 30, 2018 (Millions of dollars) Total SCANA Consolidated SCE&G PSNC Energy
Lines of credit: +

Five-year, expiring December 2020 $ 1,300.0
$ 400.0
$ 700.0
$ 200.0
Fuel Company five-year, expiring December 2020 500.0
—
500.0
—
Three-year, expiring December 2018 200.0
—
200.0
—
Total committed long-term 2,000.0
400.0
1,400.0
200.0
LOC advances 100.0
—
100.0
—
Weighted average interest rate —
3.31 % —
Outstanding commercial paper (270 or fewer days) 517.4
29.0
457.5
30.9
Weighted average interest rate 2.99 % 2.96 % 2.61 %
Letters of credit supported by LOC 33.7
33.4
0.3
—
Available $ 1,348.9
$ 337.6
$ 842.2
$ 169.1

December 31, 2017 (Millions of dollars) Total SCANA Consolidated SCE&G PSNC Energy
Lines of credit:
Five-year, expiring December 2020 $ 1,300.0
$ 400.0
$ 700.0
$ 200.0
Fuel Company five-year, expiring December 2020 500.0
—
500.0
—
Three-year, expiring December 2018 200.0
—
200.0
—
Total committed long-term 2,000.0
400.0
1,400.0
200.0
Outstanding commercial paper (270 or fewer days) 350.3
—
251.6
98.7
Weighted average interest rate —
1.92 % 1.93 %
Letters of credit supported by LOC 3.3
3.0
0.3
—
Available $ 1,646.4
$ 397.0
$ 1,148.1
$ 101.3

facility was 3.82% at December 31, 2018.

In March 2018, SCE&G borrowed $100 million under the five-year credit agreement expiring December 2020. The interest rate on this draw at June 30, 2018 was 3.31%, and this draw is classified as long-term debt. Proceeds from the draw were deposited with a natural gas supplier to provide contractually required credit support, and this deposit is reflected within other assets on the condensed consolidated balance sheet. The interest rate on this deposit currently exceeds the interest rate on the draw. Also, SCANA has issued a letter of credit in favor of a natural gas supplier to provide contractually required credit support.

~~SCE&G has obtained~~April 2019, DESC renewed its FERC authority to issue short-term indebtedness ~~and to assume liabilities as a guarantor~~ (pursuant to Section 204 of the Federal Power Act). ~~SCE&G~~DESC may issue unsecured promissory notes, commercial paper and direct loans in amounts not to exceed ~~$1.6~~$2.2 billion outstanding with maturity dates of one year or ~~less, and may enter into guaranty agreements~~less. In addition, in ~~favor of lenders, banks, and dealers in commercial paper in amounts not to exceed $600 million.~~April 2019, GENCO ~~has obtained~~renewed its FERC authority to issue short-term indebtedness not to exceed $200 million outstanding with maturity dates of one year or less. The ~~authority~~authorities described herein will expire in ~~October 2018.~~April 2020, which reflects a one-year authorization period rather than the two-year period DESC and GENCO had requested. In granting the authorization for a shorter period, FERC cited certain regulatory and legislative proceedings at the state level, as well as certain legal proceedings, arising from the NND Project that could affect DESC's and GENCO's circumstances. Were adverse developments to occur with respect to these uncertainties, ~~highlighted elsewhere,~~ the ability of ~~SCE&G~~DESC or GENCO to secure renewal of this short-term borrowing authority may be adversely impacted.

Proceeds received under or arising from the monetization of the Toshiba Settlement in 2017 have been utilized to repay maturing commercial paper balances, which short-term borrowings had been incurred primarily for the construction of Unit 2 and Unit 3 prior to the decision to stop their construction (see Note 10). Should the SCPSC or a court direct that these proceeds be refunded to customers in the near-term, or direct that such funds be escrowed or otherwise made unavailable to SCE&G, it is anticipated that SCE&G would issue commercial paper, draw on its credit facilities or issue long-term debt to fund such requirement. However, if the SCPSC were to rule in favor of the ORS in response to the Request that SCE&G suspend collections from customers of amounts previously authorized under the BLRA, if the temporary rate reduction arising from the implementation of Act 258 were to remain in effect following the order of the SCPSC arising from the Joint Petition, or were other actions of the SCPSC or others taken in order to significantly restrict SCE&G’s access to revenues or impose additional adverse refund obligations on SCE&G, the Company’s and Consolidated SCE&G's assessments regarding the recoverability of all or a portion of the remaining balance of unrecovered nuclear project costs would be adversely impacted (see Note 2 and Note 10). Further, the recognition of significant additional impairment losses with respect to unrecovered Nuclear Project costs could increase the Company’s and Consolidated SCE&G’s debt to total capitalization to a level which

~~may limit their ability to borrow under their commercial paper programs or under their credit facilities. Borrowing costs for long-term debt issuances could also be impacted.~~

~~Each of the Company and Consolidated SCE&G~~

DESC is obligated with respect to an aggregate of ~~$67.8~~$68 million of industrial revenue bonds which are secured by letters of credit issued by TD Bank N.A. These letters of credit expire, subject to renewal, in the fourth quarter of 2019.

DESC received FERC approval to enter into an inter-company credit agreement in April 2019 with Dominion Energy under which DESC may have short-term borrowings outstanding up to $900 million. At June 30, 2019, DESC had borrowings outstanding under this credit agreement totaling $61 million, which are recorded in affiliated and related party payables in DESC’s Consolidated ~~SCE&G participates~~Balance Sheets. For the three and six months ended June 30, 2019, DESC recorded interest charges of less than $1 million.

DESC participated in a utility money pool with SCANA and another regulated subsidiary of ~~SCANA.~~SCANA through April 2019. Fuel Company and GENCO remained in the utility money pool. Money pool borrowings and investments bear interest at short-term market rates. ~~Consolidated SCE&G’s~~For the three and six months ended June 30, 2019, DESC recorded interest income from money pool transactions of $3 million and $6 million, respectively, and for the same periods DESC recorded interest expense from money pool transactions of $3 million and $6 million, respectively. Interest income and interest expense for the corresponding periods in 2018 were not ~~significant for any period presented. Consolidated SCE&G~~significant. DESC had outstanding money pool borrowings due to an affiliate of ~~$187~~$224 million and investments due from an affiliate of ~~$144~~$9 million at June 30, ~~2018.~~2019. At December 31, ~~2017 Consolidated SCE&G~~2018, DESC had outstanding money pool borrowings due to an affiliate of ~~$37~~$282 million and investments due from an affiliate of ~~$28~~$353 million. ~~For each period presented, money pool borrowings were made by Fuel Company and GENCO, and money pool investments were made by SCE&G.~~ On its ~~condensed consolidated balance sheet,~~ Consolidated ~~SCE&G~~Balance Sheets, DESC includes money pool borrowings within ~~Affiliated~~affiliated and related party payables and money pool investments within ~~Affiliated companies~~affiliated and related party receivables.

6. INCOME TAXES

~~The Company files consolidated~~

DESC’s effective tax rate for the six months ended June 30, 2019 is 8.1% compared to 20.5% for the six months ended June 30, 2018. Variances in the effective tax rate are primarily driven by charges resulting from the SCANA Combination. In connection with the SCANA Merger Approval Order, Dominion Energy committed to forgo, or limit, the recovery of certain income tax-related regulatory assets associated with the NND Project. DESC's effective tax rate reflects income tax expense of $198 million in satisfaction of this commitment.

In the first quarter, DESC’s unrecognized tax benefits increased by $51 million and income tax expense increased by $40 million related to a state income tax position taken in prior years. In the second quarter, DESC’s unrecognized tax benefits increased by $24 million and income tax expense increased by $23 million primarily related to a federal income tax ~~returns which include Consolidated SCE&G, and the Company and its subsidiaries file various applicable state and local income~~position taken in prior years.

As of June 30, 2019, there have been no other material changes in DESC’s unrecognized tax ~~returns.~~

~~The Company’s federal returns through 2007 are closed by statute. In addition, federal returns for 2008 and 2009 are closed except~~benefits. See Note 6 to the ~~extent~~Consolidated Financial Statements in DESC's Annual Report on Form 10-K for the year ended December 31, 2018 for a discussion of the examination of amended return claims discussed below. The IRS is also currently examining SCANA's federal returns for years 2010 through 2016 as a result of those claims. With few exceptions, the Company, including Consolidated SCE&G, is no longer subject to state and local income tax examinations by tax authorities for years before 2010.

During 2013 and 2014, the Company amended certain of its income tax returns for 2008 through 2012 to claim additional tax-defined research and experimentation deductions (under IRC Section 174) and credits (under IRC Section 41) and to reflect related impacts on other items such as domestic production activities deductions (under IRC Section 199). The Company also made similar claims in filing its original 2013 and 2014 returns in 2014 and 2015, respectively. In 2016, 2017 and 2018, the Company claimed significant research and experimentation deductions and credits (offset by reductions in its domestic production activities deductions), related to the design and construction activities of the Nuclear Project, in its 2015, 2016 and 2017 income tax returns. These claims followed the issuance of final IRS regulations in 2014 regarding such treatment with respect to expenditures related to the design and construction of pilot models.

The IRS examined the claims in the amended 2008-2012 returns, and as the examination progressed without resolution, the Company and Consolidated SCE&G evaluated and recorded adjustments to unrecognized tax benefits; however, none of these changes materially affected the Company's and Consolidated SCE&G's effective tax rate. In October 2016, the examination of the amended tax returns progressed to the IRS Office of Appeals. In addition, the IRS has begun an examination of SCANA's 2013 through 2016 income tax returns, and it is expected that the IRS will also examine later returns.

These IRC Section 174 income tax deductions and IRC Section 41 credits were considered to be uncertain tax positions, and under relevant accounting guidance, estimates of the amounts of related tax benefits which may not be sustained upon examination by the taxing authorities were recorded as unrecognized tax benefits ~~in the financial statements. Also, following the abandonment of the Nuclear Project, the Company~~ and ~~Consolidated SCE&G claimed an abandonment loss deduction under IRC Section 165 on the 2017 tax return. As such, certain of the IRC Section 174 deductions,~~potential changes due to the ~~extent they are denied, would instead~~SCANA Combination.

DESC has significant federal and state net operating loss carryforward-related deferred tax assets where the utilization of these tax benefits may be ~~expected~~limited in future periods due to the SCANA Combination. For the period ended June 30, 2019, DESC has concluded a valuation allowance is not required on these deferred tax assets. If DESC concludes a valuation allowance is required in future periods, the impact could be material.

The 2017 Tax Reform Act limits the deductibility of interest expense to 30% of adjusted taxable income for certain businesses, with any disallowed interest carried forward indefinitely. Subject to additional guidance in yet to be finalized regulations, DESC expects its interest expense to be deductible in ~~2017 under IRC Section 165. The abandonment loss deduction is also considered an uncertain tax position; however, under relevant~~2019.

7. DERIVATIVE FINANCIAL INSTRUMENTS

DESC’s accounting guidance, no estimated unrecognized tax benefits were recorded as of June 30, 2018. The remaining unrecognized tax benefits include the impact of the IRC Section 174 deductions on domestic production activities deductions, credits,policies, objectives, and ~~certain unrecognized state tax benefits.~~

As of June 30, 2018, the Company and Consolidated SCE&G have recorded an unrecognized tax benefit of $98 million ($19 million net of the impact of state deductions on federal returns, net of NOL and credit carryforwards, and net of receivables related to the uncertain tax positions). If recognized, $98 million of the tax benefit would affect the Company’s and Consolidated SCE&G's effective tax rates. These unrecognized tax benefitsstrategies for using derivative instruments are ~~not expected to increase significantly within the next 12 months. It is also reasonably possible that these unrecognized tax benefits may decrease by $11 million within the next~~

~~12 months. No other material changes~~discussed in Note 7 in the ~~status of~~Consolidated Financial Statements in DESC’s Annual Report on Form 10-K for the ~~Company’s or Consolidated SCE&G's tax positions have occurred through June 30, 2018 (see Note 10).~~

In connection with the research and experimentation deduction and credit claims reflected on the 2015, 2016 and 2017 income tax returns and under the provisions of an SCPSC order, the Company and Consolidated SCE&G recorded regulatory assets for estimated foregone domestic production activities deductions, offset by estimated tax credits, with the expectation that these deferred costs and related interest thereon would be recoverable through customer rates in future years. However, an impairment loss with respect to such deferred regulatory asset was recorded in 2017 (see Note 10).

Also under the provisions of an SCPSC order, estimated interest expense accrued with respect to the unrecognized tax benefits related to the research and experimentation deductions in the 2015 and 2016 income tax returns was deferred as a regulatory asset and was expected to be recoverable through customer rates in future years. An impairment loss with respect to these deferred amounts was also recorded as ofyear ended December 31, 2017 (see Note 10). Otherwise, the Company and Consolidated SCE&G recognize interest accrued related to unrecognized tax benefits within interest expense or interest income and recognize tax penalties within other expenses. Related to the unrecognized tax benefits noted above, the Company and Consolidated SCE&G accrued interest expense of $5.9 million and interest income of $1.0 million during 2018. Amounts recorded for such interest income and interest expense were mostly deferred within regulatory assets during 2017 and were subsequently included within the impairment loss recorded by the Company and Consolidated SCE&G in 2017. Penalties were not material in either period presented.

~~In December of 2017, the Tax Act was enacted to lower the federal statutory corporate tax rate from 35% to 21%. The rate change resulted in the remeasurement of all federal deferred income tax~~Derivative assets and liabilities to reflect a 21% federal statutory corporate tax rate as of December 31, 2017. Due to the regulated nature of the Company’s and Consolidated SCE&G’s operations, the effect of this remeasurement is primarily reflected in deferred income tax balances within regulatory liabilities. As of June 30, 2018, the amortization of amounts arising from remeasurement have not affected the Company’s or Consolidated SCE&G’s effective tax rate due to such amortizations being deferred until such time as regulators prescribe how the benefits of such excess deferred tax amounts will be realized by customers. Upon the filing of the Company’s superseding 2017 consolidated income tax return later this year, adjustments to deferred income taxes may be recorded; however, these adjustments are ~~not expected to have a material impact~~presented gross on the ~~Company’s financial position, results of operations, or cash flows.~~

The State of North Carolina lowered its corporate income tax rate to 3.0% in 2017 and 2.5% effective January 1, 2019. In connection with these changes in tax rates, related state deferred tax amounts were remeasured, with the change in their balances being credited to a regulatory liability. The changes in income tax rates did not and are not expected to have a material impact on the Company’s financial position, results of operations or cash flows.

On July 2, 2018, the Company received a tax refund of approximately $206 million related to carry-back losses arising from the abandonment loss claimed by SCE&G under IRC Section 165 on the 2017 tax return.

~~7. DERIVATIVE FINANCIAL INSTRUMENTS~~

~~Derivative instruments are recognized either as assets or liabilities in the statement of financial position~~Consolidated Balance Sheets and are measured at fair value. ~~Changes in the~~See Note 8 for further information about fair value ~~of derivative instruments~~measurements and associated valuation methods for derivatives. Derivative contracts include over-the-counter transactions, which are recognized either in earnings, as a component of other comprehensive income (loss) or, for regulated operations, within regulatory assets or regulatory liabilities, depending upon the intended use of the derivative and the resulting designation.

Policies and procedures, and in some cases risk limits, are established to control the level of market, credit, liquidity and operational and administrative risks. SCANA’s Board of Directors has delegated to a Risk Management Committee the authority to set risk limits, establish policies and procedures for risk management and measurement, and oversee and review the risk management process and infrastructure for SCANA and each of its subsidiaries. The Risk Management Committee, which is comprised of certain officers, including the Risk Management Officer and other senior officers, apprises the Board of Directors with regard to the management of risk and brings to their attention significant areas of concern. Written policies define the physical and financial transactionsbilateral contracts that are ~~approved, as well as the authorization requirements and limits for transactions.~~

~~Commodity Derivatives~~

~~The Company uses derivative instruments~~transacted directly with a third party. In general, most over-the-counter transactions are subject to hedge forward purchases and sales of natural gas, which create market risks of different types. Instruments designated as cash flow hedges are used to hedge risks associated with fixed price obligations in a volatile market and risks associated with price differentials at different delivery locations. Instruments designated as fair value hedges are used to mitigate exposure to fluctuating market prices created by fixed prices of stored natural gas. The basic types of financial instruments utilized are exchange-traded instruments, such as NYMEX futures contracts or options, and over-the-counter instruments such as options and swaps, which are typically offered by energy companies and financial institutions. Cash settlements of commodity derivatives are classified as operating activities in the consolidated statements of cash flows.

PSNC Energy hedges natural gas purchasing activities using over-the-counter options and NYMEX futures and options. PSNC Energy’s tariffs include a provision for the recovery of actual gas costs incurred, including any costs of hedging. PSNC Energy records premiums, transaction fees, margin requirements and any realized gains or losses from its hedging program in deferred accounts as a regulatory asset or liability for the under- or over-recovery of gas costs. These derivative financial instruments are not designated as hedges for accounting purposes.

Unrealized gains and losses on qualifying cash flow hedges of nonregulated operations are deferred in AOCI. When the hedged transactions affect earnings, previously recorded gains and losses are reclassified from AOCI to cost of gas. The effects of gains or losses resulting from these hedging activities are either offset by the recording of the related hedged transactions or are included in gas sales pricing decisions made by the business unit.

As an accommodation to certain customers, SCANA Energy, as part of its energy management services, offers fixed price supply contracts which are accounted for as derivatives. These sales contracts are offset by the purchase of supply futures and swaps which are also accounted for as derivatives. Neither the sales contracts nor the related supply futures and swaps are designated as hedges for accounting purposes.

~~Interest Rate Swaps~~

Interest rate swaps may be used to manage interest rate risk and exposure to changes in fair value attributable to changes in interest rates on certain debt issuances. In cases in which swaps designated as cash flow hedges are used to synthetically convert variable rate debt to fixed rate debt, periodic payments to or receipts from swap counterparties related to these derivatives are recorded within interest expense.

Forward starting swap agreements that are designated as cash flow hedges may be used in anticipation of the issuance of debt. Except as described in the following paragraph, the effective portions of changes in fair value and payments made or received upon termination of such agreements for regulated subsidiaries are recorded in regulatory assets or regulatory liabilities. For SCANA and its nonregulated subsidiaries, such amounts are recorded in AOCI. Such amounts are amortized to interest expense over the term of the underlying debt. Ineffective portions of fair value changes are recognized in income.

collateral requirements.

Pursuant to regulatory orders, interest rate derivatives entered into by ~~SCE&G~~DESC after October 2013 have not been designated for accounting purposes as cash flow hedges, and fair value changes and settlement amounts related to them have been recorded as regulatory assets and liabilities. Settlement losses on swaps generally have been amortized over the lives of subsequent debt issuances, and gains have been amortized to interest expense or have been applied as otherwise directed by the ~~SCPSC.~~South Carolina Commission. See Note ~~2 and Note 12~~15 regarding the settlement ~~gain~~gains realized in the first quarter of 2018.

~~Cash payments made or received upon termination~~

The table below presents derivative balances by type of ~~these~~ financial ~~instruments are classified as investing activities for cash flow statement purposes.~~

~~Quantitative Disclosures Related to Derivatives~~

~~The Company was party to natural gas derivative contracts outstanding~~instrument, if the gross amounts recognized in the ~~following quantities:~~

Commodity and Other Energy Management Contracts (in MMBTU)
Hedge designation Gas Distribution Gas Marketing Total
As of June 30, 2018

Commodity contracts 6,090,000
14,412,000
20,502,000
Energy management contracts (a)
—
41,876,028
41,876,028
Total (a)
6,090,000
56,288,028
62,378,028

As of December 31, 2017

Commodity contracts 6,430,000
13,433,000
19,863,000
Energy management contracts (a)
—
41,856,890
41,856,890
Total (a)
6,430,000
55,289,890
61,719,890

~~(a)~~ ~~Includes amounts related to basis swap contracts totaling 11,864,000 MMBTU in 2018~~Consolidated Balance Sheets were netted with derivative instruments and ~~2,582,000 MMBTU in 2017.~~cash collateral received or paid:

	June 30, 2019								December 31, 2018
	Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet
(millions)	Gross Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Gross Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
Interest rate contracts:
Over-the-counter	$	19	$	—	$	19	$	—	$	11	$	—	$	11	$	—
Total derivatives	$	19	$	—	$	19	$	—	$	11	$	—	$	11	$	—

~~The aggregate notional amounts of the interest rate swaps were as follows:~~

Interest Rate Swaps
The Company Consolidated SCE&G
Millions of dollars June 30, 2018 December 31, 2017 June 30, 2018 December 31, 2017
Designated as hedging instruments $ 106.8
$ 111.2
$ 36.4
$ 36.4
Not designated as hedging instruments 35.0
735.0
35.0
735.0

Volumes

The following table ~~shows~~presents the ~~fair value and balance sheet location~~volume of derivative ~~instruments. Although derivatives subject to master netting arrangements~~activity at June 30, 2019. These volumes are ~~netted~~based on open derivative positions and represent the ~~consolidated balance sheet,~~combined absolute value of their long and short positions.

		Current				Noncurrent
Interest rate⁽¹⁾		$	—			$	71,400,000

(1)	Maturity is determined based on final settlement period.

Fair Value and Gains and Losses on Derivative Instruments

The following tables present the fair values of derivatives and where they are presented ~~below are shown gross,~~in the Consolidated Balance Sheets:

(millions)	Fair Value - Derivatives under Hedge Accounting		Fair Value - Derivatives not under Hedge Accounting		Total Fair Value
At June 30, 2019
Current Liabilities
Interest rate	$	1	$	1	$	2
Total current derivative liabilities⁽¹⁾		1		1		2
Noncurrent Liabilities
Interest rate		11		6		17
Total noncurrent derivative liabilities⁽²⁾		11		6		17
Total derivative liabilities	$	12	$	7	$	19
At December 31, 2018
Current Liabilities
Interest rate	$	1	$	—	$	1
Total current derivative liabilities⁽¹⁾		1		—		1
Noncurrent Liabilities
Interest rate		7		3		10
Total noncurrent derivative liabilities⁽²⁾		7		3		10
Total derivative liabilities	$	8	$	3	$	11

(1)	Current derivative liabilities are presented in other current liabilities in the Consolidated Balance Sheets.

(2)	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in the Consolidated Balance Sheets.

The following tables present the gains and ~~cash collateral~~losses on derivatives, as well as where the ~~derivatives has not been netted against the fair values shown.~~

associated activity is presented in its Consolidated Balance Sheets and Statements of Comprehensive Income (Loss):

Fair Values of Derivative Instruments
The Company Consolidated SCE&G
Millions of dollars Balance Sheet Location Asset Liability Asset Liability
As of June 30, 2018

Designated as hedging instruments

Interest rate contracts Derivative financial instruments —
$ 3
—
$ 1
Other deferred credits and other liabilities —
17
—
6

Commodity contracts Prepayments $ 1
—
—
—
Total $ 1
$ 20
—
$ 7

Not designated as hedging instruments

Interest rate contracts Other deferred credits and other liabilities —
$ 3
—
$ 3

Commodity contracts Prepayments $ 1
—
—
—

Energy management contracts Other current assets 1
—
—
—
Other deferred debits and other assets 1
—
—
—
Other current liabilities —
1
—
—
Derivative financial instruments —
1
—
—
Total $ 3
$ 5
—
$ 3

As of December 31, 2017
Designated as hedging instruments
Interest rate contracts Derivative financial instruments —
$ 3
—
$ 1
Other deferred credits and other liabilities —
24
—
9

Commodity contracts Prepayments —
2
—
—
Other current assets —
1
—
—
Total —
$ 30
—
$ 10

Not designated as hedging instruments
Interest rate contracts Derivative financial instruments $ 54
$ 1
$ 54
$ 1
Other deferred credits and other liabilities —
4
—
4

Commodity contracts Other current assets 1
—
—
—

Energy management contracts Prepayments —
1
—
—
Other current assets 3
—
—
—
Other deferred debits and other assets 1
—
—
—
Derivative financial instruments —
2
—
—
Total $ 59
$ 8
$ 54
$ 5

~~The effect of derivative instruments on the consolidated statements of income is as follows:~~

Derivatives in Cash Flow Hedging Relationships

(millions)	Gain (loss) Reclassified from Deferred Accounts into Income			Increase (Decrease) in Derivatives Subject to Regulatory Treatment⁽¹⁾
Three Months Ended June 30, 2019
Derivative type and location of gains (losses):
Interest rate⁽²⁾	$	—		$	—
Total	$	—		$	—
Three Months Ended June 30, 2018
Derivative type and location of gains (losses):
Interest rate⁽²⁾	$	(1	)	$	—
Total	$	(1	)	$	—
Six Months Ended June 30, 2019
Derivative type and location of gains (losses):
Interest rate⁽²⁾	$	—		$	(2	)
Total	$	—		$	(2	)
Six Months Ended June 30, 2018
Derivative type and location of gains (losses):
Interest rate⁽²⁾	$	(1	)	$	2
Total	$	(1	)	$	2

(1)	Represents net derivative activity deferred into and amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/ liabilities have no associated effect in the Consolidated Statements of Comprehensive Income (Loss).

(2)	Amounts recorded in DESC’s Consolidated Statements of Comprehensive Income (Loss) are classified in interest charges.

Derivatives Not designated as Hedging Instruments

(millions)	Increase (Decrease) in Derivatives Subject to Regulatory Treatment⁽¹⁾						Amount of Gain (Loss) Recognized in Income on Derivatives⁽²⁾
Three Months Ended June 30,	2019			2018		Location	2019		2018
Derivative type and location of gains (losses):
Interest rate contracts:						Interest charges	$	—	$	(1	)
						Other income		—		—
Total interest rate contracts	$	(2	)	$	—		$	—	$	(1	)
Six Months Ended June 30,
Derivative type and location of gains (losses):
Interest rate contracts:						Interest charges	$	—	$	(1	)
						Other income		—		115
Total interest rate contracts	$	(3	)	$	65		$	—	$	114

(1)	Represents net derivative activity deferred into and amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in the Consolidated Statements of Comprehensive Income (Loss).

The Company and Consolidated SCE&G:
Gain (Loss) Deferred in Regulatory Accounts Gain (Loss) Reclassified from Deferred Accounts into Income

Millions of dollars 2018
2017
Location 2018
2017
Three Months Ended June 30,
Interest rate contracts —
$ (1 ) Interest expense $ (1 ) —
Six Months Ended June 30,
Interest rate contracts $ 2
$ (1 ) Interest expense $ (1 ) $ (1 )

The Company:
Gain (Loss) Recognized in OCI, net of tax Gain (Loss) Reclassified from AOCI into Income, net of tax

Millions of dollars 2018
2017
Location 2018
2017
Three Months Ended June 30,
Interest rate contracts —
$ (1 ) Interest expense $ (2 ) $ (2 )
Commodity contracts $ 1
(2 ) Gas purchased for resale —
—
Total $ 1
$ (3 ) $ (2 ) $ (2 )

Six Months Ended June 30,
Interest rate contracts $ 2
$ (1 ) Interest expense $ (4 ) $ (4 )
Commodity contracts 2
(4 ) Gas purchased for resale (2 ) 2
Total $ 4
$ (5 ) $ (6 ) $ (2 )

(2)	Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in the Consolidated Statements of Comprehensive Income (Loss).

As of June 30, 2018, the Company expects that during the next 12 months reclassifications from AOCI to earnings arising from cash flow hedges will include approximately $8.6 million as an increase to interest expense. Reclassifications related to commodity and energy management contracts are not expected to be significant. As of June 30, 2018, all of the Company’s commodity cash flow hedges settle by their terms before the end of the second quarter of 2021.

As of June 30, 2018, each of the Company and Consolidated SCE&G expects that during the next 12 months reclassifications from regulatory accounts to earnings arising from cash flow hedges designated as hedging instruments will include approximately $1.1 million as an increase to interest expense.

~~Hedge Ineffectiveness~~

~~For the Company and Consolidated SCE&G, ineffectiveness on interest rate hedges designated as cash flow hedges was insignificant during all periods presented.~~

Derivatives Not designated as Hedging Instruments

The Company and Consolidated SCE&G:
Gain (Loss) Deferred in Regulatory Accounts Gain (Loss) Reclassified from Deferred Accounts into Income
Millions of dollars 2018
2017
Location 2018
2017
Three Months Ended June 30,
Interest rate contracts —
$ (35 ) Interest Expense $ (1 ) —
Other Income —
—

Six Months Ended June 30,
Interest rate contracts $ 65
$ (24 ) Interest Expense $ (1 ) $ (1 )
Other Income 115
—

As of June 30, 2018, each of the Company and Consolidated SCE&G expects that during the next 12 months reclassifications from regulatory accounts to earnings arising from derivatives not designated as hedges will include $2.7 million as an increase to interest expense.

Credit Risk Considerations

Certain derivative contracts contain contingent credit features. These features may include (i) material adverse change clauses or payment acceleration clauses that could result in immediate payments or (ii) the posting of letters of credit or termination of the derivative contract before maturity if specific events occur, such as a credit rating downgrade below investment grade or failure to post collateral.

Derivative Contracts with Credit Contingent Features

(millions)	June 30, 2019		December 31, 2018
in Net Liability Position
Aggregate fair value of derivatives in net liability position	$	19	$	11
Fair value of collateral already posted		19		11
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	$	—	$	—

Derivative Contracts with Credit Contingent Features
The Company Consolidated SCE&G
Millions of dollars June 30, 2018 December 31, 2017 June 30, 2018 December 31, 2017
in Net Liability Position

Aggregate fair value of derivatives in net liability position $ 24.1
$ 33.7
$ 10.3
$ 14.7
Fair value of collateral already posted 25.3
28.9
10.9
10.1
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered $ (1.2 ) $ 4.8
$ (0.6 ) $ 4.6

in Net Asset Position
Aggregate fair value of derivatives in net asset position —
$ 53.5
—
$ 53.5
Fair value of collateral already posted —
—
—
—
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered —
$ 53.5
—
$ 53.5

In addition, for fixed price supply contracts offered to certain of SCANA Energy's customers, the Company could have called on letters of credit in the amount of $0.5 million related to $2.8 million in commodity derivatives that are in a net asset position at June 30, 2018, compared to letters of credit in the amount of $1.2 million related to derivatives of $4.0 million at December 31, 2017, if all the contingent features underlying these instruments had been fully triggered.

~~Information related to the offsetting of derivative assets follows:~~

Derivative Assets The Company Consolidated SCE&G
Millions of dollars Interest Rate Contracts Commodity Contracts Energy Management Contracts Total Interest Rate Contracts
As of June 30, 2018

Gross Amounts of Recognized Assets —
$ 2
$ 2
$ 4
—
Gross Amounts Offset in Statement of Financial Position —
—
—
—
—
Net Amounts Presented in Statement of Financial Position —
2
2
4
—
Gross Amounts Not Offset - Financial Instruments —
—
—
—
—
Gross Amounts Not Offset - Cash Collateral Received —
—
—
—
—
Net Amount —
$ 2
$ 2
$ 4
—
Balance sheet location
     Prepayments $ 2
—
     Other current assets 1
—
     Other deferred debits and other assets 1
—
Total $ 4
—

As of December 31, 2017
Gross Amounts of Recognized Assets $ 54
$ 1
$ 4
$ 59
$ 54
Gross Amounts Offset in Statement of Financial Position —
—
—
—
—
Net Amounts Presented in Statement of Financial Position 54
1
4
59
54
Gross Amounts Not Offset - Financial Instruments —
—
—
—
—
Gross Amounts Not Offset - Cash Collateral Received —
—
—
—
—
Net Amount $ 54
$ 1
$ 4
$ 59
$ 54
Balance sheet location
     Other current assets $ 58
$ 54
     Other deferred debits and other assets 1
—
Total $ 59
$ 54

~~Information related to the offsetting of derivative liabilities follows:~~

Derivative Liabilities The Company Consolidated SCE&G
Millions of dollars Interest Rate Contracts Commodity Contracts Energy Management Contracts Total Interest Rate Contracts
As of June 30, 2018

Gross Amounts of Recognized Liabilities $ 23
—
$ 2
$ 25
$ 10
Gross Amounts Offset in Statement of Financial Position —
—
—
—
—
Net Amounts Presented in Statement of Financial Position 23
—
2
25
10
Gross Amounts Not Offset - Financial Instruments —
—
—
—
—
Gross Amounts Not Offset - Cash Collateral Posted (24 ) —
(1 ) (25 ) (11 )
Net Amount $ (1 ) —
$ 1
—
$ (1 )
Balance sheet location
     Derivative financial instruments $ 4
$ 1
     Other current liabilities 1
—
     Other deferred credits and other liabilities 20
9
Total $ 25
$ 10

As of December 31, 2017
Gross Amounts of Recognized Liabilities $ 32
$ 3
$ 3
$ 38
$ 15
Gross Amounts Offset in Statement of Financial Position —
—
(1 ) (1 ) —
Net Amounts Presented in Statement of Financial Position 32
3
2
37
15
Gross Amounts Not Offset - Financial Instruments —
—
—
—
—
Gross Amounts Not Offset - Cash Collateral Posted 28
—
(1 ) 27
—
Net Amount $ 60
$ 3
$ 1
$ 64
$ 15
Balance sheet location
     Other current assets $ 2
—
     Derivative financial instruments 7
$ 2
     Other deferred credits and other liabilities 28
13
Total $ 37
$ 15

8. FAIR VALUE MEASUREMENTS, INCLUDING DERIVATIVES

~~The Company and Consolidated SCE&G~~

Fair value ~~available for sale securities using quoted prices from a national stock exchange, such~~is defined as the ~~NASDAQ,~~price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. Fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. This includes not only the credit standing of counterparties involved and the impact of credit enhancements but also the impact of DESC’s own nonperformance risk on their liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability (the market with the most volume and activity for the asset or liability from the perspective of the reporting entity), or in the absence of a principal market, the most advantageous market for the asset or liability (the market in which the ~~securities are actively traded~~reporting entity would be able to maximize the amount received or ~~are open-ended mutual funds registered with~~minimize the ~~SEC and maintain a stable NAV and are invested in government money market agreements or fully collateralized repurchase agreements. For commodity derivative and energy management~~amount paid). DESC applies fair value measurements to interest rate assets and liabilities, the Company uses unadjusted NYMEX prices to determine fair value, and considers such measures of fair value to be Level 1 for exchange traded instruments and Level 2 for over-the-counter instruments. The Company’s and Consolidated SCE&G'sliabilities. DESC’s interest rate swap agreements are valued using discounted cash flow models with independently sourced data. DESC applies credit adjustments to its derivative fair values in accordance with the requirements described above.

Inputs and Assumptions

Fair value is based on actively-quoted market prices, if available. In the absence of actively-quoted market prices, price information is sought from external sources, including industry publications, and to a lesser extent, broker quotes. When evaluating pricing information, DESC considers the ability to transact at the quoted price. Periodically, inputs to valuation models are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third-party sources.

The inputs and assumptions used in measuring fair value for interest rate derivative contracts include the following:

•	Interest rate curves

•	Credit quality of counterparties and DESC

•	Notional value

•	Credit enhancements

•	Time value

Levels

DESC utilizes the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:

•	Level 1-Quoted prices (unadjusted) in active markets for identical assets and liabilities that they have the ability to access at the measurement date.

•

Level 2-Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include interest rate swaps.

•	Level 3-Unobservable inputs for the asset or liability, including situations where there is little, if any, market activity for the asset or liability.

The fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. In these cases, the lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability.

Recurring Fair Value Measurements

Fair value measurements ~~and the~~are separately disclosed by level within the fair value ~~hierarchy~~hierarchy.

All of DESC's interest rate swap agreements were in ~~which the measurements fall, were as follows:~~

As of June 30, 2018 As of December 31, 2017
The Company Consolidated SCE&G The Company Consolidated SCE&G
Millions of dollars Level 1 Level 2 Level 2 Level 1 Level 2 Level 1 Level 2
Assets:
Available for sale securities $ 15
—
—
$ 119
—
$ 100
—
Held to maturity securities —
$ 6
—
—
$ 6
—
—
Interest rate contracts —
—
—
—
54
—
$ 54
Commodity contracts 2
—
—
1
—
—
—
Energy management contracts —
2
—
—
4
—
—
Liabilities:
Interest rate contracts —
23
$ 10
—
32
—
15
Commodity contracts —
—
—
2
1
—
—
Energy management contracts —
4
—
1
4
—
—

~~The Company and Consolidated SCE&G had no Level 3 fair value measurements~~a liability position for ~~either period presented, and there were no transfers of fair value amounts into or out of Levels 1, 2 or 3 during either period~~all periods presented.

~~Financial instruments for which the carrying amount may not equal estimated fair value were as follows:~~

Long-Term Debt June 30, 2018 December 31, 2017
Millions of dollars
Carrying
Amount

Estimated
Fair Value

Carrying
Amount

Estimated
Fair Value
The Company $ 6,665.5
$ 6,925.0
$ 6,632.9
$ 7,399.7
Consolidated SCE&G 5,099.7
5,265.0
5,163.3
5,790.3

~~Fair values of long-term debt instruments~~ Such agreements are ~~based on net present value calculations~~valued using discounted cash flow models with independently sourced ~~market~~ data, ~~that incorporate a developed discount rate using similarly rated long-term debt, along with benchmark interest rates. As such, the aggregate fair values presented above~~and are considered to be Level ~~2. Early settlement of long-term debt may not be possible or may not be considered prudent.~~

~~Carrying values of short-term borrowings approximate~~2 fair value measurements. The fair value of these derivatives at June 30, 2019 was $19 million, and at December 31, 2018 was $11 million.

Fair Value of Financial Instruments

Substantially all of DESC’s financial instruments are ~~based on quoted prices from dealers~~recorded at fair value, with the exception of the instruments described below, which are reported at historical cost. Estimated fair values have been determined using available market information and valuation methodologies considered appropriate by management. The carrying amount of financial instruments classified within current assets and current liabilities are representative of fair value because of the short-term nature of these instruments. For financial instruments that are not recorded at fair value, the carrying amounts and estimated fair values are as follows:

June 30, 2019

December 31, 2018

(millions)

Carrying

Amount

Estimated

Fair Value⁽¹⁾

Carrying

Amount

Estimated

Fair Value⁽²⁾

Long-term debt⁽³⁾

4,171

4,982

5,146

5,470

(1)

Fair value is estimated using market prices, where available, and interest rates currently available for issuance of debt with similar terms and remaining maturities. All fair value measurements are classified as Level 2. The carrying amount of debt issuances with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value.

(2)

Fair value is estimated based on net present value calculations using independently sourced market data that incorporate a developed discount rate using similarly rated long-term debt, along with benchmark interest rates. All fair value measurements are classified as Level 2. The carrying amount of debt issuances with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value.

(3)	Carrying amount includes amounts which represent the unamortized debt issuance costs and discount or premium.

9. UTILITY PLANT AND NONUTILITY PROPERTY

Sale of Warranty Service Contract Assets

In May 2019, DESC entered into an agreement to sell certain warranty service contract assets for total consideration of $7 million. DESC expects the transaction to close in the ~~commercial paper market. The resulting fair value~~third quarter of 2019 and estimates the transaction to result in a $7 million ($5 million after-tax) gain. Pursuant to the agreement, upon closing DESC expects to enter into a commission agreement with the buyer under which the buyer will compensate DESC in connection with the right to use DESC’s brand in marketing materials and other services over a ten-year term.

Jointly Owned Utility Plant

DESC jointly owns and is ~~considered~~the operator of Summer. Each joint owner provides its own financing and shares the direct expenses and generation output in proportion to ~~be Level 2.~~

9.its ownership. DESC’s share of the direct expenses in Summer is 66.7%. In May 2019, DESC and Santee Cooper entered into an agreement in which DESC agreed to purchase 11.7% of Santee Cooper’s ownership interest in the NND Project nuclear fuel for $8 million to true up the ownership percentage from the 55% ownership percentage that was applicable for the NND Project to the 66.7% ownership percentage applicable for Summer.

10. EMPLOYEE BENEFIT PLANS

Components of net periodic benefit cost recorded by ~~the Company and Consolidated SCE&G~~DESC were as follows:

(millions)	Pension Benefits						Other Postretirement Benefits
Three Months Ended June 30,	2019			2018			2019		2018
Service cost	$	3		$	4		$	—	$	1
Interest cost		7			7			2		2
Expected return on assets		(10	)		(12	)		—		—
Amortization of actuarial losses		3			3			—		1
Curtailment⁽¹⁾		6			—			3		—
Net periodic benefit cost	$	9		$	2		$	5	$	4
Six Months Ended June 30,
Service cost	$	7		$	8		$	1	$	2
Interest cost		15			15			4		4
Expected return on assets		(20	)		(24	)		—		—
Amortization of actuarial losses		7			5			—		1
Curtailment⁽¹⁾		6			—			3		—
Net periodic benefit cost	$	15		$	4		$	8	$	7

The Company Pension Benefits Other Postretirement Benefits
Millions of dollars 2018 2017 2018 2017
Three months ended June 30,

Service cost $ 4.9
$ 5.3
$ 1.1
$ 1.2
Interest cost 8.6
9.4
2.7
2.9
Expected return on assets (14.3 ) (13.8 ) —
—
Prior service cost amortization 0.2
0.4
—
—
Amortization of actuarial losses 2.9
3.9
0.6
0.4
Net periodic benefit cost $ 2.3
$ 5.2
$ 4.4
$ 4.5

Six months ended June 30,

Service cost $ 9.9
$ 10.5
$ 2.3
$ 2.3
Interest cost 17.1
18.9
5.4
5.9
Expected return on assets (28.6 ) (27.6 ) —
—
Prior service cost amortization 0.3
0.8
—
—
Amortization of actuarial losses 5.9
7.9
1.1
0.7
Net periodic benefit cost $ 4.6
$ 10.5
$ 8.8
$ 8.9

Consolidated SCE&G Pension Benefits Other Postretirement Benefits
Millions of dollars 2018 2017 2018 2017
Three months ended June 30,
Service cost $ 4.0
$ 4.4
$ 0.8
$ 1.0
Interest cost 7.2
8.1
2.2
2.4
Expected return on assets (12.1 ) (11.8 ) —
—
Prior service cost amortization 0.1
0.3
—
—
Amortization of actuarial losses 2.5
3.4
0.5
0.3
Net periodic benefit cost $ 1.7
$ 4.4
$ 3.5
$ 3.7

Six months ended June 30,
Service cost $ 8.1
$ 8.8
$ 1.8
$ 1.9
Interest cost 14.4
16.1
4.3
4.8
Expected return on assets (24.2 ) (23.6 ) —
—
Prior service cost amortization 0.2
0.7
—
—
Amortization of actuarial losses 5.0
6.7
0.9
0.6
Net periodic benefit cost $ 3.5
$ 8.7
$ 7.0
$ 7.3

(1) Related to a voluntary retirement program.

No significant contribution to the pension trust is expected for the ~~foreseeable future~~remainder of 2019 based on current market conditions and assumptions, nor is a limitation on benefit payments expected to apply. ~~SCE&G~~DESC recovers current pension costs through either a rate rider that may be adjusted annually for retail electric operations or through cost of service rates for gas operations. ~~PSNC~~

Voluntary Retirement Program

In March 2019, Dominion Energy ~~recovers~~announced a voluntary retirement program to employees, including employees of DESC, that meet certain age and service requirements. The voluntary retirement program will not compromise safety or DESC’s ability to comply with applicable laws and regulations. In the second quarter of 2019, upon the determinations made concerning the number of employees that elected to participate in the program, DESC recorded a charge of $62 million ($47 million after-tax), of which $50 million was included within other operations and maintenance expense, $3 million within other taxes and $9 million within other income (expense), net.

In the second quarter of 2019, DESC remeasured its pension ~~costs through~~and other postretirement benefit plans as a result of the voluntary retirement program. The remeasurement resulted in an increase in the pension benefit obligation of $16 million and an increase in the accumulated postretirement benefit obligation of $10 million. In addition, the remeasurement resulted in an increase in the fair value of pension plan assets of $27 million. The impact of the remeasurement on net periodic benefit cost was recognized prospectively from the remeasurement date. The remeasurement is expected to increase the net periodic benefit cost for 2019 by approximately $1 million, excluding the impacts of ~~service rates.~~

curtailments. The discount rate used for the remeasurement was 4.07% for the pension plan and 4.08% for the other postretirement benefit plan. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2018.

~~10.~~

11. COMMITMENTS AND CONTINGENCIES

~~Abandoned Nuclear Project~~

~~SCE&G,~~

As a result of issues generated in the ordinary course of business, DESC is involved in legal proceedings before various courts and is periodically subject to governmental examinations (including by regulatory authorities), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions, or involve significant factual issues that need to be resolved, such that it is not possible for DESC to estimate a range of possible loss. For such matters that DESC cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that DESC is able to estimate a range of possible loss. For legal proceedings and governmental examinations that DESC is able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any accrued liability is recorded on ~~behalf~~a gross basis with a receivable also recorded for any probable insurance recoveries. Estimated ranges of ~~itself~~loss are inclusive of legal fees and ~~as agent~~net of any anticipated insurance recoveries. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent DESC’s maximum possible loss exposure. The circumstances of such legal proceedings and governmental examinations will change from time to time and actual results may vary significantly from the current estimate. For current proceedings not specifically reported below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on DESC’s financial position, liquidity or results of operations.

Environmental

In July 2019, the EPA published the ACE Rule, which repeals and replaces the Clean Power Plan. The ACE Rule only applies to coal-fired steam electric generating units greater than or equal to 25 MW. The rule includes unit-specific performance standards based on the degree of emission reduction levels achievable from unit efficiency improvements to be determined by the permitting agency. The ACE Rule requires states to develop plans by July 2022 to implement these performance standards, which plans must be approved by the EPA. DESC is currently evaluating the ACE Rule for ~~Santee Cooper, entered~~potential impact at its coal fired units and expects any costs incurred to comply with such rule to be recoverable through rates. While the impacts of this rule could be material to DESC’s results of operations, financial condition and/or cash flows, the existing regulatory framework in South Carolina provides rate recovery mechanisms that could substantially mitigate any such impacts.

In July 2011, the EPA issued the CSAPR to reduce emissions of SO₂and NO_X from power plants in the eastern half of the U.S. The CSAPR replaces the Clean Air Interstate Rule and requires a total of 28 states to reduce annual SO₂ emissions and annual ozone season NO_X emissions to assist in attaining the ozone and fine particle National Ambient Air Quality Standards. The rule establishes an emissions cap for SO₂and NO_X and limits the trading for emission allowances by separating affected states into two groups with no trading between the ~~EPC Contract~~groups. The State of South Carolina has chosen to remain in the CSAPR program, even though recent court rulings exempted the state. This allows the state to remain compliant with regional haze standards. Air quality control installations that DESC has already completed have positioned them to comply with the ~~Consortium~~existing allowances set by the CSAPR. Any costs incurred to comply with CSAPR are expected to be recoverable through rates.

In February 2019, the EPA published a proposed rule to reverse its previous finding that it is appropriate and necessary to regulate toxic emissions from power plants. However, the emissions standards and other requirements of the MATS rule would remain in ~~2008~~place as the EPA is not proposing to remove coal and oil fired power plants from the list of sources that are regulated under MATS. Although litigation of the MATS rule and the outcome of the EPA’s rulemaking are still pending, the regulation remains in effect and DESC is complying with the applicable requirements of the rule and does not expect any adverse impacts to its operations at this time due to plant retirements, conversions and enhancements.

The CWA provides for the imposition of effluent limitations that require treatment for wastewater discharges. Under the CWA, compliance with applicable limitations is achieved under state-issued NPDES permits such that, as a facility’s NPDES permit is renewed, any new effluent limitations would be incorporated. The ELG Rule was final in September 2015, after which state regulators are required to modify facility NPDES permits to match more restrictive standards, which would require facilities to retrofit with new wastewater treatment technologies. Compliance dates varied by type of wastewater, and some were based on a facility's five-year permit cycle and thus could range from 2018 to 2023. However, the ELG Rule is under reconsideration by the EPA and has been stayed administratively. The EPA has decided to conduct a new rulemaking that could result in revisions to certain flue gas desulfurization wastewater and bottom ash transport water requirements in the ELG Rule. Accordingly, in September 2017 the EPA finalized a rule that postpones compliance dates under the ELG Rule to a range from November 2020 to December 2023. The EPA indicates that the new rulemaking process may take up to three years to complete, such that any revisions to the ELG Rule likely would not be final until the summer of 2020. While DESC expects that wastewater treatment technology retrofits will be required at Williams and Wateree generating stations, any costs incurred to comply with the ELG Rule are expected to be recoverable through rates.

The CWA Section 316(b) Existing Facilities Rule became effective in October 2014. This rule establishes national requirements for the location, design, construction and ~~construction~~capacity of ~~Unit 2~~cooling water intake structures at existing facilities that reflect the best technology

available for minimizing the adverse environmental impacts of impingement and ~~Unit 3. Various difficulties were encountered which affected~~entrainment. DESC is conducting studies and implementing plans as required by the ~~ability~~rule to determine appropriate intake structure modifications at certain facilities to ensure compliance with this rule. Any costs incurred to comply with this rule are expected to be recoverable through rates.

The EPA's final rule for CCR became effective in the fourth quarter of 2015. This rule regulates CCR as a non-hazardous waste under Subtitle D of the ~~Consortium~~Resource Conservation and Recovery Act and imposes certain requirements on ash storage ponds and other CCR management facilities at certain of DESC's coal-fired generating facilities. DESC has already closed or has begun the process of closure of all of its ash storage ponds and has previously recognized AROs for such ash storage ponds under existing requirements. DESC does not expect the incremental compliance costs associated with this rule to ~~adhere~~be significant and expect to ~~established budgets~~recover such costs in future rates.

DESC is responsible for four decommissioned MGP sites in South Carolina which contain residues of by-product chemicals. These sites are in various stages of investigation, remediation and ~~construction schedules~~monitoring under work plans approved by or under review by SCDHEC and the EPA. DESC anticipates that major remediation activities at all of these sites will continue at least through 2022 and will cost an additional $10 million. In February 2019, SCDHEC directed DESC to pursue a stakeholder-developed modified removal action plan for one site (Congaree River). DESC is developing an engineering design for this plan, which would require permits from the U.S. Army Corps of Engineers and others and further approvals before it could be implemented. If DESC receives the necessary permits and approvals for this plan, remediation cost for the ~~Nuclear~~Congaree River site would increase by $8 million. DESC cannot predict if or when such permits or approvals will be received. Major remediation activities are accrued in other within deferred credits and other liabilities on the Consolidated Balance Sheets. DESC expects to recover any cost arising from the remediation of MGP sites through rates. At June 30, 2019, deferred amounts, net of amounts previously recovered through rates and insurance settlements, totaled $23 million and are included in regulatory assets.

Abandoned NND Project

A description of events and circumstances leading up to DESC's abandonment of the NND Project and ~~which, in light~~subsequent regulatory, legislative, legal and investigative proceedings, as well as related impairments of ~~Santee Cooper's decision to suspend construction of the Nuclear~~NND Project ~~led to the Company's decision on July 31, 2017 to stop the construction and seek recovery under the abandonment provisions of the BLRA. These difficulties~~ and other ~~developments occurring prior to the bankruptcy filing by WEC and WECTEC and other matters~~costs are described in Note ~~10 to the consolidated financial statements included~~11 in ~~the Company's and Consolidated SCE&G's combined~~DESC's Annual Report on Form 10-K for the year ended December

31, ~~2017. Significant developments and continuing contingencies regarding the abandoned Nuclear Project subsequent to December 31, 2017 are discussed below.~~

~~EPC Contract and BLRA Matters~~

~~Contractor Bankruptcy Proceedings and Related Uncertainties~~

On March 29, 2017, WEC and WECTEC, the two members of the Consortium, and certain of their affiliates filed petitions for protection under Chapter 11 of the U.S. Bankruptcy Code, citing a liquidity crisis arising from project contract losses attributable to the Nuclear Project and similar units being built for an unaffiliated company as a material factor that caused WEC and WECTEC to seek protection under the bankruptcy laws. As part of such filing, WEC and WECTEC publicly announced their inability to complete Unit 2 and Unit 3 under2018.

SCANA Merger Approval Order

In accordance with the terms of the ~~EPC Contract.~~South Carolina Commission's SCANA Merger Approval Order, DESC adopted the Plan-B Levelized Customer Benefits Plan, effective February 2019, whereby the average bill for a DESC residential electric customer approximates that which resulted from the legislatively-mandated temporary reduction that had been put into effect by the South Carolina Commission in August 2018. DESC also recorded a significant impairment charge in the fourth quarter of 2018, which charge resulted from its conclusion that NND Project capital costs exceeding the amount established in the SCANA Merger Approval Order were probable of loss, regardless of whether the SCANA Combination was completed. In addition, in the first quarter of 2019, DESC recorded the following charges and liabilities which arose from or are related to provisions in the SCANA Merger Approval Order.

•	A charge of $105 million ($79 million net of tax) related to certain assets that had been constructed in connection with the NND Project for which DESC committed to forgo recovery.

•

A regulatory liability for refunds and restitution of amounts previously collected from retail electric customers of $1.0 billion pre-tax ($756 million net of tax), recorded as a reduction in operating revenue, which will be credited to customers over an estimated 11 years. In addition, a previously existing regulatory liability of $1.0 billion will be credited to customers over 20 years. These refunds include amounts to be refunded to customers related to the monetization of guaranty settlement described in Note 2.

•	A regulatory liability for refunds to natural gas customers totaling $2 million pre-tax ($2 million net of tax).

•	A tax charge of $198 million related to $264 million of regulatory assets for which DESC committed to forgo recovery.

Further, except for rate adjustments for fuel and environmental costs, DSM costs, and other rates routinely adjusted on an annual or biannual basis, DESC will freeze retail electric base rates at current levels until January 1, 2021.

The South Carolina Commission order also approved the removal of DESC's investment in certain transmission assets that have not been abandoned from BLRA capital costs. As of June 30, 2019, such investment in these assets included $323 million within utility plant, net and $27 million within regulatory assets, which amount represents certain deferred operating costs. The South Carolina Commission approved deferral of these operating costs related to the investment until recovery of the transmission capital costs and associated deferred operating costs is addressed in a future rate proceeding. DESC believes these transmission capital and deferred operating costs are probable of recovery; however, if the South Carolina Commission were to disallow recovery of or a reasonable return on all or a portion of them, an impairment charge equal to the disallowed costs may be required.

Various parties filed petitions for rehearing or reconsideration of the SCANA Merger Approval Order. In January 2019, the South Carolina Commission issued an order (1) granting the request of various parties and finding that DESC was imprudent in its actions by not disclosing material information to the ORS and the South Carolina Commission with regard to costs incurred subsequent to March 2015 and (2) denying the petitions for rehearing or consideration as to other issues raised in the various petitions. The deadline to appeal the SCANA Merger Approval Order and the order on rehearing expired in April 2019, and no party has sought appeal.

Claims and Litigation

The following describes certain legal proceedings involving DESC relating to events occurring before closing of the SCANA Combination. Dominion Energy intends to vigorously contest the lawsuits, claims and assessments which have been filed or initiated against DESC. No reference to, or disclosure of, any proceeding, item or matter described below shall be construed as an admission or indication that such proceeding, item or matter is material. For certain of these matters, and unless otherwise noted therein, DESC is unable to estimate a reasonable range of possible loss and the related financial statement impacts, but for any such matter there could be a material impact to its results of operations, financial condition and/or cash flows. For the matters for which DESC is able to reasonably estimate a probable loss, the Consolidated Balance Sheets include reserves of $278 million included within reserves for litigation and regulatory proceedings at June 30, 2019. During the three and six months ended June 30, 2019 the Consolidated Statements of Comprehensive Income (Loss) includes charges of $100 million ($75 million after-tax) and $266 million ($200 million after-tax), respectively, included within impairment of assets and other charges.

Ratepayer Class Actions

In May 2018, a consolidated complaint against DESC, SCANA and the State of South Carolina was filed in the State Court of Common Pleas in Hampton County, South Carolina (the DESC Ratepayer Case). In September 1,2018, the court certified this case as a class action. The plaintiffs allege, among other things, that DESC was negligent and unjustly enriched, breached alleged fiduciary and contractual duties and committed fraud and misrepresentation in failing to properly manage the NND Project, and that DESC committed unfair trade practices and violated state anti-trust laws. The plaintiffs sought a declaratory judgment that DESC may not charge its customers for any past or continuing costs of the NND Project, sought to have SCANA and DESC’s assets frozen and all monies recovered from Toshiba and other sources be placed in a constructive trust for the benefit of ratepayers and sought specific performance of the alleged implied contract to construct the NND Project.

In December 2018, the State Court of Common Pleas in Hampton County entered an order granting preliminary approval of a class action settlement and a stay of pre-trial proceedings in the DESC Ratepayer Case. The settlement agreement, contingent upon the closing of the SCANA Combination, provided that SCANA and DESC would establish an escrow account and proceeds from the escrow account would be distributed to the class members, after payment of certain taxes, attorneys' fees and other expenses and administrative costs. The escrow account would include (1) up to $2.0 billion, net of a credit of up to $2.0 billion in future electric bill relief, which would inure to the benefit of the escrow account in favor of class members over a period of time established by the South Carolina Commission in its order related to matters before the South Carolina Commission related to the NND Project, (2) a cash payment of $115 million and (3) the transfer of certain DESC-owned real estate or sales proceeds from the sale of such properties, which counsel for the DESC Ratepayer Class estimate to have an aggregate value between $60 million and $85 million. At the closing of the SCANA Combination, SCANA and DESC funded the cash payment portion of the escrow account. The court held a fairness hearing on the settlement in May 2019. In June 2019, the court entered an order granting final approval of the settlement, which order became effective July 2019. In July 2019, DESC transferred $117 million representing the cash payment, plus accrued interest, to the plaintiffs. In addition, property with a net recorded value of $42 million will be transferred to the plaintiffs as soon as practicable to satisfy the settlement agreement.

In September 2017, ~~SCE&G,~~a purported class action was filed by Santee Cooper ratepayers against Santee Cooper, DESC, Palmetto Electric Cooperative, Inc. and Central Electric Power Cooperative, Inc. in the State Court of Common Pleas in Hampton County, South Carolina (the Santee Cooper Ratepayer Case). The allegations are substantially similar to those in the DESC Ratepayer Case. The plaintiffs seek a declaratory judgment that the defendants may not charge the purported class for ~~itself~~reimbursement for past or future costs of the NND Project. In March 2018, the plaintiffs filed an amended complaint including as additional named defendants certain then current and ~~as agent for~~former directors of Santee Cooper and SCANA. In June 2018, Santee Cooper filed a Notice of Petition for Original Jurisdiction with the ~~Bankruptcy~~Supreme Court ~~Proofs~~ of ~~Claim~~South Carolina which was denied. In December 2018, Santee Cooper filed its answer to the plaintiffs' fourth amended complaint and filed cross claims against DESC. This case is pending.

In July 2019, a similar purported class action was filed by certain Santee Cooper ratepayers against DESC, SCANA, Dominion Energy and former directors and officers of SCANA in the State Court of Common Pleas in Orangeburg, South Carolina. The claims are similar to the Santee Cooper Ratepayer Case. This case is pending.

RICO Class Action

In January 2018, a purported class action was filed, and subsequently amended, against SCANA, DESC and certain former executive officers in the U.S. District Court for ~~unliquidated damages~~the District of South Carolina. The plaintiff alleges, among other things, that SCANA, DESC and

the individual defendants participated in an unlawful racketeering enterprise in violation of RICO and conspired to violate RICO by fraudulently inflating utility bills to generate unlawful proceeds. The DESC Ratepayer Class Action settlement described previously contemplates dismissal of claims by DESC ratepayers in this case against ~~each~~DESC, SCANA and their officers. This case is pending.

SCANA Shareholder Litigation

In February 2018, a purported class action was filed against Dominion Energy and certain former directors of ~~WEC~~SCANA and ~~WECTEC. These Proofs~~DESC in the State Court of ~~Claim are based upon the anticipatory repudiation and material breach~~Common Pleas in Richland County, South Carolina (the Metzler Lawsuit). The plaintiff alleges, among other things, that defendants violated their fiduciary duties to shareholders by ~~the Consortium~~executing a merger agreement that would unfairly deprive plaintiffs of the ~~EPC Contract,~~true value of their SCANA stock, and ~~assert against WEC~~that Dominion Energy aided and ~~WECTEC any~~abetted these actions. Among other remedies, the plaintiff seeks to enjoin and/or rescind the merger. In February 2018, Dominion Energy removed the case to the U.S. District Court for the District of South Carolina and ~~all claims that are based thereon or that may be related thereto. These claims~~filed a Motion to Dismiss in March 2018. In August 2018, the case was remanded back to the State Court of Common Pleas in Richland County. Dominion Energy appealed the decision to remand to the U.S. Court of Appeals for the Fourth Circuit, where the appeal was consolidated with another lawsuit regarding the SCANA Merger Agreement to which DESC is not a party. In June 2019, the U.S. Court of Appeals for the Fourth Circuit reversed the order remanding the case to state court. The case is pending in the U.S. District Court for the District of South Carolina.

Employment Class Actions and Indemnification

In August 2017, a case was filed in the U.S. District Court for the District of South Carolina on behalf of persons who were ~~sold to Citibank on September 27, 2017~~formerly employed at the NND Project. In July 2018, the court certified this case as a class action. In February 2019, certain plantiffs who were not certified as part of the class action filed a ~~monetization transaction discussed below. Notwithstanding~~separate case. In those cases, the ~~sale~~plaintiffs allege, among other things, that SCANA, Fluor Corporation and Fluor Enterprises, Inc. violated the Worker Adjustment and Retraining Notification Act in connection with the decision to stop construction at the NND Project. The plaintiffs allege that the defendants failed to provide adequate advance written notice of their terminations of employment and are seeking damages, which are estimated to be as much as $75 million for 100% of the ~~claims, SCE&G~~NND Project.

In September 2018, a case was filed in the State Court of Common Pleas in Fairfield County, South Carolina by Fluor Enterprises, Inc. and Fluor Daniel Maintenance Services, Inc. against DESC and Santee ~~Cooper remain responsible~~Cooper. The plaintiffs make claims for ~~any claims that may be made by WEC~~indemnification, breach of contract and ~~WECTEC~~promissory estoppel arising from, among other things, the defendants' alleged failure and refusal to defend and indemnify the Fluor defendants in the aforementioned case. These cases are pending.

FILOT Litigation and Related Matters

In November 2017, Fairfield County filed a complaint and a motion for temporary injunction against ~~them relating~~DESC in the State Court of Common Pleas in Fairfield County, South Carolina, making allegations of breach of contract, fraud, negligent misrepresentation, breach of fiduciary duty, breach of implied duty of good faith and fair dealing and unfair trade practices related to DESC’s termination of the FILOT agreement between DESC and Fairfield County related to the ~~EPC Contract.~~

~~WEC’s Reorganization Plan~~NND Project. The plaintiff sought a temporary and permanent injunction to prevent DESC from terminating the FILOT agreement. The plaintiff withdrew the motion for temporary injunction in December 2017. This case is pending.

Governmental Proceedings and Investigations

In June 2018, DESC received a notice of proposed assessment of approximately $410 million, excluding interest, from the SCDOR following its audit of DESC’s sales and use tax returns for the periods September 1, 2008 through December 31, 2017. The proposed assessment, which includes 100% of the NND Project, is based on the SCDOR’s position that DESC’s sales and use tax exemption for the NND Project does not apply because the facility will not become operational. DESC has protested the proposed assessment, which remains pending.

In September and October 2017, SCANA was ~~confirmed~~served with subpoenas issued by the U.S. Attorney’s Office for the District of South Carolina and the Staff of the SEC’s Division of Enforcement seeking documents related to the NND Project. In addition, the South Carolina Law Enforcement Division is conducting a criminal investigation into the handling of the NND Project by SCANA and DESC. These matters are pending. SCANA and DESC are cooperating fully with the investigations, including responding to additional subpoenas and document requests.

Other Litigation

In December 2018, arbitration proceedings commenced between DESC and Cameco Corporation related to a supply agreement signed in May 2008. This agreement provides the terms and conditions under which DESC agreed to purchase uranium hexafluoride from Cameco Corporation over a period from 2010 to 2020. Cameco Corporation alleges that DESC violated this agreement by failing to

purchase the stated quantities of uranium hexafluoride for the 2017 and 2018 delivery years. DESC denies that it is in breach of the agreement and believes that it has reduced its purchase quantity within the terms of the agreement. This matter is pending.

Contractor Bankruptcy ~~Court on March 28, 2018, and~~Proceedings

Westinghouse’s reorganization plan became effective August 1, 2018. ~~In connection with the effectiveness of the Reorganization Plan, the EPC Contract was deemed rejected.~~ Initially, ~~WEC~~Westinghouse had projected that its ~~Reorganization Plan~~reorganization plan would pay in full or nearly in full its pre-petition trade creditors, including several of the ~~WEC~~Westinghouse Subcontractors which have alleged non-payment by the Consortium for amounts owed for work performed on the ~~Nuclear~~NND Project and have filed liens on related property in Fairfield County, South ~~Carolina, where Unit 2 and Unit 3 were to be located (Unit 2/3 Property). SCE&G~~Carolina. DESC is contesting approximately ~~$290~~$285 million of such filed ~~liens in Fairfield County.~~liens. Most of these asserted liens are “pre-petition” claims that relate to work performed by ~~WEC~~Westinghouse Subcontractors before the ~~WEC~~Westinghouse bankruptcy, although some of them are “post-petition” claims arising from work performed after the ~~WEC~~Westinghouse bankruptcy.

WEC has now indicated that some unsecured creditors have sought or may seek amounts beyond what WEC allocated when it submitted the Reorganization Plan. If any unsecured creditor is successful in its attempt to include its claim as part of the class of general unsecured creditors beyond the amounts in the Reorganization Plan allocated by WEC, it It is possible that the ~~Reorganization Plan~~reorganization plan will not provide for payment in full or nearly in full to its pre-petition trade creditors. The shortfall could be significant. ~~See also discussion below regarding limitations with respect to SCE&G’s pre-petition lien obligations arising from its monetization of~~In addition, payments under the Toshiba ~~Settlement.~~

~~SCE&G~~Settlement are subject to reduction if Westinghouse pays Westinghouse Subcontractors holding pre-petition liens directly. Under these circumstances, DESC and Santee Cooper, each in its pro rata share, would be required to make Citibank, N.A., which purchased the scheduled payments under the Toshiba Settlement, whole for reductions related to valid subcontractor and vendor pre-petition liens up to $60 million ($33 million for DESC's 55% share).

DESC and Santee Cooper are responsible for amounts owed to ~~WEC~~Westinghouse for valid work performed by ~~WEC~~Westinghouse Subcontractors on the ~~Nuclear~~NND Project after the ~~WEC~~Westinghouse bankruptcy filing (i.e., post-petition) until termination of the IAA (the IAA Period). ~~While SCE&G and Santee Cooper funded~~In the Westinghouse bankruptcy proceeding, deadlines were established for creditors of Westinghouse to assert the amounts owed to ~~WEC for~~ such ~~post-petition obligations on a weekly basis, SCE&G and Santee Cooper remain obligated~~creditors prior to the ~~extent amounts owed~~Westinghouse bankruptcy filing and during the IAA Period. Many of the Westinghouse Subcontractors have filed such claims. DESC does not believe that the claims asserted related to the IAA Period will exceed ~~(1)~~ the amounts ~~advanced~~previously funded for the currently asserted IAA-related claims, whether relating to ~~WEC for such purposes while the IAA was in effect~~claims already paid or ~~(2) the amounts held by WEC after the IAA was terminated. SCE&G~~those remaining to be paid. DESC intends to oppose any previously unasserted claim that is asserted against it, whether directly or indirectly by a claim through the IAA. ~~Some WEC~~

Further, some Westinghouse Subcontractors who have made claims against ~~SCE&G~~Westinghouse in the bankruptcy proceeding also filed against DESC and Santee Cooper in South Carolina state court for ~~damages~~damages. The Westinghouse Subcontractor claims in South Carolina state court include common law claims for pre-petition work, IAA Period work, and work after the ~~WEC Subcontractors claim arose after~~ termination of the IAA. ~~SCE&G intends to oppose~~Many of these ~~claims. To the extent any such claim is determined to be valid, SCE&G may be responsible for paying its 55% share thereof.~~

~~Toshiba Settlement and Subsequent Monetization~~

Payment and performance obligations under the EPC Contract are joint and several obligations of WEC and WECTEC. In 2015 Toshiba, WEC’s parent company, reaffirmed its guaranty of WEC’s payment obligations. In satisfaction of such guaranty obligations, on July 27, 2017, the Toshiba Settlement was executed under which Toshiba was to make periodic settlement payments beginning in October 2017 in the total amount of approximately $2.2 billion ($1.2 billion for SCE&G’s 55% share), subject to certain offsets for payments by WEC in bankruptcy that wouldclaimants have ~~the effect of satisfying the liens discussed above and below.~~

In September and October 2017, proceeds totaling approximately $1.997 billion were received in full satisfaction of the Toshiba Settlement ($1.098 billion for SCE&G's 55% share). The proceeds were obtained through the receipt of a payment from Toshiba and a payment from Citibank arising from its purchase of all other scheduled payments, including amounts related to the contractor liens discussed below. The purchase agreement with Citibank provides that SCE&G and Santee Cooper

~~(each according to its pro rata share) would indemnify Citibank for its losses arising from misrepresentations or covenant defaults under the purchase agreement. SCE&G and Santee Cooper~~ also assigned their claims under the WEC bankruptcy process to Citibank, and agreed to use commercially reasonable efforts to cooperate with Citibank and provide reasonable support necessary for its enforcement of those claims. The proceeds received under or arising from the monetization of the Toshiba Settlement are recorded as a regulatory liability on the accompanying condensed consolidated balance sheets, as the net value of the proceeds will be utilized to benefit SCE&G's customers in a manner to be determined by the SCPSC.

~~As described above, several WEC Subcontractors have filed~~asserted construction liens against the ~~Unit 2/3 Property,~~NND Project site. While DESC cannot be assured that it will not have any exposure on account of unpaid Westinghouse Subcontractor claims, which ~~SCE&G~~claims DESC is contesting. Payments under the Toshiba Settlement are subject to reduction if WEC pays WEC Subcontractors holding pre-petition liens directly. Under these circumstances, SCE&G and Santee Cooper, each in its pro rata share, wouldpresently disputing, DESC believes it is unlikely that it will be required to make Citibank whole for the reduction. On January 2, 2018, the purchase agreement with Citibank was amended to limit the amount that SCE&G and Santee Cooper could be required to reimburse Citibank for valid subcontractor and vendor pre-petition liens to $60 million ($33 million for SCE&G's 55% share).

~~Regulatory, Political and Legal Developments~~

In September 2017, the Company was served with a subpoena issued by the United States Attorney’s Office for the District of South Carolina seeking documents relating to the Nuclear Project. The subpoena requires the Company to produce a broad range of documents related to the project. Also, SLED is conducting a criminal investigation into the handling of the Nuclear Project by SCANA and SCE&G. In October 2017, the staff of the SEC's Division of Enforcement also issued a subpoena for documents related to an investigation they are conducting related to the Nuclear Project. These investigations are ongoing, and the Company and Consolidated SCE&G intend to fully cooperate with them. Also in connection with the abandonment of the Nuclear Project, various state and local governmental authorities have attempted and may further attempt to challenge, reverse or revoke previously-approved tax or economic development incentives, benefits or exemptions and have attempted and may further attempt to apply such actions retroactively. No assurance can be given as to the timing or outcome of these matters. See Claims and Litigation for a description of specific challenges.

On September 26, 2017, the South Carolina Office of Attorney General issued an opinion stating, among other things, that "as applied, portions of the BLRA are constitutionally suspect," including the abandonment provisions. Alsopayments on September 26, 2017, and in reliance on the opinion from the Office of Attorney General, the ORS filed the Request seeking an order from the SCPSC directing SCE&G to immediately suspend all revised rates collections from customers which were previously approved by the SCPSC pursuant to the authority of the BLRA. In the Request, the ORS noted the existence of an allegation that SCE&G failed to disclose information to the ORS, which the ORS believes should have been disclosed, that would have appeared to provide a basis for challenging prior requests, and asserted that SCE&G should not be allowed to continue to benefit from nondisclosure. The ORS also asked for an order that, if the BLRA is found to be unconstitutional or the South Carolina General Assembly amends or revokes the BLRA, then SCE&G should make credits to future bills or refunds to customers for prior revised rates collections. On October 17, 2017, the ORS filed a motion with the SCPSC to amend the Request, in which motion the ORS asked the SCPSC to consider the most prudent manner by which SCE&G will enable its customers to realize the value of the monetized Toshiba Settlement payments and other payments made by Toshiba towards satisfaction of its obligations to SCE&G.

On December 20, 2017, the SCPSC denied a motion by SCE&G to dismiss the Request and the SCPSC requested that the ORS carry out an inspection, audit and examination of SCE&G's revenue requirements to assist the SCPSC in determining whether SCE&G's present schedule of rates is fair and reasonable. Parties who have intervened in the Request or who filed a letter in support of it include the state's Governor, Office of Attorney General and Speaker of the House of Representatives, the Electric Cooperatives of South Carolina, Santee Cooper, the SCEUC, certain large industrial customers, and several environmental groups. The SCPSC has scheduled a hearing on the Joint Petition and two other dockets related to the Nuclear Project, namely the Request by the ORS and a June 2017 complaint filed by the Friends of the Earth and the Sierra Club, to begin November 1, 2018. This schedule was established in response to legislation described below. SCE&G intends to continue vigorously contesting the Request, but cannot give any assurance as to the timing or outcome of this matter. See also Note 2.

In 2017, special committees of the South Carolina General Assembly, both in the House of Representatives and in the Senate, conducted public hearings regarding the Company's decision to abandon the Nuclear Project. Several legislative proposals adverse to the Company and Consolidated SCE&G resulted from the work of these committees, two of which became law in 2018 and are described below.

average residential electric customer’s bill to approximately 3.2%, or a reduction of approximately $31 million per month, retroactive to April 1, 2018. Absent an earlier ruling from the SCPSC, which could be issued only on the SCPSC’s own initiative, these lower rates are to be effective until the SCPSC renders a final decision on the merits of the Joint Petition. On July 2 and 3, 2018, the SCPSC issued orders implementing the temporary rate reduction required by Act 258. Unless the relief discussed in the next paragraph is granted, the new rates and retroactive credits required by Act 258 are to be put into effect with the first billing cycle of August 2018. Retroactive credits for billed and unbilled amounts for the period April 1, 2018 through June 30, 2018 total approximately $109.3 million, which amount has been deferred within Revenue subject to refund on the condensed consolidated balance sheet of the Company and Consolidated SCE&G. The initial recognitionaccount of such retroactive credits includes the effects of cycle billing on unbilled usage. In addition to the reduction of electric rates (which rates had been previously approved by the SCPSC), Act 258 alters various procedures previously applicable under the BLRA, including redefining the standard of care required by the BLRA and supplying definitions of key terms that would affect the evidence required to establish SCE&G’s ability to recover its costs associated with the Nuclear Project.

On June 29, 2018, SCE&G filed a lawsuit in the District Court challenging the constitutionality of Act 258 along with joint resolution S. 954, which became law on July 2, 2018. Among other things, S. 954 prohibits the SCPSC from holding a hearing on the merits of the Joint Petition before November 1, 2018, and requires it to issue an order on the merits of the Joint Petition by December 21, 2018. In the lawsuit, which was subsequently amended, SCE&G seeks a declaration that the new laws are unconstitutional and asks the court to issue an injunction prohibiting the SCPSC from implementing Act 258. A hearing on SCE&G’s motion for the issuance of a preliminary injunction was held July 30-31, 2018. Dominion Energy and Sedona would not be obligated to complete the pending merger with SCANA if Act 258 remains in effect and is implemented. The Company and Consolidated SCE&G cannot predict the timing or outcome of this matter.

~~Proposals to Resolve Outstanding Issues~~

On November 16, 2017, SCE&G announced for public consideration a proposal to resolve outstanding issues relating to the Nuclear Project. Under the proposal, SCE&G electric customers were to receive a 3.5% electric rate reduction, the addition of an existing 540-MW natural gas fired power plant by SCE&G with the acquisition cost borne by SCANA shareholders, and the addition of approximately 100-MW of large scale solar energy by SCE&G. The proposal also provided for the recovery of the nuclear construction costs (net of the proceeds of the Toshiba Settlement not utilized for liquidation of project liens) over 50 years. While SCE&G’s proposal was not formally submitted for regulatory approval at that time, discussions with key stakeholders over the ensuing weeks indicated that SCE&G's proposal would not be sufficient to resolve the outstanding issues.

On January 2, 2018, SCANA entered into the Merger Agreement with Dominion Energy, and on January 12, 2018, SCE&G and Dominion Energy filed the Joint Petition requesting SCPSC approval of the merger or a finding that either the merger is in the public interest or that there is an absence of harm arising from the merger. In this petition, the parties commit to providing an up-front, one time rate credit to SCE&G's electric customers totaling approximately $1.3 billion within 90 days of the merger's closing, providing at least a 5% reduction in customer bills (later adjusted to approximately 7% in light of the effects of the Tax Act), shortening the amortization period for costs related to the Nuclear Project to 20 years, forgoing recovery of approximately $1.7 billion in costs related to the Nuclear Project, and to SCE&G's purchasing an existing 540-MW natural gas fired power plant with no initial investment borne by customers. The SCPSC is scheduled to hold a hearing on the Joint Petition beginning on November 1, 2018, and as noted above, pursuant to S. 954 the SCPSC is required to issue an order related to the Joint Petition no later than December 21, 2018. No assurance can be given as to the timing or outcome of efforts to consummate the Merger Agreement or to obtain approval of the Joint Petition.

On May 9, 2018, SCE&G completed its purchase of CEC, the existing 540-MW natural gas fired power plant referred to above, for approximately $180 million. As disclosed in Note 10 to the Company's and Consolidated SCE&G's Form 10-K for December 31, 2017, an impairment loss recorded in the fourth quarter of 2017 included $180 million related to SCE&G's commitment to not seek recovery from customers for the acquisition cost of this natural gas fired power plant, and accordingly, this amount was recorded as a reduction to unrecovered Nuclear Project costs within regulatory assets on the Company's and Consolidated SCE&G's consolidated balance sheets at December 31, 2017. As indicated above, the cost of the plant is being borne by SCANA shareholders. As such, the Company's and Consolidated SCE&G's condensed consolidated balance sheet as of June 30, 2018 reflect the cost for CEC within Utility Plant in Service, and the $180 million impairment initially recorded as unrecovered Nuclear Project costs within regulatory assets is now reflected within Accumulated Depreciation and Amortization, which results in the carrying value of CEC being entirely written off. SCE&G’s commitment to not seek recovery from customers for the acquisition cost of CEC was one element of certain broader rate mitigation proposals contained within the Joint Petition. Assuming that the SCPSC approves either of the mitigating proposals as outlined in the Joint Petition, SCE&G will not seek recovery of CEC acquisition costs.

~~Impairment Considerations~~

At June 30, 2018, SCE&G estimated that revised rates collections previously approved under the BLRA totaled approximately $445 million annually. SCE&G estimates that such revised rates collections for 2018 would be reduced by approximately $279 million if Act 258 remains in effect and is implemented through December 21, 2018, which is the expected pendency of the SCPSC proceeding with respect to the Joint Petition and related dockets. This reduction is comprised of the retroactive credits described above of approximately $109.3 million which are recorded as revenues subject to refund, with the remainder being related to revenues subject to refund that SCE&G expects to collect in July 2018 and lower revised rates during the period from the first billing cycle in August 2018 until the date new rates take effect. Such new rates would take effect after the SCPSC issues an order on the Joint Petition and other related matters pending before it, which order is to be issued no later than December 21, 2018. On a cumulative basis, at June 30, 2018, SCE&G estimated that revised rates collections previously approved under the BLRA totaled approximately $2.1 billion. Such estimates include the approximately $109.3 million of revenues subject to refund.

On June 28, 2018, SCANA's Board of Directors declared a dividend of $0.1237 per share payable on July 18, 2018 to shareholders of record on July 10, 2018. This quarterly cash dividend reflects a reduction from the $0.6125 per share paid on SCANA’s common stock for the first quarter of 2018. The approximately eighty percent reduction in the dividend corresponds to the portion of the dividend attributable to SCE&G's electric operations and serves to partially mitigate the liquidity impacts arising from the reduced revenues resulting from the implementation of Act 258.

Under the current regulatory construct in South Carolina, pursuant to the BLRA or through other means, the ability of SCE&G to recover costs incurred in connection with Unit 2 and Unit 3, and a reasonable return on them, will be subject to review and approval by the SCPSC. In light of the contentious nature of activity involving the General Assembly and other officials and the Request being considered by the SCPSC that could result in the suspension of all rates currently being collected under the BLRA, as well as the return of such amounts previously collected, there is significant uncertainty as to SCE&G’s ultimate ability to recover its costs of Unit 2 and Unit 3 and a return on them from its customers. SCE&G continues to contest the specific challenges described above. However, based on the consideration of those challenges, and particularly in light of SCE&G's proposed solution announced on November 16, 2017 and details in the Joint Petition filed by SCE&G and Dominion Energy with the SCPSC on January 12, 2018, the Company and Consolidated SCE&G determined that a disallowance of recovery of part of the cost of the abandoned Nuclear Project is both probable and reasonably estimable under applicable accounting guidance. In addition, the Company and Consolidated SCE&G determined that full recovery of certain other related costs deferred within regulatory assets is less than probable. As a result, in 2017 the Company and Consolidated SCE&G recognized a pre-tax impairment loss totaling $1.118 billion ($690 million net of tax). Also, in the first quarter of 2018, the Company and Consolidated SCE&G recognized an additional pre-tax impairment loss of approximately $3.6 million ($2.7 million net of tax) in order to further reduce to estimated fair value the carrying value of nuclear fuel which had been acquired for use in Unit 2 and Unit 3.

It is reasonably possible that a change in estimated impairment loss could occur in the near term and could be material; however, all such changes cannot be reasonably estimated. The impairment loss recorded in 2017 reflects impacts similar to those that would have resulted had the proposed solution announced on November 16, 2017 been implemented. If the merger benefits and cost recovery plan outlined in the Joint Petition are implemented (upon closing of the merger as contemplated in the Merger Agreement), an additional impairment loss and other charges totaling as much as approximately $1.7 billion (approximately $1.3 billion net of tax) would be expected to be recorded. This additional impairment loss would result from the write-off of unrecovered Nuclear Project costs of approximately $842 million recorded within regulatory assets and the recording of additional liabilities for customer refunds totaling approximately $1.875 billion, net of approximately $1.065 billion, which amount represents the monetization of guaranty settlement recorded within regulatory liabilities less amounts that may be required to settle contractor liens.

revenues collected from customers beginning April 1, 2018, the Company and Consolidated SCE&G do not currently anticipate that any amounts collected prior to April 1, 2018, will be subject to refund (other than amounts arising due to the effects of the Tax Act); however, no assurance can be given as to the outcome of this matter.

At June 30, 2018, the Company and Consolidated SCE&G included considerations of the impact of Act 258 in the evaluation as to their ability to recover the remaining Nuclear Project costs and a reasonable return on those costs. Because Act 258 explicitly provides for an experimental rate that is temporary and does not disallow any of the costs currently deferred as a regulatory asset, and because the experimental rate is to be replaced by rates that the SCPSC is to determine and order no later than December 21, 2018, the Company and Consolidated SCE&G have concluded that the recording of additional impairment charges related to unrecovered Nuclear Project costs would not be appropriate at this time. However, if a disallowance were ordered or the rates under Act 258 were made other than temporary by the SCPSC in the Joint Petition proceeding, the Company and Consolidated SCE&G would reevaluate this conclusion. Were a disallowance ordered or were the rates under Act 258 made other than temporary following the SCPSC's final decision on the Joint Petition, and without consideration of any other factors that may be embodied in such an order, an additional pre-tax impairment charge totaling as much as approximately $1.7 billion may be required.

~~Liquidity Considerations~~

As a result of the legislative and regulatory reactions to the decision to stop construction of Unit 2 and Unit 3, downgrades by credit ratings agencies occurred. The Company and Consolidated SCE&G have significant obligations that must be paid within the next 12 months, including long-term debt maturities and capital lease payments of $568 million for the Company (including $564 million for Consolidated SCE&G), short-term borrowings of $517 million for the Company (including $457 million for Consolidated SCE&G), interest payments of approximately $318 million for the Company (including $238 million for Consolidated SCE&G), future minimum payments for operating leases of $11 million for the Company (including $3 million for Consolidated SCE&G), and revenues collected subject to refund arising from the effects of the Tax Act of approximately $55 million for the Company (including $46 million for Consolidated SCE&G). Working capital requirements, such as those for fuel supply and similar obligations, also arise due to the lag between when such amounts are paid and when related collection of such costs through customer rates occurs. In addition, as described above under ~~Impairment Considerations~~, SCE&G has been ordered to reduce revised rates previously approved under the BLRA by approximately $279 million in 2018. This reduction assumes that Act 258 remains in effect and is implemented through December 21, 2018, which is the expected pendency of the SCPSC proceeding with respect to the Joint Petition and related dockets, and would include a refund of approximately $109.3 million previously recorded for the period April 1 through June 30, 2018.

During the pendency of SCE&G's lawsuit filed June 29, 2018 in the District Court, as amended, SCE&G may be required to escrow funds or to secure a bond corresponding to the amount it may be required to refund if its lawsuit is unsuccessful. In addition, any adverse final judgment by a court in any matter of litigation, or any levy for amounts assessed by a regulatory agency, including but not limited to matters described in Claims and Litigation, could require the Company and/or Consolidated SCE&G to escrow funds or to post one or more bonds equal to the monetary amount of the judgment or assessment while the decision is being appealed or challenged.

Management believes as of the date of issuance of these financial statements that it has access to available sources of cash to pay obligations when due over the next 12 months. These sources include committed, long-term lines of credit that expire in December 2020 totaling $1.8 billion for the Company (including $1.2 billion for Consolidated SCE&G). In addition, as of the date of issuance of these financial statements, SCE&G continues to collect the BLRA-related customer rates that remain after reductions ordered as a result of Act 258, as well as amounts provided for in other orders related to non-BLRA electric and gas rates. In 2018, however, certain of SCANA's credit ratings have fallen below investment grade, which has constrained its ability and that of Fuel Company to issue commercial paper.

Regulatory and legislative proceedings described above, and/or proceedings described under Claims and Litigation below, which are outside of the Company’s and Consolidated SCE&G’s control, may result in the temporary or permanent suspension of all or a portion of the approximately $445 million annually of rates being collected currently under the BLRA, the return of such amounts collected through June 30, 2018, of $2.1 billion, or the requirement that SCE&G's share of payments received from the Toshiba Settlement ($1.098 billion) be placed in escrow or be refunded to customers in the near term. Neither the Company nor Consolidated SCE&G can predict if or when these matters may be resolved or what additional actions, if any, may be proposed or taken, including other legislative or regulatory actions related to the BLRA or other litigation.

Were the SCPSC to grant the relief sought by the ORS in the Request or grant similar relief resulting from legislative action, and as further discussed above in Impairment Considerations, an additional impairment loss or other charges totaling as much as approximately $4.9 billion (approximately $3.7 billion net of tax) may be required. Such an impairment loss or other

charges would further stress the Company’s and Consolidated SCE&G’s debt to total capitalization ratio and may result in the Company’s and Consolidated SCE&G’s ratio of debt to total capitalization exceeding maximum levels prescribed in their respective credit agreements. Such an event likely would limit the Company’s and Consolidated SCE&G’s ability to borrow under their commercial paper programs and credit facilities and their ability to pay future dividends or may trigger events of default under such agreements.

Known and knowable conditions and events when considered in the aggregate as of the date of issuance of these financial statements do not suggest it is probable that the Company and Consolidated SCE&G will not be able to meet obligations as they come due over the next 12 months. However, possible future actions, including but not limited to actions related to the disallowance of all or part of the remaining unrecovered nuclear regulatory asset, rate reductions, refunds or lawsuits, could have a material adverse impact on the Company’s and Consolidated SCE&G’s financial condition, liquidity, results of operations and cash flows such that management’s conclusion with respect to its ability to pay obligations when due could change.

~~Claims and Litigation~~

Following the Company’s decision to stop construction of Unit 2 and Unit 3, purported derivative and class action lawsuits have been filed in multiple state circuit courts and federal district court on behalf of customers, shareholders and SCANA (in the case of the derivative shareholder actions), against SCANA, SCE&G, or both, and in certain cases some of their officers and/or directors. The plaintiffs allege various causes of action, including but not limited to waste, breach of fiduciary duty, negligence, unfair trade practices, unjust enrichment, conspiracy, fraud, constructive fraud, misrepresentation and negligent misrepresentation, promissory estoppel, constructive trust, and money had and received, among other causes of action. Plaintiffs generally seek compensatory and consequential damages and statutory treble damages and such further relief as the court deems just and proper. In addition, certain plaintiffs seek a declaration that SCE&G may not charge its customers to reimburse itself for past and continuing costs of the Nuclear Project. Certain plaintiffs also seek to freeze or appoint a receiver for certain of SCE&G’s assets, including all money SCE&G has received under the Toshiba payment guaranty and related settlement agreement and money to be collected from customers for the Nuclear Project.

Purported class action lawsuits have been filed on behalf of investors in federal court against SCANA and certain of its current and former executive officers and directors. The plaintiffs allege, among other things, that defendants violated Section 10(b) of the Exchange Act and Rule 10b-5 promulgated thereunder and RICO. In addition, one plaintiff alleges that director defendants violated Section 14(a) of the Exchange Act and SEC Rule 14a-9 by allowing or causing misleading proxy statements to be issued. The plaintiffs in each of these suits seek compensatory and consequential damages and such further relief as the court deems proper. The plaintiffs also allege, among other things, that defendants violated their fiduciary duties to shareholders by executing a merger agreement that unfairly deprived plaintiffs of the true value of their SCANA stock, and that Dominion Energy and Sedona aided and abetted these actions. Among other remedies, the plaintiffs seek to enjoin the merger and rescind the Merger Agreement or to have the Merger Agreement amended to provide more favorable terms for plaintiffs, monetary damages, attorneys' fees and such further relief as the court deems proper.

Lawsuits seeking class action status have also been filed on behalf of investors and shareholder derivative actions have been filed in the Court of Common Pleas in the Counties of Lexington and Richland, South Carolina, against SCANA, its CEO and directors, Dominion Energy and Sedona. Following removal of certain of these class action lawsuits and shareholder derivative actions from state courts to federal court and remand from the District Court back to state courts, in at least one instance such action was appealed to the United States Court of Appeals for the Fourth Circuit on July 26, 2018 by Dominion Energy.

On July 13, 2018, SCANA’s Board of Directors elected two new, independent directors and exercised its right under South Carolina corporate law to form a Special Litigation Committee comprised solely of these newly elected members ("SLC") to investigate the claims asserted against current and former officers and directors of SCANA in derivative shareholder actions and related actions ("Derivative Litigation") and to determine SCANA’s best interests with respect to these actions. On July 24, 2018, SCANA, acting at the direction of the SLC, filed a motion to stay all federal court proceedings in the Derivative Litigation ~~(In Re SCANA Corporation Derivative Litigation)~~ to allow time for the SLC to conduct an independent investigation into the facts and circumstances giving rise to the Derivative Litigation, and to determine what course of action is in the best interests of SCANA and its shareholders with respect to the Derivative Litigation (e.g., prosecution of the claims in the name of SCANA, seeking dismissal of some or all of the claims, or taking other remedial actions).

practices related to SCE&G’s termination of the FILOT agreement. Plaintiff seeks injunctive relief to prevent SCE&G from terminating the FILOT agreement; actual and consequential damages; treble damages; punitive damages; and attorneys’ fees.

The Company has also been served with subpoenas issued by the United States Attorney’s Office for the District of South Carolina and the staff of the SEC's Division of Enforcement seeking documents relating to the Nuclear Project. Also, SLED is conducting a criminal investigation into the handling of the Nuclear Project by SCANA and SCE&G. These investigations are ongoing, and the Company and Consolidated SCE&G intend to fully cooperate with them.

The DOR has initiated an audit of SCE&G's sales and use tax returns for the periods September 1, 2008 through December 31, 2017. The DOR's position is that the exemption for sales and use tax for purchases related to the Nuclear Project should not apply because Unit 2 and Unit 3 will not be placed into service and no electricity will be manufactured for sale. On June 1, 2018, SCE&G received from the DOR a notice of proposed assessment arising from that audit of approximately $410 million, plus interest. While SCE&G intends to protest the proposed assessment, it is reasonably possible that a loss estimated to be as much as $410 million, plus interest, could be incurred, of which SCE&G's proportionate share as a co-owner of the Nuclear Project would be 55%.

~~On July 17, 2018, a case filed in the District Court styled~~ ~~Pennington~~ ~~et al.~~ ~~v. SCANA, Fluor Corporation and Fluor Enterprises~~ was certified as a class action on behalf of persons who were formerly employed at the Nuclear Project. The plaintiffs allege, among other things, that the defendants violated the WARN Act in connection with the decision to stop construction at the Nuclear Project. The plaintiffs allege that the defendants failed to provide adequate advance written notice of their terminations of employment. While SCANA and SCE&G intend to contest this case, it is reasonably possible that a loss estimated to be as much as $75 million could be incurred, due to the likelihood the Fluor defendants would seek indemnification from them, of which SCE&G's proportionate share as a co-owner of the Nuclear Project would be 55%.

While the Company and Consolidated SCE&G intend to vigorously contest the lawsuits, claims, and audit positions which have been filed or initiated against them, they cannot predict the timing or outcome of these matters or others that may arise, including any claims that may be asserted by or against Santee Cooper, and adverse outcomes from some of these matters would not be covered by insurance. Except as noted above, the various claims for damages do not specify an amount for those damages and the number of plaintiffs that are ultimately certified in any class action lawsuits is unknown. In addition, each of the cases referred to above is in its early stages. For these reasons, the Company and Consolidated SCE&G (i) have not determined that a loss is probable and (ii) except as noted above, cannot provide any estimate or range of potential loss for these matters at this time. Therefore, no accrual for these potential losses has been included in the condensed consolidated financial statements. However, outcomes could have a material adverse impact on the Company's and Consolidated SCE&G's results of operations, cash flows and financial condition.

The Company and Consolidated SCE&G are subject to various other claims and litigation incidental to their business operations which management anticipates will be resolved without a material impact on the Company's and Consolidated SCE&G's results of operations, cash flows or financial condition.

claims.

Nuclear Insurance

Under Price-Anderson, ~~SCE&G~~DESC (for itself and on behalf of Santee-Cooper) maintains agreements of indemnity with the ~~NRC~~U.S. Nuclear Regulatory Commission that, together with private insurance, cover third-party liability arising from any nuclear incident occurring at ~~Unit 1.~~Summer. Price-Anderson provides funds up to ~~$13.1~~$14.0 billion for public liability claims that could arise from a single nuclear incident. Each nuclear plant is insured against this liability to a maximum of $450 million by ~~ANI~~American Nuclear Insurers with the remaining coverage provided by a mandatory program of deferred premiums that could be assessed, after a nuclear incident, against all owners of commercial nuclear reactors. Each reactor licensee is liable for up to ~~$127.3~~$138 million per reactor owned for each nuclear incident occurring at any reactor in the ~~United States,~~U.S., provided that not more than ~~$18.9~~$21 million of the liability per reactor would be assessed per year. ~~SCE&G’s~~DESC’s maximum assessment, based on its two-thirds ownership of ~~Unit 1,~~Summer, would be ~~$84.8~~$92 million per incident, but not more than ~~$12.6~~$14 million per year. Both the maximum assessment per reactor and the maximum yearly assessment are adjusted for inflation at least every five years.

~~SCE&G~~

DESC currently maintains insurance policies (for itself and on behalf of Santee Cooper) with NEIL. The policies provide coverage to ~~Unit 1~~Summer for property damage and outage costs up to $2.75 billion resulting from an event of nuclear origin and up to $2.33 billion resulting from an event of a non-nuclear origin. The NEIL policies in aggregate, are subject to a maximum loss of $2.75 billion for any single loss occurrence. The NEIL policies permit retrospective assessments under certain conditions to cover insurer’s losses. Based on the current annual premium, ~~SCE&G’s~~DESC’s portion of the retrospective premium assessment would not exceed ~~$23.4~~$24 million. ~~SCE&G~~DESC currently maintains an excess property insurance policy (for itself and on behalf of Santee Cooper) with EMANI. The policy provides coverage to ~~Unit 1~~Summer for property damage and outage costs up to $415 million resulting from an event of a non-nuclear origin. The EMANI policy permits retrospective assessments under certain conditions to cover insurer's losses. Based on the current annual premium, ~~SCE&G's~~DESC's portion of the retrospective premium assessment would not exceed ~~$2.0~~$2 million.

To the extent that insurable claims for property damage, decontamination, repair and replacement and other costs and expenses arising from an incident at ~~Unit 1~~Summer exceed the policy limits of insurance, or to the extent such insurance becomes unavailable in the future, and to the extent that ~~SCE&G's~~DESC's rates would not recover the cost of any purchased replacement power, ~~SCE&G~~DESC will retain the risk of loss as a self-insurer. ~~SCE&G~~DESC has no reason to anticipate a serious nuclear or other incident. However, if such an incident were to occur, it likely would have a material impact on ~~the Company’s and Consolidated SCE&G's~~DESC's results of operations, cash flows and financial position.

~~Environmental~~

~~On August 3, 2015, the EPA issued a revised standard for new power plants by re-proposing NSPS under the CAA for emissions of CO~~₂~~from newly constructed fossil fuel-fired units. The final rule required all new coal-fired power plants to meet a carbon emission rate of 1,400 pounds CO~~₂~~per MWh and new natural gas units to meet 1,000 pounds CO~~₂per MWh. While most new natural gas plants will not be required to include any new technologies, no new coal-fired plants could be constructed without partial carbon capture and sequestration capabilities. The Company and Consolidated SCE&G are monitoring the final rule, but do not plan to construct new coal-fired units in the foreseeable future.

On August 3, 2015, the EPA issued its final rule on emission guidelines for states to follow in developing plans to address GHG emissions from existing units. The rule included state-specific goals for reducing national CO₂ emissions by 32% from 2005 levels by 2030, and established a phased-in compliance approach beginning in 2022. The rule gave each state from one to three years to issue its SIP, which would ultimately define the specific compliance methodology that would be applied to existing units in that state. On February 9, 2016, the Supreme Court stayed the rule pending disposition of a petition of review of the rule in the Court of Appeals. As a result of an Executive Order on March 28, 2017, the EPA placed the rule under review and the Court of Appeals agreed to hold the case in abeyance. On October 10, 2017, the Administrator of the EPA signed a notice proposing to repeal the rule on the grounds that it exceeded the EPA's statutory authority. In a separate but related action, the EPA issued an Advance Notice of Proposed Rulemaking on December 18, 2017, to solicit information from the public about a potential future rulemaking to limit greenhouse gas emissions from existing units. The Company and Consolidated SCE&G expect any costs incurred to comply with such rule to be recoverable through rates.

~~In July 2011, the EPA issued the CSAPR to reduce emissions of SO~~₂~~and NO~~_X ~~from power plants in the eastern half of the United States. The CSAPR replaces the CAIR and requires a total of 28 states to reduce annual SO~~₂ ~~emissions and annual and ozone season NO~~_X ~~emissions to assist in attaining the ozone and fine particle NAAQS. The rule establishes an emissions cap for SO~~₂~~and NO~~_X and limits the trading for emission allowances by separating affected states into two groups with no trading between the groups. The State of South Carolina has chosen to remain in the CSAPR program, even though recent court rulings exempted the state. This allows the state to remain compliant with regional haze standards. Air quality control installations that SCE&G and GENCO have already completed have positioned them to comply with the existing allowances set by the CSAPR. Any costs incurred to comply with CSAPR are expected to be recoverable through rates.

In April 2012, the EPA's MATS rule containing new standards for mercury and other specified air pollutants became effective. The MATS rule has been the subject of ongoing litigation even while it remains in effect. Rulings on this litigation are not expected to have an impact on SCE&G or GENCO due to plant retirements, conversions, and enhancements. SCE&G and GENCO are in compliance with the MATS rule and expect to remain in compliance.

under reconsideration by the EPA and has been stayed administratively. The EPA has decided to conduct a new rulemaking that could result in revisions to certain flue gas desulfurization wastewater and bottom ash transport water requirements in the ELG Rule. Accordingly, in September 2017 the EPA finalized a rule that resets compliance dates under the ELG Rule to a range from November 1, 2020 to December 31, 2023. The EPA indicates that the new rulemaking process may take up to three years to complete, such that any revisions to the ELG Rule likely would not be final until the summer of 2020. While the Company and Consolidated SCE&G expect that wastewater treatment technology retrofits will be required at Williams and Wateree Stations, any costs incurred to comply with the ELG Rule are expected to be recoverable through rates.

The CWA Section 316(b) Existing Facilities Rule became effective in October 2014. This rule establishes national requirements for the location, design, construction and capacity of cooling water intake structures at existing facilities that reflect the best technology available for minimizing the adverse environmental impacts of impingement and entrainment. SCE&G and GENCO are conducting studies and implementing plans as required by the rule to determine appropriate intake structure modifications to ensure compliance with this rule. Any costs incurred to comply with this rule are expected to be recoverable through rates.

The EPA's final rule for CCR became effective in the fourth quarter of 2015. This rule regulates CCR as a non-hazardous waste under Subtitle D of the Resource Conservation and Recovery Act and imposes certain requirements on ash storage ponds and other CCR management facilities at SCE&G's and GENCO's coal-fired generating facilities. SCE&G and GENCO have already closed or have begun the process of closure of all of their ash storage ponds and have previously recognized AROs for such ash storage ponds under existing requirements. The Company and Consolidated SCE&G do not expect the incremental compliance costs associated with this rule to be significant and expect to recover such costs in future rates.

SCE&G is responsible for four decommissioned MGP sites in South Carolina which contain residues of by-product chemicals. These sites are in various stages of investigation, remediation and monitoring under work plans approved by or under review by DHEC and the EPA. SCE&G anticipates that major remediation activities at all these sites will continue at least through 2019 and will cost an additional $9.8 million, which is accrued in Other within Deferred Credits and Other Liabilities on the condensed consolidated balance sheet. SCE&G expects to recover any cost arising from the remediation of MGP sites through rates.

12. LEASES

At June 30, ~~2018,~~2019, DESC had the following lease assets and liabilities recorded in the Consolidated Balance Sheets:

(millions)	June 30, 2019
Lease assets:
Operating lease assets⁽¹⁾	$	20
Finance lease assets⁽²⁾		28
Total lease assets	$	48
Lease liabilities:
Operating lease - current⁽³⁾	$	2
Operating lease - noncurrent⁽⁴⁾		16
Finance lease - current⁽⁵⁾		7
Finance lease - noncurrent⁽⁶⁾		22
Total lease liabilities	$	47

(1)	Included in other deferred debits and other assets in the Consolidated Balance Sheets.

(2)	Included in utility plant, net, in the Consolidated Balance Sheets, net of $20 million of accumulated amortization at June 30, 2019.

(3)	Included in other current liabilities in the Consolidated Balance Sheets.

(4)	Included in other deferred credits and other liabilities in the Consolidated Balance Sheets.

(5)	Included in current portion of long-term debt in the Consolidated Balance Sheets.

(6)	Included in long-term debt in the Consolidated Balance Sheets.

For the three and six months ended June 30, 2019, total lease cost consisted of the following:

	Three Months Ended		Six Months Ended
(millions)	June 30, 2019		June 30, 2019
Finance lease cost:
Amortization	$	2	$	4
Interest		—		—
Operating lease cost		—		1
Short-term lease cost		1		1
Variable lease cost		—		—
Total lease cost	$	3	$	6

For the six months ended June 30, 2019, cash paid for amounts ~~net of amounts previously recovered through rates and insurance settlements, totaled $23.9 million and are~~ included in ~~regulatory assets.~~

~~Other~~

~~The Company and Consolidated SCE&G have recorded an estimated liability for amounts collected in customer rates during~~ the ~~period that arise from the impact~~measurement of lease liabilities consisted of the ~~Tax Act~~following amounts, included in the Consolidated Statements of Cash Flows:

	Six Months Ended
(millions)	June 30, 2019
Operating cash flows from finance leases	$	—
Operating cash flows from operating leases		2
Financing cash flows from finance leases		4

At June 30, 2019, the weighted average remaining lease term and ~~from~~weighted average discount rate for finance and operating leases were as follows:

	June 30, 2019
Weighted average remaining lease term - finance leases	5 years
Weighted average remaining lease term - operating leases	21 years
Weighted average discount rate - finance leases		2.97	%
Weighted average discount rate - operating leases		4.53	%

Lease liabilities have the ~~impact of the legislatively-mandated refund related to rates previously approved under the BLRA. Such amounts have been recorded subject to refund, and are described in Note 2.~~following scheduled maturities:

(millions)	Operating			Finance
2019	$	2		$	4
2020		2			8
2021		2			6
2022		1			5
2023		1			3
After 2023		22			5
Total undiscounted lease payments		30			31
Present value adjustment		(12	)		(2	)
Present value of lease liabilities	$	18		$	29

~~11. SEGMENT OF BUSINESS INFORMATION~~

~~Regulated operations measure profitability using operating income; therefore, net income is not allocated to the~~

13. OPERATING SEGMENTS

Operating segments include Electric Operations and Gas Distribution ~~segments.~~and are organized primarily on the basis of products and services sold.

In connection with the SCANA Combination, effective January 2019, reportable segments were changed to include a Corporate and Other segment and to utilize comprehensive income (loss) as the measure of segment profitability. The ~~Gas Marketing~~Corporate and Other segment includes specific items attributable to DESC's operating segments that are not included in profit measures ~~profitability using~~evaluated by executive management in assessing the segments' performance or in allocating resources. Corresponding amounts in prior periods have been recast to conform to the current presentation.

In the six months ended June 30, 2019, DESC reported after-tax net ~~income.~~expenses of $1.3 billion for specific items in the Corporate and Other segment, with $1.4 billion attributable to its operating segments.

The net expense for specific items attributable to DESC’s operating segments in 2019 primarily related to the impact of the following items:

•	A $1.0 billion ($756 million after-tax) charge for refunds of amounts previously collected from retail electric customers for the NND Project, attributable to Electric Operations;

•	$266 million ($200 million after-tax) of charges associated with litigation, attributable to Electric Operations;

•	A $198 million tax charge for $264 million of income tax-related regulatory assets for which DESC committed to forgo recovery, attributable to Electric Operations;

•	A $114 million ($86 million after-tax) charge for utility plant primarily for which DESC committed to forgo recovery, attributable to Electric Operations;

•	$72 million ($60 million after-tax) of merger and integration-related costs associated with the SCANA Combination, including a $62 million ($47 million after-tax) charge related to a voluntary retirement program, attributable to:

•

Electric Operations ($55 million after-tax); and

•

Gas Distribution ($5 million after-tax); and

•	$63 million tax charges for changes in unrecognized tax benefits, attributable to Electric Operations.

The Company's Gas Distribution segment is comprised of the local distribution operations of SCE&G and PSNC Energy which meet the criteria for aggregation. All Other includes the parent company, a services company and other nonreportable segments that were insignificant for all periods presented.

(millions)	External Revenue			Comprehensive Income (Loss) Available (Attributable) to Common Shareholder
Three Months Ended June 30, 2019
Electric Operations	$	620		$	104
Gas Distribution		78			(8	)
Corporate and Other		—			(166	)
Adjustments/Eliminations		—			(8	)
Consolidated Total	$	698		$	(78	)

Three Months Ended June 30, 2018
Electric Operations	$	553		$	30
Gas Distribution		79			(3	)
Corporate and Other		—			4
Adjustments/Eliminations		—			(5	)
Consolidated Total	$	632		$	26

Six Months Ended June 30, 2019
Electric Operations	$	1,147		$	152
Gas Distribution		225			14
Corporate and Other		(1,009	)		(1,339	)
Adjustments/Eliminations		—			(14	)
Consolidated Total	$	363		$	(1,187	)

Six Months Ended June 30, 2018
Electric Operations	$	1,100		$	130
Gas Distribution		234			29
Corporate and Other		—			—
Adjustments/Eliminations		—			(9	)
Consolidated Total	$	1,334		$	150

The Company
Millions of dollars
External
Revenue
Intersegment Revenue
Operating
Income

Net
Income
Three Months Ended June 30, 2018
Electric Operations $ 552
$ 2
$ 106
n/a
Gas Distribution 148
1
3
n/a
Gas Marketing 143
29
n/a
$ 3
All Other —
118
—
(24 )
Adjustments/Eliminations —
(150 ) (6 ) 29
Consolidated Total $ 843
$ —
$ 103
$ 8

Six Months Ended June 30, 2018
Electric Operations $ 1,098
$ 3
$ 179
n/a
Gas Distribution 509
1
116
n/a
Gas Marketing 416
60
n/a
$ 20
All Other —
223
—
(49 )
Adjustments/Eliminations —
(287 ) (5 ) 206
Consolidated Total $ 2,023
$ —
$ 290
$ 177

Three Months Ended June 30, 2017
Electric Operations $ 679
$ 2
$ 246
n/a
Gas Distribution 140
1
4
n/a
Gas Marketing 182
34
n/a
$ 1
All Other —
102
—
(7 )
Adjustments/Eliminations —
(139 ) 1
127
Consolidated Total $ 1,001
$ —
$ 251
$ 121

Six Months Ended June 30, 2017
Electric Operations $ 1,256
$ 3
$ 428
n/a
Gas Distribution 461
1
117
n/a
Gas Marketing 456
58
n/a
$ 16
All Other —
196
—
(7 )
Adjustments/Eliminations —
(258 ) 26
283
Consolidated Total $ 2,173
$ —
$ 571
$ 292

Consolidated SCE&G
Millions of dollars External Revenue Operating Income
Earnings Available to
Common Shareholder
Three Months Ended June 30, 2018
Electric Operations $ 553
$ 107
n/a
Gas Distribution 79
—
n/a
Adjustments/Eliminations —
—
$ 26
Consolidated Total $ 632
$ 107
$ 26

Six Months Ended June 30, 2018
Electric Operations $ 1,100
$ 180
n/a
Gas Distribution 234
47
n/a
Adjustments/Eliminations —
—
$ 150
Consolidated Total $ 1,334
$ 227
$ 150

Three Months Ended June 30, 2017
Electric Operations $ 680
$ 247
n/a
Gas Distribution 76
—
n/a
Adjustments/Eliminations —
—
$ 123
Consolidated Total $ 756
$ 247
$ 123

Six Months Ended June 30, 2017
Electric Operations $ 1,259
$ 429
n/a
Gas Distribution 217
44
n/a
Adjustments/Eliminations —
—
$ 231
Consolidated Total $ 1,476
$ 473
$ 231

Segment Assets The Company Consolidated SCE&G
June 30, December 31, June 30, December 31,
Millions of dollars 2018 2017 2018 2017
Electric Operations $ 12,082
$ 11,979
$ 12,082
$ 11,979
Gas Distribution 3,292
3,259
895
869
Gas Marketing 214
230
n/a
n/a
All Other 1,039
1,042
n/a
n/a
Adjustments/Eliminations 2,274
2,229
3,298
3,098
Consolidated Total $ 18,901
$ 18,739
$ 16,275
$ 15,946

~~12.~~

14. AFFILIATED AND RELATED PARTY TRANSACTIONS

~~The Company and Consolidated SCE&G:~~

~~SCE&G~~

DESC owns 40% of Canadys Refined Coal, LLC, which is involved in the manufacturing and sale of refined coal to reduce ~~emissions. SCE&G~~emissions at certain of DESC's generating facilities. DESC accounts for this investment using the equity method. ~~The net~~Purchases and sales of the ~~total purchases and total sales~~related coal are recorded as other income (expense), net in ~~Other expenses on~~ the ~~consolidated statements~~Consolidated Statements of ~~income (for the Company) and of comprehensive income (for Consolidated SCE&G)~~Comprehensive Income (Loss).

Three Months Ended June 30, Six Months Ended June 30,
Millions of Dollars 2018 2017 2018 2017
Purchases from Canadys Refined Coal, LLC $ 44.8
$ 52.8
$ 77.3
$ 97.4
Sales to Canadys Refined Coal, LLC 44.6
52.5
76.9
96.8

Millions of Dollars June 30, 2018 December 31, 2017
Receivable from Canadys Refined Coal, LLC $ 17.3
$ 4.9
Payable to Canadys Refined Coal, LLC 17.4
4.9

~~Consolidated SCE&G:~~

~~SCE&G~~

DESC purchases natural gas and related pipeline capacity from SCANA Energy Marketing, Inc. to serve its retail gas customers and to satisfy certain electric generation requirements.

~~SCANA Services,~~These purchases are included within gas purchased for resale or fuel used in electric generation, as applicable in the Consolidated Statements of Comprehensive Income (Loss).

DESS, on behalf of itself and its parent company, provides the following services to ~~Consolidated SCE&G,~~DESC, which are rendered at direct or allocated cost: information systems, telecommunications, customer support, marketing and sales, human resources, corporate compliance, purchasing, financial, risk management, public affairs, legal, investor relations, gas supply and capacity management, strategic planning, general administrative, and retirement benefits. In addition, ~~SCANA Services~~DESS processes and pays invoices for ~~Consolidated SCE&G~~DESC and is reimbursed. Costs for these services include amounts capitalized. Amounts expensed are primarily recorded in ~~Other operation~~other operations and maintenance - ~~nonconsolidated affiliate~~affiliated suppliers and ~~Other Income (Expense)~~other income (expense), net onin the ~~consolidated statements~~Consolidated Statements of ~~comprehensive income.~~Comprehensive Income (Loss).

	Three Months Ended June 30,				Six Months Ended June 30,
(millions)	2019		2018		2019		2018
Purchases of coal from affiliate	$	34	$	45	$	62	$	77
Sales of coal to affiliate		34		45		62		77
Purchases of fuel used in electric generation from affiliate		10		29		43		60
Direct and allocated costs from services company affiliate⁽¹⁾		82		76		140		135
Operating Revenues - Electric from sales to affiliate		1		1		2		2
Operating Expenses - Other taxes from affiliate		1		1		3		3

(1)	Includes capitalized expenditures of $11 million for both the three months ended June 30, 2019 and 2018, and $20 million and $19 million for the six months ended June 30, 2019 and 2018, respectively.

(millions)	June 30, 2019		December 31, 2018
Receivable from Canadys Refined Coal, LLC	$	10	$	7
Payable to Canadys Refined Coal, LLC		10		7
Payable to SCANA Energy Marketing, Inc.		—		14
Payable to DESS		63		38

~~Consolidated SCE&G has provided $71.0 million in funding to a rabbi trust consolidated with SCANA in~~

In connection with the ~~potential change in control arising~~SCANA Combination, purchases from certain entities owned by Dominion Energy became affiliated transactions. During the ~~Merger Agreement. This funding~~three and six months ended June 30, 2019, DESC purchased electricity generated by two such affiliates, Ridgeland Solar Farm I, LLC and Moffett Solar 1, LLC, totaling $3 million and $4 million, respectively, which is recorded as ~~long-term Other~~purchased power in the Consolidated Statements of Comprehensive Income (Loss). At June 30, 2019, DESC had accounts payable balances to these affiliates totaling $1 million. In addition, during the three and six months ended June 30, 2019, DESC incurred demand and transportation charges from Dominion Energy Carolina Gas Transmission, LLC totaling $17 million and $32 million, respectively, of which $6 million and $9 million, respectively, is recorded as fuel used in electric generation and $11 million and $23 million, respectively, is recorded as gas purchased for resale in the Consolidated Statements of Comprehensive Income (Loss). At June 30, 2019, DESC had an accounts payable balance due to this affiliate ~~assets on the condensed consolidated balance sheet of Consolidated SCE&G.~~

Three Months Ended June 30, Six Months Ended June 30,
Millions of Dollars 2018 2017 2018 2017
Purchases from SCANA Energy $ 28.7
$ 34.3
$ 60.0
$ 58.2
Direct and Allocated Costs from SCANA Services 76.0
82.9
135.4
155.4

Millions of Dollars June 30, 2018 December 31, 2017
Payable to SCANA Energy $ 10.6
$ 10.0
Payable to SCANA Services 43.2
42.0

~~Consolidated SCE&G's money pool borrowings~~totaling $5 million.

Borrowings from an affiliate are described in Note 5. ~~Certain disclosures regarding SCE&G's participation in SCANA's noncontributory defined benefit pension plan and unfunded postretirement health care and life insurance programs are included in Note 9.~~

~~13.~~

15. OTHER INCOME (EXPENSE), NET

Components of other income (expense), net are as follows:

	Three Months Ended June 30,						Six Months Ended June 30,
(millions)	2019			2018			2019			2018
Revenues from contracts with customers	$	2		$	2		$	3		$	3
Other income		2			4			6			130
Other expense		(15	)		(5	)		(25	)		(12	)
Allowance for equity funds used during construction		2			1			2			4
Other income (expense), net	$	(9	)	$	2		$	(14	)	$	125

The Company Consolidated SCE&G
Three Months Ended Six Months Ended Three Months Ended Six Months Ended
June 30, June 30, June 30, June 30,
Millions of dollars 2018 2017 2018 2017 2018 2017 2018 2017
Revenues from contracts with customers $ 5
—
$ 10
—
$ 2
—
$ 3
—
Other income 7
$ 16
136
$ 33
4
$ 7
130
$ 15
Other expense (11 ) (11 ) (20 ) (24 ) (5 ) (6 ) (12 ) (16 )
Allowance for equity funds used during construction 3
9
7
18
1
7
4
16
Other income, net $ 4
$ 14
$ 133
$ 27
$ 2
$ 8
$ 125
$ 15

The recording of revenue from contracts with customers within other income (expense) arose upon the adoption of related accounting guidance described in Note 1, and as permitted, prior periods have not been restated.

Other income in 2018 includes gains from the settlement of interest rate derivatives of ~~approximately~~ $115 million (see Note 7). Non-service cost components of pension and other postretirement benefits are included in ~~Other~~other expense.

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

OF OPERATIONS

Pursuant to General Instruction H of Form 10-Q, SCE&G is permitted to omit certain information related to itself and its consolidated affiliates called for by Item 2 of Part I of Form 10-Q, and instead provide a

MD&A provides management’s narrative analysis of its consolidated results of ~~operation~~operation. MD&A should be read in conjunction with DESC's Consolidated Financial Statements. DESC meets the conditions to file under the reduced disclosure format, and therefore has omitted certain sections of MD&A.

Forward-Looking Statements

This report contains statements concerning DESC’s expectations, plans, objectives, future financial performance and other ~~information described therein. Such information is~~statements that are not historical facts. These statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. In most cases, the reader can identify these forward-looking statements by such words as “anticipate,” “estimate,” “forecast,” “expect,” “believe,” “should,” “could,” “plan,” “may,” “continue,” “target” or other similar words.

DESC makes forward-looking statements with full knowledge that risks and uncertainties exist that may cause actual results to differ materially from predicted results. Factors that may cause actual results to differ are often presented ~~hereunder specifically for Consolidated SCE&G,~~with the forward-looking statements themselves. Additionally, other factors may cause actual results to differ materially from those indicated in any forward-looking statement. These factors include but may be presented alongside information presented for the Company generally. Consolidated SCE&G makes no representation as to information relating solely to SCANA and its subsidiaries (other than Consolidated SCE&G).are not limited to:

•	the ability of DESC to recover through rates certain costs expended on the NND Project, and a reasonable return on those costs, under the SCANA Merger Approval Order and the abandonment provisions of the BLRA or through other means;

•	uncertainties relating to the bankruptcy filing by Westinghouse and WECTEC;

•	further changes in tax laws and realization of tax benefits and credits, and the ability to realize or maintain tax credits and deductions, particularly in light of the abandonment of the NND Project;

•

legislative and regulatory actions, particularly changes related to electric and gas services, rate regulation, regulations governing electric grid reliability and pipeline integrity, environmental regulations including any imposition of fees or taxes on carbon emitting generating facilities, and any actions involving or arising from the abandonment of the NND Project;

•	current and future litigation, including particularly litigation or government investigations or any actions involving or arising from the construction or abandonment of the NND Project, including the possible impacts on liquidity and other financial impacts therefrom;

•	the results of short- and long-term financing efforts, including prospects for obtaining access to capital markets and other sources of liquidity and the effect of rating agency actions on the cost of and access to capital and sources of liquidity of DESC and Dominion Energy;

•

the ability of suppliers, both domestic and international, to timely provide the labor, secure processes, components, parts, tools, equipment and other supplies needed which may be highly specialized or in short supply, at agreed upon quality and prices, for our construction program, operations and maintenance;

•	the results of efforts to ensure the physical and cyber security of key assets and processes;

•	changes in the economy, especially in areas served by DESC;

•	the impact of competition from other energy suppliers, including competition from alternate fuels in industrial markets;

•	the impact of conservation and demand side management efforts and/or technological advances on customer usage;

•	the loss of electricity sales to distributed generation, such as solar photovoltaic systems or energy storage systems;

•	growth opportunities;

•	the effects of weather, especially in areas where the generation and transmission facilities of DESC are located and in areas served by DESC;

•	changes in accounting rules and accounting policies;

•	payment and performance by counterparties and customers as contracted and when due;

•	the results of efforts to license, site, construct and finance facilities, and to receive related rate recovery, for generation and transmission;

•	the results of efforts to operate DESC's electric and gas systems and assets in accordance with acceptable performance standards, including the impact of additional distributed generation;

•

the availability of fuels such as coal, natural gas and enriched uranium used to produce electricity; the availability of purchased power and natural gas for distribution; the level and volatility of future market prices for such fuels and purchased power; and the ability to recover the costs for such fuels and purchased power;

•	the availability and retention of skilled, licensed and experienced human resources to properly manage, operate, and grow DESC's businesses, particularly in light of uncertainties with respect to integration within the combined companies of Dominion Energy;

•	labor disputes;

•	performance of DESC’s pension plan assets and the effect(s) of associated discount rates;

•	inflation or deflation;

•	changes in interest rates;

•	compliance with regulations; and

•	natural disasters, man-made mishaps and acts of terrorism that directly affect our operations or the regulations governing them.

Additionally, other risks that could cause actual results to differ from predicted results are set forth in Part II, Item 1A. Risk Factors in this report.

DESC’s forward-looking statements are based on beliefs and assumptions using information available at the time the statements are made. DESC cautions the reader not to place undue reliance on its forward-looking statements because the assumptions, beliefs, expectations and projections about future events may, and often do, differ materially from actual results. DESC undertakes no obligation to update any forward-looking statement to reflect developments occurring after the statement is made.

RESULTS OF OPERATIONS

FOR THE THREE ~~MONTHS~~ AND SIX MONTHS ENDED JUNE 30, ~~2018~~

2019

AS COMPARED TO THE CORRESPONDING PERIODS IN ~~2017~~

~~The following discussion should be read in conjunction with Management’s Discussion and Analysis of Financial Condition and~~ 2018

Results of Operations appearing in SCANA’s and SCE&G’s Annual Report on Form 10-K for the year ended December 31, 2017. The results of operations of the Company include those of the parent holding company and each of its subsidiaries, including Consolidated SCE&G. Accordingly, discussions regarding the Company's results of operations necessarily include those of Consolidated SCE&G.

	Second Quarter								Year-To-Date
(millions)	2019			2018		$ Change			2019			2018		$ Change
Net income (loss)	$	(70	)	$	31	$	(101	)	$	(1,173	)	$	159	$	(1,332	)

~~Earnings~~

~~Earnings were as follows:~~

Second Quarter Year to Date
The Company 2018 2017 2018 2017
Earnings per share $ 0.06
$ 0.85
$ 1.24
$ 2.04

Consolidated SCE&G
Net income (millions of dollars) $ 31.0
$ 125.7
$ 158.7
$ 238.0

~~The Company's earnings per share and Consolidated SCE&G's net~~

Second Quarter 2019 vs. 2018

Net income reflect the impact of an electric rate reduction made effective for the second quarter of 2018 and the effect of weather in 2018 and 2017, while the Company's earnings per share in 2018 also reflect higher legal costs and costs incurred in connection with the Nuclear Project and the Company's announced merger with Dominion Energy. These and other results are discussed below.

~~Matters Impacting Future Results~~

~~The Company's decision on July 31, 2017~~decreased $101 million, primarily due to stop construction of Unit 2 and Unit 3 and to pursue recovery of the cost of the abandoned Nuclear Project has had and could continue to have significant adverse impacts on the Company's and Consolidated SCE&G's future earnings, cash flows and financial position, including thosecharges related to ~~the ultimate recovery of regulatory assets, the sustainability of tax positions, the results of~~ litigation and the outcome of various regulatory and governmental proceedings and investigations. The Company continues to believe the decision to abandon the Nuclear Project was prudent, and that costs incurred with respect to the Nuclear Project were prudent, and has contested specific challenges to this decision. The Company also believes that the issues related to the recovery of the cost of the abandoned Nuclear Project and related to the rates currently being collected under the BLRA for financing costs should be resolved in future proceedings before the SCPSC. However, based on various events following the abandonment, there is significant uncertainty as to SCE&G's ultimate ability to recover its costs of Unit 2 and Unit 3 and a ~~return on them from its customers.~~voluntary retirement program. These events include the contentious nature of reviews by legislative committees and others, the General Assembly's passage of certain legislation in 2018, including in particular Act 258 discussed below, and the Request being considered by the SCPSC that could result in the permanent suspension of all or a portion of rates currently being collected under the BLRA, as well as the return of such amounts previously collected. There is also significant uncertainty as to the timing and the ultimate resolution of the litigation and the various other proceedings discussed herein.

In 2017, the Company and Consolidated SCE&G determined that a disallowance of recovery of part of the cost of the abandoned Nuclear Project was both probable and reasonably estimable under applicable accounting guidance, and recorded a pre-tax impairment loss with respect to disallowance of unrecovered Nuclear Project costs and other related deferred costs totaling approximately $1.118 billion ($690 million net of tax). In the first quarter of 2018, the Company and Consolidated SCE&G recognized an additional pre-tax impairment loss totaling approximately $3.6 million ($2.7 million net of tax) in order to further reduce to estimated fair value the carrying value of nuclear fuel that had been acquired for use in Unit 2 and Unit 3. See additional discussion at Note 10 to the condensed consolidated financial statements.

It is reasonably possible that further changes in these estimates will occur in the near term and could be material; however, all such changes cannot be reasonably estimated. The impairment loss recorded in 2017 reflects impacts similar to those that would have resulted had the proposed solution announced on November 16, 2017 been implemented. If the merger benefits and cost recovery plan outlined in the Joint Petition is implemented (upon closing of the merger as contemplated in the Merger Agreement), an additional impairment loss and other charges totaling as much as approximately $1.7 billion (approximately $1.3 billion net of tax) would be expected to be recorded.

If (i) the SCPSC does not approve the Joint Petition and instead approves the Request by the ORS; (ii) the BLRA is found to be unconstitutional; or (iii) the General Assembly further amends or revokes the BLRA or approves other legislation with a similar effect, the Company and Consolidated SCE&G may be required to record an additional impairment loss and other charges totaling as much as approximately $4.9 billion (approximately $3.7 billion net of tax). This additional impairment loss would result from the write-off of approximately $3.962 billion in regulatory assets (comprised of the remaining unrecovered Nuclear Project costs of $4.142 billion offset by $180 million in previously impaired costs related to CEC, which would result from the proposals put forward in the Joint Petition not being approved by the SCPSC) and the refund of revised rates collections under the BLRA described above of approximately $2.0 billion (comprised of the $2.1 billion revised rates collections on a cumulative basis as of June 30, 2018, offset by $109.3 million of such collections that have been recorded as revenue subject to refund), net of the monetization of guaranty settlement recorded within regulatory liabilities less amounts that may be required to settle contractor liens. While Act 258 requires the Company and Consolidated SCE&G to refund certain revenues collected from customers effective April 1, 2018, the Company and Consolidated SCE&G do not currently anticipate that any amounts collected prior to April 1, 2018, will be subject to refund (other than amounts arising due to the effects of the Tax Act); however, no assurance can be given as to the outcome of this matter. Were a disallowance ordered of any of the Nuclear Project costs currently deferred as a regulatory asset or were the rates under Act 258 made other than temporary following the SCPSC's final decision on the Joint Petition, and without consideration of any other factors that may be embodied in such an order, an additional pre-tax impairment charge totaling as much as approximately $1.7 billion may be required.

On June 27, 2018, the South Carolina General Assembly adopted Act 258, which became law June 28, 2018, to temporarily reduce the amount SCE&G can collect from customers under the BLRA. Act 258 requires the SCPSC to order a reduction in the portion of SCE&G's retail electric rates associated with the Nuclear Project from approximately 18% of the average residential electric customer’s bill to approximately 3.2%, or a reduction of approximately $31 million per month, retroactive to April 1, 2018. Absent an earlier ruling from the SCPSC, which could be issued only on the SCPSC’s own initiative, these lower rates are to be effective until the SCPSC renders a final decision on the merits of the Joint Petition. On July 2 and 3, 2018, the SCPSC issued orders implementing the temporary rate reduction required by Act 258. Unless the relief discussed in the next paragraph is granted, the new rates and retroactive credits required by Act 258 are to be put into effect with the first billing cycle of August 2018. Retroactive credits for billed and unbilled amounts for the period April 1, 2018 through June 30, 2018 total approximately $109.3 million, which amount has been deferred within Revenue subject to refund on the condensed consolidated balance sheet of the Company and Consolidated SCE&G. The initial recognition of such retroactive credits includes the effects of cycle billing on unbilled usage. In addition to the reduction of electric rates (which rates had been previously approved by the SCPSC), Act 258 alters various procedures previously applicable under the BLRA, including redefining the standard of care required by the BLRA and supplying definitions of key terms that would affect the evidence required to establish SCE&G’s ability to recover its costs associated with the Nuclear Project.

In December 2017, the Tax Act was enacted, resulting in the remeasurement of all federal deferred income tax assets and liabilities to reflect a 21% federal statutory corporate tax rate. Due to the regulated nature of the Company’s and Consolidated SCE&G’s operations, the effect of this remeasurement is primarily reflected in excess deferred income tax balances within regulatory liabilities. As described in Note 2 to the condensed consolidated financial statements, SCE&G and PSNC Energy have responded to orders from state regulators seeking information regarding the effects the Tax Act would have on their respective operations. In 2018, the Company and Consolidated SCE&G are recording estimates of revenue that will be subject to refund to customers of its regulated operations. Such amounts result in reductions to revenue and are deferred within Revenue subject to refund on the condensed consolidated balance sheet. Such reductions in revenue largely correspond to reductions in current period tax expense. Going forward, once state regulators order reductions in customer rates, the lower tax expense resulting from the reduced federal statutory corporate tax rate will result in similar reductions to amounts collected from customers through electric and gas rates, and no significant impact on financial results is expected. However, the refund of revenue collected in 2018 will negatively impact cash flow. In addition, certain of these regulatory liabilities will be amortized to the benefit of customers over the remaining lives of related property in accordance with the normalization provisions of the IRC and Code of Federal Regulations, thereby mitigating any significant negative cash impact due to the extended amortization period. See also Note 6 to the condensed consolidated financial statements for additional discussion related to deferred tax assets and liabilities.

These matters impacting future results are further discussed under Liquidity Considerations and Impact of Abandonment of Nuclear Project within LIQUIDITY AND CAPITAL RESOURCES, in Note 2 and Note 10 to the condensed consolidated financial statements and in Part II, Item 1A. Risk Factors.

~~Dividends Declared~~

On February 22, 2018, SCANA's Board of Directors declared a dividend of $0.6125 per share. This dividend was payable on April 1, 2018 to shareholders of record on March 12, 2018. On June 28, 2018, SCANA's Board of Directors declared a dividend of $0.1237 per share payable on July 18, 2018 to shareholders of record on July 10, 2018. When a dividend payment date falls on a weekend or holiday, the payment is made the following business day. SCANA's Board of Directors evaluates the payment of dividends each quarter.

~~Electric Operations~~

Electric Operations for the Company and for Consolidated SCE&G is comprised of the electric operations of SCE&G, GENCO and Fuel Company. Electric Operations operating income (including transactions with affiliates) was as follows:

The Company Consolidated SCE&G
Second Quarter Year to Date Second Quarter Year to Date
Millions of dollars 2018 2017 2018 2017 2018 2017 2018 2017
Operating revenues $ 553.1
$ 680.1
$ 1,100.5
$ 1,258.6
$ 553.1
$ 680.1
$ 1,100.5
$ 1,258.6
Fuel used in electric generation 155.4
161.2
314.7
297.6
155.4
161.2
314.7
297.6
Purchased power 15.1
20.7
67.2
31.8
15.1
20.7
67.2
31.8
Other operation and maintenance 142.8
123.4
268.8
244.4
146.4
127.0
275.3
251.5
Impairment loss —
—
3.6
—
—
—
3.6
—
Depreciation and amortization 75.8
73.1
151.7
146.1
73.1
70.1
146.1
140.1
Other taxes 57.2
55.6
114.5
110.2
56.5
55.0
113.3
109.1
Operating Income $ 106.8
$ 246.1
$ 180.0
$ 428.5
$ 106.6
$ 246.1
$ 180.3
$ 428.5

Electric operations can be significantly impacted by the effects of weather. SCE&G estimates the effects on its electric business of actual temperatures in its service territory as compared to historical averages to develop an estimate of electric revenue and fuel costs attributable to the effects of abnormal weather. Results in both 2018 and 2017 reflect milder than normal weather in the first quarter, with 2017 being significantly milder than 2018, and warmer than normal weather in the second quarter, with 2018 being significantly warmer than 2017.

The Company and Consolidated SCE&G expect, if Act 258 remains in effect and is implemented, that electric operating revenues will decrease by approximately $31 million each month through the remainder of 2018 when compared to operating revenues recorded in corresponding periods in 2017.

~~Second Quarter~~

Operating revenues decreased in 2018 by $109.3 million due to the recognition of estimated amounts to be refunded to customers as a result of the enactment of Act 258, by $10.9 million due to the recognition of estimated amounts to be refunded to customers as a result of the Tax Act, lower residential and commercial average use of $18.6 million and lower fuel cost recovery of $17.7 million. These revenue decreases were partially offset by the ~~effects~~absence of ~~weather~~a charge associated with South Carolina legislation enacted in the second quarter of ~~$15.7 million, residential and commercial growth of $5.0 million, industrial growth and higher usage of $1.7 million and revenue recognized under the DER program of $4.6 million.~~

~~Fuel used in electric generation and purchased power expenses~~2018.

Year-To-Date 2019 vs. 2018

Net income decreased ~~in 2018~~$1.3 billion, primarily due to ~~lower fuel prices~~charges for refunds of ~~$17.7 million~~amounts previously collected from retail electric customers for the NND Project, certain regulatory assets and ~~lower residential~~utility plant for which DESC committed to forgo recovery, litigation and ~~commercial average use of $5.1 million.~~a voluntary retirement program. These decreases were partially offset by ~~higher amortization~~the absence of ~~DER program costs of $3.8 million, increased sales volumes~~a charge associated with ~~residential and commercial customer growth~~South Carolina legislation enacted in the second quarter of ~~$1.2 million, higher industrial usage~~2018.

Analysis of ~~$1.4 million, higher sales volumes associated with the effects of weather of $4.8 million and higher fuel handling expenses of $0.3 million.~~Consolidated Operations

	Second Quarter								Year-To-Date
(millions)	2019			2018		$ Change			2019			2018		$ Change
Operating revenues	$	698		$	632	$	66		$	363		$	1,334	$	(971	)
Fuel used in electric generation		143			155		(12	)		280			315		(35	)
Purchased power		12			15		(3	)		20			67		(47	)
Gas purchased for resale		44			45		(1	)		121			121		—
Net revenue		499			417		82			(58	)		831		(889	)
Other operations and maintenance		195			164		31			339			310		29
Impairment of assets and other charges		100			—		100			371			4		367
Depreciation and amortization		115			81		34			217			161		56
Other taxes		72			65		7			141			129		12
Other income (expense), net		(9	)		2		(11	)		(14	)		125		(139	)
Interest charges		63			76		(13	)		136			152		(16	)
Income tax expense (benefit)		15			2		13			(103	)		41		(144	)

Second Quarter 2019 vs. 2018

Net revenue increased 20%, primarily due to:

•	The absence of a $109 million charge associated with South Carolina legislation enacted in the second quarter of 2018 that required DESC to temporarily reduce the amount collected from customers under the BLRA; partially offset by

•	A $28 million decrease due to lower South Carolina Commission approved electric rates in 2019 as a result of the SCANA Merger Approval Order.

Other ~~operation~~operations and maintenance ~~expenses~~ increased ~~in 2018~~19%, primarily due to ~~wind down costs associated with the abandonment of the Nuclear Project of $3.4 million, higher legal and other costs~~a charge related to the abandonment of the Nuclear Project of approximately $10.0 million, higher non-labor generation and other electric operations costs of $4.2 million and higher injuries and damages expenses of $3.0 million. These increases werea voluntary retirement program ($50 million), partially offset by lower ~~labor~~legal costs ($9 million) and lower non-labor electric generation expenses ($5 million).

Impairment of ~~$4.4~~assets and other charges increased $100 million, ~~primarily~~ due to ~~lower incentive compensation costs.~~

a charge related to litigation.

Depreciation and amortization increased 42%, primarily ~~due to net plant additions.~~

reflecting the amortization of NND Project costs.

Other taxes increased 11%, primarily due to higher property taxes associated with net plant ~~additions.~~

~~Year to Date~~

Operating revenues decreased in 2018 by $113.7 million pursuant to an SCPSC order whereby fuel cost recovery is offset with gains realized upon the settlement of certain interest rate derivative contracts, as further described in Other Income (Expense) below,additions ($4 million) and a charge related to ~~fuel cost recovery. Operating revenue also~~ a voluntary retirement program ($3 million).

Other income (expense), net decreased ~~by $109.3~~$11 million, primarily due to ~~the recognition of estimated amounts~~a charge related to ~~be refunded to customers as~~ a ~~result of Act 258, by $35.0 million~~voluntary retirement program.

Interest charges decreased 17%, primarily due to ~~the recognition of estimated amounts to be refunded to customers~~lower long-term debt principal balances as a result of the ~~Tax Act,~~debt tender offers completed in the first quarter of 2019.

Income tax expense increased $13 million, primarily due to changes in unrecognized tax benefits ($26 million), partially offset by lower ~~collections under the rate rider for pension costs of $2.6~~pre-tax income ($13 million).

Year-To-Date 2019 vs. 2018

Net revenue decreased by $889 million, primarily due to:

•	A $1.0 billion charge to electric revenue for refunds of amounts previously collected from retail electric customers for the NND Project;

•	An $86 million decrease due to lower South Carolina Commission approved electric rates in 2019 as a result of the SCANA Merger Approval Order;

•	A $12 million decrease in gas revenues due to lower South Carolina Commission approved rates; partially offset by

•	A $114 million increase in electric revenue primarily pursuant to a South Carolina Commission order whereby fuel cost recovery was offset with gains realized upon the settlement of certain interest rate derivative contracts in 2018, as further described in other income (expense) below; and

•	The absence of a $109 million charge associated with South Carolina legislation enacted in the second quarter of 2018 that required DESC to temporarily reduce the amount collected from customers under the BLRA.

Other operations and maintenance increased 9%, primarily due to a charge related to a voluntary retirement program ($50 million), partially offset by lower non-labor electric generation expenses ($9 million) and lower ~~residential~~legal costs ($8 million).

Impairment of assets and ~~commercial average use of $20.7 million. The downward adjustment~~other charges increased $367 million, primarily due to a$266 million charge related to ~~fuel costs recovery had no effect on~~litigation and a $105 million charge for utility plant for which DESC committed to forgo recovery.

Depreciation and amortization increased 35%, primarily reflecting the amortization of NND Project costs.

Other income (expense), net ~~income as it was fully offset by~~ decreased $139 million, primarily due to the ~~recognition within other income~~absence of gains realized upon the settlement of certain derivative interest rate contracts. The lower pension rider collections had no impact on net income as they were fully offset by the recognition, within other operation and maintenance expenses, of lower pension costs. These revenue decreases were partially offset by the effects of weather of $63.2 million, residential and commercial growth of $11.4 million, industrial growth and higher usage of $4.3 million, revenue recognized under the DER program of $6.7 million and higher fuel cost recovery of $30.7 million.

Fuel used in electric generation and purchased power expenses increased due to higher fuel prices of $30.7 million, amortization of DER program costs of $5.4 million, increased sales volumes associated with residential and commercial customer growth of $2.6 million, higher industrial usage of $2.2 million, higher sales volumes associated with the effects of weather of $15.4 million and higher fuel handling expenses of $1.7 million. These increases were partially offset by lower residential and commercial average use of $5.4 million.

Other operation and maintenance expenses increased due to wind down costs associated with the abandonment of the Nuclear Project of $7.1 million, higher legal and other costs related to the abandonment of the Nuclear Project of approximately $10.7 million at the Company and approximately $10.4 million at Consolidated SCE&G, higher non-labor generation and other electric operations costs of $3.2 million and higher injuries and damages expenses of $2.4 million. These increases were partially offset by lower labor costs of $6.2 million, primarily due to lower incentive compensation costs.

~~Impairment loss represents the writedown of nuclear fuel acquired for use in Unit 2 and Unit 3 to its estimated fair value in the first quarter of 2018.~~

~~Depreciation and amortization increased primarily due to net plant additions.~~

~~Other taxes increased primarily due to higher property taxes associated with net plant additions.~~

~~Sales volumes (in GWh) related to the electric operations above, by class, were as follows:~~

Second Quarter Year to Date
Classification 2018 2017 2018 2017
Residential 1,968

1,916
3,955
3,553
Commercial 1,870

1,872
3,574
3,504
Industrial 1,612

1,565
3,101
3,024
Other 149

147
280
281
Total Retail Sales 5,599

5,500
10,910
10,362
Wholesale 244

228
486
441
Total Sales 5,843

5,728
11,396
10,803

~~Second Quarter and Year to Date~~

~~Retail and wholesale sales volumes increased primarily due to the effects of weather.~~

~~Gas Distribution~~

Gas Distribution is comprised of the local distribution operations of SCE&G, and for the Company, also includes PSNC Energy. Gas Distribution operating income (including transactions with affiliates) was as follows:

The Company Consolidated SCE&G
Second Quarter Year to Date Second Quarter Year to Date
Millions of dollars 2018 2017 2018 2017 2018 2017 2018 2017
Operating revenues $ 148.7
$ 140.2
$ 509.7
$ 462.3
$ 79.5
$ 75.9
$ 234.1
$ 216.8
Gas purchased for resale 67.2
61.5
237.8
196.3
45.2
42.1
120.6
108.0
Other operation and maintenance 42.7
43.1
84.7
85.5
17.8
18.7
35.1
36.0
Depreciation and amortization 23.1
21.1
46.0
41.9
7.6
7.2
15.1
14.2
Other taxes 12.2
11.1
24.3
21.9
8.1
7.2
16.2
14.4
Operating Income $ 3.5
$ 3.4
$ 116.9
$ 116.7
$ 0.8
$ 0.7
$ 47.1
$ 44.2

The effect of abnormal weather conditions on gas distribution operating income is mitigated by the WNA at SCE&G and the CUT at PSNC Energy as further described in Revenue Recognition in Note 3 of the condensed consolidated financial statements. The WNA and the CUT do not affect sales volumes.

~~Second Quarter~~

Operating revenues increased at SCE&G primarily due to increased base rates under the RSA of $1.5 million, customer growth of $2.4 million and higher average use of $1.4 million. These increases were partially offset by a decrease of $1.5 million due to the recognition of estimated amounts to be refunded to customers as a result of the Tax Act and lower gas cost recovery of $0.3 million. In addition to these factors, operating revenues at the Company increased due to weather at PSNC Energy of $6.1 million and customer growth of $1.1 million. These increases were partially offset by a CUT adjustment of $3.8 million, decreased cost of gas recoveries of $1.4 million and $1.8 million due to the recognition of estimated amounts to be refunded to customers as a result of the Tax Act.

Gas purchased for resale increased at SCE&G due to higher average use of $1.9 million, increased sales volumes due to weather of $0.8 million and firm customer growth of $1.4 million. These increases were partially offset by lower gas prices of $1.1 million. In addition to these factors, gas purchased for resale at the Company reflects increased sales volumes due to weather at PSNC Energy of $2.8 million. These increases were partially offset by decreased gas costs of $1.4 million and a CUT adjustment of $1.3 million.

~~Other operation and maintenance expenses decreased primarily due to lower labor costs, including lower incentive compensation.~~

~~Depreciation and amortization increased primarily due to net plant additions.~~

~~Other taxes increased primarily due to higher property taxes associated with net plant additions.~~

~~Year to Date~~

Operating revenues increased at SCE&G primarily due to increased base rates under the RSA of $5.9 million, customer growth of $6.2 million, higher average use of $2.6 million and higher gas cost recovery of $6.3 million. These increases were partially offset by a decrease of $4.6 million due to the recognition of estimated amounts to be refunded to customers as a result of the Tax Act. In addition to these factors, operating revenues at the Company increased due to weather at PSNC Energy of $60.0 million, customer growth of $6.2 million and pipeline integrity management tracking recovered costs of $3.9 million. These increases were partially offset by a CUT adjustment of $20.1 million, decreased cost of gas recoveries of $15.6 million and $8.6 million due to the recognition of estimated amounts to be refunded to customers as a result of the Tax Act.

Gas purchased for resale increased at SCE&G due to higher average use of $3.0 million, increased sales volumes due to weather of $13.4 million and firm customer growth of $3.2 million. These increases were partially offset by lower gas prices of $7.1 million. In addition to these factors, gas purchased for resale at the Company reflects increased sales volumes due to weather at PSNC Energy of $29.8 million, customer growth of $2.8 million and the effect of a CUT adjustment that decreased gas purchased for resale by $9.2 million. These increases were partially offset by decreased gas costs of $15.6 million.

~~Other operation and maintenance expenses decreased primarily due to lower labor costs, including lower incentive compensation.~~

~~Depreciation and amortization increased primarily due to net plant additions.~~

~~Other taxes increased primarily due to higher property taxes associated with net plant additions.~~

~~Sales volumes (in MMBTU) related to gas distribution above by class, including transportation, were as follows:~~

The Company Consolidated SCE&G
Second Quarter Year to Date Second Quarter Year to Date
Classification (in thousands) 2018 2017 2018 2017 2018 2017 2018 2017
Residential 4,093
3,202
27,281
19,762
1,432
1,043
8,467
5,948
Commercial 5,361
5,107
17,418
14,576
2,735
2,650
7,153
6,402
Industrial 5,370
4,758
10,878
10,080
4,890
4,347
9,540
9,000
Transportation 13,877
12,494
26,024
23,448
1,570
1,530
3,072
3,086
Total 28,701
25,561
81,601
67,866
10,627
9,570
28,232
24,436

~~Second Quarter~~

Residential and commercial firm sales volumes for the Company and Consolidated SCE&G increased due to customer growth, higher average use and the effects of weather. Industrial firm sales volumes increased at SCE&G due to customer growth and higher average use, and industrial interruptible volumes increased due to higher average use. Industrial sales and transportation volumes at the Company increased due to the effects of weather at PSNC Energy. Transportation volumes also increased at the Company due to a significant customer expansion and increased natural gas fired electric generation within PSNC Energy's territory.

~~Year to Date~~

Residential and commercial firm sales volumes for the Company and Consolidated SCE&G increased due to the effects of weather, customer growth and higher average use. Industrial firm sales volumes increased at SCE&G due to customer growth and higher average use and industrial interruptible volumes decreased due to increased curtailments in 2018. Industrial sales and transportation volumes at the Company increased due to the effects of weather at PSNC Energy. Transportation volumes also increased at the Company due to a significant customer expansion and increased natural gas fired electric generation within PSNC Energy's territory.

~~Gas Marketing~~

Gas Marketing is comprised of the Company's nonregulated marketing operation, SCANA Energy, which operates in the southeast and includes Georgia’s retail natural gas market. Gas Marketing operating revenues and net income were as follows:

Second Quarter Year to Date
Millions of dollars 2018 2017 2018 2017
Operating revenues $ 171.7
$ 216.3
$ 475.8
$ 514.3
Net income 3.6
1.1
20.6
16.2

~~Second Quarter and Year to Date~~

~~Revenues are lower primarily due to lower commodity pricing. Net income increased primarily due to the effects of the Tax Act.~~

~~Other Operating Expenses~~

~~Other operating expenses were as follows:~~

The Company Consolidated SCE&G
Second Quarter Year to Date Second Quarter Year to Date
Millions of dollars 2018 2017 2018 2017 2018 2017 2018 2017
Other operation and maintenance $ 208.3
$ 178.8
$ 410.0
$ 354.0
$ 164.2
$ 145.7
$ 310.4
$ 287.5
Impairment loss —
—
3.6
—
—
—
3.6
—
Depreciation and amortization 99.4
94.6
198.6
189.0
80.7
77.3
161.2
154.3
Other taxes 69.7
67.1
139.6
133.0
64.5
62.2
129.4
123.5

Other operation and maintenance increased primarily due to certain legal and other costs incurred in connection with the Nuclear Project and the proposed merger with Dominion Energy. Other changes in other operating expenses are also largely attributable to the electric operations and gas distribution segments and are addressed in those discussions.

~~Other Income (Expense)~~

Other income (expense) includes the results of certain incidental non-utility activities of regulated subsidiaries, the activities of certain non-regulated subsidiaries, the costs of certain governance activities at the parent company and AFC. AFC is a utility accounting practice under which a portion of the cost of both equity and borrowed funds used to finance construction (which is shown on the condensed consolidated balance sheet as construction work in progress) is capitalized. Each of the Company and Consolidated SCE&G includes an equity portion of AFC in nonoperating income and a debt portion of AFC in interest charges (credits), both of which have the effect of increasing reported net income. Components of other income (expense) and AFC were as follows:

The Company Consolidated SCE&G
Second Quarter Year to Date Second Quarter Year to Date
Millions of dollars 2018 2017 2018 2017 2018 2017 2018 2017
Other income $ 11.6
$ 15.6
$ 145.6
$ 32.5
$ 5.2
$ 7.6
$ 132.6
$ 15.3
Other expense (10.6 ) (10.8 ) (20.2 ) (24.4 ) (5.2 ) (6.6 ) (11.7 ) (16.1 )
AFC - equity funds 3.0
9.1
7.2
18.2
1.3
7.5
4.2
16.1

~~Second Quarter~~

Other income at the Company and at Consolidated SCE&G decreased by $4.0 million due to lower carrying costs on certain regulatory assets. Other expense at the Company and at Consolidated SCE&G decreased $1.8 million and $1.2 million, respectively, due to varying levels of non-service costs components of pension and other postretirement benefit expense recognized within other expense. Equity AFC decreased primarily due to the abandonment of the Nuclear Project.

~~Year to Date~~

~~Other income at the Company and at Consolidated SCE&G increased primarily due to the recognition of $113.7 million of gains realized upon the settlement of certain~~ interest rate derivative contracts ~~and $8.2 million of gains from land sales. The gains related to the settlement of interest rate derivative contracts~~in 2018 ($115 million) that were fully offset by downward adjustments to electric revenues pursuant to a previously received ~~SCPSC~~South Carolina Commission order related to fuel cost recovery and therefore had no effect on net ~~income. These increases were partially offset by $8.1 million of lower carrying costs on certain regulatory assets. Other expense at the Company~~income and ~~at Consolidated SCE&G~~ a charge related to a voluntary retirement program ($9 million).

Interest charges decreased ~~$5.6 million and $4.4 million, respectively, due to varying levels of non-~~

~~service costs components of pension and other postretirement benefit expense recognized within other expense. Equity AFC decreased~~11%, primarily due to ~~the abandonment of the Nuclear Project.~~

~~Interest Expense~~

~~Interest charges increased primarily due to the accrual of interest related to uncertain tax positions and~~ lower long-term debt AFC due to the abandonment of the Nuclear Project. In 2017, certain of such interest accruals were deferred in regulatory assets, and such deferred amounts were subsequently included in an impairment loss recorded in the fourth quarter of 2017.

~~Income Taxes~~

Income tax expense decreased in 2018 due to lower income before taxes and a lower effective tax rate. The lower effective tax rate in 2018 was primarily due to the federal corporate tax rate changing from 35% to 21%principal balances as a result of the ~~Tax Act.~~

~~LIQUIDITY AND CAPITAL RESOURCES~~

The Company and Consolidated SCE&G have experienced significant adverse events leading up to their decision to stop construction of Unit 2 and Unit 3, as well as significant adverse events since that decision was made. These difficulties and other developments occurring prior to the bankruptcy filing by WEC and WECTEC and other matters are describeddebt tender offers completed in Liquidity and Capital Resources and in Note 10 to the consolidated financial statements included in the Company's and Consolidated SCE&G's combined Form 10-K for the year ended December 31, 2017. Significant developments affecting liquidity subsequent to December 31, 2017 are discussed below.

~~Liquidity Considerations~~

The Company and Consolidated SCE&G have significant obligations that must be paid within the next 12 months, including long-term debt maturities and capital lease payments of $568 million for the Company (including $564 million for Consolidated SCE&G), short-term borrowings of $517 million for the Company (including $457 million for Consolidated SCE&G), interest payments of approximately $318 million for the Company (including $238 million for Consolidated SCE&G), future minimum payments for operating leases of $11 million for the Company (including $3 million for Consolidated SCE&G), and revenues collected subject to refund arising from the effects of the Tax Act of approximately $55 million for the Company (including $46 million for Consolidated SCE&G). Working capital requirements, such as those for fuel supply and similar obligations, also arise due to the lag between when such amounts are paid and when related collection of such costs through customer rates occurs. In addition, as described under ~~Impairment Considerations~~ in Note 10 to the condensed consolidated financial statements, SCE&G has been ordered to reduce revised rates previously approved under the BLRA by approximately $279 million in 2018. This reduction assumes that Act 258 remains in effect and is implemented through December 21, 2018, which is the expected pendency of the SCPSC proceeding with respect to the Joint Petition and related dockets, and would include a refund of approximately $109.3 million previously recorded for the period April 1 through June 30, 2018.

hearing on the merits of the Joint Petition before November 1, 2018, and requires it to issue an order on the merits of the Joint Petition by December 21, 2018. In the lawsuit, which was subsequently amended, SCE&G seeks a declaration that the new laws are unconstitutional and asks the court to issue an injunction prohibiting the SCPSC from implementing Act 258. A hearing on SCE&G’s motion for the issuance of a preliminary injunction was held July 30-31, 2018. Dominion Energy and Sedona would not be obligated to complete the pending merger with SCANA if Act 258 remains in effect and is implemented. The Company and Consolidated SCE&G cannot predict the timing or outcome of this matter.

Income tax expense decreased $144 million, primarily due to ~~the portion of the dividend attributable to SCE&G's electric operations and serves to~~lower pre-tax income ($410 million), partially ~~mitigate the liquidity impacts arising from the reduced revenues resulting from the implementation of Act 258. The payment of future dividends will be evaluated quarterly~~offset by ~~the Board of Directors.~~

Management believes as of the date of issuance of this report that it has access to available sources of cash to pay obligations when due over the next 12 months. These sources include committed long-term lines of credit that expire in December 2020 totaling $1.8 billion for the Company (including $1.2 billion for Consolidated SCE&G). In addition, as of the date of issuance of this report, SCE&G continues to collect the BLRA-related customer rates that remain after reductions ordered as a ~~result of Act 258, as well as amounts provided for in other orders~~tax charge related to ~~non-BLRA electric~~regulatory assets for which DESC committed to forgo recovery ($198 million) and ~~gas rates. In 2018, however, certain of SCANA's credit ratings have fallen to below investment grade, which has constrained its ability and that of Fuel Company to issue commercial paper.~~

~~Were the SCPSC to grant the relief sought by ORS~~change in the Request or grant similar relief resulting from legislative action, as further discussed in Note 10 in the condensed consolidated financial statements, an additional impairment loss or other charges totaling as much as approximately $4.9 billion (approximately $3.7 billion net of tax) may be required. Such an impairment loss or other charges would further stress the Company’s and Consolidated SCE&G’s debt to total capitalization ratio and may result in the Company’s and Consolidated SCE&G’s ratio of debt to total capitalization exceeding maximum levels prescribed in their respective credit agreements. Such an event likely would limit the Company’s and Consolidated SCE&G’s ability to borrow under their commercial paper programs and credit facilities and their ability to pay future dividends or may trigger events of default under such agreements.

Known and knowable conditions and events when considered in the aggregate as of the date of issuance of this report do not suggest it is probable that the Company and Consolidated SCE&G will not be able to meet obligations as they come due over the next 12 months. However, possible future actions, including but not limited to actions related to the disallowance of all or part of the remaining unrecovered nuclear regulatory asset, rate reductions, refunds or lawsuits, could have a material adverse impact on the Company’s and Consolidated SCE&G’s financial condition, liquidity, results of operations and cash flows such that management’s conclusion with respect to its ability to pay obligations when due could change.

~~Impact of Abandonment of Nuclear Project~~

Regulatory proceedings being considered by the SCPSC include the Request filed by the ORS which, if granted, would require SCE&G to (1) immediately suspend all revised rates collections from customers which were previously approved by the SCPSC pursuant to the authority of the BLRA, and (2) make credits to future bills or refunds to customers for prior revised rates collections in the event that the BLRA is found to be unconstitutional or the South Carolina General Assembly further amends or revokes it. SCE&G estimates that revised rates collections, including collections related to transmission assets which have been or are expected to be placed into service and prior to implementation of Act 258, total approximately $445 million annually, and such amounts accumulated as of June 30, 2018 total approximately $2.1 billion. In an amendment to the Request, the ORS has asked the SCPSC to consider the most prudent manner by which SCE&G will enable its customers to realize the value of the monetized Toshiba Settlement payments and other payments made by Toshiba towards satisfaction of its obligations to SCE&G. SCE&G's 55% share of such amounts totals $1.098 billion.

Parties who have intervened in the Request or who filed a letter in support of the Request, as amended, include the state's Governor, Office of Attorney General and Speaker of the House of Representatives, the Electric Cooperatives of South Carolina, Santee Cooper, the SCEUC, certain large industrial customers, and several environmental groups. The SCPSC has scheduled a hearing on the Joint Petition and two other dockets related to the Nuclear Project, namely the Request by the ORS and a June 2017 complaint filed by the Friends of the Earth and the Sierra Club, to begin November 1, 2018. This schedule was established in response to legislation described above. SCE&G intends to continue vigorously contesting the Request, but cannot give any assurance as to the timing or outcome of this matter. Any adverse action by the SCPSC, such as that sought by

~~the ORS in the Request, could have a material adverse impact on the Company's and Consolidated SCE&G's results of operations, cash flows and financial condition.~~

Should the SCPSC or a court direct that proceeds arising from the Toshiba Settlement be refunded to customers in the near-term, or direct that such funds be escrowed or otherwise made unavailable to SCE&G, it is anticipated that SCE&G would issue commercial paper, draw on its credit facilities or issue long-term debt to fund such requirement if such sources are available. However, were the SCPSC to rule in favor of the ORS in response to the Request that SCE&G suspend collections from customers of amounts previously authorized under the BLRA, or were other actions of the SCPSC or others taken in order to significantly restrict SCE&G’s access to revenues or impose additional adverse refund obligations on SCE&G, the Company’s and Consolidated SCE&G's assessments regarding the recoverability of all or a portion of the remaining balance of unrecovered Nuclear Project costs (see Note 2 and Note 10 to the condensed consolidated financial statements) would be adversely impacted and additional impairment losses would likely be recorded. Further, the recognition of significant additional impairment losses with respect to unrecovered Nuclear Project costs could increase the Company’s and Consolidated SCE&G’s debt to total capitalization to a level which may limit their ability to borrow under their commercial paper programs or under their credit facilities and also could constitute a default under these credit facilities. Borrowing costs for long-term debt issuances and access to capital markets could also be negatively impacted.

~~For additional background on the Nuclear Project and further details on the matters described above, see Note 10 to the condensed consolidated financial statements under Abandoned Nuclear Project -~~ ~~Toshiba Settlement and Subsequent Monetization~~ ~~and~~ ~~Regulatory, Political and Legal Developments.~~

Adverse developments relating to the WEC bankruptcy, including the decision to stop construction of Unit 2 and Unit 3, and a decline in the regulatory and legislative environment in 2017 and 2018 have caused credit ratings agencies to place SCANA and SCE&G’s credit ratings on negative outlook or evolving status. On January 3, 2018, after SCANA announced a proposed merger with Dominion Energy, each of the three agencies affirmed or reported no change to their respective credit ratings, and one agency revised its rating outlook for SCANA and its rated operating companies from negative to evolving. However, on January 31, 2018, the South Carolina House of Representatives overwhelmingly approved a bill (similar provisions from which later would become Act 258) designed to temporarily repeal rates SCE&G collects under the BLRA. As a result, on February 5, 2018, one agency downgraded its ratings for SCANA and SCE&G, and attributed the downgrade to the passage of this bill and the politically charged environment that is expected to weigh heavily on any decisions by the SCPSC related to SCE&G's electric rates. unrecognized tax benefits ($66 million).

ITEM 4. CONTROLS AND PROCEDURES

As of June 30, 2018, the issuer ratings and the senior unsecured debt ratings for SCANA are considered below investment grade by two agencies; the issuer ratings for SCE&G are considered to be at the threshold for investment grade by two agencies while its senior secured debt ratings remain above investment grade; and the issuer ratings for PSNC Energy are considered to be at the threshold for investment grade by one agency while its senior unsecured debt ratings remain above investment grade. On July 2 and 3, 2018, the agencies affirmed their ratings; however, one agency changed its outlook from review to negative. As a result, all of the ratings for SCANA, SCE&G and PSNC Energy have either a negative or evolving outlook, indicating that the ratings are being scrutinized for possible rating actions either currently or dependent on the outcome of uncertain future events.

During the pendency of SCE&G's lawsuit filed June 29, 2018 in the District Court, as amended, SCE&G may be required to escrow funds or to secure a bond corresponding to the amount it may be required to refund if its lawsuit is unsuccessful. In addition, any adverse final judgment by a court in any matter of litigation, or any levy for amounts assessed by a regulatory agency, including but not limited to matters described in Part II, Item 1. Legal Proceedings, could require the Company and/or Consolidated SCE&G to escrow funds or to post one or more bonds equal to the monetary amount of the judgment or assessment while the decision is being appealed or challenged.

Any actions taken by or anticipated to be taken by regulators or legislators that are viewed as adverse, including a further change to the BLRA or a requirement that SCE&G make additional credits to future bills or refunds to customers or any requirement that SCE&G make such credits or refunds in the absence of the merger being consummated, or deterioration of the rated companies’ commonly monitored financial credit metrics or any additional adverse developments with respect to the Nuclear Project, could further negatively affect their debt ratings. If these rating agencies were to further lower any of these ratings, borrowing costs on new issuances of long-term debt and commercial paper would increase, which could adversely impact financial results, and refinancing opportunities would be limited or eliminated to the extent that the potential pool of investors and funding sources decreased. In addition, further ratings downgrades may result in lower collateral thresholds being applied to the Company's and Consolidated SCE&G's commodity derivatives, or the removal of such thresholds altogether. This action would have the effect of requiring the Company to post additional collateral for commodity derivative instruments with unfavorable fair values. Ratings downgrades have also resulted in prepayments and demands from vendors for letters of credit, cash deposits, or other forms of credit support under certain gas supply and other agreements. SCANA has obtained a letter of credit of $30.4 million in favor of a natural gas distributor, which is in addition to a $3 million letter of credit that

previously existed, and in March 2018, SCE&G borrowed $100 million under a credit agreement to fund a deposit with one of its natural gas transporters. These actions have reduced amounts available under the credit facilities (see Note 5 to the condensed consolidated financial statements). Further ratings downgrades could result in requirements for additional deposits or the provision of additional credit support in order to conduct business under these agreements.

~~Significant Tax Deductions and Credits~~

The Company and Consolidated SCE&G have claimed significant research and experimentation tax deductions and credits related to the design and construction activities of Unit 2 and Unit 3. A significant portion of these claims followed the issuance of final IRS regulations in 2014 regarding such treatment with respect to expenditures related to the design and construction of pilot models. (See also Note 6 to the condensed consolidated financial statements.) The Company and Consolidated SCE&G have also claimed a significant tax deduction related to the decision to stop construction and to abandon the Nuclear Project in 2017. Following that claim and a related carry back of tax net operating losses, on July 2, 2018, the Company received a refund of federal taxes previously paid totaling approximately $206 million.

These tax claims primarily involve the timing of recognition of tax deductions rather than permanent tax attributes, and their permanent attributes (net), as well as most of the interest accruals required to be recorded with respect to them, had been deferred within regulatory assets until December 31, 2017, at which time these deferrals were considered to be impaired. These claims have contributed significantly to the Company’s and Consolidated SCE&G’s cash flows by providing a significant source of capital and lessening the level of debt and equity financing that the Company and Consolidated SCE&G have needed to raise in the financial markets.

The research and experimentation claims made to date are under (or are expected to come under) examination, and are considered controversial by the IRS. Tax deductions which have been claimed in connection with the determination to abandon the construction of Unit 2 and Unit 3 also are considered controversial; therefore, it is also expected that the IRS will examine future tax returns. To the extent that any of these claims are not sustained as ordinary losses on examination or through any subsequent appeal, the Company and Consolidated SCE&G will be required to repay any cash received for tax benefit claims which are ultimately disallowed, along with interest on those amounts. Such amounts could be significant and could adversely affect the Company's and Consolidated SCE&G's liquidity, cash flows, results of operations and financial condition. In certain circumstances, which2019, management considers to be remote, penalties for underpayment of income taxes could also be assessed. Additionally, in such circumstances, the Company and Consolidated SCE&G may need to access the capital markets to fund those tax and interest payments, which could in turn adversely impact their ability to access those markets for other purposes.

~~Other Liquidity Requirements and Restrictions~~

The terms of the Merger Agreement place limits on the Company and its subsidiaries as to certain investing and financing transactions. While the Merger Agreement permits the Company and its subsidiaries to refinance and issue certain long-term debt, make capital expenditures at certain levels, consummate certain planned investments, and make regular quarterly dividend payments to its shareholders at certain levels, transactions above these levels would require consent from Dominion Energy, which consent cannot be unreasonably withheld. Permitted transactions include, but are not limited to, the planned refinancing of $710 million of long-term debt maturing in 2018 at Consolidated SCE&G ($160 million of which matured in June 2018; see Note 5 to the condensed consolidated financial statements), the new issuance of $100 million of long-term debt at PSNC Energy which was completed in June 2018, the purchase of an existing 540-MW gas fired power plant which was completed in May 2018, and the payment by SCANA of regular quarterly dividends to its shareholders subject to certain limits. In addition, SCANA’s Supplementary Key Executive Severance Benefits Plan provides certain payments to qualified senior executive officers in connection with a change in control. In 2018, the Company has provided approximately $116 million in a rabbi trust, designated as irrevocable subject to the change in control, to fund payments pursuant to this and certain other deferred compensation, incentive and retirement plans, which might arise in connection with a change in control and/or a termination of employment or service if and when such payments become due. Under the terms of the rabbi trust, if the change in control does not occur, SCANA could request a return of all or part of those funds.

The Company expects to meet contractual cash obligations in 2018 through internally generated funds and additional short- and long-term borrowings. Subject to the outcome of the regulatory, legislative and legal proceedings discussed above, the Company expects that, barring a future impairment of the capital markets or its access to such markets, it has or can obtain adequate sources of financing to meet its projected cash requirements over the next 12 months, including the cash requirements for refinancing maturing long-term debt. As noted above, adverse developments in regulatory, legislative or legal proceedings could alter these conclusions. The Company's ratio of earnings to fixed charges for the six and 12 months ended June 30, 2018 was 2.17 and (0.04), respectively. Consolidated SCE&G's ratio of earnings to fixed charges for the six and 12 months ended

June 30, 2018 was 2.27 and (0.55), respectively. These ratios reflect impairment losses recorded in 2017 and 2018 related to the Nuclear Project, which are discussed in Note 10 to the condensed consolidated financial statements and in SCANA's and SCE&G's combined Form 10-K for the year ended December 31, 2017. Also, these ratios reflect the 2018 temporary reduction of retail electric rates required by Act 258. See Note 2 and Note 10 to the condensed consolidated financial statements.

SCANA's ability to pay dividends on its common stock may be limited by existing covenants that limit the right of its subsidiaries to pay dividends on their common stock. Further, SCANA has agreed to obtain the consent of Dominion Energy, which consent cannot be unreasonably withheld, prior to making dividend payments to shareholders greater than $0.6125 per share for any quarter while the Merger Agreement is pending. For the quarter ended June 30, 2018, SCANA's board of directors declared a dividend of $0.1237 per share, which represents an approximately 80% reduction from the dividend paid to its shareholders for the quarter ended March 31, 2018. The reduction corresponds to the portion of dividend attributable to SCE&G's electric operations and serves to partially mitigate the liquidity impacts arising from the reduced revenues resulting from the implementation of Act 258. Any determination to pay dividends to holders of SCANA common stock in the future, as well as the amount of any dividend, are subject to approval by the board of directors, and will depend upon many factors that the board of directors deems relevant. Any further or sustained reduction in SCANA's payment of dividends in the future may result in a decline in the value of its common stock. Such a decline in value could limit SCANA's ability to raise debt and equity capital.

Cash requirements for SCANA’s regulated subsidiaries arise primarily from their operational needs, funding their construction programs and payment of dividends to SCANA. The ability of the regulated subsidiaries to replace existing plant investment, to expand to meet future demand for electricity and gas and to install equipment necessary to comply with environmental regulations, will depend on their ability to attract the necessary financial capital on reasonable terms. Regulated subsidiaries recover the costs of providing services through rates charged to customers. Rates for regulated services are generally based on historical costs. As customer growth and inflation occur and these subsidiaries continue their ongoing construction programs, rate increases will be sought. The future financial position and results of operations of regulated subsidiaries will be affected by their ability to obtain adequate and timely rate and other regulatory relief.

Rating agencies consider qualitative and quantitative factors when assessing SCANA and its rated operating companies’ credit ratings, including the legislative and regulatory environment, capital structure and the ability to meet liquidity requirements. As previously noted, adverse developments with respect to recovery of Nuclear Project costs have negatively affected the Company’s and Consolidated SCE&G's debt ratings. Further adverse developments, changes in the legislative and regulatory environment or deterioration of SCANA's or its rated operating companies' commonly monitored financial credit metrics could cause the Company and Consolidated SCE&G to pay higher interest rates on its long- and short-term indebtedness, could limit the Company's and Consolidated SCE&G's access to capital markets and liquidity, and could trigger more stringent collateral requirements on interest rate and commodity hedges and under gas supply agreements and other contracts.

SCE&G has obtained FERC authority to issue short-term indebtedness and to assume liabilities as a guarantor (pursuant to Section 204 of the Federal Power Act). SCE&G may issue unsecured promissory notes, commercial paper and direct loans in amounts not to exceed $1.6 billion outstanding with maturity dates of one year or less, and may enter into guaranty agreements in favor of lenders, banks, and dealers in commercial paper in amounts not to exceed $600 million. GENCO has obtained FERC authority to issue short-term indebtedness not to exceed $200 million outstanding with maturity dates of one year or less. The authority described herein will expire in October 2018. Were adverse developments to occur with respect to uncertainties highlighted elsewhere, the ability of SCE&G or GENCO to secure renewal of this short-term borrowing authority may be adversely impacted.

Cash provided from operating activities in 2017 reflects significant tax benefits (reductions in income tax payments and tax refunds) arising from the deductions previously described under Significant Tax Deductions and Credits. The Company's decision in 2017 to stop construction of Unit 2 and Unit 3 and to abandon the Nuclear Project resulted in a significant tax deduction and an associated NOL for tax purposes. The Company obtained a refund of taxes paid in certain prior years as a result of the carryback of the NOL, and expects to benefit from the carryforward of the NOL in future years. These cash flows are expected to fund operations and may be used to reduce short-term borrowings.

Enactment of the Tax Act resulted in the remeasurement of deferred income tax assets and liabilities and the recognition as regulatory liabilities of certain excess deferred income taxes (see Note 2 and Note 6 to the condensed consolidated financial statements). Certain of these regulatory liabilities will be amortized to the benefit of customers over the remaining lives of related property in accordance with the normalization provisions of the IRC and Code of Federal Regulations, thereby mitigating any significant negative cash impact. However, since the majority of the Company’s and

~~Consolidated SCE&G's businesses are rate regulated, lower income taxes payable in future years due to the Tax Act will also result in lower collections from customers in rates.~~

~~Cash flows from operating activities in 2018 reflect the posting of credit assurance deposits with a natural gas transporter.~~

Cash flows from investing activities in both periods were primarily related to capital expenditures, and in 2018 includes the acquisition of CEC for approximately $180 million. In 2018, investing inflows included proceeds received upon the settlement of certain interest rate swaps.

Cash flows from financing activities in both periods included dividend payments, increases in commercial paper balances and proceeds from the issuance of debt. In 2018, such inflows included proceeds from a draw on a long-term credit facility.

In June 2018, GENCO redeemed at maturity $160 million of 6.06% secured notes at their face value. Funds to pay the notes were primarily borrowings from the utility money pool and a $20 million equity contribution from SCANA.

In June 2018, PSNC Energy issued $100 million of 4.33% senior notes due June 15, 2028. Proceeds from this sale were used to repay short-term debt, to finance capital expenditures, and for general corporate purposes.

In June 2017, PSNC Energy issued $150 million of 4.18% senior notes due June 30, 2047. Proceeds from this sale were used to repay short-term debt, to finance capital expenditures, and for general corporate purposes.

~~OTHER MATTERS~~

For information related to environmental matters, nuclear generation, and claims and litigation, see Note 10 of the condensed consolidated financial statements. For information related to the Company's and Consolidated SCE&G's unrecognized tax benefits, see Note 6 of the condensed consolidated financial statements.

~~ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK~~

~~SCANA:~~

Interest Rate Risk - Interest rates on all outstanding long-term debt are fixed either through the issuance of fixed rate debt or through the use of interest rate derivatives. The Company is not aware of any facts or circumstances that would significantly affect exposures on existing indebtedness in the near future.

For further discussion of changes in long-term debt and interest rate derivatives, including changes in the Company's market risk exposures relative to interest rate risk, see the Liquidity and Capital Resources section in Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations and Notes 2, 5, 7 and 8 of the condensed consolidated financial statements.

Commodity price risk - The Company uses derivative instruments to hedge forward purchases and sales of natural gas, which create market risks of different types. See Note 7 and 8 of the condensed consolidated financial statements. The following tables provide information about the Company’s financial instruments, which are limited to financial positions of SCANA Energy and PSNC Energy, that are sensitive to changes in natural gas prices. Weighted average settlement prices are per 10,000 MMBTU. Fair value represents quoted market prices for these or similar instruments.

Expected Maturity 2018 2019 2020 2021
Futures - Long
Settlement Price (a) 2.97
2.95
2.89
—
Contract Amount (b) 27.1
32.9
2.9
—
Fair Value (b) 27.4
33.0
2.9
—

Futures - Short
Settlement Price (a) 2.91
—
—
—
Contract Amount (b) 0.9
—
—
—
Fair Value (b) 0.9
—
—
—

Options - Purchased Call (Long)
Strike Price (a) 3.26
3.08
—
—
Contract Amount (b) 8.7
10.3
—
—
Fair Value (b) 0.6
0.8
—
—

Options Sold Call (Short)
Strike Price (a) 0.20
—
—
—
Contract Amount (b) 0.3
—
—
—
Fair Value (b) 0.3
—
—
—

Swaps - Commodity
Pay fixed/receive variable (b) 5.6
7.1
3.3
0.3
Average pay rate (a) 3.2210
2.9257
2.8627
2.7890
Average received rate (a) 2.9520
2.8581
2.7039
2.7157
Fair value (b) 5.1
6.9
3.2
0.2

Pay variable/receive fixed (b) 14.5
18.3
3.3
—
Average pay rate (a) 2.9532
2.8607
2.7172
—
Average received rate (a) 3.0556
2.9001
2.8586
—
Fair value (b) 15.0
18.5
3.5
—

Swaps - Basis

Pay variable/receive variable (b) 19.8
15.2
—
—
Average pay rate (a) 2.9162
3.0094
—
—
Average received rate (a) 2.9004
3.0033
—
—
Fair value (b) 19.7
15.2
—
—

(a) Weighted average, in dollars
(b) Millions of dollars


~~ITEM 4.~~	~~CONTROLS AND PROCEDURES~~

~~As of~~ ~~June 30, 2018, management for each of the Registrants~~ has evaluated, with the participation of the CEO and CFO, (a) the effectiveness of the design and operation of disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act) and (b) any change in internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act). Based on this evaluation, the CEO and CFO concluded that, as of June 30, ~~2018~~,2019, these disclosure controls and procedures were effective. There has been no change in internal control over financial reporting during the quarter ended June 30, ~~2018~~2019 that has materially affected or is reasonably likely to materially affect internal control over financial ~~reporting for either of the Registrants.~~

reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

~~SCANA and SCE&G:~~

~~The following describes certain~~

From time to time, DESC is alleged to be in violation or in default under orders, statutes, rules or regulations relating to the environment, compliance plans imposed upon or agreed to by DESC, or permits issued by various local, state and/or federal agencies for the construction or operation of facilities. Administrative proceedings may also be pending on these matters. In addition, DESC is involved in various legal proceedings ~~that originated or have been terminated during the three months ended June 30, 2018 or for which developments have occurred during the period. The Company and Consolidated SCE&G intend~~from time to vigorously contest the lawsuits which have been filed against them. For developments related to these or other proceedings subsequent to June 30, 2018, if any, see Note 2 and Note 10 to the condensed consolidated financial statements. No reference to, or disclosure of, any proceeding, item or matter described below shall be construed as an admission or indication that such proceeding, item or matter is material or that such proceeding, item or matter is required to be referred to or disclosed in this Form 10-Q.

~~Ratepayer Class Actions~~

In May 2018, certain purported ratepayer class actions were consolidated. These include actions which in previous Exchange Act filings were defined as the Cleckley Lawsuit, the Lightsey Lawsuit, and an action filed by plaintiff Edwinda Goodman. The consolidated complaint is styled Richard Lightsey, LeBrian Cleckley, Phillip Cooper ~~et al.~~ ~~on behalf of themselves and all others similarly situated v. SCE&G, SCANA, and the State of South Carolina (the "SCE&G Ratepayer Case") and was filed~~time, whether in the ~~State Court~~ordinary course of Common Pleas in Hampton County (the "Hampton County Court"). The plaintiffs allege, among other things, that SCE&G was negligent and unjustly enriched, breached alleged fiduciary and contractual duties, and committed fraud and misrepresentation in failing to properly managebusiness or particularly following the Nuclear Project, and that SCE&G committed unfair trade practices and violated state anti-trust laws. The plaintiffs seek a declaratory judgment that SCE&G may not charge its customers for any past or continuing costsabandonment of the ~~Nuclear~~NND Project. ~~In addition,~~

See the ~~plaintiffs also seek to have the defendants’ assets frozen and all monies recovered from Toshiba~~following for discussions on various legal, environmental and other sources be placed in a constructive trust for the benefit of ratepayers. The plaintiffs seek specific performance of the alleged implied contract to construct the now abandoned project, as well as compensatory, punitive and statutory treble damages, attorneys’ fees, and any other relief the court deems proper. At June 30, 2018, the Motion for Class Certification and other motions were pending.

On September 7, 2017, a purported class action was filed against Santee Cooper, SCE&G, Palmetto Electric Cooperative, Inc. and Central Electric Power Cooperative, Inc. by plaintiff Jessica Cook, on behalf of herself and all others similarly situated (the "Santee Cooper Ratepayer Case") in the Hampton County Court. The plaintiff makes substantially similar allegations as the SCE&G Ratepayer Case. The plaintiff seeks a declaratory judgment that defendants may not charge the purported class for reimbursement for past or future costs of the Nuclear Project, as well as other compensatory and statutory treble damages, attorneys’ fees, and any other relief the court deems proper. On March 27, 2018, the plaintiff and additional named plaintiffs filed an amended complaint including as additional named defendants current and former directors of Santee Cooper and SCANA. On June 25, 2018, Santee Cooper filed a Notice of Petition for Original Jurisdiction with the Supreme Court of South Carolina, which Notice was pending at June 30, 2018.

On January 31, 2018, a purported class action was filed by Plaintiff Timothy Glibowski, on behalf of himself and all others similarly situated, in the District Court (the "Glibowski Lawsuit"). The action, as subsequently amended on April 23, 2018, is against SCANA, SCE&G, Kevin Marsh, Jimmy Addison, Stephen Byrne, Martin Phalen, Mark Cannon, Russell Harris, Ronald T. Lindsay, James Micali, and Lonnie Carter. The plaintiff alleges, among other things, that the Company, SCE&G and the individual defendants participated in an unlawful racketeering enterprise in violation of RICO 18 U.S.C. §1961 et seq., and conspired to violate RICO 18 U.S.C. §1962(c) by fraudulently inflating utility bills to generate unlawful proceeds. Plaintiff seeks treble damages, attorneys’ fees, and any other relief the court deems proper. As amended, the Glibowski Lawsuit effectively consolidated the claims brought by Christine Delmater as reported in previous Exchange Act filings. The case Christine Delmater ~~et al. v. SCANA was dismissed on May 18, 2018.~~

~~State Court Shareholder Derivative Actions~~

On September 26, 2017, a purported shareholder derivative action was filed against defendants Kevin Marsh, Gregory Aliff, James Bennett, John Cecil, Sharon Decker, Maybank Hagood, Lynne Miller, James Roquemore, Maceo Sloan, Alfredo Trujillo, Jimmy Addison, Stephen Byrne, and nominal defendant SCANA by plaintiff John Crangle, purportedly on behalf of SCANA, in the State Court of Common Pleas in Richland County, South Carolina (the "Richland County Court") (the "Crangle Lawsuit"). The plaintiff alleges, among other things, that the defendants breached their fiduciary duties to shareholders by their gross mismanagement of the Nuclear Project, and that the defendants Marsh, Addison, and Byrne were unjustly enriched by bonuses they were paid in connection with the project. The plaintiff seeks compensatory and consequential damages, attorneys’ fees, and any other relief the court deems proper. Defendants filed a Motion for Consolidation and appointment of lead

plaintiff's counsel in this case and the Todd Lawsuit (as hereinafter defined) on November 29, 2017, and also filed a motion to have these cases transferred to the Richland County Business Court. On January 8, 2018, the court notified the parties that the Crangle Lawsuit and the Todd Lawsuit would be transferred to the Business Court Pilot Program in Richland County. On March 5, 2018, Defendants' Motion to Stay these shareholder derivative actions pending the resolution of the ongoing related regulatory proceedings ~~ratepayer class actions, securities class actions, and government investigations was denied. On May 9, 2018, defendants' Motion for Consolidation was denied. At June 30, 2018, various motions~~ to ~~dismiss remain pending.~~which DESC is a party, which information is incorporated herein by reference:

•	Notes 2 and 11 to the Consolidated Financial Statements in DESC’s Annual Report on Form 10-K for the year ended December 31, 2018.

•	Note 10 to the Consolidated Financial Statements in DESC’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2019.

On October 30, 2017, a purported shareholder derivative action was filed by plaintiff R. Wayne Todd, purportedly on behalf of SCANA, in Richland County Court (the “Todd Lawsuit”). The defendants named in the Todd Lawsuit are identical to those of the Crangle Lawsuit. The plaintiff also makes substantially similar allegations as those alleged in the Crangle Lawsuit, and alleges that the defendants Marsh, Addison, and Byrne were unjustly enriched by bonuses they were paid in connection with the Nuclear Project. The plaintiff seeks compensatory and consequential damages, punitive damages, attorneys’ fees, and any other relief the court deems proper. While the Todd Lawsuit has not been consolidated with the Crangle Lawsuit, these cases are being heard by the same judge, and the disposition and pendency of various motions made by the defendants and the plaintiff are the same and are described above with the Crangle Lawsuit.

•	Note 11 to the Consolidated Financial Statements in this report.

On December 13, 2017, a purported shareholder derivative action was filed against Kevin Marsh, Jimmy Addison, Stephen Byrne, Maybank Hagood, Lynne Miller, James Bennett, Maceo Sloan, Sharon Decker, James Roquemore, Alfredo Trujillo, John F.A.V. Cecil, Gregory Aliff, James Micali, Harold Stowe, and nominal defendant SCANA by plaintiff Firemen's Retirement System of St. Louis, purportedly on behalf of SCANA, in the Richland County Court. The plaintiff makes substantially similar allegations as those alleged in the Crangle and Todd Lawsuits. On January 8, 2018, the court notified the parties that this lawsuit, the Crangle Lawsuit and the Todd Lawsuit would be consolidated in the Business Court Pilot Program in Richland County. On January 12, 2018, the suit was amended to add Dominion Energy and Sedona as defendants and to assert putative class action claims alleging, among other things, that defendants violated their fiduciary duties to shareholders by executing a merger agreement that unfairly deprived plaintiffs of the true value of their SCANA stock, and that Dominion Energy and Sedona aided and abetted these actions. Among other remedies, the plaintiff seeks to enjoin defendants from finalizing and consummating the proposed merger and seeks compensatory and consequential damages, injunctive relief, restitution, attorneys’ fees, and any other relief the court deems proper. On February 21, 2018, Dominion Energy removed the case to the District Court. On June 27, 2018, the case was remanded back to the Richland County Court.

On January 23, 2018, a purported class action was filed against SCANA, Dominion Energy, Sedona, Jimmy Addison, Gregory Aliff, James Bennett, John Cecil, Sharon Decker, Maybank Hagood, Lynne Miller, James Roquemore, Maceo Sloan, and Alfredo Trujillo, by plaintiff City of Warren Police and Fire Retirement System in the State Court of Common Pleas in Lexington County, South Carolina (the "Lexington County Court"). The plaintiff alleges, among other things, that defendants violated their fiduciary duties to shareholders by executing a merger agreement that would unfairly deprive plaintiffs of the true value of their SCANA stock, and that Dominion Energy and Sedona aided and abetted these actions. Among other remedies, the plaintiff seeks to enjoin and/or rescind the proposed merger, as well as unspecified monetary damages, attorneys’ fees, costs and any other relief the court deems proper. On February 21, 2018, Dominion Energy removed the case to the District Court, and filed its Motion to Dismiss on March 9, 2018. On June 27, 2018, the case was remanded back to the Lexington County Court.

On February 8, 2018, a purported class action was filed against Gregory Aliff, James Bennett, John Cecil, Sharon Decker, Maybank Hagood, Lynne Miller, James Roquemore, Maceo Sloan, Alfredo Trujillo, Dominion Energy, and Sedona by plaintiffs Metzler Asset Management GmbH and Joseph Heinz in the Richland County Court. The plaintiffs allege, among other things, that defendants violated their fiduciary duties to shareholders by executing a merger agreement that would unfairly deprive plaintiffs of the true value of their SCANA stock, and that Dominion Energy and Sedona aided and abetted these actions. Among other remedies, the plaintiffs seek to enjoin and/or rescind the proposed merger, as well as unspecified monetary damages, attorneys’ fees, and any other relief the court deems proper. On February 21, 2018, Dominion Energy removed the case to the District Court, and filed its Motion to Dismiss on March 9, 2018. At June 30, 2018, the Motion to Dismiss was pending.

~~Federal Court Shareholder Derivative Actions~~

On November 21, 2017, a purported shareholder derivative action was filed against Kevin Marsh, Gregory Aliff, James Bennett, John Cecil, Sharon Decker, Maybank Hagood, Lynn Miller, James Roquemore, Maceo Sloan, Aldredo Trujillo, Jimmy Addison, Stephen Byrne, and SCANA by plaintiff Colleen Witmer, purportedly on behalf of SCANA in the District Court (the "Witmer Lawsuit"). The plaintiff alleges, among other things, that the defendants violated their fiduciary duties to shareholders by disseminating false and misleading information about the Nuclear Project, failing to maintain proper internal controls, failing to properly oversee and manage the company, and that the individual defendants were unjustly enriched in their

compensation. The plaintiff seeks compensatory and consequential damages, disgorgement of compensation, punitive damages, attorneys’ fees, and any other relief the court deems proper. On January 23, 2018, the District Court granted consolidation of the Wickstrom Lawsuit (as hereinafter defined), and the Witmer Lawsuit, and granted plaintiffs’ requests for appointment of lead counsel. The consolidated case is captioned ~~In re SCANA Corporation Derivative Litigation. On January 30, 2018, the plaintiffs filed their consolidated amended complaint. On June 27, 2018, the court denied defendants' motions to dismiss.~~

On November 22, 2017, a purported shareholder derivative action was filed against Kevin Marsh, Gregory Aliff, James Bennett, John Cecil, Sharon Decker, Maybank Hagood, Lynn Miller, James Roquemore, Maceo Sloan, Aldredo Trujillo, and SCANA by plaintiff Richard Wickstrom, purportedly on behalf of SCANA in the District Court (the "Wickstrom Lawsuit"). The plaintiff alleges, among other things, that the defendants violated their fiduciary duties to shareholders by affirmatively making and allowing material misstatements to be made to shareholders regarding the Nuclear Project. The plaintiff seeks compensatory and consequential damages, disgorgement of Marsh’s compensation, attorneys’ fees, and any other relief the court deems proper. As noted, on January 23, 2018, this case was consolidated and is captioned ~~In re SCANA Corporation Derivative Litigation~~.

~~Federal Court 10b-5 and Merger Actions~~

On September 27, 2017, a purported class action was filed against SCANA, Kevin B. Marsh, Jimmy E. Addison, and Stephen A. Byrne by plaintiff Robert L. Norman, on behalf of himself and all others similarly situated, in the District Court (the "Norman Lawsuit"). The plaintiff alleges, among other things, that the defendants violated §10(b) of the Exchange Act and Rule 10b-5 promulgated thereunder, and that the individual named defendants are liable under §20(a) of the Exchange Act. The plaintiff seeks compensatory and consequential damages, attorneys’ fees, and any other relief the court deems proper. On January 23, 2018, the District Court granted consolidation of the Norman Lawsuit, the Evans Lawsuit, the Fox Lawsuit, and the West Palm Beach Lawsuit, (as such terms are hereinafter defined), and granted plaintiffs’ requests for appointment of lead counsel. The consolidated case is captioned ~~In re SCANA Corporation Securities Litigation.The plaintiffs filed a consolidated amended complaint on March 30, 2018. At June 30, 2018, the defendants' motions to dismiss were pending.~~

On October 5, 2017, a purported class action was filed against SCANA, Kevin B. Marsh, and Jimmy E. Addison by plaintiff Kenneth Evans on behalf of himself and all others similarly situated in the District Court (the "Evans Lawsuit"). The plaintiff makes substantially similar allegations as those alleged in the Norman Lawsuit, and seeks substantially similar relief. As noted, on January 23, 2018, this case was consolidated and is captioned ~~In re SCANA Corporation Securities Litigation~~.

On November 10, 2017, a purported class action was filed against SCANA, Kevin Marsh, Jimmy Addison, and Steve Byrne by plaintiff Marsha Fox on behalf of herself and all others similarly situated in the District Court (the "Fox Lawsuit"). The plaintiff makes substantially similar allegations as those alleged in the Norman Lawsuit, and seeks substantially similar relief. As noted, on January 23, 2018, this case was consolidated and is captioned ~~In re SCANA Corporation Securities Litigation~~.

On November 17, 2017, a purported class action was filed against SCANA, Kevin B. Marsh, Jimmy E. Addison, and Steve B. Byrne by plaintiff West Palm Beach Firefighters’ Pension Fund on behalf of itself and all others similarly situated in the District Court (the "West Palm Beach Lawsuit"). The plaintiff makes substantially similar allegations as those alleged in the Norman Lawsuit, and seeks substantially similar relief. As noted, on January 23, 2018, this case was consolidated and is captioned ~~In re SCANA Corporation Securities Litigation~~.

On March 15, 2018, a purported class action was filed against SCANA, Dominion Energy, Sedona, Jimmy E. Addison, Gregory E. Aliff, James A. Bennett, John F.A.V. Cecil, Sharon A. Decker, D. Maybank Hagood, Lynne M. Miller, James W. Roquemore, Maceo K. Sloan, and Alfredo Trujillo by plaintiff Mary Turner, on behalf of herself and all others similarly situated in the District Court. The plaintiff alleges, among other things, that the defendants violated provisions of Section 14(a) of the Exchange Act and SEC Rule 14a-9 by allowing or causing misleading proxy statements to be issued. The plaintiffs alternatively seek to enjoin the merger, monetary damages, attorneys’ fees, and any other relief the court deems proper. The defendants' motions for extension of time to respond to the plaintiff's Complaint have been granted. Defendants' responses are due July 31, 2018.

~~FILOT Litigation~~

On November 29, 2017, Fairfield County filed a Complaint and a Motion for Temporary Injunction against SCE&G in the State Court of Common Pleas in Fairfield County, making allegations of breach of contract, fraud, negligent misrepresentation, breach of fiduciary duty, breach of the implied duty of good faith and fair dealing, and unfair trade practices related to SCE&G’s termination of the FILOT agreement between SCE&G and Fairfield County, related to Unit 2 and Unit 3.

Plaintiff sought a temporary and permanent injunction to prevent SCE&G from terminating the FILOT; actual and consequential damages; treble damages; punitive damages; and attorneys’ fees. Plaintiff sought a hearing within ten days on their motion for temporary injunction. The court heard arguments on December 15, 2017 on the motion for temporary injunction, and asked the parties to submit supplemental briefing and proposed orders by December 20, 2017. Plaintiff voluntarily withdrew the Motion for Temporary Injunction on December 20, 2017. On April 12, 2018, the court denied SCE&G's Motion to Transfer Venue. On May 9, 2018, the defendant served its written responses to the plaintiff's interrogatories and documents responsive to the plaintiff's request for production. On May 31, 2018, the plaintiff issued a subpoena for production of evidence to Ernst & Young with respect to SCANA's income tax reporting position as it pertains to the Nuclear Project and the FILOT. On June 13, 2018, Ernst & Young objected to the subpoena. At June 30, 2018, the defendant's motion to dismiss was pending.

~~Regulatory and Governmental Proceedings and Investigations~~

On January 26, 2018, the DOR notified SCANA that it was initiating an audit of SCE&G's sales and use tax returns for the periods September 1, 2008 through December 31, 2017. The Company and Consolidated SCE&G understand that the DOR's position is that the exemption for sales and use tax for purchases related to the Nuclear Project should not apply because Unit 2 and Unit 3 will not be placed into service and no electricity will be manufactured for sale. On April 6, 2018, SCE&G responded to the DOR in a letter setting out certain reasons why SCE&G believes the exemptions apply and the audit is improper. On June 1, 2018, SCE&G received from the DOR a notice of proposed assessment arising from that audit of approximately $410 million plus $10.9 million in interest. Under the South Carolina Revenue Procedures Act, SCE&G has 90 days, or until August 30, 2018, to provide a protest to the proposed assessment. The Company and Consolidated SCE&G intend to vigorously contest the DOR's position.

~~Employment Class Action~~

On August 8, 2017, a purported class action was filed against SCANA, SCE&G, and its co-defendants Fluor and Fluor Enterprises, Inc., by plaintiffs Harry Pennington III and Timothy Lorenz, on behalf of themselves and all others similarly situated, in the District Court. The plaintiffs allege, among other things, that the defendants violated the WARN Act in connection with the decision to stop construction on the Nuclear Project. The plaintiffs allege that the defendants failed to provide adequate advance written notice of their terminations of employment. SCANA's and SCE&G's Motion to Dismiss has been denied.

~~Act 258 and S. 954~~

On June 29, 2018, SCE&G filed a lawsuit in the District Court challenging the constitutionality of Act 258 along with joint resolution S. 954, which became law on July 2, 2018. Among other things, S. 954 prohibits the SCPSC from holding a hearing on the merits of the Joint Petition before November 1, 2018, and requires it to issue an order on the merits of the Joint Petition by December 21, 2018. In the lawsuit, SCE&G seeks a declaration that the new laws are unconstitutional and asks the court to issue an injunction prohibiting the SCPSC from implementing Act 258. A hearing on SCE&G’s motion for the issuance of a preliminary injunction was scheduled to begin July 30, 2018.

ITEM 1A. RISK FACTORS

~~The~~

DESC’s business is influenced by many factors that are difficult to predict, involve uncertainties that may materially affect actual results and are often beyond its control. A number of these risk factors ~~from the Registrants' combined~~have been identified in DESC’s Annual Report on Form 10-K for the year ended December 31, ~~2017,~~2018, which should be taken into consideration when reviewing the information contained in this report. DESC filed such annual report on a combined basis with SCANA. Accordingly, the information presented in such risk factors is presented on a combined basis and ~~Quarterly~~therefore some of the information may apply only to SCANA and not DESC. DESC makes no representation as to any such information. There have been no material changes with regard to the risk factors previously disclosed in DESC's Annual Report on Form ~~10-Q~~10-K for the ~~quarter~~year ended ~~March 31, 2018, have been updated and are restated below in their entirety.~~

~~The risk factors that follow relate in each case to the Company, and where indicated the risk factors also relate to Consolidated SCE&G.~~

The completion of the merger is subject to the receipt of consents, approvals and/or findings from governmental entities, which may impose conditions that could have an adverse effect on Dominion Energy or SCANA or could cause either Dominion Energy or SCANA to terminate the merger. The completion of the merger is also subject to there having not been certain substantive changes in certain South Carolina laws that have or would reasonably be expected to have an adverse effect on SCANA or its subsidiaries or changes in law that impose any condition that would reasonably be expected to result in specified changes to the Joint Petition. Additionally, any such changes in certain South Carolina law could affect the considerations which were relied upon by SCANA and/or Dominion Energy prior to the signing of the Merger Agreement.

Dominion Energy and SCANA are not required to complete the merger until after the requisite authorizations, approvals, consents and/or permits are received from the FERC, NRC, SCPSC, NCUC and GPSC. The FERC and the GPSC have approved the merger. Any of the remaining relevant governmental entities may oppose the merger, fail to approve the merger, fail to make required findings in favor of the merger, or impose certain requirements or obligations as conditions for their consent, approval or findings or in connection with their review. Regulatory approvals of the merger or findings with respect to the merger may not be obtained on a timely basis or at all, and such approvals or findings may include conditions that could have an adverse effect on the Company or Consolidated SCE&G, and/or result in the termination of the merger. No assurance can be given that the necessary approvals or findings will be obtained or that any required conditions will not have an adverse effect on Dominion Energy following the merger. Notwithstanding the approval of the Merger Agreement by SCANA shareholders at a special meeting on July 31, 2018, Dominion Energy or SCANA may make decisions after the special meeting to waive a condition or approve certain actions required to obtain regulatory approvals or findings without seeking further approval of the SCANA shareholders.

Subject to the terms and conditions set forth in the Merger Agreement, the Merger Agreement requires Dominion Energy to accept conditions from regulators that could adversely impact Dominion Energy after the merger without either of Dominion Energy or SCANA having the right to refuse to close the merger on the basis of those regulatory conditions, except that Dominion Energy is generally not required, and SCANA is generally not permitted without Dominion Energy’s prior approval, to take any action or accept any condition that results in a burdensome condition.

In addition, the Merger Agreement provides that Dominion Energy (but not SCANA) will have the right to refuse to complete the merger if, since the date of the Merger Agreement, any governmental entity shall have enacted any order, or there shall have been any change in law (including the BLRA and the other laws governing South Carolina public utilities), which imposes any material change to the terms, conditions or undertakings set forth in the Joint Petition, or any significant changes to the economic value of the Joint Petition, in each case as determined by Dominion Energy in good faith. One such law (Act 258) could affect the economic value of the Joint Petition. See additional discussion in the next paragraph.

The Merger Agreement further provides that Dominion Energy (but not SCANA) will have the right to refuse to complete the merger if there shall have occurred any substantive change in the BLRA or other laws governing South Carolina public utilities which has or would reasonably be expected to have an adverse effect on SCANA or any of its subsidiaries. One such law (Act 258) makes substantive changes to the BLRA and orders the SCPSC to temporarily reduce collections from rates previously approved by the SCPSC under the BLRA. SCE&G has filed a lawsuit in the District Court challenging the constitutionality of Act 258. If Act 258 remains in effect and is implemented, Dominion Energy would not be obligated to complete the merger.

Certain lawsuits and regulatory actions have been filed against SCANA and SCE&G, and several motions are currently pending, in connection with the abandonment of the Nuclear Project. If the relief requested in these matters (including a request for declaratory judgment that the BLRA is unconstitutional) is granted, Dominion Energy might not be obligated to complete the merger.

No assurance can be given that these risks will not materialize and either adversely impact Dominion Energy after the completion of the merger or, if such conditions rise to the thresholds discussed above, some of which, as described above, are in the subjective determination of Dominion Energy acting in good faith, or if the required authorizations, approvals, consents and/or permits are not obtained or received, result in the termination of the merger and adversely impact the results of operations, cash flows and financial conditions of the Company and Consolidated SCE&G.

~~Failure to complete the merger could negatively impact the stock price and the future business and financial results of SCANA.~~

If the merger is not completed, the ongoing business of the Company and Consolidated SCE&G may be adversely affected and the Company and Consolidated SCE&G could be subject to several risks, including the following:

~~the price of SCANA common stock may decline to the extent that the current market price reflects an expectation by the market that the merger will be completed;~~

~~obligations to pay certain costs relating to the merger, such as legal, accounting, financial advisory, filing, proxy solicitation, printing and mailing fees;~~

the disruption of the Company’s and Consolidated SCE&G’s ongoing business or inconsistencies in its services, standards, controls, procedures and policies due to management’s focus on the merger, any of which could adversely affect the ability of the Company and Consolidated SCE&G to maintain relationships with customers, regulators, vendors and employees, or could otherwise adversely affect the business and financial results of the

~~Company or Consolidated SCE&G, without realizing any of the benefits of having the merger completed;~~

the potential negative impact on the Company and Consolidated SCE&G of ultimately resolving the rate and regulatory issues, including pending investigations and legal challenges, relating to the abandonment of the Nuclear Project in a manner satisfactory to SCANA on account of SCANA working with Dominion Energy to pursue the resolution of these issues as contemplated by the Merger Agreement rather than pursuing its regulatory and legal options for resolving these issues independently of considerations and obligations related to the merger; and

the loss of other opportunities that could be beneficial to the Company and Consolidated SCE&G that could have been pursued during the pendency of the merger, without realizing any of the benefits of having the merger completed.

~~In addition to the above risks, SCANA may be required, under certain circumstances, to pay to Dominion Energy a termination fee of $240 million.~~

~~If the merger is not completed, no assurance can be given that these risks will not materialize and will not materially adversely affect SCANA's business, financial results and stock price.~~

The Merger Agreement contains provisions that limit SCANA’s ability to pursue alternatives to the merger, which could discourage a potential competing acquirer of SCANA or could result in any competing proposal being at a lower price than it might otherwise be.

The Merger Agreement contains provisions that, subject to certain exceptions, restrict SCANA’s ability to initiate, solicit, knowingly encourage, facilitate or discuss competing third-party proposals to acquire all or a significant part of SCANA, or provide information to a third party that could reasonably be expected to lead to such a proposal. In addition, Dominion Energy generally has an opportunity to offer to modify the terms of the merger in response to any superior acquisition proposal that may be made before the SCANA board of directors is permitted to withdraw or qualify its recommendation. In some circumstances on termination of the Merger Agreement, SCANA may be required to pay to Dominion Energy a termination fee of $240 million.

These provisions, which the SCANA board regards as customary for transactions of this type, could discourage a potential competing acquirer that might have an interest in acquiring all or a significant part of SCANA from considering or proposing that acquisition, even if it were prepared to pay consideration with a higher per share cash or market value than the merger consideration, or might result in a potential competing acquirer proposing to pay a lower price than it might otherwise have proposed to pay because of the added expense of the termination fee that may become payable by SCANA in certain circumstances.

~~The pendency of the merger could adversely affect the business and operations of SCANA.~~

In connection with the pending merger, some current or prospective customers or vendors of SCANA’s utilities may delay or defer decisions regarding their existing or proposed relationships with those utilities, which could negatively impact the operations, revenues, earnings, cash flows and expenses of the Company and Consolidated SCE&G, regardless of whether the merger is completed. Similarly, current and prospective employees of SCANA and its utilities may experience uncertainty about their future roles following the merger, which may adversely affect the ability of SCANA and its utilities to attract and retain key personnel during the pendency of the merger. In addition, due to operating covenants in the Merger Agreement, during the pendency of or following the merger, SCANA and its utilities may be unable to pursue strategic transactions, undertake significant capital projects, undertake certain significant financing or other specified transactions or pursue actions that are not in the ordinary course of business, even if such actions would prove beneficial.

~~Following the merger, Dominion Energy may be unable to successfully integrate the Company’s and Consolidated SCE&G’s businesses.~~

Dominion Energy and SCANA currently operate as independent public companies. After the merger, Dominion Energy will be required to devote significant management attention and resources to integrating the Company’s and Consolidated SCE&G’s~~business. Potential difficulties Dominion Energy may encounter in the integration process include the following:~~

~~the complexities associated with integrating SCANA and its utility businesses, while at the same time providing consistent, high quality services;~~

~~the complexities of integrating a company with different core services, markets and customers;~~

~~the inability to attract and retain key employees;~~

~~potential unknown liabilities and unforeseen increased expenses, delays or regulatory conditions associated with the merger;~~

~~difficulties in managing political and regulatory conditions related to SCANA’s utility businesses after the merger;~~

the cost recovery plan outlined in the Joint Petition includes a moratorium on filing requests for adjustments in SCANA’s base electric rates until 2021 if the merger is approved by the SCPSC, which would limit Dominion Energy’s ability to recover increases in non-fuel related costs of electric operations for SCE&G’s customers; and

~~performance shortfalls as a result of the diversion of Dominion Energy management’s attention caused by completing the merger and integrating SCANA’s utility businesses.~~

For these reasons, it is possible that the integration process following the merger could result in the distraction of Dominion Energy’s management, the disruption of Dominion Energy’s ongoing business or inconsistencies in its services, standards, controls, procedures and policies, any of which could adversely affect the ability of Dominion Energy to maintain or establish relationships with current and prospective customers, vendors and employees or could otherwise adversely affect the business and financial results of Dominion Energy.

Dominion Energy, the Company and Consolidated SCE&G have been and may continue to be adversely affected by negative publicity related to the merger and in connection with other related matters, including the abandonment of the Nuclear Project.

Political and public sentiment in connection with the merger and in connection with other matters, including the abandonment of the Nuclear Project, have resulted in and may continue to result in a significant amount of adverse press coverage and other adverse public statements affecting Dominion Energy and the Company and Consolidated SCE&G. Adverse press coverage and other adverse statements, whether or not driven by political or public sentiment, may also result in further investigations by regulators, legislators and law enforcement officials or in legal claims. Responding to these investigations and lawsuits, regardless of the ultimate outcome of the proceedings, as well as responding to and addressing adverse press coverage and other adverse public statements, can divert the time and effort of senior management from the management of Dominion Energy’s, the Company’s and Consolidated SCE&G’s respective businesses.

Addressing any adverse publicity, governmental scrutiny or enforcement or other legal proceedings is time consuming and expensive and, regardless of the factual basis for the assertions being made, can have a negative impact on the reputation of Dominion Energy, the Company and Consolidated SCE&G, on the morale and performance of their employees and on their relationships with their respective regulators, customers and commercial counterparties. It may also have a negative impact on their ability to take timely advantage of various business and market opportunities. The direct and indirect effects of negative publicity, and the demands of responding to and addressing it, may have an adverse effect on Dominion Energy’s, the Company’s and Consolidated SCE&G’s respective businesses, financial condition, results of operations and prospects.

Pending litigation against SCANA and Dominion Energy could result in an injunction preventing the completion of the merger or requiring the Merger Agreement to be amended, or may require the payment of monetary damages or may adversely affect the combined company’s business, financial condition or results of operations following the merger.

Following the announcement of the merger, multiple lawsuits were filed asserting claims relating to the merger. Purported class actions on behalf of SCANA shareholders have been filed in the Court of Common Pleas of the Counties of Lexington and Richland, South Carolina, respectively, and in the District Court against SCANA, the members of the SCANA board of directors, Dominion Energy and Sedona, and certain current and former officers of SCANA, alleging breaches of various fiduciary duties by the members of the SCANA board of directors in connection with the merger and alleging that SCANA, Dominion Energy and Sedona aided and abetted such alleged breaches. Plaintiffs also allege that SCANA, SCE&G and individual defendants violated or conspired to violate RICO, and that defendants violated provisions of Section 14(a) of the Exchange Act and SEC Rule 14a-9 by allowing or causing misleading proxy statements to be issued. Among other remedies, the plaintiffs seek to enjoin the merger and rescind the Merger Agreement or to have the Merger Agreement amended to provide more favorable terms for plaintiffs, monetary damages, attorney's fees and such further relief as the court deems proper or, in certain cases, seeking compensatory and consequential damages.

While the defendants believe that dismissal is warranted, the outcome of any such litigation is inherently uncertain. The defense or settlement of any lawsuit or claim that remains unresolved at the time the merger closes may adversely affect the combined company’s business, financial condition or results of operations.

There is uncertainty as to whether the Company and Consolidated SCE&G will be able to recover costs expended for the Nuclear Project, and a reasonable return on those costs, under the abandonment provisions of the BLRA or through

other means. In 2017 the Company and Consolidated SCE&G recognized a significant estimated impairment loss with respect to such investment and related costs. In the event the Company and Consolidated SCE&G were to determine that all or an additional portion of their remaining unrecovered Nuclear Project and related costs are probable of being disallowed and that significant additional impairment losses must be recognized, further material adverse impacts on their results of operations, cash flows and financial condition would occur.

During the term of the Interim Assessment Agreement, SCE&G and Santee Cooper evaluated the various elements of the Nuclear Project, including forecasted costs and completion dates, while construction continued, and SCE&G and Santee Cooper continued to make payments for such work. Based on this evaluation, and in light of Santee Cooper's decision to suspend construction, on July 31, 2017, the Company determined to stop construction of Unit 2 and Unit 3 and to pursue recovery of costs incurred in connection with such construction under the abandonment provisions of the BLRA or through other means. On July 31, 2017, SCE&G gave WEC a five-day notice of termination of the Interim Assessment Agreement, and notified WEC of its determination to stop construction of Unit 2 and Unit 3.

On August 1, 2017, SCE&G senior management provided an allowable ex parte briefing to the SCPSC regarding the Nuclear Project and this decision, and SCE&G also filed a petition with the SCPSC which included its plan of abandonment and certain proposed actions which would mitigate related customer rate increases, including a proposal to return to customers the net value of the proceeds received by SCE&G under or arising from the Toshiba Settlement.

The BLRA provides that, in the event of abandonment prior to plant completion, costs incurred, including AFC, and a return on those costs may be recoverable through rates, if the SCPSC determines that the decision to abandon the Nuclear Project was prudent. Through its August 1, 2017 petition, SCE&G had sought recovery of such costs expended on the construction of the project, including certain costs incurred subsequent to SCE&G's last revised rates update, and a reasonable return on those costs, and certain other costs under the abandonment provisions of the BLRA. Subsequently, SCE&G’s management met with various stakeholders and members of the South Carolina General Assembly, including legislative leaders, to discuss the abandonment of the Nuclear Project and to hear their concerns. In response to those concerns, and to allow for adequate time for governmental officials to conduct their reviews, SCE&G voluntarily withdrew its August 1, 2017 petition from the SCPSC on August 15, 2017.

In August 2017, special committees of the South Carolina General Assembly, both in the House of Representatives and in the Senate, began conducting public hearings regarding the decision to abandon the Nuclear Project. Members of SCE&G's senior management, along with representatives from Santee Cooper, the ORS and other interested parties, testified before these committees. Several legislative proposals adverse to the Company and Consolidated SCE&G resulted from the work of these committees, two of which became law in 2018 and are described below.

In September 2017, the Company was served with a subpoena issued by the United States Attorney’s Office for the District of South Carolina seeking documents relating to the Nuclear Project. The subpoena requires the Company to produce a broad range of documents related to the project. Also, SLED is conducting a criminal investigation into the handling of the Nuclear Project by SCANA and SCE&G. In October 2017, the staff of the SEC's Division of Enforcement also issued a subpoena for documents related to an investigation they are conducting related to the Nuclear Project. These investigations are ongoing, and the Company and Consolidated SCE&G intend to fully cooperate with them. No assurance can be given as to the timing or outcome of these matters. Also in connection with the abandonment of the Nuclear Project, various state and local governmental authorities have attempted and may further attempt to challenge, reverse or revoke one or more previously-approved tax or economic development incentives, benefits or exemptions and have attempted and may further attempt to apply such actions retroactively. No assurance can be given as to the timing or outcome of these matters.

On September 26, 2017, the South Carolina Office of Attorney General issued an opinion stating, among other things, that "as applied, portions of the BLRA are constitutionally suspect," including the abandonment provisions. Also on September 26, 2017, and in reliance on the opinion from the Office of Attorney General, the ORS filed the Request seeking an order from the SCPSC directing SCE&G to immediately suspend all revised rates collections from customers which were previously approved by the SCPSC pursuant to the authority of the BLRA. In the Request, the ORS noted the existence of an allegation that SCE&G failed to disclose information to the ORS that should have been disclosed and that would have appeared to provide a basis for challenging prior requests, and asserted that SCE&G should not be allowed to continue to benefit from nondisclosure. The ORS also asked for an order that, if the BLRA is found to be unconstitutional or the South Carolina General Assembly amends or revokes the BLRA, then SCE&G should make credits to future bills or refunds to customers for prior revised rates collections. On October 17, 2017, the ORS filed a motion with the SCPSC to amend the Request, in which motion the ORS asked the SCPSC to consider the most prudent manner by which SCE&G will enable its customers to realize the value of the monetized Toshiba Settlement payments and other payments made by Toshiba towards satisfaction of its obligations to SCE&G.

On December 20, 2017, the SCPSC denied a motion by SCE&G to dismiss the Request and the SCPSC requested that the ORS carry out an inspection, audit and examination of SCE&G's revenue requirements to assist the SCPSC in determining whether SCE&G's present schedule of rates is fair and reasonable. Parties who have intervened in the Request or who filed a letter in support of it include the state's Governor, Office of Attorney General and Speaker of the House of Representatives, the Electric Cooperatives of South Carolina, Santee Cooper, the SCEUC, certain large industrial customers, and several environmental groups. The SCPSC has scheduled a hearing on the Joint Petition and two other dockets related to the Nuclear Project, namely the Request by the ORS and a June 2017 complaint filed by the Friends of the Earth and the Sierra Club, to begin November 1, 2018. This schedule was established in response to legislation (Act 258 and S. 954) described below. SCE&G intends to continue vigorously contesting the Request, but cannot give any assurance as to the timing or outcome of this matter.

On September 27, 2017, certain scheduled payments under the Toshiba Settlement were purchased by Citibank, including amounts related to certain liens that SCE&G was contesting but for which SCE&G may ultimately have been liable. This transaction, together with an October 2017 payment received from Toshiba, resulted in the receipt of $1.997 billion (approximately $1.098 billion for SCE&G's 55% share). A regulatory liability has been recorded on the condensed consolidated balance sheets to reflect the amount related to the Toshiba Settlement that will be utilized to benefit SCE&G's customers in a manner to be determined by the SCPSC. It is possible that the outcome of regulatory or legal proceedings could result in requiring SCE&G's share of these proceeds to be placed in escrow pending their final disposition, or could require these proceeds to be refunded to customers in the near-term or otherwise make these funds unavailable to SCE&G. If any of these circumstances were to arise, it is anticipated that SCE&G may issue commercial paper, draw on its credit facilities or issue long-term debt to fund such requirement. However, such sources may not be available. Any such requirement would significantly harm the Company's and Consolidated SCE&G's results of operations, cash flows and financial condition. In addition, the purchase agreement with Citibank provides that SCE&G and Santee Cooper (each according to its pro rata share) would indemnify Citibank for its losses arising from misrepresentations or covenant defaults under the purchase agreement.

On June 27, 2018, the South Carolina General Assembly adopted Act 258, which became law June 28, 2018, to temporarily reduce the amount SCE&G can collect from customers under the BLRA related to the Nuclear Project. Act 258 requires the SCPSC to order a reduction in the portion of SCE&G's retail electric rates associated with the Nuclear Project from approximately 18% of the average residential electric customer’s bill to approximately 3.2%, or a reduction of approximately $31 million per month, retroactive to April 1, 2018. Absent an earlier ruling from the SCPSC, which could be issued only on the SCPSC’s own initiative, these lower rates are to be effective until the SCPSC renders a final decision on the merits of the Joint Petition. On July 2 and 3, 2018, the SCPSC issued orders implementing the temporary rate reduction required by Act 258. Unless the relief discussed in the next paragraph is granted, the new rates and retroactive credits required by Act 258 are to be put into effect with the first billing cycle of August 2018. Retroactive credits for billed and unbilled amounts for the period April 1, 2018 through June 30, 2018 total approximately $109.3 million. The initial recognition of such retroactive credits includes the effects of cycle billing on unbilled usage. In addition to the reduction of electric rates (which rates had been previously approved by the SCPSC), Act 258 alters various procedures previously applicable under the BLRA, including redefining the standard of care required by the BLRA and supplying definitions of key terms that would affect the evidence required to establish SCE&G’s ability to recover its costs associated with the Nuclear Project.

On June 29, 2018, SCE&G filed a lawsuit in the District Court challenging the constitutionality of Act 258 along with joint resolution S. 954, which became law on July 2, 2018. Among other things, S. 954 prohibits the SCPSC from holding a hearing on the merits of the Joint Petition before November 1, 2018, and requires it to issue an order on the merits of the Joint Petition by December 21, 2018. In the lawsuit, which was subsequently amended, SCE&G seeks a declaration that the new laws are unconstitutional and asks the court to issue an injunction prohibiting the SCPSC from implementing Act 258. A hearing on SCE&G’s motion for the issuance of a preliminary injunction was held on July 30-31, 2018. Dominion Energy and Sedona would not be obligated to complete the pending merger with SCANA if Act 258 remains in effect and is implemented. The Company and Consolidated SCE&G cannot predict the timing or outcome of this matter.

In 2017, SCE&G recorded a pre-tax impairment loss of $1.118 billion related to unrecovered nuclear project costs and other related costs. In the first quarter of 2018, SCE&G recorded an additional pre-tax impairment loss of $3.6 million related to the fair value of nuclear fuel. These impairment losses have had the effect of increasing the Company's and Consolidated SCE&G's ratio of debt to total capitalization. If the SCPSC were to rule in favor of the ORS in response to the Request that SCE&G suspend collections from customers of amounts previously authorized under the BLRA, or were other actions of the SCPSC or others taken in order to significantly restrict SCE&G’s access to revenues or impose additional adverse refund obligations on SCE&G, the Company’s and Consolidated SCE&G's assessments regarding the recoverability of all or a portion of the remaining balance of unrecovered Nuclear Project costs would be adversely impacted. Resulting additional pre-tax impairment losses and other charges could total as much as $4.9 billion. Also, the recognition of significant additional

impairment losses with respect to unrecovered Nuclear Project or other related costs could further increase the Company’s and Consolidated SCE&G’s ratio of debt to total capitalization to a level which could constitute a default under their credit facilities. If such a default occurred, the Company and Consolidated SCE&G would be unable to borrow under their commercial paper programs or, absent a waiver from lenders, under their credit facilities. Borrowing costs for long-term debt issuances and access to capital markets could also be negatively impacted.

The ability of SCE&G to recover its costs related to the construction and subsequent abandonment of the Nuclear Project, and a reasonable return on them, through rates will be subject to review and approval by the SCPSC. An application under the abandonment provisions of the BLRA, and the regulatory process contemplated thereby, have never been pursued or legally challenged. As a result, and in light of recently enacted legislation such as Act 258 and S. 954, the contentious nature of activities involving the General Assembly and other officials, and the Request being considered by the SCPSC, it is uncertain whether SCE&G will be able to successfully recover the costs of the abandoned units, and a reasonable return on them. The SCPSC's hearing to consider the Joint Petition, the Request and a related docket is scheduled to begin November 1, 2018. In any case, anticipated appeals of any ruling by the SCPSC could be protracted. Further, should the regulatory construct in South Carolina change in such a manner that recovery is sought through other legal proceedings or through regulatory proceedings outside the provisions of the BLRA, such as in a general rate case, other uncertainties may arise, such as those highlighted with respect to the Merger Agreement.

Further downgrades in the credit ratings of SCANA or any of SCANA’s subsidiaries, including SCE&G, could negatively affect our ability to access capital and to operate our businesses, thereby adversely affecting results of operations, cash flows and financial condition.

Various rating agencies currently rate SCE&G’s senior secured debt and the senior unsecured debt of PSNC Energy as investment grade. One rating agency currently rates SCANA’s senior unsecured debt as investment grade, and two rating agencies rate SCANA's senior unsecured debt as below investment grade. In addition, rating agencies maintain ratings on the short- and long-term debt of SCANA, SCE&G and PSNC Energy and the short-term debt of Fuel Company (which ratings are based upon the guarantee of SCE&G). Rating agencies consider qualitative and quantitative factors when assessing SCANA and its rated operating companies’ credit ratings, including regulatory environment, capital structure and the ability to meet liquidity requirements.

In the first quarter of 2017, the rating agencies placed SCANA and SCE&G’s credit ratings on negative outlook or watch status due to adverse developments relating to the WEC bankruptcy. In the third quarter of 2017, two agencies lowered their ratings for SCANA and its rated subsidiaries, citing a decline in the regulatory environment as a principal reason for the downgrades, and both agencies maintained their negative outlook. On January 3, 2018, after SCANA announced a proposed merger with Dominion Energy, each of the three agencies affirmed or reported no change to their respective credit ratings, and one agency revised its rating outlook for SCANA and its rated operating companies from negative to evolving. However, on January 31, 2018, the South Carolina House of Representatives overwhelmingly approved a bill (which later would become Act 258) designed to temporarily repeal rates SCE&G collects under the BLRA. As a result, on February 5, 2018, one agency downgraded its ratings for SCANA and SCE&G, and attributed the downgrade to the passage of this bill and the politically charged environment that is expected to weigh heavily on any decisions by the SCPSC related to SCE&G's electric rates. After Act 258 became law, on July 2 and 3, 2018, the agencies affirmed their ratings; however, one agency changed its outlook from review to negative. As a result, all of the ratings for SCANA, SCE&G and PSNC Energy have either a negative or evolving outlook, indicating that the ratings are being scrutinized for possible rating actions either currently or dependent on the outcome of uncertain future events.

Any actions taken by or anticipated to be taken by regulators or legislators that are viewed as adverse, including a further change to the BLRA or a requirement that SCE&G make credits to future bills or refunds to customers or any requirement that SCE&G make such credits or refunds in the absence of the merger being consummated, or deterioration of our rated companies’ commonly monitored financial credit metrics and additional adverse developments with respect to the Nuclear Project (including adverse litigation outcomes), could further negatively affect their debt ratings. If these rating agencies were to further lower any of these ratings, borrowing costs on new issuances of long-term debt and commercial paper would increase, which could adversely impact financial results, and refinancing opportunities would be limited or eliminated to the extent that the potential pool of investors and funding sources decreased. Any further lowering of these ratings could also trigger higher interest costs as well as more stringent collateral requirements on interest rate and commodity hedges and under gas supply agreements and a reduction in the availability of suppliers.

The Company and Consolidated SCE&G are defendants in numerous legal proceedings and the subject of ongoing governmental investigations, examinations and other inquiries stemming from the decision to abandon the Nuclear Project.

~~The outcome of each of these matters is uncertain, and any resolution adverse to the Company and Consolidated SCE&G could adversely affect results of operations, cash flows and financial condition.~~

Following the Company’s decision to abandon construction of Unit 2 and Unit 3, purported derivative and class action lawsuits have been filed in multiple state circuit courts and federal district court on behalf of customers, shareholders and SCANA (in the case of the derivative shareholder actions), against SCANA, SCE&G, or both, and in certain cases some of their officers and/or directors. The plaintiffs allege various causes of action, including waste, breach of fiduciary duty, negligence, unfair trade practices, unjust enrichment, conspiracy, fraud, constructive fraud, misrepresentation and negligent misrepresentation, promissory estoppel, constructive trust, and money had and received, among other causes of action. Plaintiffs generally seek compensatory, consequential and statutory treble damages and such further relief as the court deems just and proper. In addition, certain plaintiffs seek a declaration that SCE&G may not charge its customers to reimburse itself for past and continuing costs of the Nuclear Project. Certain plaintiffs also seek to freeze or appoint a receiver for certain of SCE&G’s assets, namely all money SCE&G has received under the Toshiba payment guaranty and related settlement agreement for the Nuclear Project.

A complaint has been filed by Fairfield County against SCE&G making allegations of breach of contract, fraud, negligent misrepresentation, breach of fiduciary duty, breach of the implied duty of good faith and fair dealing, and unfair trade practices related to SCE&G’s termination of the FILOT agreement. Plaintiff seeks injunctive relief to prevent SCE&G from terminating the FILOT agreement; actual and consequential damages; treble damages; punitive damages; and attorneys’ fees.

~~The DOR has initiated an audit of SCE&G's sales and use tax returns for the periods September 1, 2008 through~~ December 31, 2017. The DOR's position is that the exemption for sales and use tax for purchases related to the Nuclear Project should not apply because Unit 2 and Unit 3 will not be placed into service and no electricity will be manufactured for sale. On June 1, 2018, SCE&G received from the DOR a notice of proposed assessment arising from that audit of approximately $410 million, plus interest. SCE&G intends to protest the proposed assessment.

While the Company and Consolidated SCE&G intend to vigorously contest the lawsuits, claims, and audit positions or assessments which have been filed or initiated against them, they cannot predict the timing or outcome of these matters or other claims, allegations or assessments which may arise, including any claims that may be asserted by Santee Cooper, and it is possible that adverse outcomes from some of these matters would not be covered by insurance. A resolution adverse to the Company and Consolidated SCE&G could adversely affect results of operations, cash flows and financial condition.

The Company and Consolidated SCE&G are engaged in activities for which they have claimed research and experimentation tax deductions and credits and tax abandonment losses, all of which are the subject of uncertainty and which may be considered controversial by the taxing authorities. The outcome of those uncertainties could adversely impact cash flows, results of operations and financial condition.

These tax claims primarily involve the timing of recognition of tax deductions rather than permanent tax attributes, and their permanent attributes (net), as well as most of the interest accruals required to be recorded with respect to them, had been deferred within regulatory assets. As such, until December 31, 2017 when these deferrals were considered to be impaired, these claims had not had, and were not expected to have in the future, significant direct effects on the Company’s and Consolidated SCE&G’s results of operations. Nonetheless, the claims have contributed significantly to the Company’s and Consolidated SCE&G’s cash flows by providing a significant source of capital and lessening the level of debt and equity financing that the Company and Consolidated SCE&G have needed to raise in the financial markets.

The claims made to date are under (or are expected to come under) examination and are considered controversial by the IRS. To the extent that any of these claims are not sustained as ordinary losses on examination or through any subsequent appeal, the Company and Consolidated SCE&G will be required to repay any cash received for tax benefit claims which are ultimately disallowed, along with interest on those amounts. Such amounts could be significant and could adversely affect the Company's and Consolidated SCE&G's liquidity, cash flows, results of operations and financial condition. In certain circumstances, which management considers to be remote, penalties for underpayment of income taxes could also be assessed. Additionally, in such circumstances, the Company and Consolidated SCE&G may need to access the capital markets to fund those tax and interest payments, which could in turn adversely impact their ability to access capital markets for other purposes.

The Company and Consolidated SCE&G are subject to numerous environmental laws and regulations that require significant capital expenditures, can increase our costs of operations and may impact our business plans or expose us to environmental liabilities.

The Company and Consolidated SCE&G are subject to extensive federal, state and local environmental laws and regulations, including those relating to water quality and air emissions (such as reducing NO_X~~, SO~~₂, mercury and particulate matter). Some form of regulation is expected at the federal and state levels to impose regulatory requirements specifically directed at reducing GHG emissions from fossil fuel-fired electric generating units. On August 3, 2015, the EPA issued a revised standard for new power plants by re-proposing NSPS under the CAA for emissions of CO₂from newly constructed fossil fuel-fired units. No new coal-fired plants could be constructed without partial carbon capture and sequestration capabilities. The Company and Consolidated SCE&G do not plan to construct new coal-fired units in the foreseeable future. In addition, on August 3, 2015, the EPA issued its final rule on emission guidelines for states to follow in developing plans to address GHG emissions from existing units. On October 10, 2017, the Administrator of the EPA signed a notice proposing to repeal the rule on the grounds that it exceeds the EPA's statutory authority. The EPA is further considering the scope of any potential replacement rule and plans to formally solicit information on systems of emission reduction that are in accord with the EPA's interpretation of its statutory authority. However, a number of bills have been introduced in Congress that seek to require GHG emissions reductions from fossil fuel-fired electric generation facilities, natural gas facilities and other sectors of the economy, although none has yet been enacted. In April 2012, the EPA issued the finalized MATS for power plants that requires

reduced emissions from new and existing coal and oil-fired electric utility steam generating facilities. The EPA's rule for cooling water intake structures to meet the best technology available became effective in October 2014, and the EPA also issued a final rule in December 2014 regarding the handling of coal ash and other combustion by-products produced by power plant operations. Furthermore, the EPA finalized new standards under the CWA governing effluent limitation guidelines for electric generating units in September 2015. The rule setting forth these new standards has been stayed administratively, and the EPA has begun a new rulemaking process that could take until 2020 before revisions to the effluent limitation guidelines for electric generating units is complete.

Compliance with these environmental laws and regulations requires us to commit significant resources toward environmental monitoring, installation of pollution control equipment, emissions fees and permitting at our facilities. These expenditures have been significant in the past and are expected to continue or even increase in the future. Changes in compliance requirements, additional regulations and related costs, or more restrictive interpretations by governmental authorities of existing requirements may impose additional costs on us (such as more stringent clean-up of contaminated sites or reduced emission allowances) or require us to incur additional expenditures or curtail some of our cost savings activities (such as the recycling of fly ash and other coal combustion products for beneficial use). Compliance with any GHG emission reduction requirements, including any mandated renewable portfolio standards, also may impose significant costs on us, and the resulting price increases to our customers may lower customer consumption. Such costs of compliance with environmental regulations could negatively impact our businesses and our results of operations and financial position, especially if emissions or discharge limits are reduced or more onerous permitting requirements or additional regulatory requirements are imposed. Additionally, there can be no assurance that a federal tax or fee for carbon emitting generating facilities will not be imposed.

Renewable and/or alternative electric generation portfolio standards may be enacted at the federal or state level. Such renewable energy may not be readily available in our service territories and could be costly to build, finance, acquire, integrate, and/or operate. Resulting increases in the price of electricity to recover the cost of these types of generation, and the costs of their integration to the electric system, could result in lower usage of electricity by our customers. In addition, DER generation at customers’ facilities could result in the loss of sales to those customers. Compliance with potential future portfolio standards could significantly impact our capital expenditures and our results of operations and financial condition. Utility scale solar development companies are currently working in South Carolina to develop projects in SCE&G's service territory. The integration of those resources at high penetration levels may be challenging.

The compliance costs of these environmental laws and regulations are important considerations in the Company's and Consolidated SCE&G's strategic planning and, as a result, significantly affect the decisions to construct, operate, and retire facilities, including generating facilities. In turn, they affect the costs and rates of the Company and Consolidated SCE&G.2018. For ~~example, in effecting compliance with MATS, SCE&G has retired three of its oldest and smallest coal-fired units and converted three others such that they are gas-fired.~~

Commodity price changes, delays in delivery of commodities, commodity availability and other factors may affect the operating cost, capital expenditures and competitive positions of the Company’s and Consolidated SCE&G’s energy businesses, thereby adversely impacting results of operations, cash flows and financial condition.

Our energy businesses are sensitive to changes in coal, natural gas, uranium and other commodity prices (as well as their transportation costs), availability and deliverability. Any such changes could affect the prices these businesses charge, their operating costs, and the competitive position of their products and services. In addition, the abandonment of the Nuclear Project may heighten the Company's and Consolidated SCE&G's future exposure to volatility in prices of non-nuclear commodities such as natural gas. Consolidated SCE&G is permitted to recover the prudently incurred cost of purchased power and fuel (including transportation) used in electric generation through retail customers’ bills, but purchased power and fuel cost increases affect electric prices and therefore the competitive position of electricity against other energy sources. In addition, when natural gas prices are low enough relative to coal to result in the dispatch of gas-fired electric generation ahead of coal-fired electric generation, higher inventories of coal, with related increased carrying costs, may result. This may adversely affect our results of operations, cash flows and financial condition.

In the case of regulated natural gas operations, costs prudently incurred for purchased gas and pipeline capacity may be recovered through retail customers’ bills. However, in both our regulated and deregulated natural gas markets, increases in gas costs affect total retail prices and therefore the competitive position of gas relative to electricity and other forms of energy. Accordingly, customers able to do so may switch to alternate forms of energy and reduce their usage of gas from the Company and Consolidated SCE&G. Customers on a volumetric rate structure unable to switch to alternate fuels or suppliers may reduce their usage of gas from the Company and Consolidated SCE&G. A regulatory mechanism applies to residential and commercial customers at PSNC Energy to mitigate the earnings impact of an increase or decrease in gas usage.

Certain construction-related commodities, such as copper and aluminum used in our transmission and distribution lines and in our electrical equipment, and steel, concrete and rare earth elements, have experienced significant price fluctuations due to changes in worldwide demand. To operate our air emissions control equipment, we use significant quantities of ammonia, limestone and lime. With EPA-mandated industry-wide compliance requirements for air emissions controls, increased demand for these reagents, combined with the increased demand for low sulfur coal, may result in higher costs for coal and reagents used for compliance purposes.

Changing and complex laws and regulations to which the Company and Consolidated SCE&G are subject could adversely affect revenues, increase costs, or curtail activities, thereby adversely impacting results of operations, cash flows and financial condition.

The Company and Consolidated SCE&G operate under the regulatory authority of the United States government and its various regulatory agencies, including the FERC, NRC, SEC, IRS, EPA, the Department of Homeland Security, CFTC and PHMSA. In addition, the Company and Consolidated SCE&G are subject to regulation by the state governments of South Carolina, North Carolina and Georgia via regulatory agencies, state environmental agencies, and state employment commissions. Accordingly, the Company and Consolidated SCE&G must comply with extensive federal, state and local laws and regulations. Such governmental oversight and regulation broadly and materially affect the operation of our businesses. In addition to many other aspects of our businesses, these requirements impact the services mandated or offered to our customers, and the licensing, siting, construction and operation of facilities. They affect our management of safety, the reliability of our electric and natural gas systems, the physical and cyber security of key assets, customer conservation through DSM Programs, information security, the issuance of securities and borrowing of money, financial reporting, interactions among affiliates, the pricing of utility services, the payment of dividends and employment programs and practices. Changes to governmental regulations are continual and potentially costly to effect compliance. Non-compliance with these requirements by third parties, such as our contractors, vendors and agents, may subject the Company and Consolidated SCE&G to operational risks and to liability. We cannot predict the future course of changes in this regulatory environment or the ultimate effect that this changing regulatory environment will have on the Company’s or Consolidated SCE&G’s businesses. Non-compliance with these laws and regulations could result in fines, litigation, loss of licenses or permits, mandated capital expenditures and other adverse business outcomes, as well as reputational damage, which could adversely affect the cash flows, results of operations, and financial condition of the Company and Consolidated SCE&G.

Furthermore, changes in or uncertainty in monetary, fiscal, tax, economic, trade, or regulatory policies of the Federal government may adversely affect the debt and equity markets and the economic climate for the nation, region or particular industries, such as ours or those of our customers. The Company and Consolidated SCE&G also could be adversely impacted by changes in tax policy, or taxes related to the usage of certain fuel types in our businesses or our ownership and/or operation of certain types of generating facilities. Future, unknown regulation of hydraulic fracturing activities also could impact the operations and finances of the Company and Consolidated SCE&G.

The Company and Consolidated SCE&G are subject to extensive rate regulation which could adversely affect operations. Large capital projects (including the abandonment of Unit 2 and Unit 3 as previously described), results of DSM Programs, results of DER programs, and/or increases in operating costs may lead to requests for regulatory relief and any related administrative or legislative action, decision, regulation or law affecting rates, such as rate increases, which may be denied, in whole or part, by rate regulators. Rate increases may also result in reductions in customer usage of electricity or gas, legislative action and lawsuits. Additionally, in 2018 certain state legislative proposals became law (Act 258 and S. 954) which could lead to adverse impacts on SCE&G’s rate recovery with respect to the Nuclear Project. Furthermore, there can be no assurance that other legislation which might modify or repeal the BLRA in a manner which would adversely impact SCE&G’s rate recovery, including its reasonable return on costs, with respect to its abandonment of Unit 2 and Unit 3 will not be proposed and passed. Any such action, particularly Act 258 remaining in effect and implemented, could also result in a failure to consummate the merger.

SCE&G’s electric operations in South Carolina and the Company’s gas distribution operations in South Carolina and North Carolina are regulated by state utilities commissions. The ability of SCE&G to recover the cost of the Nuclear Project, including abandonment costs, and a reasonable return on those costs, is subject to rate regulation by the SCPSC. Consolidated SCE&G’s generating facilities are subject to extensive regulation and oversight from the NRC and SCPSC. SCE&G's electric transmission system is subject to extensive regulations and oversight from the SCPSC, NERC and FERC. Implementing and maintaining compliance with the NERC's mandatory reliability standards, enforced by FERC, for bulk electric systems could result in higher operating costs and capital expenditures. Non-compliance with these standards could subject SCE&G to substantial monetary penalties. Our gas marketing operations in Georgia are subject to state regulatory oversight and, for a portion of its operations, to rate regulation. There can be no assurance that Georgia’s gas delivery regulatory framework will remain unchanged as market conditions evolve.

Furthermore, Dodd-Frank affects the use and reporting of derivative instruments. The regulations under this legislation provide for substantial additional regulation of over-the-counter and security-based derivative instruments, among other things, and require numerous rule-makings by the CFTC and the SEC to implement, many of which are still pending final action by those federal agencies. The Company and Consolidated SCE&G have determined that they meet the end-user exception to mandatory clearing of swaps under Dodd-Frank. In addition, the Company and Consolidated SCE&G have taken steps to ensure that they are not the party required to report these transactions in real-time (the "reporting party") by transacting solely with swap dealers and major swap participants, when possible, as well as entering into reporting party agreements with counterparties who also are not swap dealers or major swap participants, which establishes that those counterparties are obligated to report the transactions in accordance with applicable Dodd-Frank regulations. While these actions minimize the reporting obligations of the Company, they do not eliminate required recordkeeping for any Dodd-Frank regulated transactions. Despite qualifying for the end-user exception to mandatory clearing and ensuring that neither the Company nor Consolidated SCE&G is the reporting party to a transaction required to be reported in real-time, we cannot predict when the final regulations will be issued or what requirements they will impose.

Our ability to charge customer rates that will allow us to maintain reasonable rates of return is dependent upon regulatory determinations, and there can be no assurance that we will be able to implement rate adjustments when sought.

The Company and Consolidated SCE&G are subject to the reputational risks that may result from a failure to adhere to high standards related to compliance with laws and regulations, ethical conduct, operational effectiveness, customer service and the safety of employees, customers and the public. These risks could adversely affect the valuation of our common stock and the Company’s and Consolidated SCE&G’s access to capital.

The Company and Consolidated SCE&G are committed to comply with all laws and regulations, to assure reliability of provided services, to focus on the safety of employees, customers and the public, to ensure environmental compliance, to maintain the physical and cyber security of their operations and assets, to maintain the privacy of information related to our customers and employees, and to maintain effective communications with the public and key stakeholder groups, particularly during emergencies and times of crisis. Traditional news media and social media can very rapidly convey information, whether factual or not, to large numbers of people, including customers, investors, regulators, legislators and other stakeholders, and the failure to effectively manage timely, accurate communication through these channels could adversely impact our reputation. The Company and Consolidated SCE&G also are committed to operational excellence, to quality customer service, and, through our Code of Conduct and Ethics, to maintain high standards of ethical conduct in our business operations. A failure to meet these commitments, or a perceived failure to meet these commitments, may subject the Company and Consolidated SCE&G not only to fraud, regulatory action, litigation or financial loss, but also to reputational risk that could adversely affect the valuation of SCANA’s stock, adversely affect the Company’s and Consolidated SCE&G’s access to capital, and result in further regulatory oversight. Insurance may not be available or adequate to respond to these events.

A failure of the Company and Consolidated SCE&G to maintain the physical and cyber security of its operations may result in the failure of operations, damage to equipment, or loss of information, and could result in a significant adverse impact to the Company's and Consolidated SCE&G's financial condition, results of operations and cash flows.

The Company and Consolidated SCE&G depend on maintaining the physical and cyber security of their operations and assets. As much of our business is part of the nation's critical infrastructure, the loss or physical impairment of the assets associated with that portion of our businesses could have serious adverse impacts on the customers and communities that we serve. Virtually all of the Company's and Consolidated SCE&G's operations are dependent in some manner upon our cyber systems, which encompass electric and gas operations, nuclear and fossil fuel generating plants, human resource and customer systems and databases, information system networks, and systems containing confidential corporate information. Cyber systems, such as those of the Company and Consolidated SCE&G, are often targets of malicious cyber attacks. A successful physical or cyber attack could lead to outages, failure of operations of all or portions of our businesses, damage to key components and equipment, and exposure of confidential customer, vendor, shareholder, employee, or corporate information. The Company and Consolidated SCE&G may not be readily able to recover from such events. In addition, the failure to secure our operations from such physical and cyber events may cause us reputational damage. Litigation, penalties and claims from a number of parties, including customers, regulators and shareholders, may ensue. Insurance may not be adequate to mitigate the adverse impacts of these events. As a result, the Company's and Consolidated SCE&G's financial condition, results of operations, and cash flows may be adversely affected.

The Company and Consolidated SCE&G are vulnerable to interest rate increases, which would increase our borrowing costs, and we may not have access to capital at favorable rates, if at all. Additionally, potential disruptions in the capital and credit markets may further adversely affect the availability and cost of short-term funds for liquidity

~~requirements and our ability to meet long-term commitments; each could in turn adversely affect our results of operations, cash flows and financial condition.~~

The Company and Consolidated SCE&G rely on the capital markets, particularly for publicly offered debt and equity, as well as the banking and commercial paper markets, to meet our financial commitments and short-term liquidity needs if internal funds are not available from operations. Changes in interest rates affect the cost of borrowing. The Company’s and Consolidated SCE&G’s business plans, which include significant investments in energy generation and other internal infrastructure projects, reflect the expectation that we will have access to the capital markets on satisfactory terms to fund commitments. Moreover, the ability to maintain short-term liquidity by utilizing commercial paper programs is dependent upon maintaining satisfactory short-term debt ratings and the existence of a market for our commercial paper generally.

The Company’s and Consolidated SCE&G’s ability to draw on our respective bank revolving credit facilities is dependent on the ability of the banks that are parties to the facilities to meet their funding commitments and on our ability to timely renew such facilities. Those banks may not be able to meet their funding commitments to the Company or Consolidated SCE&G if they experience shortages of capital and liquidity or if they experience excessive volumes of borrowing requests from us and other borrowers within a short period of time. Longer-term disruptions in the capital and credit markets as a result of uncertainty, changing or increased regulation, reduced alternatives or failures of significant financial institutions could adversely affect our access to liquidity needed for our businesses. Any disruption could require the Company and Consolidated SCE&G to take measures to conserve cash until the markets stabilize or until alternative credit arrangements or other funding for our business needs can be arranged. Such measures could include deferring capital expenditures or other discretionary uses of cash or reducing or eliminating dividend payments. Disruptions in capital and credit markets also could result in higher interest rates on debt securities, limited or no access to the commercial paper market, increased costs associated with commercial paper borrowing or limitations on the maturities of commercial paper that can be sold (if at all), increased costs under bank credit facilities and reduced availability thereof, and increased costs for certain variable interest rate debt securities of the Company and Consolidated SCE&G.

Disruptions in the capital markets and their actual or perceived effects on particular businesses and the greater economy also adversely affect the value of the investments held within SCANA’s pension trust. A significant long-term decline in the value of these investments may require us to make or increase contributions to the trust to meet future funding requirements. In addition, a significant decline in the market value of the investments may adversely impact the Company’s and Consolidated SCE&G’s results of operations, cash flows and financial condition, including its shareholders’ equity.

~~Operating results may be adversely affected by natural disasters, man-made mishaps and abnormal weather.~~

The Company has delivered less gas and, in deregulated markets, received lower prices for natural gas when weather conditions have been milder than normal, and as a consequence earned less income from those operations. Mild weather in the future could adversely impact the revenues and results of operations and harm the financial condition of the Company and Consolidated SCE&G. Hot or cold weather could result in higher bills for customers and result in higher write-offs of receivables and in a greater number of disconnections for non-payment. In addition, for the Company and Consolidated SCE&G, severe weather can be destructive, causing outages and property damage, adversely affecting operating expenses and revenues.

Natural disasters (such as hurricanes or other significant weather events, electromagnetic events, earthquakes, flooding or fires) or man-made mishaps (such as natural gas transmission pipeline failure, electric utility companies' ash pond failures, and cyber-security failures experienced by many businesses) could have direct significant impacts on the Company and Consolidated SCE&G and on our key contractors and suppliers or could impact us through changes to federal, state or local policies, laws and regulations, and have a significant impact on our financial condition, operating expenses, and cash flows.

The costs of large capital projects, such as the Company’s and Consolidated SCE&G’s construction and environmental compliance programs, are significant, and these projects are subject to a number of risks and uncertainties that may adversely affect the cost, timing and completion of these projects.

The Company’s and Consolidated SCE&G’s businesses are capital intensive and require significant investments in electric generation and in other internal infrastructure projects, including projects for environmental compliance. Achieving the intended benefits of any large construction project is subject to many uncertainties. For instance, the ability to adhere to established budgets and construction schedules may be affected by many variables, such as the regulatory, legal, training and construction processes associated with securing approvals, permits and licenses and necessary amendments to them within projected timeframes, the availability of labor and materials at estimated costs, the availability and cost of financing, and weather. There also may be contractor or supplier performance issues or adverse changes in their creditworthiness and/or

financial stability, unforeseen difficulties meeting critical regulatory requirements, contract disputes and litigation, and changes in key contractors or subcontractors. There may be unforeseen engineering problems or unanticipated changes in project design or scope. Our ability to complete construction projects as well as our ability to maintain current operations at reasonable cost could be affected by the availability of key components or commodities, increases in the price of or the unavailability of labor, commodities or other materials, increases in lead times for components, adverse changes in applicable laws and regulations, new or enhanced environmental or regulatory requirements, supply chain failures (whether resulting from the foregoing or other factors), and disruptions in the transportation of components, commodities and fuels. To the extent that, in connection with the construction of a project, delays occur, costs become unrecoverable, or we otherwise become unable to effectively manage and complete the project, our results of operations, cash flows and financial condition, as well as our qualifications for applicable governmental programs, benefits and tax credits may be adversely affected.

A significant portion of Consolidated SCE&G’s generating capacity is derived from nuclear power, the use of which exposes us to regulatory, environmental and business risks. These risks could increase our costs or otherwise constrain our business, thereby adversely impacting our results of operations, cash flows and financial condition.

~~SCE&G jointly owns and is the operator of Unit 1. Various risks of nuclear generation to which SCE&G is subject include the following:~~

The potential harmful effects on the environment and human health resulting from a release of radioactive materials in connection with the operation of nuclear facilities and the storage, handling and disposal of radioactive materials;

~~Limitations on the amounts and types of insurance commercially available to cover losses that might arise in connection with our nuclear operations or those of others in the United States;~~

~~The possibility that new laws and regulations could be enacted that could adversely affect the liability structure that currently exists in the United States;~~

~~Uncertainties with respect to procurement of nuclear fuel and suppliers thereof, fabrication of nuclear fuel and related vendors, and the storage of spent nuclear fuel;~~

~~Uncertainties with respect to contingencies if insurance coverage is inadequate;~~

~~Uncertainties with respect to possible future increased regulation of nuclear facilities and nuclear generation, and related costs thereof; and~~

~~Uncertainties with respect to the technological and financial aspects of decommissioning nuclear plants at the end of their operating lives.~~

The NRC has broad authority under federal law to impose licensing and safety-related requirements for the operation of nuclear generation facilities. In the event of non-compliance, the NRC has the authority to impose fines or shut down a unit, or both, depending upon its assessment of the severity of the situation, until compliance is achieved. Revised safety requirements promulgated by the NRC could necessitate capital expenditures at nuclear plants such as ours. In today’s environment, there is a heightened risk of terrorist attack on the nation’s nuclear facilities, which has resulted in increased security costs at our nuclear plant. Although we have no reason to anticipate a serious nuclear incident, a major incident at a nuclear facility anywhere in the world could cause the NRC to limit or prohibit the operation or licensing of any domestic nuclear unit, resulting in costly changes to units in operation and adversely impacting our results of operations, cash flows and financial condition. Furthermore, a major incident at a domestic nuclear facility could result in retrospective premium assessments under our nuclear insurance coverages.

~~Potential competitive changes may adversely affect our gas and electricity businesses due to the loss of customers, reductions in revenues, or write-down of stranded assets.~~

The utility industry has been undergoing structural change for a number of years, resulting in increasing competitive pressures on electric and natural gas utility companies. Competition in wholesale power sales via an RTO/ISO is in effect across much of the country, but the Southeastern utilities have retained the traditional bundled, vertically integrated structure. Should an RTO/ISO-market be implemented in the Southeast, potential risks emerge from reliance on volatile wholesale market prices as well as increased costs associated with new transmission and distribution infrastructure.

Some states have also mandated or encouraged unbundled retail competition. Should this occur in South Carolina or North Carolina, increased competition may create greater risks to the stability of utility earnings generally and may in the future reduce earnings from retail electric and natural gas sales. In a deregulated environment, formerly regulated utility companies that are not responsive to a competitive energy marketplace may suffer erosion in market share, revenues and profits as competitors gain access to their customers. In addition, the Company’s and Consolidated SCE&G’s generation assets would be exposed to considerable financial risk in a deregulated electric market. If market prices for electric generation do not

produce adequate revenue streams and the enabling legislation or regulatory actions do not provide for recovery of the resulting stranded costs, a write-down in the value of the related assets could be required.

The Company and Consolidated SCE&G are subject to the risk of loss of sales due to the growth of distributed generation especially in the form of renewable power such as solar photovoltaic systems, which systems have undergone a rapid decline in their costs. As a result of federal and state subsidies, potential regulations allowing third-party retail sales, and advances in distributed generation technology, particularly when combined with storage solutions, the growth of such distributed generation could be significant in the future. Such growth will lessen Company and Consolidated SCE&G sales and will slow growth, potentially causing higher rates to customers.

The Company and Consolidated SCE&G are subject to risks associated with changes in business and economic climate which could adversely affect revenues, results of operations, cash flows and financial condition and could limit access to capital.

Sales, sales growth and customer usage patterns are dependent upon the economic climate in the service territories of the Company and Consolidated SCE&G, which may be affected by regional, national or even international economic factors. Adverse events, economic or otherwise, may also affect the operations of suppliers and key customers. Such events may result in the loss of suppliers or customers, in higher costs charged by suppliers, in changes to customer usage patterns and in the failure of customers to make timely payments to us. Such events also could adversely impact the results of operations through the recording of a goodwill or other asset impairment. Also, in connection with the pending merger, some customers or vendors of the Company and Consolidated SCE&G may delay or defer decisions, which could negatively impact the revenues, earnings, cash flows and expenses of the Company and Consolidated SCE&G regardless of whether the merger is completed. The success of local and state governments in attracting new industry to our service territories is important to our sales and growth in sales, as are stable levels of taxation (including property, income or other taxes) which may be affected by local, state, or federal budget deficits, adverse economic climates generally, legislative actions (including tax reform), or regulatory actions. Industrial and commercial customer growth also potentially is affected by the availability of "clean" energy options in our service territory. Budget cutbacks also adversely affect funding levels of federal and state support agencies and non-profit organizations that assist low income customers with bill payments.

In addition, conservation and demand side management efforts and/or technological advances, including storage technology, may cause or enable customers to significantly reduce their usage of the Company’s and SCE&G’s products and adversely affect sales, sales growth, and customer usage patterns. For instance, improvements in energy storage technology, if realized, could have dramatic impacts on the viability of and growth in distributed generation.

Factors that generally could affect our ability to access capital, in addition to issues arising from the Nuclear Project and our credit ratings, include economic conditions and our capital structure. Much of our business is capital intensive, and achievement of our capital plan and long-term growth targets is dependent, at least in part, upon our ability to access capital at rates and on terms that are attractive. If our ability to access capital becomes significantly constrained, our interest costs will likely increase and our financial condition and future results of operations could be adversely impacted.

Problems with operations could cause us to curtail or limit our ability to serve customers or cause us to incur substantial costs, thereby adversely impacting revenues, results of operations, cash flows and financial condition.

Critical processes or systems in the Company’s or Consolidated SCE&G’s operations could become impaired or fail from a variety of causes, such as equipment breakdown, transmission equipment failure, information systems failure or security breach, operator error, natural disasters, and the effects of a pandemic, terrorist attack or cyber attack on our workforce or facilities or on vendors and suppliers necessary to maintain services key to our operations.

In particular, as the operator of power generation facilities, many of which entered service prior to 1985 and may be difficult to maintain, Consolidated SCE&G could incur problems, such as the breakdown or failure of power generation or emission control equipment, transmission equipment, or other equipment or processes which would result in performance below assumed levels of output or efficiency. The integration of a significant amount of distributed generation into our systems may entail additional cycling of our coal-fired generation facilities and may thereby increase the number of unplanned outages at those facilities. In addition, any such breakdown or failure may result in Consolidated SCE&G purchasing emission allowances or replacement power at market rates, if such allowances and replacement power are available at all. These purchases are subject to state regulatory prudency reviews for recovery through rates. If replacement power is not available, such problems could result in interruptions of service (blackout or brownout conditions) in all or part of SCE&G’s territory or elsewhere in the region. Similarly, a natural gas line failure of the Company or Consolidated SCE&G could affect the safety of the public, destroy property, and interrupt our ability to serve customers.

Events such as these could entail substantial repair costs, litigation, fines and penalties, and damage to reputation, each of which could have an adverse effect on the Company’s and Consolidated SCE&G's revenues, results of operations, cash flows, and financial condition. Insurance may not be available or adequate to mitigate the adverse impacts of these events.

SCANA’s ability to pay dividends and to make payments on SCANA’s debt securities may be limited by covenants in certain financial instruments (including the Merger Agreement) and by the financial results and condition of its subsidiaries, thereby adversely impacting the valuation of our common stock and our access to capital.

We are a holding company that conducts substantially all of our operations through our subsidiaries. Our assets consist primarily of investments in subsidiaries. Therefore, our ability to meet our obligations for payment of interest and principal on outstanding debt and to pay dividends to shareholders and corporate expenses depends on many factors, including the earnings, cash flows, liquidity and results of operations, historical and anticipated financial condition, capital requirements, market conditions, growth strategy and the availability of growth opportunities of our subsidiaries, and the ability of our subsidiaries, principally Consolidated SCE&G, PSNC Energy and SCANA Energy, to pay dividends or to repay funds to us. Our ability to pay dividends on our common stock may also be limited by existing or future covenants limiting the right of our subsidiaries to pay dividends on their common stock. Further, SCANA has agreed to obtain the consent of Dominion Energy, which consent cannot be unreasonably withheld, prior to making dividend payments to shareholders greater than $0.6125 per share for any quarter while the Merger Agreement is pending.

For the quarter ended June 30, 2018, our board of directors declared a dividend that is reduced by approximately 80% from the dividend paid to our shareholders for the quarter ended March 31, 2018. The reduction corresponds to the portion of dividend attributable to SCE&G's electric operations and serves to partially mitigate the liquidity impacts arising from the reduced revenues resulting from the implementation of Act 258. Any determination to pay dividends to holders of our common stock in the future, as well as the amount of any dividend, are subject to approval by our board of directors, and will depend upon many factors, including those described above and other factors that ~~our board of directors deems relevant. Any further~~may cause actual results to differ materially from those indicated in any forward-looking statement or sustained reduction in our payment of dividends in the future may result in a decline in the value of our common stock. Such a decline in value could limit our ability to raise debt and equity capital.

The use of derivative instruments could result in financial losses and liquidity constraints. The Company and Consolidated SCE&G do not fully hedge against financial market risks or price changes in commodities. This could result in increased costs, thereby resulting in lower margins and adversely affecting results of operations, cash flows and financial condition.

The Company and Consolidated SCE&G may use derivative instruments, including futures, forwards, options and swaps, to manage our financial market risks. The Company also uses such derivative instruments to manage certain commodity (i.e., natural gas) market risk. We could be required to provide cash collateral or recognize financial losses on these contracts as a result of volatility in the market values of the underlying commodities and financial contracts or if a counterparty fails to perform under a contract. We could also be required to provide additional cash collateral if credit rating agency downgrades of our debt trigger more stringent requirements.

The Company strives to manage commodity price exposure by establishing risk limits and utilizing various financial instruments (exchange traded and over-the-counter instruments) to hedge physical obligations and reduce price volatility. We do not hedge the entire exposure of our operations from commodity price volatility. To the extent we do not hedge against commodity price volatility or our hedges are not effective, results of operations, cash flows and financial condition may be adversely impacted.

Failure to retain and attract key personnel could adversely affect the Company’s and Consolidated SCE&G’s operations and financial performance, particularly in light of uncertainties related to and resulting from abandonment of the Nuclear Project and the pending merger.

A significant portion of our workforce will be eligible for retirement during the next few years. Uncertainties related to regulatory, legislative and legal proceedings, as well as the proposed merger, also weigh significantly on the employment considerations made by current and prospective employees. We must attract, retain and develop executive officers and other professional, technical and craft employees with the skills and experience necessary to successfully manage, operate and grow our businesses. Competition for these employees is high, and in some cases we must compete for these employees on a regional or national basis. We may be unable to attract and retain these personnel. Further, the Company’s or Consolidated SCE&G’s ability to construct or maintain generation or other assets requires the availability of suitable skilled contractor personnel. We may be unable to obtain appropriate contractor personnel at the times and places needed. Labor disputes with employees or

contractors covered by collective bargaining agreements also could adversely affect implementation of our strategic plan and our operational and financial performance. Furthermore, increased medical benefit costs of employees and retirees could adversely affect the results of operations of the Company and Consolidated SCE&G. Medical costsprojection contained in this country have risen significantly over the past number of years and are expected to continue to increase at unpredictable rates. Such increases, unless satisfactorily managed by the Company and Consolidated SCE&G, could adversely affect results of operations.

report, see Forward-Looking Statements in Part I, Item 2. MD&A.

The Company and Consolidated SCE&G are subject to the risk that strategic decisions made by us either do not result in a return of or on invested capital or might negatively impact our competitive position, which can adversely impact our results of operations, cash flows, financial condition, and access to capital.

From time to time, the Company and Consolidated SCE&G make strategic decisions that may impact our direction with regard to business opportunities, the services and technologies offered to customers or that are used to serve customers, and the generating plants and other infrastructure that form the basis of much of our business. These strategic decisions may not result in a return of or on our invested capital, and the effects of these strategic decisions may have long-term implications that are not likely to be known to us in the short-term. Changing political climates and public attitudes, including customers' concerns regarding rate increases, such as the current environment relating to proposed recovery of costs, and a reasonable return on those costs, under the abandonment provisions of the BLRA or through other means, may adversely affect the ongoing acceptability of strategic decisions that have been made (and, in some cases, previously supported by legislation or approved by regulators), to the detriment of the Company or Consolidated SCE&G (e.g., further revision or repeal of the BLRA). In addition, operating covenants in the Merger Agreement require the consent of Dominion Energy prior to SCANA taking certain actions, which consent cannot be unreasonably withheld, during the pendency of the merger. As a result, the Company and Consolidated SCE&G may be unable to pursue strategic transactions, undertake significant capital projects, undertake certain significant financing or other specified transactions or pursue actions that are not in the ordinary course of business even if such actions would prove beneficial. Further, the Company's and Consolidated SCE&G's management and employees may be focused on completion of the merger, which could lead to the disruption of ongoing business or inconsistencies in service, standards, controls, procedures and policies, any of which could adversely affect the ability of the Company and Consolidated SCE&G to maintain relationships with customers, regulators, vendors and employees, or could otherwise adversely affect their business and financial results, without realizing any of the benefits of having the merger completed. Over time, these strategic decisions or changing attitudes toward such decisions, which could be adverse to the Company’s or Consolidated SCE&G’s interests, may have a negative effect on our results of operations, cash flows and financial condition, as well as limit our ability to access capital.

~~ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS~~

~~SCANA:~~

The following table provides information about purchases by or on behalf of SCANA or any affiliated purchaser (as defined in Rule 10b-18(a)(3) under the Securities Exchange Act of 1934, as amended (Exchange Act)) of shares or other units of any class of SCANA's equity securities that are registered pursuant to Section 12 of the Exchange Act:

Issuer Purchases of Equity Securities
(a) (b) (c) (d)
Period Total number of shares (or units) purchased
Average price paid
per share (or unit)

Total number of shares (or units) purchased as
part of publicly announced
plans or programs

Maximum number (or approximate dollar value) of shares (or units) that may yet be
purchased under the
plans or programs
April 1 - 30 10,197
$ 37.43
10,197

May 1 - 31 —
—
—

June 1 - 30 —
—
—

Total 10,197

10,197
*

*The preceding table represents shares acquired for non-employee directors under the Director Compensation and Deferral Plan. On December 16, 2014, SCANA announced a program to convert from original issue to open market purchase of SCANA common stock for all applicable compensation and dividend reinvestment plans. This program took effect in the first quarter of 2015 and has no stated maximum number of shares that may be purchased and no stated expiration date.

~~ITEM 5. OTHER INFORMATION~~

~~SCANA and SCE&G:~~

SCANA and SCE&G post information from time to time regarding developments relating to SCE&G’s Nuclear Project and other matters of interest to investors on SCANA’s website at www.scana.com (which is not intended to be an active hyperlink; the information on SCANA’s website is not a part of this report or any other report or document that SCANA or SCE&G files with or furnishes to the SEC). On SCANA’s homepage, there is a yellow box containing links to the Nuclear and Other Investor Information sections of the website. The Nuclear section contains a yellow box with a link to project news and updates. The Other Investor Information section of the website contains a link to recent investor-related information that cannot be found at other areas of the website. Some of the information that will be posted from time to time, including the quarterly reports that SCE&G submits to the SCPSC and the ORS in connection with the Nuclear Project, may be deemed to be material information that has not otherwise become public. Investors, media and other interested persons are encouraged to review this information and can sign up, under the Investor Relations section of the website, for an email alert when there is a new posting in the Nuclear and Other Investor Information yellow box.

ITEM 6. EXHIBITS

~~SCANA and SCE&G:~~

Exhibits filed or furnished with this Quarterly Report on Form 10-Q are listed in the following Exhibit Index.

As permitted under Item 601(b) (4) (iii) of Regulation S-K, instruments defining the rights of holders of long-term debt of less than 10% of the total consolidated assets of ~~SCANA, for itself and its subsidiaries, and of SCE&G,~~DESC, for itself and its consolidated affiliates, have been omitted and ~~SCANA and SCE&G agree~~DESC agrees to furnish a copy of such instruments to the SEC upon request.

EXHIBIT INDEX

Exhibit No.		Description
3.1
	~~Applicable to~~ ~~Form 10-Q of~~
~~Exhibit No.~~	~~SCANA~~	~~SCE&G~~	~~Description~~
2.01*	X		~~Agreement~~ Amended and ~~Plan of Merger by and among Dominion Energy, Sedona, and SCANA, dated as of January 2, 2018 (Filed as Exhibit 2.1 to Form 8-K~~ ~~on January 5, 2018 (File No. 001-08809 (SCANA)) and incorporated by reference herein)~~
~~3.01~~	X		Restated Articles of Incorporation, effective April 29, 2019 (Exhibit 3.1, Form 8-K filed April 29, 2019, File No. 1-3375).
3.2		Amended and Restated Bylaws, effective April 29, 2019 (Exhibit 3.2, Form 8-K filed April 29, 2019, File No. 1-3375).
31.1		Certification by Chief Executive Officer of ~~SCANA, as adopted on April 26, 1989 (Filed as Exhibit 3-A to Registration Statement No. 33-49145 and incorporated by reference herein). (Filed on paper - hyperlink is not required~~Dominion Energy South Carolina, Inc. pursuant to ~~Rule 105~~Section 302 of ~~Regulation S-T)~~the Sarbanes-Oxley Act of 2002 (filed herewith).
~~3.02~~ 31.2	X		~~Articles~~ Certification by Chief Financial Officer of ~~Amendment dated April 27, 1995 (Filed as Exhibit 4-A~~Dominion Energy South Carolina, Inc. pursuant to ~~Registration Statement No. 33-62421~~Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith). ~~and incorporated by reference herein)~~
~~3.03~~ 32.1	X		~~Articles of Amendment effective April 25, 2011 (~~ ~~Filed as Exhibit 4.03~~Certification to ~~Registration Statement No. 333-174796~~the Securities and ~~incorporated~~Exchange Commission by ~~reference herein)~~
~~3.04~~		X	~~Restated Articles of Incorporation of SCE&G, as adopted on December 30, 2009 (Filed as Exhibit 1 to Form 8-A (File Number 000-53860)~~ ~~and incorporated by reference herein)~~
~~3.05~~	X		~~By-Laws of SCANA as amended and restated as of December 30, 2016~~ ~~(Filed as Exhibit 3.05 to Form 10-K for the period ended December 31, 2016 (File No. 001-08809)~~ ~~and incorporated by reference herein)~~
~~3.06~~		X	~~By-Laws of SCE&G as revised and amended on February 22, 2001 (Filed as Exhibit 3.05 to Registration Statement No. 333-65460~~ ~~and incorporated by reference herein)~~
~~12.01~~	X	X	~~Statement Re Computation of Ratios~~ ~~(Filed herewith)~~
~~31.01~~	X		~~Certification of Principal Executive Officer Required by Rule 13a-14~~ ~~(Filed herewith)~~
~~31.02~~	X		~~Certification of Principal Financial Officer Required by Rule 13a-14~~ ~~(Filed herewith)~~
~~31.03~~		X	~~Certification of Principal Executive Officer Required by Rule 13a-14~~ ~~(Filed herewith)~~
~~31.04~~		X	~~Certification of Principal Financial Officer Required by Rule 13a-14~~ ~~(Filed herewith)~~
~~32.01~~	X		~~Certification of Principal~~Chief Executive Officer and ~~Principal~~Chief Financial Officer ~~Pursuant to 18 U.S.C.~~of Dominion Energy South Carolina, Inc. as required by Section ~~1350~~906 of the Sarbanes-Oxley Act of 2002 (furnished herewith). ~~(Furnished herewith)~~
~~32.02~~ 101		X	~~Certification~~ The following financial statements from Dominion Energy South Carolina, Inc.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2019, filed on August 2, 2019, formatted in iXBRL (Inline eXtensible Reporting Language): (i) Consolidated Balance Sheets, (ii) Consolidated Statements of ~~Principal Executive Officer~~Comprehensive Income (Loss), (iii) Consolidated Statements of Cash Flows, (iv) Consolidated Statements of Changes in Common Equity, and ~~Principal~~(v) the Notes to Consolidated Financial ~~Officer Pursuant to 18 U.S.C. Section 1350~~ ~~(Furnished herewith)~~
101. INS**	X	X	~~XBRL Instance Document~~
101. SCH**	X	X	~~XBRL Taxonomy Extension Schema~~
101. CAL**	X	X	~~XBRL Taxonomy Extension Calculation Linkbase~~
101. DEF**	X	X	~~XBRL Taxonomy Extension Definition Linkbase~~
101. LAB**	X	X	~~XBRL Taxonomy Extension Label Linkbase~~
101. PRE**	X	X	~~XBRL Taxonomy Extension Presentation Linkbase~~Statements.

* Schedules have been omitted pursuant to Item 601(b)(2) of Regulation S-K. SCANA agrees to furnish supplementally to the SEC a copy of any omitted schedule upon request by the SEC.

** Pursuant to Rule 406T of Regulation S-T, this interactive data file is deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, is deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, and otherwise is not subject to liability under these sections.

~~SIGNATURES~~

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, ~~each of~~ the ~~registrants~~registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. ~~The signature of each registrant shall be deemed to relate only to matters having reference to such registrant and any subsidiaries thereof.~~

	DOMINION ENERGY SOUTH CAROLINA, INC.
		(Registrant)
~~SCANA CORPORATION~~
~~SOUTH CAROLINA ELECTRIC & GAS COMPANY~~	By:	/s/ Michele L. Cardiff
~~(Registrants)~~



	~~By:~~	~~/s/James E. Swan, IV~~
Date: August 2, ~~2018~~2019		~~James E. Swan, IV~~	Michele L. Cardiff
		Vice President, Controller and ~~Controller~~
		~~(Principal accounting officer)~~Chief Accounting Officer

South Carolina	57-0248695
State or Other Jurisdiction of Incorporation or Organization		I.R.S. Employer Identification No.
~~Commission~~	~~Registrant, State of Incorporation,~~	~~I.R.S. Employer~~
~~File Number~~	~~Address and Telephone Number~~	~~Identification No.~~
~~1-8809~~	~~SCANA Corporation(a South Carolina corporation)~~	~~57-0784499~~
~~1-3375~~	~~South Carolina Electric & Gas Company(a South Carolina corporation)~~	~~57-0248695~~
	~~100 SCANA~~ 400 Otarre Parkway, Cayce, South Carolina ~~29033~~	29033
Address of Principal Executive Offices	~~(803) 217-9000~~	Zip Code



~~SCANA Corporation~~	Large accelerated filerx	☐		Accelerated filero	☐	Emerging growth company	☐
Non-accelerated filero	☒		Smaller reporting companyo	~~Emerging growth company~~ o
~~South Carolina Electric & Gas Company~~ ☐	~~Large accelerated filer~~ o	~~Accelerated filer~~ o	~~Non-accelerated filer~~ x	~~Smaller reporting company~~ o	~~Emerging growth company~~ o



	~~Description of~~	~~Shares Outstanding~~
~~Registrant~~	~~Common Stock~~	~~at July 27, 2018~~
~~SCANA Corporation~~	~~Without Par Value~~	~~142,625,416~~
~~South Carolina Electric & Gas Company~~	~~Without Par Value~~	~~40,296,147 (a)~~

Abbreviation or Acronym		Definition
2015 Task Order		Retail services agreement between DESC and the DOE, which includes a potential FERC jurisdictional charge for operating and maintaining DOE transmission facilities at the Savannah River Site
~~TERM~~ 2017 Tax Reform Act		~~MEANING~~
~~Act 258~~		~~Act 258 (previously referenced as H. 4375) adopted by the South Carolina General Assembly~~
~~AFC~~		~~Allowance for Funds Used During Construction~~
~~ANI~~		~~American Nuclear Insurers~~
~~AOCI~~		~~Accumulated Other Comprehensive Income (Loss)~~
~~ARO~~		~~Asset Retirement Obligation~~
~~Bankruptcy Court~~		~~U.S. Bankruptcy Court for the Southern District of New York~~
~~BLRA~~		~~Base Load Review Act~~
~~CAA~~		~~Clean Air Act, as amended~~
~~CAIR~~		~~Clean Air Interstate Rule~~
~~CCR~~		~~Coal Combustion Residuals~~
~~CEC~~		~~Columbia Energy Center~~
~~CEO~~		~~Chief Executive Officer~~
~~CFO~~		~~Chief Financial Officer~~
~~CFTC~~		~~Commodity Futures Trading Commission~~
~~Citibank~~		~~Citibank, N.A.~~
CO₂		~~Carbon Dioxide~~
~~Company~~		~~SCANA, together with its consolidated subsidiaries~~
~~Consolidated SCE&G~~		~~SCE&G and its consolidated affiliates~~
~~Consortium~~		~~A consortium consisting of WEC and WECTEC~~
~~Court of Appeals~~		~~United States Court of Appeals for the District of Columbia~~
~~CSAPR~~		~~Cross-State Air Pollution Rule~~
~~CUT~~		~~Customer Usage Tracker (decoupling mechanism)~~
~~CWA~~		~~Clean Water Act~~
~~DER~~		~~Distributed Energy Resource~~
~~DHEC~~		~~South Carolina Department of Health and Environmental Control~~
~~District Court~~		~~United States District Court for the District of South Carolina~~
~~Dodd-Frank~~		~~Dodd-Frank Wall Street Reform and Consumer Protection Act~~
~~Dominion Energy~~		~~Dominion Energy, Inc.~~
~~DOR~~		~~South Carolina Department of Revenue~~
~~DSM Programs~~		~~Electric Demand Side Management Programs~~
~~ELG Rule~~		~~Federal effluent limitation guidelines for steam electric generating units~~
~~EMANI~~		~~European Mutual Association for Nuclear Insurance~~
~~EPA~~		~~United States Environmental Protection Agency~~
~~EPC Contract~~		~~Engineering, Procurement and Construction Agreement dated May 23, 2008, as amended by the October 2015 Amendment~~
~~Exchange Act~~		~~Securities Exchange Act of 1934, as amended~~
~~FASB~~		~~Financial Accounting Standards Board~~
~~FERC~~		~~United States Federal Energy Regulatory Commission~~
~~FILOT~~		~~Fee in Lieu of Taxes~~
~~Fluor~~		~~Fluor Corporation~~
~~Fuel Company~~		~~South Carolina Fuel Company, Inc.~~
~~GAAP~~		~~Accounting principles generally accepted in the United States of America~~
~~GENCO~~		~~South Carolina Generating Company, Inc.~~
~~GHG~~		~~Greenhouse Gas~~
~~GPSC~~		~~Georgia Public Service Commission~~
~~GWh~~		~~Gigawatt hour~~
~~IAA~~		~~Interim Assessment Agreement dated March 28, 2017, as amended, among SCE&G, Santee Cooper, WEC and WECTEC~~
~~IRC~~		~~Internal Revenue Code of 1986, as amended~~



~~IRS~~		~~Internal Revenue Service~~
~~Joint Petition~~		Joint application and petition of SCE&G and Dominion Energy for review and approval of a proposed business combination as set forth in the Merger Agreement and for a prudency determination regarding the abandonment of the Nuclear Project and associated merger benefits and cost recovery plans, filed with the SCPSC on January 12, 2018
~~Level 1~~		~~A fair value measurement using unadjusted quoted prices in active markets for identical assets or liabilities~~
~~Level 2~~		A fair value measurement using observable inputs other than those for Level 1, including quoted prices for similar (not identical) assets or liabilities or inputs that are derived from observable market data by correlation or other means
~~Level 3~~		~~A fair value measurement using unobservable inputs, including situations where there is little, if any, market activity for the asset or liability~~
~~LOC~~		~~Lines of Credit~~
~~MATS~~		~~Mercury and Air Toxics Standards~~
~~Merger Agreement~~		~~Agreement and Plan of Merger, dated as of January 2, 2018, by and among Dominion Energy, Sedona and SCANA~~
~~MGP~~		~~Manufactured Gas Plant~~
~~MMBTU~~		~~Million British Thermal Units~~
~~MW or MWh~~		~~Megawatt or Megawatt-hour~~
~~NAAQS~~		~~National Ambient Air Quality Standards~~
~~NASDAQ~~		~~The NASDAQ Stock Market, Inc.~~
~~NAV~~		~~Net Asset Value~~
~~NCUC~~		~~North Carolina Utilities Commission~~
~~NEIL~~		~~Nuclear Electric Insurance Limited~~
~~NERC~~		~~North American Electric Reliability Corporation~~
~~NOL~~		~~Net Operating Loss~~
NO_X		~~Nitrogen Oxide~~
~~NPDES~~		~~National Pollutant Discharge Elimination System~~
~~NRC~~		~~United States Nuclear Regulatory Commission~~
~~NSPS~~		~~New Source Performance Standards~~
~~Nuclear Project~~		~~Project to construct Unit 2 and Unit 3 under the EPC Contract~~
~~NYMEX~~		~~New York Mercantile Exchange~~
~~OCI~~		~~Other Comprehensive Income~~
~~ORS~~		~~South Carolina Office of Regulatory Staff~~
~~PHMSA~~		~~United States Pipeline Hazardous Materials Safety Administration~~
~~Price-Anderson~~		~~Price-Anderson Indemnification Act~~
~~PSNC Energy~~		~~Public Service Company of North Carolina, Incorporated~~
~~Registrants~~		~~SCANA and SCE&G~~
~~Reorganization Plan~~		~~Modified Second Amended Joint Chapter 11 Plan of Reorganization, filed by WEC~~
~~Request~~		~~Request for Rate Relief filed by the ORS on September 26, 2017, as subsequently amended~~
~~RICO~~		~~The Racketeer Influenced and Corrupt Organizations Act~~
~~RSA~~		~~Natural Gas Rate Stabilization Act~~
~~RTO/ISO~~		~~Regional Transmission Organization/Independent System Operator~~
~~Santee Cooper~~		~~South Carolina Public Service Authority~~
~~SCANA~~		~~SCANA Corporation, the parent company~~
~~SCANA Energy~~		~~SCANA Energy Marketing, Inc.~~
~~SCANA Services~~		~~SCANA Services, Inc.~~
~~SCE&G~~		~~South Carolina Electric & Gas Company~~
~~SCEUC~~		~~South Carolina Energy Users Committee~~
~~SCPSC~~		~~Public Service Commission of South Carolina~~
~~SEC~~		~~United States Securities and Exchange Commission~~
~~Sedona~~		~~Sedona Corp., a wholly-owned subsidiary of Dominion Energy~~
~~SIP~~		~~State Implementation Plan~~
~~SLED~~		~~South Carolina Law Enforcement Division~~
SO₂		~~Sulfur Dioxide~~
~~Summer Station~~		~~V. C. Summer Nuclear Station~~


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

				Page
		Glossary of Terms		3
	~~Page~~
~~Cautionary Statement Regarding Forward-Looking Information~~			3

~~Definitions~~			4

PART I. FINANCIAL INFORMATION
~~Item 1. Financial Statements~~	7
Item 1.	~~SCANA Corporation~~	7Financial Statements		5
		~~Condensed Consolidated Balance Sheets~~	7
		~~Condensed Consolidated Statements of Income~~	9
		~~Condensed Consolidated Statements of Comprehensive Income~~	10
		~~Condensed Consolidated Statements of Cash Flows~~	11
		~~Condensed Consolidated Statements of Changes in Common Equity~~	12
	~~South Carolina Electric & Gas Company~~		13
		~~Condensed Consolidated Balance Sheets~~	13
		~~Condensed Consolidated Statements of Comprehensive Income~~	15
		~~Condensed Consolidated Statements of Cash Flows~~	16
		~~Condensed Consolidated Statements of Changes in Equity~~	17
	~~Notes to Condensed Consolidated Financial Statements~~		18

Item 2.				Management's Discussion and Analysis of Financial Condition and Results of Operations	53	31

~~Item 3. Quantitative and Qualitative Disclosures About Market Risk~~	65

Item 4.				Controls and Procedures	66	34

PART II. OTHER INFORMATION

Item 1.		Legal Proceedings	67	35

Item 1A.		Risk Factors	70	35

Item ~~2. Unregistered Sales of Equity Securities and Use of Proceeds~~ 6.		86Exhibits		36

~~Item 5. Other Information~~			87

~~Item 6. Exhibits~~			87

~~Exhibit Index~~			88

~~Signatures~~			89



~~Supreme Court~~		~~United States Supreme Court~~
~~Tax Act~~		An Act to Provide for Reconciliation Pursuant to Titles II and V of the Concurrent Resolution on the Budget for Fiscal Year 2018 (previously known as The Tax Cuts and Jobs Act) enacted on December 22, 2017
~~Toshiba~~ ACE Rule		Affordable Clean Energy Rule
AOCI		Accumulated other comprehensive income (loss)
ARO		Asset retirement obligation
BLRA		South Carolina Base Load Review Act
CCR		Coal combustion residual
CEO		Chief Executive Officer
CFO		Chief Financial Officer
Consortium		A consortium consisting of Westinghouse and WECTEC
CSAPR		Cross-State Air Pollution Rule
CWA		Clean Water Act
DESC		The legal entity, Dominion Energy South Carolina, Inc. (formerly known as South Carolina Electric & Gas Company), one or more of its consolidated affiliates or operating segments, or the entirety of Dominion Energy South Carolina, Inc. and its consolidated affiliates
DESS		Dominion Energy Southeast Services, Inc. (formerly known as SCANA Services, Inc.)
DOE		U.S. Department of Energy
Dominion Energy		The legal entity, Dominion Energy, Inc., one or more of its consolidated subsidiaries (other than SCANA and DESC) or operating segments, or the entirety of Dominion Energy, Inc. and its consolidated subsidiaries
DSM		Demand-side management
Electric Operations		Electric Operations Group operating segment
ELG Rule		Effluent limitations guidelines for the steam electric power generating category
EMANI		European Mutual Association for Nuclear Insurance
EPA		U.S. Environmental Protection Agency
Exchange Act		Securities Exchange Act of 1934, as amended
FERC		Federal Energy Regulatory Commission
FILOT		Fee in lieu of taxes
Fuel Company		South Carolina Fuel Company, Inc.
GAAP		U.S. generally accepted accounting principles
Gas Distribution		Gas Distribution Group operating segment
GENCO		South Carolina Generating Company, Inc.
IAA		Interim Assessment Agreement dated March 28, 2017, as amended, among DESC, Santee Cooper, Westinghouse and WECTEC
MATS		Utility Mercury and Air Toxics Standard Rule
MD&A		Management's Discussion and Analysis of Financial Condition and Results of Operations
MGP		Manufactured gas plant
MW		Megawatt
NEIL		Nuclear Electric Insurance Limited
NO_X		Nitrogen oxide
NPDES		National Pollutant Discharge Elimination System
NND Project		V. C. Summer Units 2 and 3 nuclear development project under which SCANA and Santee Cooper undertook to construct two Westinghouse AP1000 Advanced Passive Safety nuclear units in Jenkinsville, South Carolina
ORS		South Carolina Office of Regulatory Staff

Abbreviation or Acronym		Definition
Price-Anderson		Price-Anderson Nuclear Industries Indemnity Act
Reorganization Plan		Modified Second Amended Joint Chapter 11 Plan of Reorganization, filed by Westinghouse
RICO		Racketeer Influenced and Corrupt Organizations Act
Santee Cooper		South Carolina Public Service Authority
SCANA		The legal entity, SCANA Corporation, one or more of its consolidated subsidiaries (other than DESC) or the entirety of SCANA Corporation and its consolidated subsidiaries
SCANA Combination		Dominion Energy's acquisition of SCANA completed on January 1, 2019 pursuant to the terms of the SCANA Merger Agreement
SCANA Merger Agreement		Agreement and plan of merger entered on January 2, 2018 between Dominion Energy and SCANA
SCANA Merger Approval Order		Final order issued by the South Carolina Commission on December 21, 2018 setting forth its approval of the SCANA Combination
SCDHEC		South Carolina Department of Health and Environmental Control
SCDOR		South Carolina Department of Revenue
SEC		U.S. Securities and Exchange Commission
SO₂		Sulfur dioxide
South Carolina Commission		Public Service Commission of South Carolina
Summer		V. C. Summer nuclear power station
Toshiba		Toshiba Corporation, parent company of ~~WEC~~Westinghouse
Toshiba Settlement		Settlement Agreement dated as of July 27, 2017, by and among Toshiba, ~~SCE&G~~DESC and Santee Cooper
~~Unit 1~~ VIE		~~Nuclear Unit 1 at Summer Station~~ Variable interest entity
~~Unit 2~~ WECTEC		~~Nuclear Unit 2 at Summer Station (abandoned prior to construction completion)~~
~~Unit 3~~		~~Nuclear Unit 3 at Summer Station (abandoned prior to construction completion)~~
~~VIE~~		~~Variable Interest Entity~~
~~WARN Act~~		~~Worker Adjustment and Retraining Notification Act~~
~~WEC~~		~~Westinghouse Electric Company LLC~~
~~WEC Subcontractors~~		~~Subcontractors to the Consortium~~
~~WECTEC~~		WECTEC Global Project Services, Inc. (formerly known as Stone & Webster, Inc.), a wholly-owned subsidiary of ~~WEC~~Westinghouse
~~Williams Station~~ Westinghouse		~~A.M. Williams Generating Station, owned by GENCO~~ Westinghouse Electric Company LLC
~~WNA~~ Westinghouse Subcontractors		~~Weather Normalization Adjustment~~ Subcontractors and suppliers to the Consortium



Millions of dollars	June 30, 2018			December 31, 2017
Assets
Utility Plant In Service	$	14,926		$	14,370
Accumulated Depreciation and Amortization	(4,995		)	(4,611		)
Construction Work in Progress	470			471
Nuclear Fuel, Net of Accumulated Amortization	193			208
Goodwill, net of writedown of $230	210			210
Utility Plant, Net	10,804			10,648
Nonutility Property and Investments:
Nonutility property, net of accumulated depreciation of $138 and $133	267			270
Assets held in trust, net-nuclear decommissioning	136			136
Other investments	139			68
Nonutility Property and Investments, Net	542			474
Current Assets:
Cash and cash equivalents	238			409
Receivables:
Customer, net of allowance for uncollectible accounts of $6 and $6	517			665
Income taxes	206			198
Other	99			105
Inventories (at average cost):
Fuel and gas supply	119			143
Materials and supplies	167			161
Prepayments	134			99
Other current assets	14			17
Derivative financial instruments	—			54
Total Current Assets	1,494			1,851
Deferred Debits and Other Assets:
Regulatory assets	5,757			5,580
Other	304			186
Total Deferred Debits and Other Assets	6,061			5,766
Total	$	18,901		$	18,739



	Common Stock									Accumulated Other Comprehensive Income (Loss)
Millions	Shares	Outstanding Amount		Treasury Amount			Retained Earnings			Gains (Losses) from Cash Flow Hedges			Deferred Employee Benefit Plans			Total AOCI			Total
Balance as of January 1, 2018	143	$	2,402	$	(12	)	$	2,915		$	(37	)	$	(13	)	$	(50	)	$	5,255
Net Income							177												177
Other Comprehensive Income (Loss)
Gains arising during the period										4			—			4			4
Losses/amortization reclassified from AOCI										6			1			7			7
Total Comprehensive Income							177			10			1			11			188
Purchase of Treasury Stock	—	—		(1		)													(1		)
Dividends Declared							(105		)										(105		)
Balance as of June 30, 2018	143	$	2,402	$	(13	)	$	2,987		$	(27	)	$	(12	)	$	(39	)	$	5,337

Balance as of January 1, 2017	143	$	2,402	$	(12	)	$	3,384		$	(36	)	$	(13	)	$	(49	)	$	5,725
Net Income							292												292
Other Comprehensive Income (Loss)
Losses arising during the period										(5		)	—			(5		)	(5		)
Losses/amortization reclassified from AOCI										2			—			2			2
Total Comprehensive Income							292			(3		)	—			(3		)	289
Purchase of Treasury Stock	—	—		(1		)													(1		)
Dividends Declared							(175		)										(175		)
Balance as of June 30, 2017	143	$	2,402	$	(13	)	$	3,501		$	(39	)	$	(13	)	$	(52	)	$	5,838



Increase (Decrease) Millions of dollars	The Company						Consolidated SCE&G
June 30, 2017	Three Months Ended			Six Months Ended			Three Months Ended			Six Months Ended
Other operation and maintenance	$	(2	)	$	(6	)	$	(1	)	$	(5	)
Total Operating Expenses	(2		)	(6		)	(1		)	(5		)
Operating Income	2			6			1			5
Other Income (Expense), Net	(2		)	(6		)	(1		)	(5		)



Regulatory Liabilities:
Monetization of guaranty settlement	$	1,098	$	1,095	$	1,098	$	1,095
Accumulated deferred income taxes	1,074		1,076		915		914
Asset removal costs	768		757		535		527
Deferred gains on interest rate derivatives	78		131		78		131
Other	1		—		1		—
Total Regulatory Liabilities	$	3,019	$	3,059	$	2,627	$	2,667



The Company	Consolidated SCE&G				PSNC Energy				Gas-nonregulated
Millions of dollars	Electric		Gas-regulated		Gas-regulated		Total Gas-regulated		Gas-nonregulated
Three months ended June 30, 2018
Customer class:
Residential	$	243	$	34	$	38	$	72	$	30
Commercial	171		22		18		40		16
Industrial	106		21		4		25		91
Other	30		2		7		9		6
Revenues from contracts with customers	550		79		67		146		143
Other operating revenues	3		—		2		2		—
Total Operating Revenues	$	553	$	79	$	69	$	148	$	143

Six months ended June 30, 2018
Customer class:
Residential	$	495	$	120	$	183	$	303	$	136
Commercial	340		61		66		127		50
Industrial	191		45		10		55		211
Other	68		7		15		22		19
Revenues from contracts with customers	1,094		233		274		507		416
Other operating revenues	6		1		1		2		—
Total Operating Revenues	$	1,100	$	234	$	275	$	509	$	416



The Company and Consolidated SCE&G
Millions of dollars	Regulatory Assets
January 1, 2018	$	16.3
Additional costs	—
Amortization	(0.8		)
Impairment	—
June 30, 2018	$	15.5



June 30, 2018 (Millions of dollars)	Total		SCANA			Consolidated SCE&G			PSNC Energy
Lines of credit:	+
Five-year, expiring December 2020	$	1,300.0	$	400.0		$	700.0		$	200.0
Fuel Company five-year, expiring December 2020	500.0		—			500.0			—
Three-year, expiring December 2018	200.0		—			200.0			—
Total committed long-term	2,000.0		400.0			1,400.0			200.0
LOC advances	100.0		—			100.0			—
Weighted average interest rate			—			3.31		%	—
Outstanding commercial paper (270 or fewer days)	517.4		29.0			457.5			30.9
Weighted average interest rate			2.99		%	2.96		%	2.61		%
Letters of credit supported by LOC	33.7		33.4			0.3			—
Available	$	1,348.9	$	337.6		$	842.2		$	169.1



December 31, 2017 (Millions of dollars)	Total		SCANA		Consolidated SCE&G			PSNC Energy
Lines of credit:
Five-year, expiring December 2020	$	1,300.0	$	400.0	$	700.0		$	200.0
Fuel Company five-year, expiring December 2020	500.0		—		500.0			—
Three-year, expiring December 2018	200.0		—		200.0			—
Total committed long-term	2,000.0		400.0		1,400.0			200.0
Outstanding commercial paper (270 or fewer days)	350.3		—		251.6			98.7
Weighted average interest rate			—		1.92		%	1.93		%
Letters of credit supported by LOC	3.3		3.0		0.3			—
Available	$	1,646.4	$	397.0	$	1,148.1		$	101.3



	Commodity and Other Energy Management Contracts (in MMBTU)
Hedge designation	Gas Distribution	Gas Marketing	Total
As of June 30, 2018
Commodity contracts	6,090,000	14,412,000	20,502,000
Energy management contracts (a)	—	41,876,028	41,876,028
Total (a)	6,090,000	56,288,028	62,378,028

As of December 31, 2017
Commodity contracts	6,430,000	13,433,000	19,863,000
Energy management contracts (a)	—	41,856,890	41,856,890
Total (a)	6,430,000	55,289,890	61,719,890



Interest Rate Swaps
	The Company				Consolidated SCE&G
Millions of dollars	June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
Designated as hedging instruments	$	106.8	$	111.2	$	36.4	$	36.4
Not designated as hedging instruments	35.0		735.0		35.0		735.0



Fair Values of Derivative Instruments
		The Company				Consolidated SCE&G
Millions of dollars	Balance Sheet Location	Asset		Liability		Asset		Liability
As of June 30, 2018
Designated as hedging instruments
Interest rate contracts	Derivative financial instruments	—		$	3	—		$	1
	Other deferred credits and other liabilities	—		17		—		6

Commodity contracts	Prepayments	$	1	—		—		—
Total		$	1	$	20	—		$	7

Not designated as hedging instruments
Interest rate contracts	Other deferred credits and other liabilities	—		$	3	—		$	3

Commodity contracts	Prepayments	$	1	—		—		—

Energy management contracts	Other current assets	1		—		—		—
	Other deferred debits and other assets	1		—		—		—
	Other current liabilities	—		1		—		—
	Derivative financial instruments	—		1		—		—
Total		$	3	$	5	—		$	3

As of December 31, 2017
Designated as hedging instruments
Interest rate contracts	Derivative financial instruments	—		$	3	—		$	1
	Other deferred credits and other liabilities	—		24		—		9

Commodity contracts	Prepayments	—		2		—		—
	Other current assets	—		1		—		—
Total		—		$	30	—		$	10

Not designated as hedging instruments
Interest rate contracts	Derivative financial instruments	$	54	$	1	$	54	$	1
	Other deferred credits and other liabilities	—		4		—		4

Commodity contracts	Other current assets	1		—		—		—

Energy management contracts	Prepayments	—		1		—		—
	Other current assets	3		—		—		—
	Other deferred debits and other assets	1		—		—		—
	Derivative financial instruments	—		2		—		—
Total		$	59	$	8	$	54	$	5



The Company and Consolidated SCE&G:
	Gain (Loss) Deferred in Regulatory Accounts						Gain (Loss) Reclassified from Deferred Accounts into Income
	Gain (Loss) Deferred in Regulatory Accounts						Gain (Loss) Reclassified from Deferred Accounts into Income
Millions of dollars	2018		2017			Location	2018			2017
Three Months Ended June 30,
Interest rate contracts	—		$	(1	)	Interest expense	$	(1	)	—
Six Months Ended June 30,
Interest rate contracts	$	2	$	(1	)	Interest expense	$	(1	)	$	(1	)



The Company:
	Gain (Loss) Recognized in OCI, net of tax						Gain (Loss) Reclassified from AOCI into Income, net of tax
	Gain (Loss) Recognized in OCI, net of tax						Gain (Loss) Reclassified from AOCI into Income, net of tax
Millions of dollars	2018		2017			Location	2018			2017
Three Months Ended June 30,
Interest rate contracts	—		$	(1	)	Interest expense	$	(2	)	$	(2	)
Commodity contracts	$	1	(2		)	Gas purchased for resale	—			—
Total	$	1	$	(3	)		$	(2	)	$	(2	)

Six Months Ended June 30,
Interest rate contracts	$	2	$	(1	)	Interest expense	$	(4	)	$	(4	)
Commodity contracts	2		(4		)	Gas purchased for resale	(2		)	2
Total	$	4	$	(5	)		$	(6	)	$	(2	)



Derivative Assets	The Company								Consolidated SCE&G
Millions of dollars	Interest Rate Contracts		Commodity Contracts		Energy Management Contracts		Total		Interest Rate Contracts
As of June 30, 2018
Gross Amounts of Recognized Assets	—		$	2	$	2	$	4	—
Gross Amounts Offset in Statement of Financial Position	—		—		—		—		—
Net Amounts Presented in Statement of Financial Position	—		2		2		4		—
Gross Amounts Not Offset - Financial Instruments	—		—		—		—		—
Gross Amounts Not Offset - Cash Collateral Received	—		—		—		—		—
Net Amount	—		$	2	$	2	$	4	—
Balance sheet location
Prepayments							$	2	—
Other current assets							1		—
Other deferred debits and other assets							1		—
Total							$	4	—

As of December 31, 2017
Gross Amounts of Recognized Assets	$	54	$	1	$	4	$	59	$	54
Gross Amounts Offset in Statement of Financial Position	—		—		—		—		—
Net Amounts Presented in Statement of Financial Position	54		1		4		59		54
Gross Amounts Not Offset - Financial Instruments	—		—		—		—		—
Gross Amounts Not Offset - Cash Collateral Received	—		—		—		—		—
Net Amount	$	54	$	1	$	4	$	59	$	54
Balance sheet location
Other current assets							$	58	$	54
Other deferred debits and other assets							1		—
Total							$	59	$	54



Derivative Liabilities	The Company											Consolidated SCE&G
Millions of dollars	Interest Rate Contracts			Commodity Contracts		Energy Management Contracts			Total			Interest Rate Contracts
As of June 30, 2018
Gross Amounts of Recognized Liabilities	$	23		—		$	2		$	25		$	10
Gross Amounts Offset in Statement of Financial Position	—			—		—			—			—
Net Amounts Presented in Statement of Financial Position	23			—		2			25			10
Gross Amounts Not Offset - Financial Instruments	—			—		—			—			—
Gross Amounts Not Offset - Cash Collateral Posted	(24		)	—		(1		)	(25		)	(11		)
Net Amount	$	(1	)	—		$	1		—			$	(1	)
Balance sheet location
Derivative financial instruments									$	4		$	1
Other current liabilities									1			—
Other deferred credits and other liabilities									20			9
Total									$	25		$	10

As of December 31, 2017
Gross Amounts of Recognized Liabilities	$	32		$	3	$	3		$	38		$	15
Gross Amounts Offset in Statement of Financial Position	—			—		(1		)	(1		)	—
Net Amounts Presented in Statement of Financial Position	32			3		2			37			15
Gross Amounts Not Offset - Financial Instruments	—			—		—			—			—
Gross Amounts Not Offset - Cash Collateral Posted	28			—		(1		)	27			—
Net Amount	$	60		$	3	$	1		$	64		$	15
Balance sheet location
Other current assets									$	2		—
Derivative financial instruments									7			$	2
Other deferred credits and other liabilities									28			13
Total									$	37		$	15



Three Months Ended June 30, 2017
Electric Operations	$	679	$	2		$	246	n/a
Gas Distribution	140		1			4		n/a
Gas Marketing	182		34			n/a		$	1
All Other	—		102			—		(7		)
Adjustments/Eliminations	—		(139		)	1		127
Consolidated Total	$	1,001	$	—		$	251	$	121

Six Months Ended June 30, 2017
Electric Operations	$	1,256	$	3		$	428	n/a
Gas Distribution	461		1			117		n/a
Gas Marketing	456		58			n/a		$	16
All Other	—		196			—		(7		)
Adjustments/Eliminations	—		(258		)	26		283
Consolidated Total	$	2,173	$	—		$	571	$	292



Consolidated SCE&G
Millions of dollars	External Revenue		Operating Income		Earnings Available to Common Shareholder
Three Months Ended June 30, 2018
Electric Operations	$	553	$	107	n/a
Gas Distribution	79		—		n/a
Adjustments/Eliminations	—		—		$	26
Consolidated Total	$	632	$	107	$	26

Six Months Ended June 30, 2018
Electric Operations	$	1,100	$	180	n/a
Gas Distribution	234		47		n/a
Adjustments/Eliminations	—		—		$	150
Consolidated Total	$	1,334	$	227	$	150



Segment Assets	The Company				Consolidated SCE&G
	June 30,		December 31,		June 30,		December 31,
Millions of dollars	2018		2017		2018		2017
Electric Operations	$	12,082	$	11,979	$	12,082	$	11,979
Gas Distribution	3,292		3,259		895		869
Gas Marketing	214		230		n/a		n/a
All Other	1,039		1,042		n/a		n/a
Adjustments/Eliminations	2,274		2,229		3,298		3,098
Consolidated Total	$	18,901	$	18,739	$	16,275	$	15,946



	Second Quarter				Year to Date
The Company	2018		2017		2018		2017
Earnings per share	$	0.06	$	0.85	$	1.24	$	2.04

Consolidated SCE&G
Net income (millions of dollars)	$	31.0	$	125.7	$	158.7	$	238.0



	Second Quarter		Year to Date
Classification	2018	2017	2018	2017
Residential	1,968	1,916	3,955	3,553
Commercial	1,870	1,872	3,574	3,504
Industrial	1,612	1,565	3,101	3,024
Other	149	147	280	281
Total Retail Sales	5,599	5,500	10,910	10,362
Wholesale	244	228	486	441
Total Sales	5,843	5,728	11,396	10,803



Expected Maturity	2018	2019	2020	2021
Futures - Long
Settlement Price (a)	2.97	2.95	2.89	—
Contract Amount (b)	27.1	32.9	2.9	—
Fair Value (b)	27.4	33.0	2.9	—

Futures - Short
Settlement Price (a)	2.91	—	—	—
Contract Amount (b)	0.9	—	—	—
Fair Value (b)	0.9	—	—	—

Options - Purchased Call (Long)
Strike Price (a)	3.26	3.08	—	—
Contract Amount (b)	8.7	10.3	—	—
Fair Value (b)	0.6	0.8	—	—

Options Sold Call (Short)
Strike Price (a)	0.20	—	—	—
Contract Amount (b)	0.3	—	—	—
Fair Value (b)	0.3	—	—	—

Swaps - Commodity
Pay fixed/receive variable (b)	5.6	7.1	3.3	0.3
Average pay rate (a)	3.2210	2.9257	2.8627	2.7890
Average received rate (a)	2.9520	2.8581	2.7039	2.7157
Fair value (b)	5.1	6.9	3.2	0.2

Pay variable/receive fixed (b)	14.5	18.3	3.3	—
Average pay rate (a)	2.9532	2.8607	2.7172	—
Average received rate (a)	3.0556	2.9001	2.8586	—
Fair value (b)	15.0	18.5	3.5	—

Swaps - Basis
Pay variable/receive variable (b)	19.8	15.2	—	—
Average pay rate (a)	2.9162	3.0094	—	—
Average received rate (a)	2.9004	3.0033	—	—
Fair value (b)	19.7	15.2	—	—

(a) Weighted average, in dollars
(b) Millions of dollars



Issuer Purchases of Equity Securities
	(a)	(b)		(c)	(d)
Period	Total number of shares (or units) purchased	Average price paid per share (or unit)		Total number of shares (or units) purchased as part of publicly announced plans or programs	Maximum number (or approximate dollar value) of shares (or units) that may yet be purchased under the plans or programs
April 1 - 30	10,197	$	37.43	10,197
May 1 - 31	—	—		—
June 1 - 30	—	—		—
Total	10,197			10,197	*