|
||||||||||||
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
|
||||||||||||
FORM 10-Q
|
||||||||||||
(Mark One)
|
||||||||||||
[X]
|
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
|
|||||||||||
For the quarterly period ended
|
June 30, 2015
|
|||||||||||
or
|
||||||||||||
[ ]
|
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
|
|||||||||||
For the transition period from
|
to
|
|||||||||||
Commission File No.
|
Exact Name of Registrants as Specified in their Charters, Address and Telephone Number
|
States of Incorporation
|
I.R.S. Employer
Identification Nos.
|
Former name, former address and former fiscal year, if changed since last report
|
||||||||
1-14201
|
SEMPRA ENERGY
|
California
|
33-0732627
|
101 Ash Street
|
||||||||
488 8th Avenue
|
San Diego,
|
|||||||||||
San Diego, California 92101
|
California 92101
|
|||||||||||
(619)696-2000
|
||||||||||||
1-03779
|
SAN DIEGO GAS & ELECTRIC COMPANY
|
California
|
95-1184800
|
No change
|
||||||||
8326 Century Park Court
|
||||||||||||
San Diego, California 92123
|
||||||||||||
(619)696-2000
|
||||||||||||
1-01402
|
SOUTHERN CALIFORNIA GAS COMPANY
|
California
|
95-1240705
|
No change
|
||||||||
555 West Fifth Street
|
||||||||||||
Los Angeles, California 90013
|
||||||||||||
(213)244-1200
|
||||||||||||
|
||||||||||||
Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.
|
||||||||||||
Yes
|
X
|
No
|
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
|
||||||||||||
Sempra Energy
|
Yes
|
X
|
No
|
|||||||||
San Diego Gas & Electric Company
|
Yes
|
X
|
No
|
|||||||||
Southern California Gas Company
|
Yes
|
X
|
No
|
|||||||||
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
|
||||||||||||
|
||||||||||||
Large
accelerated filer
|
Accelerated filer
|
Non-accelerated filer
|
Smaller reporting company
|
|||||||||
Sempra Energy
|
[ X ]
|
[ ]
|
[ ]
|
[ ]
|
||||||||
San Diego Gas & Electric Company
|
[ ]
|
[ ]
|
[ X ]
|
[ ]
|
||||||||
Southern California Gas Company
|
[ ]
|
[ ]
|
[ X ]
|
[ ]
|
||||||||
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
|
||||||||||||
|
||||||||||||
Sempra Energy
|
Yes
|
No
|
X
|
|||||||||
San Diego Gas & Electric Company
|
Yes
|
No
|
X
|
|||||||||
Southern California Gas Company
|
Yes
|
No
|
X
|
|||||||||
Indicate the number of shares outstanding of each of the issuers’ classes of common stock, as of the latest practicable date.
|
||||||||||||
Common stock outstanding on July 29, 2015:
|
||||||||||||
Sempra Energy
|
247,915,696 shares
|
|||||||||||
San Diego Gas & Electric Company
|
Wholly owned by Enova Corporation, which is wholly owned by Sempra Energy
|
|||||||||||
Southern California Gas Company
|
Wholly owned by Pacific Enterprises, which is wholly owned by Sempra Energy
|
|||||||||||
SEMPRA ENERGY FORM 10-Q
SAN DIEGO GAS & ELECTRIC COMPANY FORM 10-Q
SOUTHERN CALIFORNIA GAS COMPANY FORM 10-Q
TABLE OF CONTENTS
|
||
Page
|
||
Information Regarding Forward-Looking Statements
|
4
|
|
PART I – FINANCIAL INFORMATION
|
||
Item 1.
|
Financial Statements
|
6
|
Item 2.
|
Management’s Discussion and Analysis of Financial Condition and Results of Operations
|
76
|
Item 3.
|
Quantitative and Qualitative Disclosures About Market Risk
|
116
|
Item 4.
|
Controls and Procedures
|
117
|
PART II – OTHER INFORMATION
|
||
Item 1.
|
Legal Proceedings
|
118
|
Item 1A.
|
Risk Factors
|
118
|
Item 6.
|
Exhibits
|
118
|
Signatures
|
120
|
|
§
|
local, regional, national and international economic, competitive, political, legislative and regulatory conditions and developments;
|
§
|
actions and the timing of actions, including issuances of permits to construct and licenses for operation, by the California Public Utilities Commission, California State Legislature, U.S. Department of Energy, Federal Energy Regulatory Commission, Nuclear Regulatory Commission, Atomic Safety and Licensing Board, California Energy Commission, U.S. Environmental Protection Agency, California Air Resources Board, and other regulatory, governmental and environmental bodies in the United States and other countries in which we operate;
|
§
|
the timing and success of business development efforts and construction, maintenance and capital projects, including risks in obtaining, maintaining or extending permits, licenses, certificates and other authorizations on a timely basis and risks in obtaining adequate and competitive financing for such projects;
|
§
|
energy markets, including the timing and extent of changes and volatility in commodity prices, and the impact of any protracted reduction in oil prices from historical averages;
|
§
|
the impact on the value of our natural gas storage assets from low natural gas prices, low volatility of natural gas prices and the inability to procure favorable long-term contracts for natural gas storage services;
|
§
|
delays in the timing of costs incurred and the timing of the regulatory agency authorization to recover such costs in rates from customers;
|
§
|
deviations from regulatory precedent or practice that result in a reallocation of benefits or burdens among shareholders and ratepayers;
|
§
|
capital markets conditions, including the availability of credit and the liquidity of our investments;
|
§
|
inflation, interest and currency exchange rates;
|
§
|
the impact of benchmark interest rates, generally Moody’s A-rated utility bond yields, on our California Utilities’ cost of capital;
|
§
|
the availability of electric power, natural gas and liquefied natural gas, and natural gas pipeline and storage capacity, including disruptions caused by failures in the North American transmission grid, pipeline explosions and equipment failures and the decommissioning of San Onofre Nuclear Generating Station (SONGS);
|
§
|
cybersecurity threats to the energy grid, natural gas storage and pipeline infrastructure, the information and systems used to operate our businesses and the confidentiality of our proprietary information and the personal information of our customers, terrorist attacks that threaten system operations and critical infrastructure, and wars;
|
§
|
the ability to win competitively bid infrastructure projects against a number of strong competitors willing to aggressively bid for these projects;
|
§
|
weather conditions, conservation efforts, natural disasters, catastrophic accidents, and other events that may disrupt our operations, damage our facilities and systems, and subject us to third-party liability for property damage or personal injuries;
|
§
|
risks that our partners or counterparties will be unable or unwilling to fulfill their contractual commitments;
|
§
|
risks posed by decisions and actions of third parties who control the operations of investments in which we do not have a controlling interest;
|
§
|
risks inherent with nuclear power facilities and radioactive materials storage, including the catastrophic release of such materials, the disallowance of the recovery of the investment in, or operating costs of, the nuclear facility due to an extended outage and facility closure, and increased regulatory oversight, including motions to modify settlements;
|
§
|
business, regulatory, environmental and legal decisions and requirements;
|
§
|
expropriation of assets by foreign governments and title and other property disputes;
|
§
|
the impact on reliability of San Diego Gas & Electric Company’s (SDG&E) electric transmission and distribution system due to increased amount and variability of power supply from renewable energy sources;
|
§
|
the impact on competitive customer rates of the growth in distributed and local power generation and the corresponding decrease in demand for power delivered through SDG&E’s electric transmission and distribution system;
|
§
|
the inability or determination not to enter into long-term supply and sales agreements or long-term firm capacity agreements due to insufficient market interest, unattractive pricing or other factors;
|
§
|
the resolution of litigation; and
|
§
|
other uncertainties, all of which are difficult to predict and many of which are beyond our control.
|
SEMPRA ENERGY
|
|||||||||
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
|
|||||||||
(Dollars in millions, except per share amounts)
|
|||||||||
Three months ended June 30,
|
Six months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
||||||
(unaudited)
|
|||||||||
REVENUES
|
|||||||||
Utilities
|
$
|
2,133
|
$
|
2,370
|
$
|
4,555
|
$
|
4,855
|
|
Energy-related businesses
|
234
|
308
|
494
|
618
|
|||||
Total revenues
|
2,367
|
2,678
|
5,049
|
5,473
|
|||||
EXPENSES AND OTHER INCOME
|
|||||||||
Utilities:
|
|||||||||
Cost of natural gas
|
(239)
|
(395)
|
(585)
|
(1,015)
|
|||||
Cost of electric fuel and purchased power
|
(498)
|
(571)
|
(979)
|
(1,081)
|
|||||
Energy-related businesses:
|
|||||||||
Cost of natural gas, electric fuel and purchased power
|
(73)
|
(126)
|
(171)
|
(264)
|
|||||
Other cost of sales
|
(42)
|
(42)
|
(77)
|
(80)
|
|||||
Operation and maintenance
|
(713)
|
(729)
|
(1,371)
|
(1,405)
|
|||||
Depreciation and amortization
|
(307)
|
(288)
|
(610)
|
(574)
|
|||||
Franchise fees and other taxes
|
(96)
|
(92)
|
(203)
|
(197)
|
|||||
Plant closure adjustment
|
―
|
―
|
21
|
13
|
|||||
Gain on sale of equity interest and assets
|
62
|
2
|
62
|
29
|
|||||
Equity earnings, before income tax
|
27
|
23
|
46
|
40
|
|||||
Other income, net
|
37
|
49
|
76
|
89
|
|||||
Interest income
|
10
|
5
|
17
|
9
|
|||||
Interest expense
|
(139)
|
(138)
|
(273)
|
(274)
|
|||||
Income before income taxes and equity earnings
|
|||||||||
of certain unconsolidated subsidiaries
|
396
|
376
|
1,002
|
763
|
|||||
Income tax expense
|
(98)
|
(93)
|
(261)
|
(220)
|
|||||
Equity earnings, net of income tax
|
22
|
9
|
37
|
15
|
|||||
Net income
|
320
|
292
|
778
|
558
|
|||||
Earnings attributable to noncontrolling interests
|
(24)
|
(22)
|
(45)
|
(41)
|
|||||
Preferred dividends of subsidiary
|
(1)
|
(1)
|
(1)
|
(1)
|
|||||
Earnings
|
$
|
295
|
$
|
269
|
$
|
732
|
$
|
516
|
|
Basic earnings per common share
|
$
|
1.19
|
$
|
1.10
|
$
|
2.95
|
$
|
2.10
|
|
Weighted-average number of shares outstanding, basic (thousands)
|
248,108
|
245,688
|
247,916
|
245,484
|
|||||
Diluted earnings per common share
|
$
|
1.17
|
$
|
1.08
|
$
|
2.91
|
$
|
2.07
|
|
Weighted-average number of shares outstanding, diluted (thousands)
|
251,491
|
250,061
|
251,264
|
249,816
|
|||||
Dividends declared per share of common stock
|
$
|
0.70
|
$
|
0.66
|
$
|
1.40
|
$
|
1.32
|
|
See Notes to Condensed Consolidated Financial Statements.
|
SEMPRA ENERGY
|
|||||||||||
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
|
|||||||||||
(Dollars in millions)
|
|||||||||||
Sempra Energy shareholders' equity
|
|||||||||||
Pretax
|
Income tax
|
Net-of-tax
|
Noncontrolling
|
||||||||
amount
|
(expense) benefit
|
amount
|
interests (after-tax)
|
Total
|
|||||||
Three months ended June 30, 2015 and 2014
|
|||||||||||
(unaudited)
|
|||||||||||
2015:
|
|||||||||||
Net income
|
$
|
394
|
$
|
(98)
|
$
|
296
|
$
|
24
|
$
|
320
|
|
Other comprehensive income (loss):
|
|||||||||||
Foreign currency translation adjustments
|
(43)
|
―
|
(43)
|
(5)
|
(48)
|
||||||
Pension and other postretirement benefits
|
2
|
(1)
|
1
|
―
|
1
|
||||||
Financial instruments
|
95
|
(36)
|
59
|
6
|
65
|
||||||
Total other comprehensive income
|
54
|
(37)
|
17
|
1
|
18
|
||||||
Comprehensive income
|
448
|
(135)
|
313
|
25
|
338
|
||||||
Preferred dividends of subsidiary
|
(1)
|
―
|
(1)
|
―
|
(1)
|
||||||
Comprehensive income, after preferred
|
|||||||||||
dividends of subsidiary
|
$
|
447
|
$
|
(135)
|
$
|
312
|
$
|
25
|
$
|
337
|
|
2014:
|
|||||||||||
Net income
|
$
|
363
|
$
|
(93)
|
$
|
270
|
$
|
22
|
$
|
292
|
|
Other comprehensive income (loss):
|
|||||||||||
Foreign currency translation adjustments
|
2
|
―
|
2
|
1
|
3
|
||||||
Pension and other postretirement benefits
|
8
|
(3)
|
5
|
―
|
5
|
||||||
Financial instruments
|
(12)
|
5
|
(7)
|
(1)
|
(8)
|
||||||
Total other comprehensive loss
|
(2)
|
2
|
―
|
―
|
―
|
||||||
Comprehensive income
|
361
|
(91)
|
270
|
22
|
292
|
||||||
Preferred dividends of subsidiary
|
(1)
|
―
|
(1)
|
―
|
(1)
|
||||||
Comprehensive income, after preferred
|
|||||||||||
dividends of subsidiary
|
$
|
360
|
$
|
(91)
|
$
|
269
|
$
|
22
|
$
|
291
|
Six months ended June 30, 2015 and 2014
|
|||||||||||
(unaudited)
|
|||||||||||
2015:
|
|||||||||||
Net income
|
$
|
994
|
$
|
(261)
|
$
|
733
|
$
|
45
|
$
|
778
|
|
Other comprehensive income (loss):
|
|||||||||||
Foreign currency translation adjustments
|
(105)
|
―
|
(105)
|
(13)
|
(118)
|
||||||
Pension and other postretirement benefits
|
4
|
(2)
|
2
|
―
|
2
|
||||||
Financial instruments
|
6
|
(2)
|
4
|
1
|
5
|
||||||
Total other comprehensive loss
|
(95)
|
(4)
|
(99)
|
(12)
|
(111)
|
||||||
Comprehensive income
|
899
|
(265)
|
634
|
33
|
667
|
||||||
Preferred dividends of subsidiary
|
(1)
|
―
|
(1)
|
―
|
(1)
|
||||||
Comprehensive income, after preferred
|
|||||||||||
dividends of subsidiary
|
$
|
898
|
$
|
(265)
|
$
|
633
|
$
|
33
|
$
|
666
|
|
2014:
|
|||||||||||
Net income
|
$
|
737
|
$
|
(220)
|
$
|
517
|
$
|
41
|
$
|
558
|
|
Other comprehensive income (loss):
|
|||||||||||
Foreign currency translation adjustments
|
(41)
|
―
|
(41)
|
(1)
|
(42)
|
||||||
Pension and other postretirement benefits
|
13
|
(5)
|
8
|
―
|
8
|
||||||
Financial instruments
|
(20)
|
8
|
(12)
|
(1)
|
(13)
|
||||||
Total other comprehensive loss
|
(48)
|
3
|
(45)
|
(2)
|
(47)
|
||||||
Comprehensive income
|
689
|
(217)
|
472
|
39
|
511
|
||||||
Preferred dividends of subsidiary
|
(1)
|
―
|
(1)
|
―
|
(1)
|
||||||
Comprehensive income, after preferred
|
|||||||||||
dividends of subsidiary
|
$
|
688
|
$
|
(217)
|
$
|
471
|
$
|
39
|
$
|
510
|
|
See Notes to Condensed Consolidated Financial Statements.
|
SEMPRA ENERGY
|
|||||
CONDENSED CONSOLIDATED BALANCE SHEETS
|
|||||
(Dollars in millions)
|
|||||
June 30,
|
December 31,
|
||||
2015
|
2014(1)
|
||||
(unaudited)
|
|||||
ASSETS
|
|||||
Current assets:
|
|||||
Cash and cash equivalents
|
$
|
636
|
$
|
570
|
|
Restricted cash
|
8
|
11
|
|||
Trade accounts receivable, net
|
990
|
1,242
|
|||
Other accounts and notes receivable, net
|
164
|
152
|
|||
Due from unconsolidated affiliates
|
4
|
38
|
|||
Income taxes receivable
|
100
|
45
|
|||
Deferred income taxes
|
99
|
305
|
|||
Inventories
|
266
|
396
|
|||
Regulatory balancing accounts – undercollected
|
798
|
746
|
|||
Fixed-price contracts and other derivatives
|
85
|
93
|
|||
Asset held for sale, power plant
|
―
|
293
|
|||
Other
|
356
|
293
|
|||
Total current assets
|
3,506
|
4,184
|
|||
Investments and other assets:
|
|||||
Restricted cash
|
17
|
29
|
|||
Due from unconsolidated affiliates
|
169
|
188
|
|||
Regulatory assets
|
3,095
|
3,031
|
|||
Nuclear decommissioning trusts
|
1,145
|
1,131
|
|||
Investments
|
2,929
|
2,848
|
|||
Goodwill
|
885
|
931
|
|||
Other intangible assets
|
410
|
415
|
|||
Dedicated assets in support of certain benefit plans
|
483
|
512
|
|||
Sundry
|
674
|
561
|
|||
Total investments and other assets
|
9,807
|
9,646
|
|||
Property, plant and equipment:
|
|||||
Property, plant and equipment
|
36,523
|
35,407
|
|||
Less accumulated depreciation and amortization
|
(9,830)
|
(9,505)
|
|||
Property, plant and equipment, net ($396 and $410 at June 30, 2015 and
December 31, 2014, respectively, related to VIE)
|
26,693
|
25,902
|
|||
Total assets
|
$
|
40,006
|
$
|
39,732
|
|
(1)
|
Derived from audited financial statements.
|
||||
See Notes to Condensed Consolidated Financial Statements.
|
SEMPRA ENERGY
|
|||||
CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
|
|||||
(Dollars in millions)
|
|||||
June 30,
|
December 31,
|
||||
2015
|
2014(1)
|
||||
(unaudited)
|
|||||
LIABILITIES AND EQUITY
|
|||||
Current liabilities:
|
|||||
Short-term debt
|
$
|
738
|
$
|
1,733
|
|
Accounts payable – trade
|
890
|
1,198
|
|||
Accounts payable – other
|
124
|
155
|
|||
Due to unconsolidated affiliate
|
―
|
2
|
|||
Dividends and interest payable
|
300
|
282
|
|||
Accrued compensation and benefits
|
271
|
373
|
|||
Current portion of long-term debt
|
1,273
|
469
|
|||
Fixed-price contracts and other derivatives
|
55
|
55
|
|||
Customer deposits
|
150
|
153
|
|||
Other
|
598
|
649
|
|||
Total current liabilities
|
4,399
|
5,069
|
|||
Long-term debt ($310 and $315 at June 30, 2015 and December 31, 2014, respectively,
related to VIE)
|
12,626
|
12,167
|
|||
Deferred credits and other liabilities:
|
|||||
Customer advances for construction
|
144
|
144
|
|||
Pension and other postretirement benefit plan obligations, net of plan assets
|
1,101
|
1,064
|
|||
Deferred income taxes
|
3,016
|
3,003
|
|||
Deferred investment tax credits
|
35
|
37
|
|||
Regulatory liabilities arising from removal obligations
|
2,762
|
2,741
|
|||
Asset retirement obligations
|
2,067
|
2,048
|
|||
Fixed-price contracts and other derivatives
|
300
|
255
|
|||
Deferred credits and other
|
1,081
|
1,104
|
|||
Total deferred credits and other liabilities
|
10,506
|
10,396
|
|||
Commitments and contingencies (Note 11)
|
|||||
Equity:
|
|||||
Preferred stock (50 million shares authorized; none issued)
|
―
|
―
|
|||
Common stock (750 million shares authorized; 248 million and 246 million shares
|
|||||
outstanding at June 30, 2015 and December 31, 2014, respectively; no par value)
|
2,555
|
2,484
|
|||
Retained earnings
|
9,724
|
9,339
|
|||
Accumulated other comprehensive income (loss)
|
(596)
|
(497)
|
|||
Total Sempra Energy shareholders’ equity
|
11,683
|
11,326
|
|||
Preferred stock of subsidiary
|
20
|
20
|
|||
Other noncontrolling interests
|
772
|
754
|
|||
Total equity
|
12,475
|
12,100
|
|||
Total liabilities and equity
|
$
|
40,006
|
$
|
39,732
|
|
(1)
|
Derived from audited financial statements.
|
||||
See Notes to Condensed Consolidated Financial Statements.
|
SEMPRA ENERGY
|
|||||
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
|
|||||
(Dollars in millions)
|
|||||
Six months ended June 30,
|
|||||
2015
|
2014
|
||||
(unaudited)
|
|||||
CASH FLOWS FROM OPERATING ACTIVITIES
|
|||||
Net income
|
$
|
778
|
$
|
558
|
|
Adjustments to reconcile net income to net cash provided by operating activities:
|
|||||
Depreciation and amortization
|
610
|
574
|
|||
Deferred income taxes and investment tax credits
|
203
|
105
|
|||
Gain on sale of equity interest and assets
|
(62)
|
(29)
|
|||
Plant closure adjustment
|
(21)
|
(13)
|
|||
Equity earnings
|
(83)
|
(55)
|
|||
Fixed-price contracts and other derivatives
|
―
|
(17)
|
|||
Other
|
(8)
|
(6)
|
|||
Net change in other working capital components
|
(116)
|
(125)
|
|||
Changes in other assets
|
(89)
|
21
|
|||
Changes in other liabilities
|
7
|
21
|
|||
Net cash provided by operating activities
|
1,219
|
1,034
|
|||
CASH FLOWS FROM INVESTING ACTIVITIES
|
|||||
Expenditures for property, plant and equipment
|
(1,466)
|
(1,513)
|
|||
Expenditures for investments and acquisition of business
|
(161)
|
(160)
|
|||
Proceeds from sale of equity interest and assets, net of cash sold
|
347
|
66
|
|||
Distributions from investments
|
9
|
6
|
|||
Purchases of nuclear decommissioning and other trust assets
|
(229)
|
(356)
|
|||
Proceeds from sales by nuclear decommissioning and other trusts
|
221
|
350
|
|||
Decrease in restricted cash
|
49
|
87
|
|||
Increase in restricted cash
|
(34)
|
(87)
|
|||
Advances to unconsolidated affiliates
|
(20)
|
(24)
|
|||
Repayments of advances to unconsolidated affiliates
|
74
|
―
|
|||
Other
|
9
|
10
|
|||
Net cash used in investing activities
|
(1,201)
|
(1,621)
|
|||
CASH FLOWS FROM FINANCING ACTIVITIES
|
|||||
Common dividends paid
|
(308)
|
(301)
|
|||
Preferred dividends paid by subsidiary
|
(1)
|
(1)
|
|||
Issuances of common stock
|
31
|
28
|
|||
Repurchases of common stock
|
(66)
|
(37)
|
|||
Issuances of debt (maturities greater than 90 days)
|
1,547
|
2,345
|
|||
Payments on debt (maturities greater than 90 days)
|
(846)
|
(1,475)
|
|||
Decrease in short-term debt, net
|
(339)
|
(54)
|
|||
Net distributions to noncontrolling interests
|
(14)
|
(23)
|
|||
Other
|
46
|
(10)
|
|||
Net cash provided by financing activities
|
50
|
472
|
|||
Effect of exchange rate changes on cash and cash equivalents
|
(2)
|
―
|
|||
Increase (decrease) in cash and cash equivalents
|
66
|
(115)
|
|||
Cash and cash equivalents, January 1
|
570
|
904
|
|||
Cash and cash equivalents, June 30
|
$
|
636
|
$
|
789
|
|
See Notes to Condensed Consolidated Financial Statements.
|
SEMPRA ENERGY
|
|||||
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
|
|||||
(Dollars in millions)
|
|||||
Six months ended June 30,
|
|||||
2015
|
2014
|
||||
(unaudited)
|
|||||
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
|
|||||
Interest payments, net of amounts capitalized
|
$
|
260
|
$
|
269
|
|
Income tax payments, net of refunds
|
72
|
148
|
|||
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
|
|||||
Acquisition of business:
|
|||||
Assets acquired
|
$
|
10
|
$
|
―
|
|
Liabilities assumed
|
(2)
|
―
|
|||
Accrued purchase price
|
(6)
|
―
|
|||
Cash paid
|
$
|
2
|
$
|
―
|
|
Accrued capital expenditures
|
$
|
302
|
$
|
287
|
|
Redemption of industrial development bonds
|
79
|
―
|
|||
Increase in capital lease obligations for investment in property, plant and equipment
|
―
|
60
|
|||
Dividends declared but not paid
|
178
|
165
|
|||
Financing of build-to-suit property
|
39
|
32
|
|||
See Notes to Condensed Consolidated Financial Statements.
|
SAN DIEGO GAS & ELECTRIC COMPANY
|
||||||||
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
|
||||||||
(Dollars in millions)
|
||||||||
Three months ended June 30,
|
Six months ended June 30,
|
|||||||
2015
|
2014
|
2015
|
2014
|
|||||
(unaudited)
|
||||||||
Operating revenues
|
||||||||
Electric
|
$
|
874
|
$
|
948
|
$
|
1,679
|
$
|
1,759
|
Natural gas
|
98
|
115
|
259
|
291
|
||||
Total operating revenues
|
972
|
1,063
|
1,938
|
2,050
|
||||
Operating expenses
|
||||||||
Cost of electric fuel and purchased power
|
251
|
329
|
479
|
595
|
||||
Cost of natural gas
|
31
|
51
|
85
|
126
|
||||
Operation and maintenance
|
255
|
256
|
472
|
508
|
||||
Depreciation
|
149
|
131
|
294
|
261
|
||||
Franchise fees and other taxes
|
59
|
54
|
120
|
110
|
||||
Plant closure adjustment
|
―
|
―
|
(21)
|
(13)
|
||||
Total operating expenses
|
745
|
821
|
1,429
|
1,587
|
||||
Operating income
|
227
|
242
|
509
|
463
|
||||
Other income, net
|
9
|
7
|
18
|
20
|
||||
Interest expense
|
(52)
|
(51)
|
(104)
|
(101)
|
||||
Income before income taxes
|
184
|
198
|
423
|
382
|
||||
Income tax expense
|
(54)
|
(69)
|
(142)
|
(152)
|
||||
Net income
|
130
|
129
|
281
|
230
|
||||
Earnings attributable to noncontrolling interest
|
(4)
|
(6)
|
(8)
|
(8)
|
||||
Earnings attributable to common shares
|
$
|
126
|
$
|
123
|
$
|
273
|
$
|
222
|
See Notes to Condensed Consolidated Financial Statements.
|
SAN DIEGO GAS & ELECTRIC COMPANY
|
||||||||||
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
|
||||||||||
(Dollars in millions)
|
||||||||||
SDG&E shareholder's equity
|
||||||||||
Pretax
|
Income tax
|
Net-of-tax
|
Noncontrolling
|
|||||||
amount
|
expense
|
amount
|
interest (after-tax)
|
Total
|
||||||
Three months ended June 30, 2015 and 2014
|
||||||||||
(unaudited)
|
||||||||||
2015:
|
||||||||||
Net income
|
$
|
180
|
$
|
(54)
|
$
|
126
|
$
|
4
|
$
|
130
|
Other comprehensive income:
|
||||||||||
Financial instruments
|
―
|
―
|
―
|
3
|
3
|
|||||
Total other comprehensive income
|
―
|
―
|
―
|
3
|
3
|
|||||
Comprehensive income
|
$
|
180
|
$
|
(54)
|
$
|
126
|
$
|
7
|
$
|
133
|
2014:
|
||||||||||
Net income
|
$
|
192
|
$
|
(69)
|
$
|
123
|
$
|
6
|
$
|
129
|
Other comprehensive income (loss):
|
||||||||||
Pension and other postretirement benefits
|
2
|
(1)
|
1
|
―
|
1
|
|||||
Financial instruments
|
―
|
―
|
―
|
(1)
|
(1)
|
|||||
Total other comprehensive income (loss)
|
2
|
(1)
|
1
|
(1)
|
―
|
|||||
Comprehensive income
|
$
|
194
|
$
|
(70)
|
$
|
124
|
$
|
5
|
$
|
129
|
Six months ended June 30, 2015 and 2014
|
||||||||||
(unaudited)
|
||||||||||
2015:
|
||||||||||
Net income
|
$
|
415
|
$
|
(142)
|
$
|
273
|
$
|
8
|
$
|
281
|
Other comprehensive income:
|
||||||||||
Financial instruments
|
―
|
―
|
―
|
1
|
1
|
|||||
Total other comprehensive income
|
―
|
―
|
―
|
1
|
1
|
|||||
Comprehensive income
|
$
|
415
|
$
|
(142)
|
$
|
273
|
$
|
9
|
$
|
282
|
2014:
|
||||||||||
Net income
|
$
|
374
|
$
|
(152)
|
$
|
222
|
$
|
8
|
$
|
230
|
Other comprehensive income (loss):
|
||||||||||
Pension and other postretirement benefits
|
2
|
(1)
|
1
|
―
|
1
|
|||||
Financial instruments
|
―
|
―
|
―
|
(1)
|
(1)
|
|||||
Total other comprehensive income (loss)
|
2
|
(1)
|
1
|
(1)
|
―
|
|||||
Comprehensive income
|
$
|
376
|
$
|
(153)
|
$
|
223
|
$
|
7
|
$
|
230
|
See Notes to Condensed Consolidated Financial Statements.
|
SAN DIEGO GAS & ELECTRIC COMPANY
|
|||||
CONDENSED CONSOLIDATED BALANCE SHEETS
|
|||||
(Dollars in millions)
|
|||||
June 30,
|
December 31,
|
||||
2015
|
2014(1)
|
||||
(unaudited)
|
|||||
ASSETS
|
|||||
Current assets:
|
|||||
Cash and cash equivalents
|
$
|
23
|
$
|
8
|
|
Restricted cash
|
7
|
8
|
|||
Accounts receivable – trade, net
|
314
|
285
|
|||
Accounts receivable – other, net
|
21
|
35
|
|||
Due from unconsolidated affiliates
|
1
|
1
|
|||
Income taxes receivable
|
59
|
―
|
|||
Inventories
|
67
|
73
|
|||
Regulatory balancing accounts – net undercollected
|
626
|
711
|
|||
Regulatory assets
|
116
|
54
|
|||
Fixed-price contracts and other derivatives
|
40
|
44
|
|||
Other
|
86
|
125
|
|||
Total current assets
|
1,360
|
1,344
|
|||
Other assets:
|
|||||
Restricted cash
|
12
|
11
|
|||
Deferred taxes recoverable in rates
|
848
|
824
|
|||
Other regulatory assets
|
1,026
|
1,086
|
|||
Nuclear decommissioning trusts
|
1,145
|
1,131
|
|||
Sundry
|
368
|
282
|
|||
Total other assets
|
3,399
|
3,334
|
|||
Property, plant and equipment:
|
|||||
Property, plant and equipment
|
15,882
|
15,478
|
|||
Less accumulated depreciation
|
(4,008)
|
(3,860)
|
|||
Property, plant and equipment, net ($396 and $410 at June 30, 2015 and
December 31, 2014, respectively, related to VIE)
|
11,874
|
11,618
|
|||
Total assets
|
$
|
16,633
|
$
|
16,296
|
|
(1)
|
Derived from audited financial statements.
|
||||
See Notes to Condensed Consolidated Financial Statements.
|
SAN DIEGO GAS & ELECTRIC COMPANY
|
|||||
CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
|
|||||
(Dollars in millions)
|
|||||
June 30,
|
December 31,
|
||||
2015
|
2014(1)
|
||||
(unaudited)
|
|||||
LIABILITIES AND EQUITY
|
|||||
Current liabilities:
|
|||||
Short-term debt
|
$
|
40
|
$
|
246
|
|
Accounts payable
|
361
|
441
|
|||
Due to unconsolidated affiliates
|
7
|
21
|
|||
Income taxes payable
|
―
|
30
|
|||
Deferred income taxes
|
185
|
53
|
|||
Interest payable
|
41
|
40
|
|||
Accrued compensation and benefits
|
74
|
124
|
|||
Current portion of long-term debt
|
470
|
365
|
|||
Asset retirement obligations
|
100
|
120
|
|||
Fixed-price contracts and other derivatives
|
45
|
40
|
|||
Customer deposits
|
70
|
71
|
|||
Other
|
203
|
237
|
|||
Total current liabilities
|
1,596
|
1,788
|
|||
Long-term debt ($310 and $315 at June 30, 2015 and December 31, 2014,
respectively, related to VIE)
|
4,498
|
4,319
|
|||
Deferred credits and other liabilities:
|
|||||
Customer advances for construction
|
42
|
41
|
|||
Pension and other postretirement benefit plan obligations, net of plan assets
|
225
|
216
|
|||
Deferred income taxes
|
2,133
|
2,121
|
|||
Deferred investment tax credits
|
20
|
22
|
|||
Regulatory liabilities arising from removal obligations
|
1,584
|
1,557
|
|||
Asset retirement obligations
|
745
|
754
|
|||
Fixed-price contracts and other derivatives
|
179
|
153
|
|||
Deferred credits and other
|
345
|
333
|
|||
Total deferred credits and other liabilities
|
5,273
|
5,197
|
|||
Commitments and contingencies (Note 11)
|
|||||
Equity:
|
|||||
Common stock (255 million shares authorized; 117 million shares outstanding;
|
|||||
no par value)
|
1,338
|
1,338
|
|||
Retained earnings
|
3,879
|
3,606
|
|||
Accumulated other comprehensive income (loss)
|
(12)
|
(12)
|
|||
Total SDG&E shareholder's equity
|
5,205
|
4,932
|
|||
Noncontrolling interest
|
61
|
60
|
|||
Total equity
|
5,266
|
4,992
|
|||
Total liabilities and equity
|
$
|
16,633
|
$
|
16,296
|
|
(1)
|
Derived from audited financial statements.
|
||||
See Notes to Condensed Consolidated Financial Statements.
|
SAN DIEGO GAS & ELECTRIC COMPANY
|
||||
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
|
||||
(Dollars in millions)
|
||||
Six months ended June 30,
|
||||
2015
|
2014
|
|||
(unaudited)
|
||||
CASH FLOWS FROM OPERATING ACTIVITIES
|
||||
Net income
|
$
|
281
|
$
|
230
|
Adjustments to reconcile net income to net cash provided by operating activities:
|
||||
Depreciation
|
294
|
261
|
||
Deferred income taxes and investment tax credits
|
103
|
132
|
||
Plant closure adjustment
|
(21)
|
(13)
|
||
Fixed-price contracts and other derivatives
|
(2)
|
(3)
|
||
Other
|
(9)
|
(24)
|
||
Net change in other working capital components
|
(40)
|
(231)
|
||
Changes in other assets
|
(59)
|
37
|
||
Changes in other liabilities
|
3
|
19
|
||
Net cash provided by operating activities
|
550
|
408
|
||
CASH FLOWS FROM INVESTING ACTIVITIES
|
||||
Expenditures for property, plant and equipment
|
(600)
|
(543)
|
||
Purchases of nuclear decommissioning trust assets
|
(227)
|
(354)
|
||
Proceeds from sales by nuclear decommissioning trusts
|
221
|
350
|
||
Decrease in restricted cash
|
19
|
62
|
||
Increase in restricted cash
|
(19)
|
(64)
|
||
Net cash used in investing activities
|
(606)
|
(549)
|
||
CASH FLOWS FROM FINANCING ACTIVITIES
|
||||
Issuances of long-term debt
|
388
|
100
|
||
Payments on long-term debt
|
(105)
|
(20)
|
||
(Decrease) increase in short-term debt, net
|
(206)
|
68
|
||
Capital distributions made by Otay Mesa VIE
|
(6)
|
(13)
|
||
Net cash provided by financing activities
|
71
|
135
|
||
Increase (decrease) in cash and cash equivalents
|
15
|
(6)
|
||
Cash and cash equivalents, January 1
|
8
|
27
|
||
Cash and cash equivalents, June 30
|
$
|
23
|
$
|
21
|
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
|
||||
Interest payments, net of amounts capitalized
|
$
|
99
|
$
|
98
|
Income tax payments, net of refunds
|
99
|
12
|
||
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
|
||||
Accrued capital expenditures
|
$
|
118
|
$
|
103
|
Increase in capital lease obligations for investment in property, plant and equipment
|
―
|
60
|
||
See Notes to Condensed Consolidated Financial Statements.
|
SOUTHERN CALIFORNIA GAS COMPANY
|
||||||||
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
|
||||||||
(Dollars in millions)
|
||||||||
Three months ended June 30,
|
Six months ended June 30,
|
|||||||
2015
|
2014
|
2015
|
2014
|
|||||
(unaudited)
|
||||||||
Operating revenues
|
$
|
780
|
$
|
917
|
$
|
1,828
|
$
|
2,002
|
Operating expenses
|
||||||||
Cost of natural gas
|
196
|
321
|
463
|
829
|
||||
Operation and maintenance
|
346
|
337
|
660
|
642
|
||||
Depreciation
|
113
|
107
|
226
|
212
|
||||
Franchise fees and other taxes
|
31
|
30
|
65
|
68
|
||||
Total operating expenses
|
686
|
795
|
1,414
|
1,751
|
||||
Operating income
|
94
|
122
|
414
|
251
|
||||
Other income, net
|
9
|
3
|
17
|
7
|
||||
Interest income
|
3
|
―
|
3
|
―
|
||||
Interest expense
|
(19)
|
(16)
|
(38)
|
(33)
|
||||
Income before income taxes
|
87
|
109
|
396
|
225
|
||||
Income tax expense
|
(16)
|
(28)
|
(111)
|
(66)
|
||||
Net income
|
71
|
81
|
285
|
159
|
||||
Preferred dividend requirements
|
(1)
|
(1)
|
(1)
|
(1)
|
||||
Earnings attributable to common shares
|
$
|
70
|
$
|
80
|
$
|
284
|
$
|
158
|
See Notes to Condensed Consolidated Financial Statements.
|
SOUTHERN CALIFORNIA GAS COMPANY
|
||||||
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
|
||||||
(Dollars in millions)
|
||||||
Pretax
|
Income tax
|
Net-of-tax
|
||||
amount
|
expense
|
amount
|
||||
Three months ended June 30, 2015 and 2014
|
||||||
(unaudited)
|
||||||
2015:
|
||||||
Net income/Comprehensive income
|
$
|
87
|
$
|
(16)
|
$
|
71
|
2014:
|
||||||
Net income/Comprehensive income
|
$
|
109
|
$
|
(28)
|
$
|
81
|
Six months ended June 30, 2015 and 2014
|
||||||
(unaudited)
|
||||||
2015:
|
||||||
Net income/Comprehensive income
|
$
|
396
|
$
|
(111)
|
$
|
285
|
2014:
|
||||||
Net income/Comprehensive income
|
$
|
225
|
$
|
(66)
|
$
|
159
|
See Notes to Condensed Consolidated Financial Statements.
|
SOUTHERN CALIFORNIA GAS COMPANY
|
|||||
CONDENSED CONSOLIDATED BALANCE SHEETS
|
|||||
(Dollars in millions)
|
|||||
June 30,
|
December 31,
|
||||
2015
|
2014(1)
|
||||
(unaudited)
|
|||||
ASSETS
|
|||||
Current assets:
|
|||||
Cash and cash equivalents
|
$
|
231
|
$
|
85
|
|
Accounts receivable – trade, net
|
348
|
586
|
|||
Accounts receivable – other, net
|
76
|
51
|
|||
Due from unconsolidated affiliates
|
273
|
4
|
|||
Income taxes receivable
|
―
|
5
|
|||
Inventories
|
57
|
181
|
|||
Regulatory balancing accounts – net undercollected
|
172
|
35
|
|||
Regulatory assets
|
7
|
5
|
|||
Temporary LIFO liquidation
|
41
|
―
|
|||
Other
|
28
|
36
|
|||
Total current assets
|
1,233
|
988
|
|||
Other assets:
|
|||||
Regulatory assets arising from pension obligations
|
650
|
617
|
|||
Other regulatory assets
|
539
|
472
|
|||
Other postretirement benefit plan assets, net of plan obligations
|
5
|
4
|
|||
Sundry
|
146
|
136
|
|||
Total other assets
|
1,340
|
1,229
|
|||
Property, plant and equipment:
|
|||||
Property, plant and equipment
|
13,403
|
12,886
|
|||
Less accumulated depreciation
|
(4,767)
|
(4,642)
|
|||
Property, plant and equipment, net
|
8,636
|
8,244
|
|||
Total assets
|
$
|
11,209
|
$
|
10,461
|
|
(1)
|
Derived from audited financial statements.
|
||||
See Notes to Condensed Consolidated Financial Statements.
|
SOUTHERN CALIFORNIA GAS COMPANY
|
|||||
CONDENSED CONSOLIDATED BALANCE SHEETS (CONTINUED)
|
|||||
(Dollars in millions)
|
|||||
June 30,
|
December 31,
|
||||
2015
|
2014(1)
|
||||
(unaudited)
|
|||||
LIABILITIES AND SHAREHOLDERS' EQUITY
|
|||||
Current liabilities:
|
|||||
Short-term debt
|
$
|
―
|
$
|
50
|
|
Accounts payable – trade
|
305
|
532
|
|||
Accounts payable – other
|
66
|
88
|
|||
Due to unconsolidated affiliate
|
―
|
13
|
|||
Income taxes payable
|
13
|
―
|
|||
Deferred income taxes
|
146
|
53
|
|||
Accrued compensation and benefits
|
118
|
129
|
|||
Current portion of long-term debt
|
9
|
―
|
|||
Customer deposits
|
73
|
75
|
|||
Other
|
142
|
149
|
|||
Total current liabilities
|
872
|
1,089
|
|||
Long-term debt
|
2,498
|
1,906
|
|||
Deferred credits and other liabilities:
|
|||||
Customer advances for construction
|
102
|
102
|
|||
Pension obligation, net of plan assets
|
666
|
633
|
|||
Deferred income taxes
|
1,267
|
1,212
|
|||
Deferred investment tax credits
|
14
|
16
|
|||
Regulatory liabilities arising from removal obligations
|
1,160
|
1,167
|
|||
Asset retirement obligations
|
1,281
|
1,255
|
|||
Deferred credits and other
|
284
|
300
|
|||
Total deferred credits and other liabilities
|
4,774
|
4,685
|
|||
Commitments and contingencies (Note 11)
|
|||||
Shareholders' equity:
|
|||||
Preferred stock
|
22
|
22
|
|||
Common stock (100 million shares authorized; 91 million shares outstanding;
|
|||||
no par value)
|
866
|
866
|
|||
Retained earnings
|
2,195
|
1,911
|
|||
Accumulated other comprehensive income (loss)
|
(18)
|
(18)
|
|||
Total shareholders' equity
|
3,065
|
2,781
|
|||
Total liabilities and shareholders' equity
|
$
|
11,209
|
$
|
10,461
|
|
(1)
|
Derived from audited financial statements.
|
||||
See Notes to Condensed Consolidated Financial Statements.
|
SOUTHERN CALIFORNIA GAS COMPANY
|
||||
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
|
||||
(Dollars in millions)
|
||||
Six months ended June 30,
|
||||
2015
|
2014
|
|||
(unaudited)
|
||||
CASH FLOWS FROM OPERATING ACTIVITIES
|
||||
Net income
|
$
|
285
|
$
|
159
|
Adjustments to reconcile net income to net cash provided by operating activities:
|
||||
Depreciation
|
226
|
212
|
||
Deferred income taxes and investment tax credits
|
76
|
59
|
||
Other
|
(15)
|
(2)
|
||
Net change in other working capital components
|
(58)
|
61
|
||
Changes in other assets
|
(30)
|
(27)
|
||
Changes in other liabilities
|
(1)
|
1
|
||
Net cash provided by operating activities
|
483
|
463
|
||
CASH FLOWS FROM INVESTING ACTIVITIES
|
||||
Expenditures for property, plant and equipment
|
(603)
|
(500)
|
||
Increase in loans to affiliates, net
|
(279)
|
―
|
||
Net cash used in investing activities
|
(882)
|
(500)
|
||
CASH FLOWS FROM FINANCING ACTIVITIES
|
||||
Preferred dividends paid
|
(1)
|
(1)
|
||
Issuances of long-term debt
|
599
|
248
|
||
Repayment of long-term debt
|
―
|
(250)
|
||
(Decrease) increase in short-term debt, net
|
(50)
|
31
|
||
Other
|
(3)
|
(2)
|
||
Net cash provided by financing activities
|
545
|
26
|
||
Increase (decrease) in cash and cash equivalents
|
146
|
(11)
|
||
Cash and cash equivalents, January 1
|
85
|
27
|
||
Cash and cash equivalents, June 30
|
$
|
231
|
$
|
16
|
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
|
||||
Interest payments, net of amounts capitalized
|
$
|
36
|
$
|
32
|
Income tax payments, net
|
14
|
19
|
||
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING ACTIVITY
|
||||
Accrued capital expenditures
|
$
|
143
|
$
|
102
|
See Notes to Condensed Consolidated Financial Statements.
|
§
|
San Diego Gas & Electric Company (SDG&E) and SoCalGas, which are separate, reportable segments;
|
§
|
Sempra International, which includes our Sempra South American Utilities and Sempra Mexico reportable segments; and
|
§
|
Sempra U.S. Gas & Power, which includes our Sempra Renewables and Sempra Natural Gas reportable segments.
|
DECONSOLIDATION OF SUBSIDIARY
|
|||
(Dollars in millions)
|
|||
Copper Mountain Solar 3
|
|||
At March 13, 2014
|
|||
Proceeds from sale, net of negligible transaction costs
|
$
|
68
|
|
Cash
|
(2)
|
||
Property, plant and equipment, net
|
(247)
|
||
Other assets
|
(11)
|
||
Accounts payable and accrued expenses
|
82
|
||
Long-term debt, including current portion
|
97
|
||
Other liabilities
|
3
|
||
Accumulated other comprehensive income
|
(2)
|
||
Gain on sale of equity interest
|
(27)
|
||
(Increase) in equity method investment upon deconsolidation
|
$
|
(39)
|
INVENTORY BALANCES
|
|||||||||||||||||
(Dollars in millions)
|
|||||||||||||||||
Natural gas
|
Liquefied natural gas
|
Materials and supplies
|
Total
|
||||||||||||||
June 30,
2015
|
December 31,
2014
|
June 30,
2015
|
December 31,
2014
|
June 30,
2015
|
December 31,
2014
|
June 30,
2015
|
December 31,
2014
|
||||||||||
SDG&E
|
$
|
3
|
$
|
8
|
$
|
―
|
$
|
―
|
$
|
64
|
$
|
65
|
$
|
67
|
$
|
73
|
|
SoCalGas
|
29
|
155
|
―
|
―
|
28
|
26
|
57
|
181
|
|||||||||
Sempra South American
|
|||||||||||||||||
Utilities
|
―
|
―
|
―
|
―
|
35
|
33
|
35
|
33
|
|||||||||
Sempra Mexico
|
―
|
―
|
10
|
9
|
9
|
9
|
19
|
18
|
|||||||||
Sempra Renewables
|
―
|
―
|
―
|
―
|
2
|
2
|
2
|
2
|
|||||||||
Sempra Natural Gas
|
81
|
83
|
4
|
5
|
1
|
1
|
86
|
89
|
|||||||||
Sempra Energy
|
|||||||||||||||||
Consolidated
|
$
|
113
|
$
|
246
|
$
|
14
|
$
|
14
|
$
|
139
|
$
|
136
|
$
|
266
|
$
|
396
|
§
|
the purpose and design of the VIE;
|
§
|
the nature of the VIE’s risks and the risks we absorb;
|
§
|
the power to direct activities that most significantly impact the economic performance of the VIE; and
|
§
|
the obligation to absorb losses or right to receive benefits that could be significant to the VIE.
|
AMOUNTS ASSOCIATED WITH OTAY MESA VIE
|
||||||||
(Dollars in millions)
|
||||||||
Three months ended June 30,
|
Six months ended June 30,
|
|||||||
2015
|
2014
|
2015
|
2014
|
|||||
Operating expenses
|
||||||||
Cost of electric fuel and purchased power
|
$
|
(21)
|
$
|
(22)
|
$
|
(39)
|
$
|
(40)
|
Operation and maintenance
|
6
|
5
|
10
|
10
|
||||
Depreciation
|
6
|
7
|
12
|
14
|
||||
Total operating expenses
|
(9)
|
(10)
|
(17)
|
(16)
|
||||
Operating income
|
9
|
10
|
17
|
16
|
||||
Interest expense
|
(5)
|
(4)
|
(9)
|
(8)
|
||||
Income before income taxes/Net income
|
4
|
6
|
8
|
8
|
||||
Earnings attributable to noncontrolling interest
|
(4)
|
(6)
|
(8)
|
(8)
|
||||
Earnings attributable to common shares
|
$
|
―
|
$
|
―
|
$
|
―
|
$
|
―
|
NET PERIODIC BENEFIT COST – SEMPRA ENERGY CONSOLIDATED
|
||||||||
(Dollars in millions)
|
||||||||
Pension benefits
|
Other postretirement benefits
|
|||||||
Three months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
|||||
Service cost
|
$
|
29
|
$
|
26
|
$
|
7
|
$
|
6
|
Interest cost
|
39
|
41
|
11
|
12
|
||||
Expected return on assets
|
(44)
|
(43)
|
(17)
|
(16)
|
||||
Amortization of:
|
||||||||
Prior service cost (credit)
|
2
|
3
|
―
|
(1)
|
||||
Actuarial loss
|
11
|
5
|
―
|
―
|
||||
Settlement
|
―
|
6
|
―
|
―
|
||||
Regulatory adjustment
|
(30)
|
―
|
―
|
―
|
||||
Total net periodic benefit cost
|
$
|
7
|
$
|
38
|
$
|
1
|
$
|
1
|
Six months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
|||||
Service cost
|
$
|
59
|
$
|
52
|
$
|
14
|
$
|
12
|
Interest cost
|
78
|
82
|
23
|
24
|
||||
Expected return on assets
|
(88)
|
(86)
|
(34)
|
(32)
|
||||
Amortization of:
|
||||||||
Prior service cost (credit)
|
5
|
5
|
(1)
|
(2)
|
||||
Actuarial loss
|
19
|
10
|
―
|
―
|
||||
Settlements
|
―
|
9
|
―
|
―
|
||||
Regulatory adjustment
|
(59)
|
(24)
|
―
|
―
|
||||
Total net periodic benefit cost
|
$
|
14
|
$
|
48
|
$
|
2
|
$
|
2
|
NET PERIODIC BENEFIT COST – SDG&E
|
||||||||
(Dollars in millions)
|
||||||||
Pension benefits
|
Other postretirement benefits
|
|||||||
Three months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
|||||
Service cost
|
$
|
8
|
$
|
7
|
$
|
2
|
$
|
1
|
Interest cost
|
10
|
11
|
2
|
2
|
||||
Expected return on assets
|
(13)
|
(14)
|
(3)
|
(3)
|
||||
Amortization of:
|
||||||||
Prior service cost
|
1
|
1
|
1
|
1
|
||||
Actuarial loss
|
2
|
1
|
―
|
―
|
||||
Settlements
|
―
|
2
|
―
|
―
|
||||
Regulatory adjustment
|
(7)
|
6
|
(2)
|
(1)
|
||||
Total net periodic benefit cost
|
$
|
1
|
$
|
14
|
$
|
―
|
$
|
―
|
Six months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
|||||
Service cost
|
$
|
16
|
$
|
15
|
$
|
4
|
$
|
3
|
Interest cost
|
20
|
22
|
4
|
4
|
||||
Expected return on assets
|
(27)
|
(28)
|
(6)
|
(6)
|
||||
Amortization of:
|
||||||||
Prior service cost
|
1
|
1
|
2
|
2
|
||||
Actuarial loss
|
4
|
2
|
―
|
―
|
||||
Settlements
|
―
|
2
|
―
|
―
|
||||
Regulatory adjustment
|
(12)
|
1
|
(4)
|
(3)
|
||||
Total net periodic benefit cost
|
$
|
2
|
$
|
15
|
$
|
―
|
$
|
―
|
NET PERIODIC BENEFIT COST – SOCALGAS
|
||||||||
(Dollars in millions)
|
||||||||
Pension benefits
|
Other postretirement benefits
|
|||||||
Three months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
|||||
Service cost
|
$
|
19
|
$
|
16
|
$
|
5
|
$
|
4
|
Interest cost
|
24
|
26
|
9
|
10
|
||||
Expected return on assets
|
(27)
|
(26)
|
(14)
|
(13)
|
||||
Amortization of:
|
||||||||
Prior service cost (credit)
|
2
|
2
|
(2)
|
(2)
|
||||
Actuarial loss
|
6
|
2
|
―
|
―
|
||||
Regulatory adjustment
|
(23)
|
(6)
|
2
|
1
|
||||
Total net periodic benefit cost
|
$
|
1
|
$
|
14
|
$
|
―
|
$
|
―
|
Six months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
|||||
Service cost
|
$
|
38
|
$
|
32
|
$
|
10
|
$
|
8
|
Interest cost
|
49
|
51
|
18
|
19
|
||||
Expected return on assets
|
(54)
|
(52)
|
(28)
|
(26)
|
||||
Amortization of:
|
||||||||
Prior service cost (credit)
|
4
|
4
|
(4)
|
(4)
|
||||
Actuarial loss
|
11
|
4
|
―
|
―
|
||||
Regulatory adjustment
|
(47)
|
(25)
|
4
|
3
|
||||
Total net periodic benefit cost
|
$
|
1
|
$
|
14
|
$
|
―
|
$
|
―
|
BENEFIT PLAN CONTRIBUTIONS
|
||||||
(Dollars in millions)
|
||||||
Sempra Energy
|
||||||
Consolidated
|
SDG&E
|
SoCalGas
|
||||
Contributions through June 30, 2015:
|
||||||
Pension plans
|
$
|
17
|
$
|
2
|
$
|
1
|
Other postretirement benefit plans
|
1
|
―
|
―
|
|||
Total expected contributions in 2015:
|
||||||
Pension plans
|
$
|
36
|
$
|
3
|
$
|
7
|
Other postretirement benefit plans
|
11
|
8
|
―
|
EARNINGS PER SHARE COMPUTATIONS
|
||||||||||
(Dollars in millions, except per share amounts; shares in thousands)
|
||||||||||
Three months ended June 30,
|
Six months ended June 30,
|
|||||||||
2015
|
2014
|
2015
|
2014
|
|||||||
Numerator:
|
||||||||||
Earnings/Income attributable to common shares
|
$
|
295
|
$
|
269
|
$
|
732
|
$
|
516
|
||
Denominator:
|
||||||||||
Weighted-average common shares
|
||||||||||
outstanding for basic EPS(1)
|
248,108
|
245,688
|
247,916
|
245,484
|
||||||
Dilutive effect of stock options, restricted
|
||||||||||
stock awards and restricted stock units
|
3,383
|
4,373
|
3,348
|
4,332
|
||||||
Weighted-average common shares
|
||||||||||
outstanding for diluted EPS
|
251,491
|
250,061
|
251,264
|
249,816
|
||||||
Earnings per share:
|
||||||||||
Basic
|
$
|
1.19
|
$
|
1.10
|
$
|
2.95
|
$
|
2.10
|
||
Diluted
|
1.17
|
1.08
|
2.91
|
2.07
|
||||||
(1)
|
Includes fully vested restricted stock units of 501 and 476 held in our Deferred Compensation Plan for the three months and six months ended June 30, 2015, respectively, and 221 and 202 for the three months and six months ended June 30, 2014, respectively. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.
|
CAPITALIZED FINANCING COSTS
|
|||||||||
(Dollars in millions)
|
|||||||||
Three months ended June 30,
|
Six months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
||||||
Sempra Energy Consolidated:
|
|||||||||
AFUDC related to debt
|
$
|
7
|
$
|
4
|
$
|
13
|
$
|
10
|
|
AFUDC related to equity
|
31
|
24
|
58
|
49
|
|||||
Other capitalized financing costs
|
17
|
8
|
34
|
16
|
|||||
Total Sempra Energy Consolidated
|
$
|
55
|
$
|
36
|
$
|
105
|
$
|
75
|
|
SDG&E:
|
|||||||||
AFUDC related to debt
|
$
|
4
|
$
|
3
|
$
|
7
|
$
|
7
|
|
AFUDC related to equity
|
10
|
7
|
18
|
18
|
|||||
Total SDG&E
|
$
|
14
|
$
|
10
|
$
|
25
|
$
|
25
|
|
SoCalGas:
|
|||||||||
AFUDC related to debt
|
$
|
3
|
$
|
1
|
$
|
6
|
$
|
3
|
|
AFUDC related to equity
|
10
|
6
|
19
|
11
|
|||||
Total SoCalGas
|
$
|
13
|
$
|
7
|
$
|
25
|
$
|
14
|
CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
|
|||||||||||
SEMPRA ENERGY CONSOLIDATED
|
|||||||||||
(Dollars in millions)
|
|||||||||||
Pension and other
|
|||||||||||
postretirement benefits
|
|||||||||||
Foreign
|
Total
|
||||||||||
currency
|
Unamortized
|
Unamortized
|
accumulated other
|
||||||||
translation
|
net actuarial
|
prior service
|
Financial
|
comprehensive
|
|||||||
adjustments
|
gain (loss)
|
cost
|
instruments
|
income (loss)
|
|||||||
Three months ended June 30, 2015 and 2014
|
|||||||||||
2015:
|
|||||||||||
Balance as of March 31, 2015
|
$
|
(384)
|
$
|
(82)
|
$
|
(2)
|
$
|
(145)
|
$
|
(613)
|
|
Other comprehensive (loss) income before
|
|||||||||||
reclassifications
|
(43)
|
―
|
―
|
57
|
14
|
||||||
Amounts reclassified from accumulated other
|
|||||||||||
comprehensive income
|
―
|
1
|
―
|
2
|
3
|
||||||
Net other comprehensive (loss) income
|
(43)
|
1
|
―
|
59
|
17
|
||||||
Balance as of June 30, 2015
|
$
|
(427)
|
$
|
(81)
|
$
|
(2)
|
$
|
(86)
|
$
|
(596)
|
|
2014:
|
|||||||||||
Balance as of March 31, 2014
|
$
|
(172)
|
$
|
(70)
|
$
|
―
|
$
|
(31)
|
$
|
(273)
|
|
Other comprehensive income (loss) before
|
|||||||||||
reclassifications
|
2
|
―
|
―
|
(12)
|
(10)
|
||||||
Amounts reclassified from accumulated other
|
|||||||||||
comprehensive income
|
―
|
5
|
―
|
5
|
10
|
||||||
Net other comprehensive income (loss)
|
2
|
5
|
―
|
(7)
|
―
|
||||||
Balance as of June 30, 2014
|
$
|
(170)
|
$
|
(65)
|
$
|
―
|
$
|
(38)
|
$
|
(273)
|
|
Six months ended June 30, 2015 and 2014
|
|||||||||||
2015:
|
|||||||||||
Balance as of December 31, 2014
|
$
|
(322)
|
$
|
(83)
|
$
|
(2)
|
$
|
(90)
|
$
|
(497)
|
|
Other comprehensive (loss) income before
|
|||||||||||
reclassifications
|
(105)
|
―
|
―
|
3
|
(102)
|
||||||
Amounts reclassified from accumulated other
|
|||||||||||
comprehensive income
|
―
|
2
|
―
|
1
|
3
|
||||||
Net other comprehensive (loss) income
|
(105)
|
2
|
―
|
4
|
(99)
|
||||||
Balance as of June 30, 2015
|
$
|
(427)
|
$
|
(81)
|
$
|
(2)
|
$
|
(86)
|
$
|
(596)
|
|
2014:
|
|||||||||||
Balance as of December 31, 2013
|
$
|
(129)
|
$
|
(73)
|
$
|
―
|
$
|
(26)
|
$
|
(228)
|
|
Other comprehensive loss before
|
|||||||||||
reclassifications
|
(41)
|
―
|
―
|
(26)
|
(67)
|
||||||
Amounts reclassified from accumulated other
|
|||||||||||
comprehensive income
|
―
|
8
|
―
|
14
|
22
|
||||||
Net other comprehensive (loss) income
|
(41)
|
8
|
―
|
(12)
|
(45)
|
||||||
Balance as of June 30, 2014
|
$
|
(170)
|
$
|
(65)
|
$
|
―
|
$
|
(38)
|
$
|
(273)
|
|
(1)
|
All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.
|
CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
|
||||||||
SAN DIEGO GAS & ELECTRIC COMPANY
|
||||||||
(Dollars in millions)
|
||||||||
Pension and other
|
||||||||
postretirement benefits
|
||||||||
Total
|
||||||||
Unamortized
|
Unamortized
|
accumulated other
|
||||||
net actuarial
|
prior service
|
comprehensive
|
||||||
gain (loss)
|
credit
|
income (loss)
|
||||||
Three months ended June 30, 2015 and 2014
|
||||||||
2015:
|
||||||||
Balance as of March 31, and June 30, 2015
|
$
|
(13)
|
$
|
1
|
$
|
(12)
|
||
2014:
|
||||||||
Balance as of March 31, 2014
|
$
|
(10)
|
$
|
1
|
$
|
(9)
|
||
Amounts reclassified from accumulated other
|
||||||||
comprehensive income
|
1
|
―
|
1
|
|||||
Net other comprehensive income
|
1
|
―
|
1
|
|||||
Balance as of June 30, 2014
|
$
|
(9)
|
$
|
1
|
$
|
(8)
|
||
Six months ended June 30, 2015 and 2014
|
||||||||
2015:
|
||||||||
Balance as of December 31, 2014 and June 30, 2015
|
$
|
(13)
|
$
|
1
|
$
|
(12)
|
||
2014:
|
||||||||
Balance as of December 31, 2013
|
$
|
(10)
|
$
|
1
|
$
|
(9)
|
||
Amounts reclassified from accumulated other
|
||||||||
comprehensive income
|
1
|
―
|
1
|
|||||
Net other comprehensive income
|
1
|
―
|
1
|
|||||
Balance as of June 30, 2014
|
$
|
(9)
|
$
|
1
|
$
|
(8)
|
||
(1)
|
All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.
|
RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
|
||||||||||||
(Dollars in millions)
|
||||||||||||
Details about accumulated
|
Amounts reclassified
|
|||||||||||
other comprehensive income (loss)
|
from accumulated other
|
Affected line item on Condensed
|
||||||||||
components
|
comprehensive income (loss)
|
Consolidated Statements of Operations
|
||||||||||
Three months ended June 30,
|
||||||||||||
2015
|
2014
|
|||||||||||
Sempra Energy Consolidated:
|
||||||||||||
Financial instruments:
|
||||||||||||
Interest rate and foreign exchange instruments
|
$
|
3
|
$
|
6
|
Interest Expense
|
|||||||
Interest rate instruments
|
3
|
2
|
Equity Earnings, Before Income Tax
|
|||||||||
Total before income tax
|
6
|
8
|
||||||||||
(1)
|
(1)
|
Income Tax Expense
|
||||||||||
Net of income tax
|
5
|
7
|
||||||||||
(3)
|
(2)
|
Earnings Attributable to Noncontrolling Interests
|
||||||||||
$
|
2
|
$
|
5
|
|||||||||
Pension and other postretirement benefits:
|
||||||||||||
Amortization of actuarial loss
|
$
|
2
|
$
|
8
|
See note (1) below
|
|||||||
(1)
|
(3)
|
Income Tax Expense
|
||||||||||
Net of income tax
|
$
|
1
|
$
|
5
|
||||||||
Total reclassifications for the period, net of tax
|
$
|
3
|
$
|
10
|
||||||||
SDG&E:
|
||||||||||||
Financial instruments:
|
||||||||||||
Interest rate instruments
|
$
|
3
|
$
|
2
|
Interest Expense
|
|||||||
(3)
|
(2)
|
Earnings Attributable to Noncontrolling Interest
|
||||||||||
$
|
―
|
$
|
―
|
|||||||||
Pension and other postretirement benefits:
|
||||||||||||
Amortization of actuarial loss
|
$
|
―
|
$
|
2
|
See note (1) below
|
|||||||
―
|
(1)
|
Income Tax Expense
|
||||||||||
Net of income tax
|
$
|
―
|
$
|
1
|
||||||||
Total reclassifications for the period, net of tax
|
$
|
―
|
$
|
1
|
||||||||
(1)
|
Amounts are included in the computation of net periodic benefit cost (see "Pension and Other Postretirement Benefits" above).
|
RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
|
|||||||||||
(Dollars in millions)
|
|||||||||||
Details about accumulated
|
Amount reclassified
|
||||||||||
other comprehensive income (loss)
|
from accumulated other
|
Affected line item on Condensed
|
|||||||||
components
|
comprehensive income (loss)
|
Consolidated Statements of Operations
|
|||||||||
Six months ended June 30,
|
|||||||||||
2015
|
2014
|
||||||||||
Sempra Energy Consolidated:
|
|||||||||||
Financial instruments:
|
|||||||||||
Interest rate and foreign exchange instruments
|
$
|
9
|
$
|
9
|
Interest Expense
|
||||||
Interest rate instruments
|
―
|
2
|
Gain on Sale of Equity Interest and Assets
|
||||||||
Interest rate instruments
|
6
|
5
|
Equity Earnings, Before Income Tax
|
||||||||
Commodity contracts not subject to
|
Revenues: Energy-Related
|
||||||||||
rate recovery
|
(7)
|
10
|
Businesses
|
||||||||
Total before income tax
|
8
|
26
|
|||||||||
―
|
(7)
|
Income Tax Expense
|
|||||||||
Net of income tax
|
8
|
19
|
|||||||||
(7)
|
(5)
|
Earnings Attributable to Noncontrolling Interests
|
|||||||||
$
|
1
|
$
|
14
|
||||||||
Pension and other postretirement benefits:
|
|||||||||||
Amortization of actuarial loss
|
$
|
4
|
$
|
13
|
See note (1) below
|
||||||
(2)
|
(5)
|
Income Tax Expense
|
|||||||||
Net of income tax
|
$
|
2
|
$
|
8
|
|||||||
Total reclassifications for the period, net of tax
|
$
|
3
|
$
|
22
|
|||||||
SDG&E:
|
|||||||||||
Financial instruments:
|
|||||||||||
Interest rate instruments
|
$
|
6
|
$
|
5
|
Interest Expense
|
||||||
(6)
|
(5)
|
Earnings Attributable to Noncontrolling Interest
|
|||||||||
$
|
―
|
$
|
―
|
||||||||
Pension and other postretirement benefits:
|
|||||||||||
Amortization of actuarial loss
|
$
|
―
|
$
|
2
|
See note (1) below
|
||||||
―
|
(1)
|
Income Tax Expense
|
|||||||||
Net of income tax
|
$
|
―
|
$
|
1
|
|||||||
Total reclassifications for the period, net of tax
|
$
|
―
|
$
|
1
|
|||||||
(1)
|
Amounts are included in the computation of net periodic benefit cost (see "Pension and Other Postretirement Benefits" above).
|
SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS ― SEMPRA ENERGY CONSOLIDATED
|
|||||||
(Dollars in millions)
|
|||||||
Sempra Energy
|
Non-
|
||||||
shareholders’
|
controlling
|
Total
|
|||||
equity
|
interests
|
equity
|
|||||
Balance at December 31, 2014
|
$
|
11,326
|
$
|
774
|
$
|
12,100
|
|
Comprehensive income
|
634
|
33
|
667
|
||||
Preferred dividends of subsidiary
|
(1)
|
―
|
(1)
|
||||
Share-based compensation expense
|
26
|
―
|
26
|
||||
Common stock dividends declared
|
(347)
|
―
|
(347)
|
||||
Issuance of common stock
|
59
|
―
|
59
|
||||
Repurchase of common stock
|
(66)
|
―
|
(66)
|
||||
Tax benefit related to share-based compensation
|
52
|
―
|
52
|
||||
Equity contributed by noncontrolling interest
|
―
|
1
|
1
|
||||
Distributions to noncontrolling interests
|
―
|
(16)
|
(16)
|
||||
Balance at June 30, 2015
|
$
|
11,683
|
$
|
792
|
$
|
12,475
|
|
Balance at December 31, 2013
|
$
|
11,008
|
$
|
842
|
$
|
11,850
|
|
Comprehensive income
|
472
|
39
|
511
|
||||
Preferred dividends of subsidiary
|
(1)
|
―
|
(1)
|
||||
Share-based compensation expense
|
21
|
―
|
21
|
||||
Common stock dividends declared
|
(324)
|
―
|
(324)
|
||||
Issuance of common stock
|
42
|
―
|
42
|
||||
Repurchase of common stock
|
(37)
|
―
|
(37)
|
||||
Tax benefit related to share-based compensation
|
13
|
―
|
13
|
||||
Equity contributed by noncontrolling interest
|
―
|
1
|
1
|
||||
Distributions to noncontrolling interests
|
―
|
(25)
|
(25)
|
||||
Balance at June 30, 2014
|
$
|
11,194
|
$
|
857
|
$
|
12,051
|
SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST ― SDG&E
|
||||||
(Dollars in millions)
|
||||||
SDG&E
|
Non-
|
|||||
shareholder’s
|
controlling
|
Total
|
||||
equity
|
interest
|
equity
|
||||
Balance at December 31, 2014
|
$
|
4,932
|
$
|
60
|
$
|
4,992
|
Comprehensive income
|
273
|
9
|
282
|
|||
Distributions to noncontrolling interest
|
―
|
(8)
|
(8)
|
|||
Balance at June 30, 2015
|
$
|
5,205
|
$
|
61
|
$
|
5,266
|
Balance at December 31, 2013
|
$
|
4,628
|
$
|
91
|
$
|
4,719
|
Comprehensive income
|
223
|
7
|
230
|
|||
Distributions to noncontrolling interest
|
―
|
(13)
|
(13)
|
|||
Balance at June 30, 2014
|
$
|
4,851
|
$
|
85
|
$
|
4,936
|
SHAREHOLDERS' EQUITY ― SOCALGAS
|
||
(Dollars in millions)
|
||
SoCalGas
|
||
shareholders'
|
||
equity
|
||
Balance at December 31, 2014
|
$
|
2,781
|
Comprehensive income
|
285
|
|
Preferred stock dividends declared
|
(1)
|
|
Balance at June 30, 2015
|
$
|
3,065
|
Balance at December 31, 2013
|
$
|
2,549
|
Comprehensive income
|
159
|
|
Preferred stock dividends declared
|
(1)
|
|
Balance at June 30, 2014
|
$
|
2,707
|
OTHER NONCONTROLLING INTERESTS
|
|||||||||
(Dollars in millions)
|
|||||||||
Percent ownership held by others
|
|||||||||
June 30,
|
December 31,
|
June 30,
|
December 31,
|
||||||
2015
|
2014
|
2015
|
2014
|
||||||
SDG&E:
|
|||||||||
Otay Mesa VIE
|
100
|
%
|
100
|
%
|
$
|
61
|
$
|
60
|
|
Sempra South American Utilities:
|
|||||||||
Chilquinta Energía subsidiaries(1)
|
23.5 – 43.4
|
23.6 – 43.4
|
22
|
23
|
|||||
Luz del Sur
|
16.4
|
16.4
|
171
|
177
|
|||||
Tecsur
|
9.8
|
9.8
|
3
|
4
|
|||||
Sempra Mexico:
|
|||||||||
IEnova, S.A.B. de C.V.
|
18.9
|
18.9
|
476
|
452
|
|||||
Sempra Natural Gas:
|
|||||||||
Bay Gas Storage Company, Ltd.
|
9.1
|
9.1
|
24
|
23
|
|||||
Liberty Gas Storage, LLC
|
25.0
|
25.0
|
14
|
14
|
|||||
Southern Gas Transmission Company
|
49.0
|
49.0
|
1
|
1
|
|||||
Total Sempra Energy
|
$
|
772
|
$
|
754
|
|||||
(1)
|
Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages amongst these subsidiaries.
|
DUE FROM UNCONSOLIDATED AFFILIATES(1)
|
|||||
(Dollars in millions)
|
|||||
June 30, 2015
|
December 31, 2014
|
||||
Sempra South American Utilities:
|
|||||
Eletrans S.A.:
|
|||||
4% Note(2)
|
$
|
61
|
$
|
41
|
|
Sempra Mexico:
|
|||||
Affiliates of joint venture with PEMEX:
|
|||||
Note due November 13, 2017(3)(4)
|
3
|
44
|
|||
Note due November 14, 2018(3)
|
41
|
40
|
|||
Note due November 14, 2018(3)
|
33
|
33
|
|||
Note due November 14, 2018(3)
|
8
|
8
|
|||
Energía Sierra Juárez:
|
|||||
Note due June 15, 2018(5)
|
23
|
22
|
|||
Other(6)
|
4
|
38
|
|||
Total
|
$
|
173
|
$
|
226
|
|
(1)
|
Amounts include principal balances plus accumulated interest outstanding.
|
||||
(2)
|
U.S. dollar-denominated loan, at a fixed interest rate with no stated maturity date, to provide project financing for the construction of transmission lines at Eletrans S.A., an affiliate of Chilquinta Energía.
|
||||
(3)
|
U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.68 percent at June 30, 2015), to finance the Los Ramones Norte pipeline project.
|
||||
(4)
|
In May 2015, approximately $41 million was paid with proceeds from project financing at the joint venture.
|
||||
(5)
|
U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 637.5 basis points (6.56 percent at June 30, 2015), to finance the first phase of the Energía Sierra Juárez wind project.
|
||||
(6)
|
Amounts represent accounts receivable from various Sempra Renewables and Sempra Mexico joint venture investments.
|
AMOUNTS DUE TO AND FROM AFFILIATES AT SDG&E AND SOCALGAS
|
||||||
(Dollars in millions)
|
||||||
June 30, 2015
|
December 31, 2014
|
|||||
SDG&E:
|
||||||
Current:
|
||||||
Due from various affiliates
|
$
|
1
|
$
|
1
|
||
Due to Sempra Energy
|
$
|
7
|
$
|
17
|
||
Due to SoCalGas
|
―
|
4
|
||||
$
|
7
|
$
|
21
|
|||
Income taxes due from Sempra Energy(1)
|
$
|
97
|
$
|
16
|
||
SoCalGas:
|
||||||
Current:
|
||||||
Due from Sempra Energy(2)
|
$
|
273
|
$
|
―
|
||
Due from SDG&E
|
―
|
4
|
||||
$
|
273
|
$
|
4
|
|||
Due to Sempra Energy
|
$
|
―
|
$
|
13
|
||
Income taxes due (to) from Sempra Energy(1)
|
$
|
(19)
|
$
|
9
|
||
(1)
|
SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return.
|
|||||
(2)
|
Net receivable includes a loan to Sempra Energy of $279 million at June 30, 2015 at an interest rate of 0.08 percent.
|
REVENUES FROM UNCONSOLIDATED AFFILIATES AT SDG&E AND SOCALGAS
|
||||||||
(Dollars in millions)
|
||||||||
Three months ended June 30,
|
Six months ended June 30,
|
|||||||
2015
|
2014
|
2015
|
2014
|
|||||
SDG&E
|
$
|
2
|
$
|
3
|
$
|
5
|
$
|
6
|
SoCalGas
|
17
|
16
|
36
|
34
|
OTHER INCOME, NET
|
|||||||||
(Dollars in millions)
|
|||||||||
Three months ended June 30,
|
Six months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
||||||
Sempra Energy Consolidated:
|
|||||||||
Allowance for equity funds used during construction
|
$
|
31
|
$
|
24
|
$
|
58
|
$
|
49
|
|
Investment (losses) gains(1)
|
(2)
|
15
|
7
|
23
|
|||||
(Losses) gains on interest rate and foreign exchange instruments, net
|
(3)
|
11
|
(3)
|
16
|
|||||
Electrical infrastructure relocation income(2)
|
4
|
3
|
4
|
3
|
|||||
Regulatory interest, net(3)
|
1
|
2
|
2
|
3
|
|||||
Foreign currency (losses) gains
|
(2)
|
1
|
(3)
|
1
|
|||||
Sundry, net
|
8
|
(7)
|
11
|
(6)
|
|||||
Total
|
$
|
37
|
$
|
49
|
$
|
76
|
$
|
89
|
|
SDG&E:
|
|||||||||
Allowance for equity funds used during construction
|
$
|
10
|
$
|
7
|
$
|
18
|
$
|
18
|
|
Regulatory interest, net(3)
|
1
|
2
|
2
|
3
|
|||||
Sundry, net
|
(2)
|
(2)
|
(2)
|
(1)
|
|||||
Total
|
$
|
9
|
$
|
7
|
$
|
18
|
$
|
20
|
|
SoCalGas:
|
|||||||||
Allowance for equity funds used during construction
|
$
|
10
|
$
|
6
|
$
|
19
|
$
|
11
|
|
Sundry, net
|
(1)
|
(3)
|
(2)
|
(4)
|
|||||
Total
|
$
|
9
|
$
|
3
|
$
|
17
|
$
|
7
|
|
(1)
|
Represents investment (losses) gains on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are partially offset by corresponding changes in compensation expense related to the plans.
|
||||||||
(2)
|
Income at Luz del Sur associated with the relocation of electrical infrastructure.
|
||||||||
(3)
|
Interest on regulatory balancing accounts.
|
INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
|
|||||||||||
(Dollars in millions)
|
|||||||||||
Effective
|
Effective
|
||||||||||
Income tax
|
income
|
Income tax
|
income
|
||||||||
expense
|
tax rate
|
expense
|
tax rate
|
||||||||
Three months ended June 30,
|
|||||||||||
2015
|
2014
|
||||||||||
Sempra Energy Consolidated
|
$
|
98
|
25
|
%
|
$
|
93
|
25
|
%
|
|||
SDG&E
|
54
|
29
|
69
|
35
|
|||||||
SoCalGas
|
16
|
18
|
28
|
26
|
|||||||
Six months ended June 30,
|
|||||||||||
2015
|
2014
|
||||||||||
Sempra Energy Consolidated
|
$
|
261
|
26
|
%
|
$
|
220
|
29
|
%
|
|||
SDG&E
|
142
|
34
|
152
|
40
|
|||||||
SoCalGas
|
111
|
28
|
66
|
29
|
§
|
a $17 million charge in 2014 to reduce certain tax regulatory assets attributed to SDG&E’s investment in the San Onofre Nuclear Generating Station (SONGS) that we discuss in Note 9; and
|
§
|
favorable resolution of prior years’ income tax items in 2015.
|
§
|
utility self-developed software expenditures
|
§
|
repairs to certain utility plant assets
|
§
|
renewable energy income tax credits
|
§
|
deferred income tax benefits related to renewable energy projects
|
§
|
exclusions from taxable income of the equity portion of AFUDC
|
§
|
depreciation on a certain portion of utility plant assets
|
§
|
U.S. tax on repatriation of current year earnings from non-U.S. subsidiaries
|
§
|
a $17 million charge in 2014 to reduce certain tax regulatory assets attributed to SDG&E’s investment in SONGS that we discuss in Note 9; and
|
§
|
favorable resolution of prior years’ income tax items in 2015.
|
§
|
favorable resolution of prior years’ income tax items in 2015;
|
§
|
higher exclusions from taxable income of the equity portion of AFUDC; and
|
§
|
higher favorable impact of deductions for self-developed software expenditures.
|
§
|
repairs expenditures related to a certain portion of utility plant assets
|
§
|
the equity portion of AFUDC
|
§
|
a portion of the cost of removal of utility plant assets
|
§
|
utility self-developed software expenditures
|
§
|
depreciation on a certain portion of utility plant assets
|
§
|
The California Utilities use energy derivatives, both natural gas and electricity, for the benefit of customers, with the objective of managing price risk and basis risks, and lowering natural gas and electricity costs. These derivatives include fixed price natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Condensed Consolidated Statements of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas.
|
§
|
SDG&E is allocated and may purchase congestion revenue rights (CRRs), which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs are recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, on the Condensed Consolidated Statements of Operations.
|
§
|
Sempra Mexico and Sempra Natural Gas may use natural gas and electricity derivatives, as appropriate, to optimize the earnings of their assets which support the following businesses: liquefied natural gas (LNG), natural gas transportation, power generation, and Sempra Natural Gas’ storage. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Cost of Natural Gas, Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. Sempra Mexico also uses natural gas energy derivatives with the objective of managing price risk and lowering natural gas prices at its Mexican distribution operations. These derivatives, which are recorded as commodity costs that are offset by regulatory account balances and recovered in rates, are recognized in Cost of Natural Gas on the Condensed Consolidated Statements of Operations.
|
§
|
From time to time, our various businesses, including the California Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel.
|
NET ENERGY DERIVATIVE VOLUMES
|
|||||
Segment and Commodity
|
June 30, 2015
|
December 31, 2014
|
|||
California Utilities:
|
|||||
SDG&E:
|
|||||
Natural gas
|
57 million MMBtu
|
55 million MMBtu
|
(1)
|
||
Electricity
|
1 million MWh
|
―
|
(2)
|
||
Congestion revenue rights
|
23 million MWh
|
27 million MWh
|
|||
SoCalGas - natural gas
|
―
|
1 million MMBtu
|
|||
Energy-Related Businesses:
|
|||||
Sempra Natural Gas - natural gas
|
29 million MMBtu
|
29 million MMBtu
|
|||
(1)
|
Million British thermal units
|
||||
(2)
|
Megawatt hours
|
INTEREST RATE DERIVATIVES
|
|||||||
(Dollars in millions)
|
|||||||
June 30, 2015
|
December 31, 2014
|
||||||
Notional debt
|
Maturities
|
Notional debt
|
Maturities
|
||||
Sempra Energy Consolidated:
|
|||||||
Cash flow hedges(1)
|
$
|
392
|
2015-2028
|
$
|
399
|
2015-2028
|
|
Fair value hedges
|
300
|
2016
|
300
|
2016
|
|||
SDG&E:
|
|||||||
Cash flow hedge(1)
|
320
|
2015-2019
|
325
|
2015-2019
|
|||
(1)
|
Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE.
|
DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
|
|||||||||
(Dollars in millions)
|
|||||||||
June 30, 2015
|
|||||||||
Deferred
|
|||||||||
credits
|
|||||||||
Current
|
Current
|
and other
|
|||||||
assets:
|
liabilities:
|
liabilities:
|
|||||||
Fixed-price
|
Investments
|
Fixed-price
|
Fixed-price
|
||||||
contracts
|
and other
|
contracts
|
contracts
|
||||||
and other
|
assets:
|
and other
|
and other
|
||||||
derivatives(1)
|
Sundry
|
derivatives(2)
|
derivatives
|
||||||
Sempra Energy Consolidated:
|
|||||||||
Derivatives designated as hedging instruments:
|
|||||||||
Interest rate and foreign exchange instruments(3)
|
$
|
9
|
$
|
2
|
$
|
(17)
|
$
|
(129)
|
|
Commodity contracts not subject to rate recovery
|
1
|
―
|
―
|
―
|
|||||
Derivatives not designated as hedging instruments:
|
|||||||||
Interest rate and foreign exchange instruments
|
8
|
24
|
(6)
|
(20)
|
|||||
Commodity contracts not subject to rate recovery
|
78
|
24
|
(76)
|
(16)
|
|||||
Associated offsetting commodity contracts
|
(69)
|
(15)
|
69
|
15
|
|||||
Associated offsetting cash collateral
|
―
|
―
|
5
|
1
|
|||||
Commodity contracts subject to rate recovery
|
15
|
75
|
(37)
|
(64)
|
|||||
Associated offsetting commodity contracts
|
(1)
|
(1)
|
1
|
1
|
|||||
Associated offsetting cash collateral
|
―
|
―
|
21
|
21
|
|||||
Net amounts presented on the balance sheet
|
41
|
109
|
(40)
|
(191)
|
|||||
Additional cash collateral for commodity contracts
|
|||||||||
not subject to rate recovery
|
17
|
―
|
―
|
―
|
|||||
Additional cash collateral for commodity contracts
|
|||||||||
subject to rate recovery
|
27
|
―
|
―
|
―
|
|||||
Total(4)
|
$
|
85
|
$
|
109
|
$
|
(40)
|
$
|
(191)
|
|
SDG&E:
|
|||||||||
Derivatives designated as hedging instruments:
|
|||||||||
Interest rate instruments(3)
|
$
|
―
|
$
|
―
|
$
|
(15)
|
$
|
(28)
|
|
Derivatives not designated as hedging instruments:
|
|||||||||
Commodity contracts not subject to rate recovery
|
―
|
―
|
(1)
|
―
|
|||||
Associated offsetting cash collateral
|
―
|
―
|
1
|
―
|
|||||
Commodity contracts subject to rate recovery
|
14
|
75
|
(37)
|
(64)
|
|||||
Associated offsetting commodity contracts
|
(1)
|
(1)
|
1
|
1
|
|||||
Associated offsetting cash collateral
|
―
|
―
|
21
|
21
|
|||||
Net amounts presented on the balance sheet
|
13
|
74
|
(30)
|
(70)
|
|||||
Additional cash collateral for commodity contracts
|
|||||||||
not subject to rate recovery
|
1
|
―
|
―
|
―
|
|||||
Additional cash collateral for commodity contracts
|
|||||||||
subject to rate recovery
|
26
|
―
|
―
|
―
|
|||||
Total(4)
|
$
|
40
|
$
|
74
|
$
|
(30)
|
$
|
(70)
|
|
SoCalGas:
|
|||||||||
Derivatives not designated as hedging instruments:
|
|||||||||
Commodity contracts not subject to rate recovery
|
$
|
―
|
$
|
―
|
$
|
(1)
|
$
|
―
|
|
Associated offsetting cash collateral
|
―
|
―
|
1
|
―
|
|||||
Commodity contracts subject to rate recovery
|
1
|
―
|
―
|
―
|
|||||
Net amounts presented on the balance sheet
|
1
|
―
|
―
|
―
|
|||||
Additional cash collateral for commodity contracts
|
|||||||||
not subject to rate recovery
|
2
|
―
|
―
|
―
|
|||||
Additional cash collateral for commodity contracts
|
|||||||||
subject to rate recovery
|
1
|
―
|
―
|
―
|
|||||
Total
|
$
|
4
|
$
|
―
|
$
|
―
|
$
|
―
|
|
(1)
|
Included in Current Assets: Other for SoCalGas.
|
||||||||
(2)
|
Included in Current Liabilities: Other for SoCalGas.
|
||||||||
(3)
|
Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.
|
||||||||
(4)
|
Normal purchase contracts previously measured at fair value are excluded.
|
DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
|
|||||||||
(Dollars in millions)
|
|||||||||
December 31, 2014
|
|||||||||
Deferred
|
|||||||||
credits
|
|||||||||
Current
|
Current
|
and other
|
|||||||
assets:
|
liabilities:
|
liabilities:
|
|||||||
Fixed-price
|
Investments
|
Fixed-price
|
Fixed-price
|
||||||
contracts
|
and other
|
contracts
|
contracts
|
||||||
and other
|
assets:
|
and other
|
and other
|
||||||
derivatives(1)
|
Sundry
|
derivatives(2)
|
derivatives
|
||||||
Sempra Energy Consolidated:
|
|||||||||
Derivatives designated as hedging instruments:
|
|||||||||
Interest rate and foreign exchange instruments(3)
|
$
|
10
|
$
|
3
|
$
|
(17)
|
$
|
(109)
|
|
Commodity contracts not subject to rate recovery
|
25
|
―
|
―
|
―
|
|||||
Derivatives not designated as hedging instruments:
|
|||||||||
Interest rate instruments
|
8
|
27
|
(7)
|
(22)
|
|||||
Commodity contracts not subject to rate recovery
|
143
|
32
|
(135)
|
(29)
|
|||||
Associated offsetting commodity contracts
|
(129)
|
(27)
|
129
|
27
|
|||||
Associated offsetting cash collateral
|
(11)
|
―
|
―
|
―
|
|||||
Commodity contracts subject to rate recovery
|
36
|
76
|
(36)
|
(20)
|
|||||
Associated offsetting commodity contracts
|
(3)
|
(1)
|
3
|
1
|
|||||
Associated offsetting cash collateral
|
―
|
―
|
23
|
13
|
|||||
Net amounts presented on the balance sheet
|
79
|
110
|
(40)
|
(139)
|
|||||
Additional cash collateral for commodity contracts
|
|||||||||
subject to rate recovery
|
14
|
―
|
―
|
―
|
|||||
Total(4)
|
$
|
93
|
$
|
110
|
$
|
(40)
|
$
|
(139)
|
|
SDG&E:
|
|||||||||
Derivatives designated as hedging instruments:
|
|||||||||
Interest rate instruments(3)
|
$
|
―
|
$
|
―
|
$
|
(16)
|
$
|
(31)
|
|
Derivatives not designated as hedging instruments:
|
|||||||||
Commodity contracts subject to rate recovery
|
32
|
76
|
(32)
|
(20)
|
|||||
Associated offsetting commodity contracts
|
―
|
(1)
|
―
|
1
|
|||||
Associated offsetting cash collateral
|
―
|
―
|
23
|
13
|
|||||
Net amounts presented on the balance sheet
|
32
|
75
|
(25)
|
(37)
|
|||||
Additional cash collateral for commodity contracts
|
|||||||||
subject to rate recovery
|
12
|
―
|
―
|
―
|
|||||
Total(4)
|
$
|
44
|
$
|
75
|
$
|
(25)
|
$
|
(37)
|
|
SoCalGas:
|
|||||||||
Derivatives not designated as hedging instruments:
|
|||||||||
Commodity contracts subject to rate recovery
|
$
|
4
|
$
|
―
|
$
|
(4)
|
$
|
―
|
|
Associated offsetting commodity contracts
|
(3)
|
―
|
3
|
―
|
|||||
Net amounts presented on the balance sheet
|
1
|
―
|
(1)
|
―
|
|||||
Additional cash collateral for commodity contracts
|
|||||||||
subject to rate recovery
|
2
|
―
|
―
|
―
|
|||||
Total
|
$
|
3
|
$
|
―
|
$
|
(1)
|
$
|
―
|
|
(1)
|
Included in Current Assets: Other for SoCalGas.
|
||||||||
(2)
|
Included in Current Liabilities: Other for SoCalGas.
|
||||||||
(3)
|
Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.
|
||||||||
(4)
|
Normal purchase contracts previously measured at fair value are excluded.
|
FAIR VALUE HEDGE IMPACT ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
|
||||||||||
(Dollars in millions)
|
||||||||||
Gain (loss) on derivatives recognized in earnings
|
||||||||||
Three months ended June 30,
|
Six months ended June 30,
|
|||||||||
Location
|
2015
|
2014
|
2015
|
2014
|
||||||
Sempra Energy Consolidated:
|
||||||||||
Interest rate instruments
|
Interest Expense
|
$
|
2
|
$
|
2
|
$
|
4
|
$
|
5
|
|
Interest rate instruments
|
Other Income, Net
|
(3)
|
5
|
(2)
|
1
|
|||||
Total(1)
|
$
|
(1)
|
$
|
7
|
$
|
2
|
$
|
6
|
||
(1)
|
There was no hedge ineffectiveness on these swaps in the three months or six months ended June 30, 2015, respectively, and $7 million and $9 million in the three months and six months ended June 30, 2014, respectively. All other changes in the fair value of the interest rate swap agreements are exactly offset by changes in the fair value of the underlying long-term debt and are recorded in Other Income, Net.
|
CASH FLOW HEDGE IMPACT ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
|
|||||||||||
(Dollars in millions)
|
|||||||||||
Pretax gain (loss) recognized
|
Pretax gain (loss) reclassified from
|
||||||||||
in OCI (effective portion)
|
AOCI into earnings (effective portion)
|
||||||||||
Three months ended June 30,
|
Three months ended June 30,
|
||||||||||
2015
|
2014
|
Location
|
2015
|
2014
|
|||||||
Sempra Energy Consolidated:
|
|||||||||||
Interest rate and foreign
|
|||||||||||
exchange instruments(1)
|
$
|
6
|
$
|
(7)
|
Interest Expense
|
$
|
(3)
|
$
|
(6)
|
||
Equity Earnings,
|
|||||||||||
Interest rate instruments
|
89
|
(15)
|
Before Income Tax
|
(3)
|
(2)
|
||||||
Commodity contracts not subject
|
Revenues: Energy-Related
|
||||||||||
to rate recovery
|
1
|
―
|
Businesses
|
―
|
―
|
||||||
Total(2)
|
$
|
96
|
$
|
(22)
|
$
|
(6)
|
$
|
(8)
|
|||
SDG&E:
|
|||||||||||
Interest rate instruments(1)(2)
|
$
|
―
|
$
|
(3)
|
Interest Expense
|
$
|
(3)
|
$
|
(2)
|
||
Six months ended June 30,
|
Six months ended June 30,
|
||||||||||
2015
|
2014
|
Location
|
2015
|
2014
|
|||||||
Sempra Energy Consolidated:
|
|||||||||||
Interest rate and foreign
|
|||||||||||
exchange instruments(1)
|
$
|
(12)
|
$
|
(10)
|
Interest Expense
|
$
|
(9)
|
$
|
(9)
|
||
Gain on Sale of Equity Interest
|
|||||||||||
Interest rate instruments
|
―
|
(2)
|
and Assets
|
―
|
(2)
|
||||||
Equity Earnings,
|
|||||||||||
Interest rate instruments
|
11
|
(30)
|
Before Income Tax
|
(6)
|
(5)
|
||||||
Commodity contracts not subject
|
Revenues: Energy-Related
|
||||||||||
to rate recovery
|
―
|
(6)
|
Businesses
|
7
|
(10)
|
||||||
Total(2)
|
$
|
(1)
|
$
|
(48)
|
$
|
(8)
|
$
|
(26)
|
|||
SDG&E:
|
|||||||||||
Interest rate instruments(1)(2)
|
$
|
(5)
|
$
|
(6)
|
Interest Expense
|
$
|
(6)
|
$
|
(5)
|
||
(1)
|
Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.
|
||||||||||
(2)
|
There was a negligible amount of ineffectiveness related to these hedges in 2015 and 2014.
|
UNDESIGNATED DERIVATIVE IMPACT ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
|
||||||||||
(Dollars in millions)
|
||||||||||
Gain (loss) on derivatives recognized in earnings
|
||||||||||
Three months ended
June 30,
|
Six months ended
June 30,
|
|||||||||
Location
|
2015
|
2014
|
2015
|
2014
|
||||||
Sempra Energy Consolidated:
|
||||||||||
Interest rate and foreign exchange
|
||||||||||
instruments
|
Other Income, Net
|
$
|
(3)
|
$
|
4
|
$
|
(3)
|
$
|
7
|
|
Foreign exchange instruments
|
Equity Earnings,
|
|||||||||
Net of Income Tax
|
―
|
―
|
(1)
|
(2)
|
||||||
Commodity contracts not subject
|
Revenues: Energy-Related
|
|||||||||
to rate recovery
|
Businesses
|
9
|
4
|
12
|
(1)
|
|||||
Commodity contracts not subject
|
Cost of Natural Gas, Electric Fuel
|
|||||||||
to rate recovery
|
and Purchased Power
|
―
|
1
|
―
|
2
|
|||||
Commodity contracts not subject
|
||||||||||
to rate recovery
|
Operation and Maintenance
|
1
|
―
|
1
|
―
|
|||||
Commodity contracts subject
|
Cost of Electric Fuel
|
|||||||||
to rate recovery
|
and Purchased Power
|
(53)
|
8
|
(73)
|
20
|
|||||
Commodity contracts subject
|
||||||||||
to rate recovery
|
Cost of Natural Gas
|
―
|
(1)
|
1
|
1
|
|||||
Total
|
$
|
(46)
|
$
|
16
|
$
|
(63)
|
$
|
27
|
||
SDG&E:
|
||||||||||
Commodity contracts subject
|
Cost of Electric Fuel
|
|||||||||
to rate recovery
|
and Purchased Power
|
$
|
(53)
|
$
|
8
|
$
|
(73)
|
$
|
20
|
|
SoCalGas:
|
||||||||||
Commodity contracts not subject
|
|
|||||||||
to rate recovery
|
Operation and Maintenance
|
$
|
1
|
$
|
―
|
$
|
1
|
$
|
―
|
|
Commodity contracts subject
|
||||||||||
to rate recovery
|
Cost of Natural Gas
|
―
|
(1)
|
1
|
1
|
|||||
Total
|
$
|
1
|
$
|
(1)
|
$
|
2
|
$
|
1
|
§
|
Nuclear decommissioning trusts reflect the assets of SDG&E’s nuclear decommissioning trusts, excluding cash balances. A third party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Equity and certain debt securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other debt securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2).
|
§
|
We enter into commodity contracts and interest rate derivatives primarily as a means to manage price exposures. We may also manage foreign exchange rate exposures using derivatives. We primarily use a market approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long-term, fixed-price electricity positions at SDG&E, as we discuss below under “Level 3 Information.” We record commodity derivative contracts that are subject to rate recovery as commodity costs that are offset by regulatory account balances and are recovered in rates.
|
§
|
Investments include marketable securities that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1).
|
RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED
|
|||||||||||
(Dollars in millions)
|
|||||||||||
Fair value at June 30, 2015
|
|||||||||||
Level 1
|
Level 2
|
Level 3
|
Netting(1)
|
Total
|
|||||||
Assets:
|
|||||||||||
Nuclear decommissioning trusts:
|
|||||||||||
Equity securities
|
$
|
665
|
$
|
―
|
$
|
―
|
$
|
―
|
$
|
665
|
|
Debt securities:
|
|||||||||||
Debt securities issued by the U.S. Treasury and other
|
|||||||||||
U.S. government corporations and agencies
|
50
|
48
|
―
|
―
|
98
|
||||||
Municipal bonds
|
―
|
152
|
―
|
―
|
152
|
||||||
Other securities
|
―
|
209
|
―
|
―
|
209
|
||||||
Total debt securities
|
50
|
409
|
―
|
―
|
459
|
||||||
Total nuclear decommissioning trusts(2)
|
715
|
409
|
―
|
―
|
1,124
|
||||||
Interest rate and foreign exchange instruments
|
―
|
43
|
―
|
―
|
43
|
||||||
Commodity contracts not subject to rate recovery
|
6
|
13
|
―
|
17
|
36
|
||||||
Commodity contracts subject to rate recovery
|
―
|
1
|
87
|
27
|
115
|
||||||
Total
|
$
|
721
|
$
|
466
|
$
|
87
|
$
|
44
|
$
|
1,318
|
|
Liabilities:
|
|||||||||||
Interest rate and foreign exchange instruments
|
$
|
―
|
$
|
172
|
$
|
―
|
$
|
―
|
$
|
172
|
|
Commodity contracts not subject to rate recovery
|
4
|
4
|
―
|
(6)
|
2
|
||||||
Commodity contracts subject to rate recovery
|
―
|
54
|
45
|
(42)
|
57
|
||||||
Total
|
$
|
4
|
$
|
230
|
$
|
45
|
$
|
(48)
|
$
|
231
|
|
Fair value at December 31, 2014
|
|||||||||||
Level 1
|
Level 2
|
Level 3
|
Netting(1)
|
Total
|
|||||||
Assets:
|
|||||||||||
Nuclear decommissioning trusts:
|
|||||||||||
Equity securities
|
$
|
655
|
$
|
―
|
$
|
―
|
$
|
―
|
$
|
655
|
|
Debt securities:
|
|||||||||||
Debt securities issued by the U.S. Treasury and other
|
|||||||||||
U.S. government corporations and agencies
|
62
|
47
|
―
|
―
|
109
|
||||||
Municipal bonds
|
―
|
129
|
―
|
―
|
129
|
||||||
Other securities
|
―
|
207
|
―
|
―
|
207
|
||||||
Total debt securities
|
62
|
383
|
―
|
―
|
445
|
||||||
Total nuclear decommissioning trusts(2)
|
717
|
383
|
―
|
―
|
1,100
|
||||||
Interest rate and foreign exchange instruments
|
―
|
48
|
―
|
―
|
48
|
||||||
Commodity contracts not subject to rate recovery
|
28
|
16
|
―
|
(11)
|
33
|
||||||
Commodity contracts subject to rate recovery
|
―
|
1
|
107
|
14
|
122
|
||||||
Total
|
$
|
745
|
$
|
448
|
$
|
107
|
$
|
3
|
$
|
1,303
|
|
Liabilities:
|
|||||||||||
Interest rate and foreign exchange instruments
|
$
|
―
|
$
|
155
|
$
|
―
|
$
|
―
|
$
|
155
|
|
Commodity contracts not subject to rate recovery
|
3
|
9
|
―
|
(4)
|
8
|
||||||
Commodity contracts subject to rate recovery
|
―
|
52
|
―
|
(36)
|
16
|
||||||
Total
|
$
|
3
|
$
|
216
|
$
|
―
|
$
|
(40)
|
$
|
179
|
|
(1)
|
Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
|
||||||||||
(2)
|
Excludes cash balances and cash equivalents.
|
RECURRING FAIR VALUE MEASURES – SDG&E
|
|||||||||||
(Dollars in millions)
|
|||||||||||
Fair value at June 30, 2015
|
|||||||||||
Level 1
|
Level 2
|
Level 3
|
Netting(1)
|
Total
|
|||||||
Assets:
|
|||||||||||
Nuclear decommissioning trusts:
|
|||||||||||
Equity securities
|
$
|
665
|
$
|
―
|
$
|
―
|
$
|
―
|
$
|
665
|
|
Debt securities:
|
|||||||||||
Debt securities issued by the U.S. Treasury and other
|
|||||||||||
U.S. government corporations and agencies
|
50
|
48
|
―
|
―
|
98
|
||||||
Municipal bonds
|
―
|
152
|
―
|
―
|
152
|
||||||
Other securities
|
―
|
209
|
―
|
―
|
209
|
||||||
Total debt securities
|
50
|
409
|
―
|
―
|
459
|
||||||
Total nuclear decommissioning trusts(2)
|
715
|
409
|
―
|
―
|
1,124
|
||||||
Commodity contracts not subject to rate recovery
|
―
|
―
|
―
|
1
|
1
|
||||||
Commodity contracts subject to rate recovery
|
―
|
―
|
87
|
26
|
113
|
||||||
Total
|
$
|
715
|
$
|
409
|
$
|
87
|
$
|
27
|
$
|
1,238
|
|
Liabilities:
|
|||||||||||
Interest rate instruments
|
$
|
―
|
$
|
43
|
$
|
―
|
$
|
―
|
$
|
43
|
|
Commodity contracts not subject to rate recovery
|
1
|
―
|
―
|
(1)
|
―
|
||||||
Commodity contracts subject to rate recovery
|
―
|
54
|
45
|
(42)
|
57
|
||||||
Total
|
$
|
1
|
$
|
97
|
$
|
45
|
$
|
(43)
|
$
|
100
|
|
Fair value at December 31, 2014
|
|||||||||||
Level 1
|
Level 2
|
Level 3
|
Netting(1)
|
Total
|
|||||||
Assets:
|
|||||||||||
Nuclear decommissioning trusts:
|
|||||||||||
Equity securities
|
$
|
655
|
$
|
―
|
$
|
―
|
$
|
―
|
$
|
655
|
|
Debt securities:
|
|||||||||||
Debt securities issued by the U.S. Treasury and other
|
|||||||||||
U.S. government corporations and agencies
|
62
|
47
|
―
|
―
|
109
|
||||||
Municipal bonds
|
―
|
129
|
―
|
―
|
129
|
||||||
Other securities
|
―
|
207
|
―
|
―
|
207
|
||||||
Total debt securities
|
62
|
383
|
―
|
―
|
445
|
||||||
Total nuclear decommissioning trusts(2)
|
717
|
383
|
―
|
―
|
1,100
|
||||||
Commodity contracts subject to rate recovery
|
―
|
―
|
107
|
12
|
119
|
||||||
Total
|
$
|
717
|
$
|
383
|
$
|
107
|
$
|
12
|
$
|
1,219
|
|
Liabilities:
|
|||||||||||
Interest rate instruments
|
$
|
―
|
$
|
47
|
$
|
―
|
$
|
―
|
$
|
47
|
|
Commodity contracts not subject to rate recovery
|
1
|
―
|
―
|
(1)
|
―
|
||||||
Commodity contracts subject to rate recovery
|
―
|
51
|
―
|
(36)
|
15
|
||||||
Total
|
$
|
1
|
$
|
98
|
$
|
―
|
$
|
(37)
|
$
|
62
|
|
(1)
|
Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
|
||||||||||
(2)
|
Excludes cash balances and cash equivalents.
|
RECURRING FAIR VALUE MEASURES – SOCALGAS
|
|||||||||||
(Dollars in millions)
|
|||||||||||
Fair value at June 30, 2015
|
|||||||||||
Level 1
|
Level 2
|
Level 3
|
Netting(1)
|
Total
|
|||||||
Assets:
|
|||||||||||
Commodity contracts not subject to rate recovery
|
$
|
―
|
$
|
―
|
$
|
―
|
$
|
2
|
$
|
2
|
|
Commodity contracts subject to rate recovery
|
―
|
1
|
―
|
1
|
2
|
||||||
Total
|
$
|
―
|
$
|
1
|
$
|
―
|
$
|
3
|
$
|
4
|
|
Liabilities:
|
|||||||||||
Commodity contracts not subject to rate recovery
|
$
|
1
|
$
|
―
|
$
|
―
|
$
|
(1)
|
$
|
―
|
|
Total
|
$
|
1
|
$
|
―
|
$
|
―
|
$
|
(1)
|
$
|
―
|
|
Fair value at December 31, 2014
|
|||||||||||
Level 1
|
Level 2
|
Level 3
|
Netting(1)
|
Total
|
|||||||
Assets:
|
|||||||||||
Commodity contracts subject to rate recovery
|
$
|
―
|
$
|
1
|
$
|
―
|
$
|
2
|
$
|
3
|
|
Total
|
$
|
―
|
$
|
1
|
$
|
―
|
$
|
2
|
$
|
3
|
|
Liabilities:
|
|||||||||||
Commodity contracts not subject to rate recovery
|
$
|
2
|
$
|
―
|
$
|
―
|
$
|
(2)
|
$
|
―
|
|
Commodity contracts subject to rate recovery
|
―
|
1
|
―
|
―
|
1
|
||||||
Total
|
$
|
2
|
$
|
1
|
$
|
―
|
$
|
(2)
|
$
|
1
|
|
(1)
|
Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
|
LEVEL 3 RECONCILIATIONS
|
||||
(Dollars in millions)
|
||||
Three months ended June 30,
|
||||
2015
|
2014
|
|||
Balance as of April 1
|
$
|
102
|
$
|
95
|
Realized and unrealized (losses) gains
|
(60)
|
5
|
||
Allocated transmission instruments
|
1
|
―
|
||
Settlements
|
(1)
|
(15)
|
||
Balance as of June 30
|
$
|
42
|
$
|
85
|
Change in unrealized gains or losses relating to
|
||||
instruments still held at June 30
|
$
|
45
|
$
|
―
|
Six months ended June 30,
|
||||
2015
|
2014
|
|||
Balance as of January 1
|
$
|
107
|
$
|
99
|
Realized and unrealized (losses) gains
|
(54)
|
6
|
||
Allocated transmission instruments
|
1
|
1
|
||
Settlements
|
(12)
|
(21)
|
||
Balance as of June 30
|
$
|
42
|
$
|
85
|
Change in unrealized gains or losses relating to
|
||||
instruments still held at June 30
|
$
|
46
|
$
|
―
|
FAIR VALUE OF FINANCIAL INSTRUMENTS
|
||||||||||||
(Dollars in millions)
|
||||||||||||
June 30, 2015
|
||||||||||||
Carrying
|
Fair value
|
|||||||||||
amount
|
Level 1
|
Level 2
|
Level 3
|
Total
|
||||||||
Sempra Energy Consolidated:
|
||||||||||||
Total long-term debt(1)(2)
|
$
|
13,569
|
$
|
―
|
$
|
13,772
|
$
|
725
|
$
|
14,497
|
||
Preferred stock of subsidiary
|
20
|
―
|
23
|
―
|
23
|
|||||||
SDG&E:
|
||||||||||||
Total long-term debt(2)(3)
|
$
|
4,747
|
$
|
―
|
$
|
4,772
|
$
|
320
|
$
|
5,092
|
||
SoCalGas:
|
||||||||||||
Total long-term debt(4)
|
$
|
2,512
|
$
|
―
|
$
|
2,608
|
$
|
―
|
$
|
2,608
|
||
Preferred stock
|
22
|
―
|
24
|
―
|
24
|
|||||||
December 31, 2014
|
||||||||||||
Carrying
|
Fair value
|
|||||||||||
amount
|
Level 1
|
Level 2
|
Level 3
|
Total
|
||||||||
Sempra Energy Consolidated:
|
||||||||||||
Total long-term debt(1)(2)
|
$
|
12,347
|
$
|
―
|
$
|
12,782
|
$
|
917
|
$
|
13,699
|
||
Preferred stock of subsidiary
|
20
|
―
|
23
|
―
|
23
|
|||||||
SDG&E:
|
||||||||||||
Total long-term debt(2)(3)
|
$
|
4,461
|
$
|
―
|
$
|
4,563
|
$
|
425
|
$
|
4,988
|
||
SoCalGas:
|
||||||||||||
Total long-term debt(4)
|
$
|
1,913
|
$
|
―
|
$
|
2,124
|
$
|
―
|
$
|
2,124
|
||
Preferred stock
|
22
|
―
|
25
|
―
|
25
|
|||||||
(1)
|
Before reductions for unamortized discount (net of premium) of $21 million at both June 30, 2015 and December 31, 2014, and excluding build-to-suit and capital leases of $351 million and $310 million at June 30, 2015 and December 31, 2014, respectively. We discuss our long-term debt in Note 6 above and in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.
|
|||||||||||
(2)
|
Level 3 instruments include $320 million and $325 million at June 30, 2015 and December 31, 2014, respectively, related to Otay Mesa VIE.
|
|||||||||||
(3)
|
Before reductions for unamortized discount of $10 million and $11 million at June 30, 2015 and December 31, 2014, respectively, and excluding capital leases of $231 million and $234 million at June 30, 2015 and December 31, 2014, respectively.
|
|||||||||||
(4)
|
Before reductions for unamortized discount of $7 million and $8 million at June 30, 2015 and December 31, 2014, respectively, and excluding capital leases of $2 million and $1 million at June 30, 2015 and December 31, 2014, respectively.
|
NUCLEAR DECOMMISSIONING TRUSTS
|
|||||||||
(Dollars in millions)
|
|||||||||
Gross
|
Gross
|
Estimated
|
|||||||
unrealized
|
unrealized
|
fair
|
|||||||
Cost
|
gains
|
losses
|
value
|
||||||
At June 30, 2015:
|
|||||||||
Debt securities:
|
|||||||||
Debt securities issued by the U.S. Treasury and other
|
|||||||||
U.S. government corporations and agencies(1)
|
$
|
94
|
$
|
4
|
$
|
―
|
$
|
98
|
|
Municipal bonds(2)
|
147
|
6
|
(1)
|
152
|
|||||
Other securities(2)
|
214
|
4
|
(9)
|
209
|
|||||
Total debt securities
|
455
|
14
|
(10)
|
459
|
|||||
Equity securities
|
218
|
450
|
(3)
|
665
|
|||||
Cash and cash equivalents
|
21
|
―
|
―
|
21
|
|||||
Total
|
$
|
694
|
$
|
464
|
$
|
(13)
|
$
|
1,145
|
|
At December 31, 2014:
|
|||||||||
Debt securities:
|
|||||||||
Debt securities issued by the U.S. Treasury and other
|
|||||||||
U.S. government corporations and agencies
|
$
|
103
|
$
|
6
|
$
|
―
|
$
|
109
|
|
Municipal bonds
|
121
|
8
|
―
|
129
|
|||||
Other securities
|
206
|
7
|
(6)
|
207
|
|||||
Total debt securities
|
430
|
21
|
(6)
|
445
|
|||||
Equity securities
|
215
|
444
|
(4)
|
655
|
|||||
Cash and cash equivalents
|
30
|
1
|
―
|
31
|
|||||
Total
|
$
|
675
|
$
|
466
|
$
|
(10)
|
$
|
1,131
|
|
(1)
|
Maturity dates are 2016-2060.
|
||||||||
(2)
|
Maturity dates are 2015-2115.
|
SALES OF SECURITIES
|
|||||||||
(Dollars in millions)
|
|||||||||
Three months ended June 30,
|
Six months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
||||||
Proceeds from sales(1)
|
$
|
127
|
$
|
155
|
$
|
221
|
$
|
350
|
|
Gross realized gains
|
4
|
―
|
6
|
4
|
|||||
Gross realized losses
|
(3)
|
(1)
|
(7)
|
(5)
|
|||||
(1)
|
Excludes securities that are held to maturity.
|
§
|
approved the utilities’ model for implementing PSEP;
|
§
|
approved a process, including a reasonableness review, to determine the amount that the utilities will be authorized to recover from ratepayers for the interim costs incurred through the date of the final decision to implement PSEP, which is recorded in the regulatory accounts authorized by the CPUC as noted above;
|
§
|
approved balancing account treatment, subject to a reasonableness review, for incremental costs yet to be incurred to implement PSEP; and
|
§
|
established the criteria to determine the amounts that would not be eligible for cost recovery, including:
|
□
|
certain costs incurred or to be incurred searching for pipeline test records,
|
□
|
the cost of pressure testing pipelines installed after July 1, 1961 for which the company has not found sufficient records of testing, and
|
□
|
any undepreciated balances for pipelines installed after 1961 that were replaced due to insufficient documentation of pressure testing.
|
FUTURE MINIMUM PAYMENTS – POWER PURCHASE AGREEMENT
|
||||
(Dollars in millions)
|
||||
2015
|
$
|
―
|
||
2016
|
―
|
|||
2017
|
38
|
|||
2018
|
65
|
|||
2019
|
65
|
|||
Thereafter
|
1,460
|
|||
Total minimum lease payments(1)
|
1,628
|
|||
Less: estimated executory costs
|
(392)
|
|||
Less: interest(2)
|
(736)
|
|||
Present value of net minimum lease payments
|
$
|
500
|
||
(1)
|
This amount will be recorded over the life of the lease as Cost of Electric Fuel and Purchased Power on Sempra Energy’s and SDG&E’s Condensed Consolidated Statements of Operations. This expense will receive ratemaking treatment consistent with purchased-power costs, which are recovered in rates.
|
|||
(2)
|
Amount necessary to reduce net minimum lease payments to estimated present value at the inception of the lease.
|
1.
|
SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County.
|
2.
|
SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California.
|
3.
|
Sempra South American Utilities operates electric transmission and distribution utilities in Chile and Peru.
|
4.
|
Sempra Mexico develops, owns and operates, or holds interests in, natural gas transmission pipelines and propane and ethane systems, a natural gas distribution utility, electric generation facilities (including wind), a terminal for the import of LNG, and marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico.
|
5.
|
Sempra Renewables develops, owns and operates, or holds interests in, wind and solar energy projects in Arizona, California, Colorado, Hawaii, Indiana, Kansas, Minnesota, Nebraska, Nevada and Pennsylvania to serve wholesale electricity markets in the United States.
|
6.
|
Sempra Natural Gas develops, owns and operates, or holds interests in, natural gas pipelines and storage facilities, natural gas distribution utilities and a terminal for the import and export of LNG and sale of natural gas, all within the United States. Sempra Natural gas also owned and operated the Mesquite Power plant, a natural gas-fired electric generation asset, the remaining 625-MW block of which was sold in April 2015, as we discuss in Note 3.
|
SEGMENT INFORMATION
|
|||||||||||||||||
(Dollars in millions)
|
|||||||||||||||||
Three months ended June 30,
|
Six months ended June 30,
|
||||||||||||||||
2015
|
2014
|
2015
|
2014
|
||||||||||||||
REVENUES
|
|||||||||||||||||
SDG&E
|
$
|
972
|
41
|
%
|
$
|
1,063
|
40
|
%
|
$
|
1,938
|
38
|
%
|
$
|
2,050
|
37
|
%
|
|
SoCalGas
|
780
|
33
|
917
|
34
|
1,828
|
36
|
2,002
|
37
|
|||||||||
Sempra South American Utilities
|
389
|
16
|
390
|
15
|
778
|
15
|
768
|
14
|
|||||||||
Sempra Mexico
|
152
|
6
|
186
|
7
|
315
|
6
|
387
|
7
|
|||||||||
Sempra Renewables
|
10
|
1
|
9
|
―
|
18
|
1
|
15
|
―
|
|||||||||
Sempra Natural Gas
|
155
|
7
|
236
|
9
|
352
|
7
|
496
|
9
|
|||||||||
Adjustments and eliminations
|
(1)
|
―
|
(2)
|
―
|
(1)
|
―
|
(2)
|
―
|
|||||||||
Intersegment revenues(1)
|
(90)
|
(4)
|
(121)
|
(5)
|
(179)
|
(3)
|
(243)
|
(4)
|
|||||||||
Total
|
$
|
2,367
|
100
|
%
|
$
|
2,678
|
100
|
%
|
$
|
5,049
|
100
|
%
|
$
|
5,473
|
100
|
%
|
|
INTEREST EXPENSE
|
|||||||||||||||||
SDG&E
|
$
|
52
|
$
|
51
|
$
|
104
|
$
|
101
|
|||||||||
SoCalGas
|
19
|
16
|
38
|
33
|
|||||||||||||
Sempra South American Utilities
|
8
|
9
|
13
|
17
|
|||||||||||||
Sempra Mexico
|
6
|
4
|
11
|
8
|
|||||||||||||
Sempra Renewables
|
1
|
1
|
2
|
1
|
|||||||||||||
Sempra Natural Gas
|
23
|
33
|
44
|
65
|
|||||||||||||
All other
|
65
|
57
|
128
|
115
|
|||||||||||||
Intercompany eliminations
|
(35)
|
(33)
|
(67)
|
(66)
|
|||||||||||||
Total
|
$
|
139
|
$
|
138
|
$
|
273
|
$
|
274
|
|||||||||
INTEREST INCOME
|
|||||||||||||||||
SoCalGas
|
$
|
3
|
$
|
―
|
$
|
3
|
$
|
―
|
|||||||||
Sempra South American Utilities
|
5
|
3
|
9
|
6
|
|||||||||||||
Sempra Mexico
|
2
|
1
|
4
|
1
|
|||||||||||||
Sempra Renewables
|
1
|
―
|
1
|
―
|
|||||||||||||
Sempra Natural Gas
|
25
|
32
|
44
|
63
|
|||||||||||||
All other
|
―
|
1
|
―
|
1
|
|||||||||||||
Intercompany eliminations
|
(26)
|
(32)
|
(44)
|
(62)
|
|||||||||||||
Total
|
$
|
10
|
$
|
5
|
$
|
17
|
$
|
9
|
|||||||||
DEPRECIATION AND AMORTIZATION
|
|||||||||||||||||
SDG&E
|
$
|
149
|
48
|
%
|
$
|
131
|
45
|
%
|
$
|
294
|
48
|
%
|
$
|
261
|
45
|
%
|
|
SoCalGas
|
113
|
37
|
107
|
37
|
226
|
37
|
212
|
37
|
|||||||||
Sempra South American Utilities
|
12
|
4
|
13
|
5
|
25
|
4
|
27
|
5
|
|||||||||
Sempra Mexico
|
17
|
6
|
15
|
5
|
34
|
6
|
31
|
5
|
|||||||||
Sempra Renewables
|
1
|
―
|
2
|
1
|
3
|
―
|
3
|
1
|
|||||||||
Sempra Natural Gas
|
12
|
4
|
16
|
6
|
24
|
4
|
33
|
6
|
|||||||||
All other
|
3
|
1
|
4
|
1
|
4
|
1
|
7
|
1
|
|||||||||
Total
|
$
|
307
|
100
|
%
|
$
|
288
|
100
|
%
|
$
|
610
|
100
|
%
|
$
|
574
|
100
|
%
|
|
INCOME TAX EXPENSE (BENEFIT)
|
|||||||||||||||||
SDG&E
|
$
|
54
|
$
|
69
|
$
|
142
|
$
|
152
|
|||||||||
SoCalGas
|
16
|
28
|
111
|
66
|
|||||||||||||
Sempra South American Utilities
|
18
|
18
|
34
|
33
|
|||||||||||||
Sempra Mexico
|
5
|
12
|
13
|
24
|
|||||||||||||
Sempra Renewables
|
(11)
|
(13)
|
(28)
|
(19)
|
|||||||||||||
Sempra Natural Gas
|
27
|
3
|
29
|
9
|
|||||||||||||
All other
|
(11)
|
(24)
|
(40)
|
(45)
|
|||||||||||||
Total
|
$
|
98
|
$
|
93
|
$
|
261
|
$
|
220
|
SEGMENT INFORMATION (CONTINUED)
|
|||||||||||||||||
(Dollars in millions)
|
|||||||||||||||||
Three months ended June 30,
|
Six months ended June 30,
|
||||||||||||||||
2015
|
2014
|
2015
|
2014
|
||||||||||||||
EQUITY EARNINGS (LOSSES)
|
|||||||||||||||||
Earnings recorded before tax:
|
|||||||||||||||||
Sempra Renewables
|
$
|
10
|
$
|
9
|
$
|
12
|
$
|
11
|
|||||||||
Sempra Natural Gas
|
17
|
14
|
34
|
29
|
|||||||||||||
Total
|
$
|
27
|
$
|
23
|
$
|
46
|
$
|
40
|
|||||||||
Earnings (losses) recorded net of tax:
|
|||||||||||||||||
Sempra South American Utilities
|
$
|
―
|
$
|
―
|
$
|
(1)
|
$
|
(2)
|
|||||||||
Sempra Mexico
|
22
|
9
|
38
|
17
|
|||||||||||||
Total
|
$
|
22
|
$
|
9
|
$
|
37
|
$
|
15
|
|||||||||
EARNINGS (LOSSES)
|
|||||||||||||||||
SDG&E
|
$
|
126
|
43
|
%
|
$
|
123
|
46
|
%
|
$
|
273
|
37
|
%
|
$
|
222
|
43
|
%
|
|
SoCalGas(2)
|
70
|
24
|
80
|
30
|
284
|
39
|
158
|
31
|
|||||||||
Sempra South American Utilities
|
45
|
15
|
42
|
15
|
86
|
12
|
77
|
15
|
|||||||||
Sempra Mexico
|
50
|
17
|
34
|
13
|
97
|
13
|
76
|
15
|
|||||||||
Sempra Renewables
|
19
|
6
|
18
|
7
|
32
|
4
|
46
|
9
|
|||||||||
Sempra Natural Gas
|
40
|
14
|
4
|
1
|
42
|
6
|
13
|
2
|
|||||||||
All other
|
(55)
|
(19)
|
(32)
|
(12)
|
(82)
|
(11)
|
(76)
|
(15)
|
|||||||||
Total
|
$
|
295
|
100
|
%
|
$
|
269
|
100
|
%
|
$
|
732
|
100
|
%
|
$
|
516
|
100
|
%
|
|
Six months ended June 30,
|
|||||||||||||||||
2015
|
2014
|
||||||||||||||||
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
|
|||||||||||||||||
SDG&E
|
$
|
600
|
41
|
%
|
$
|
543
|
36
|
%
|
|||||||||
SoCalGas
|
603
|
41
|
500
|
33
|
|||||||||||||
Sempra South American Utilities
|
66
|
5
|
89
|
6
|
|||||||||||||
Sempra Mexico
|
120
|
8
|
189
|
13
|
|||||||||||||
Sempra Renewables
|
22
|
1
|
122
|
8
|
|||||||||||||
Sempra Natural Gas
|
28
|
2
|
67
|
4
|
|||||||||||||
All other
|
27
|
2
|
3
|
―
|
|||||||||||||
Total
|
$
|
1,466
|
100
|
%
|
$
|
1,513
|
100
|
%
|
|||||||||
June 30, 2015
|
December 31, 2014
|
||||||||||||||||
ASSETS
|
|||||||||||||||||
SDG&E
|
$
|
16,633
|
42
|
%
|
$
|
16,296
|
41
|
%
|
|||||||||
SoCalGas
|
11,209
|
28
|
10,461
|
26
|
|||||||||||||
Sempra South American Utilities
|
3,312
|
8
|
3,379
|
9
|
|||||||||||||
Sempra Mexico
|
3,568
|
9
|
3,488
|
9
|
|||||||||||||
Sempra Renewables
|
1,312
|
3
|
1,338
|
3
|
|||||||||||||
Sempra Natural Gas
|
5,535
|
14
|
6,436
|
16
|
|||||||||||||
All other
|
893
|
2
|
895
|
2
|
|||||||||||||
Intersegment receivables
|
(2,456)
|
(6)
|
(2,561)
|
(6)
|
|||||||||||||
Total
|
$
|
40,006
|
100
|
%
|
$
|
39,732
|
100
|
%
|
|||||||||
INVESTMENTS IN EQUITY METHOD INVESTEES
|
|||||||||||||||||
Sempra South American Utilities
|
$
|
(9)
|
$
|
(8)
|
|||||||||||||
Sempra Mexico
|
474
|
434
|
|||||||||||||||
Sempra Renewables
|
868
|
911
|
|||||||||||||||
Sempra Natural Gas
|
1,510
|
1,347
|
|||||||||||||||
All other
|
86
|
164
|
|||||||||||||||
Total
|
$
|
2,929
|
$
|
2,848
|
|||||||||||||
(1)
|
Revenues for reportable segments include intersegment revenues of $3 million, $17 million, $24 million and $46 million for the three months ended June 30, 2015; $5 million, $36 million, $49 million and $89 million for the six months ended June 30, 2015; $2 million, $16 million, $23 million and $80 million for the three months ended June 30, 2014; and $5 million, $34 million, $45 million and $159 million for the six months ended June 30, 2014 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.
|
||||||||||||||||
(2)
|
After preferred dividends.
|
§
|
Sempra Energy and its consolidated entities
|
§
|
SDG&E
|
§
|
SoCalGas
|
CALIFORNIA UTILITIES
|
||
MARKET
|
SERVICE TERRITORY
|
|
SAN DIEGO GAS & ELECTRIC COMPANY (SDG&E)
A regulated public utility; infrastructure supports electric generation, transmission and distribution, and natural gas distribution
|
§ Provides electricity to a population of 3.5 million (1.4 million meters)
§ Provides natural gas to a population of 3.2 million (0.9 million meters)
|
Serves the county of San Diego, California and an adjacent portion of southern Orange County covering 4,100 square miles
|
SOUTHERN CALIFORNIA GAS COMPANY (SOCALGAS)
A regulated public utility; infrastructure supports natural gas distribution, transmission and storage
|
§ Residential, commercial, industrial, utility electric generation and wholesale customers
§ Covers a population of 21.4 million (5.9 million meters)
|
Southern California and portions of central California (excluding San Diego County, the city of Long Beach and the desert area of San Bernardino County) covering 20,000 square miles
|
SEMPRA INTERNATIONAL
|
||
MARKET
|
GEOGRAPHIC REGION
|
|
SEMPRA SOUTH AMERICAN UTILITIES
Infrastructure supports electric transmission and distribution
|
§ Provides electricity to approximately 2.4 million consumers (approximately 657,000 meters) in Chile and approximately 4.8 million consumers (approximately 1,029,000 meters) in Peru
|
§ Chile
§ Peru
|
SEMPRA MEXICO
Develops, owns and operates, or holds interests in:
§ natural gas transmission pipelines and propane and ethane systems
§ a natural gas distribution utility
§ electric generation facilities, including wind
§ a terminal for the import of liquefied natural gas (LNG)
§ marketing operations for the purchase of LNG and the purchase and sale of natural gas
|
§ Natural gas
§ Wholesale electricity
§ Liquefied natural gas
|
§ Mexico
|
SEMPRA U.S. GAS & POWER
|
||
MARKET
|
GEOGRAPHIC REGION
|
|
SEMPRA RENEWABLES
Develops, owns, operates, or holds interests in renewable energy generation projects
|
§ Wholesale electricity
|
§ U.S.A.
|
SEMPRA NATURAL GAS
Develops, owns and operates, or holds interests in:
§ natural gas pipelines and storage facilities
§ natural gas distribution utilities
§ a terminal in the U.S. for the import and export of LNG and sale of natural gas
§ marketing operations
|
§ Natural gas
§ Liquefied natural gas
§ Wholesale electricity
|
§ U.S.A.
|
§
|
Overall results of our operations and factors affecting those results
|
§
|
Our segment results
|
§
|
Significant changes in revenues, costs and earnings between periods
|
§
|
$(48) million lower earnings due to SoCalGas recognizing annual core gas authorized revenue during interim periods based on seasonal factors starting in 2015 due to the adoption of a Triennial Cost Allocation Proceeding (TCAP) decision. Prior to 2015, SoCalGas recognized such revenue ratably over the year. While this “seasonalization” impacts quarterly and quarterly year-to-date comparisons of operating revenues and earnings for both Sempra Energy and SoCalGas, it will not impact full-year results. We discuss the TCAP decision further in Note 10 of the Notes to Condensed Consolidated Financial Statements herein
|
§
|
$13 million of earnings from a California Public Utilities Commission (CPUC)-approved retroactive increase in authorized general rate case (GRC) revenue requirement for years 2012 through 2014 and the first quarter of 2015 due to increased rate base
|
§
|
$6 million higher CPUC base operating margin authorized for 2015
|
§
|
$6 million write-off in 2014 of certain costs incurred that were disallowed for recovery in the final Pipeline Safety Enhancement Plan (PSEP) decision
|
§
|
$6 million from the favorable resolution of a legal settlement in 2015
|
§
|
$17 million higher pipeline earnings, primarily due to the start of operations of the Los Ramones I pipeline and a section of the Sonora pipeline in the fourth quarter of 2014
|
§
|
$(5) million increase in earnings attributable to noncontrolling interests at Infraestructura Energética Nova, S.A.B. de C.V (IEnova)
|
§
|
$36 million gain on the April 2015 sale of the remaining 625-megawatt (MW) block of the Mesquite Power plant
|
§
|
$(1) million investment loss in 2015 compared to $(10) million investment gain in 2014 on dedicated assets in support of our executive retirement and deferred compensation plans, net of the decrease in deferred compensation liability associated with the investments
|
§
|
$33 million higher earnings from CPUC base operations and from electric transmission
|
§
|
$13 million reduction to the loss from plant closure in 2015 based on CPUC approval of a compliance filing related to SDG&E’s authorized recovery of its investment in San Onofre Nuclear Generating Station (SONGS) compared to a $9 million increase to the loss in 2014 as a result of reaching a preliminary settlement agreement on the closure, as we discuss in Note 9 of the Notes to Condensed Consolidated Financial Statements herein
|
§
|
$65 million incremental earnings due to SoCalGas recognizing annual core gas authorized revenue during interim periods based on seasonal factors starting in 2015 due to the adoption of a TCAP decision
|
§
|
$16 million higher earnings from CPUC base operating margin authorized for 2015
|
§
|
$11 million of earnings from a CPUC-approved retroactive increase in authorized GRC revenue requirement for years 2012 through 2014 due to increased rate base
|
§
|
$8 million from the gas cost incentive mechanism (GCIM) award approved by the CPUC in February 2015
|
§
|
$10 million higher earnings from operations mainly in Peru due to an increase in rates and volumes
|
§
|
$31 million higher pipeline earnings, primarily due to the start of operations of the Los Ramones I pipeline and a section of the Sonora pipeline in the fourth quarter of 2014
|
§
|
$(6) million increase in earnings attributable to noncontrolling interests at IEnova
|
§
|
$(16) million gain in 2014 from the sale of a 50-percent equity interest in Copper Mountain Solar 3
|
§
|
$36 million gain on the April 2015 sale of the remaining 625-MW block of the Mesquite Power plant
|
SEMPRA ENERGY EARNINGS (LOSSES) BY SEGMENT
|
|||||||||||||||||
(Dollars in millions)
|
|||||||||||||||||
Three months ended June 30,
|
Six months ended June 30,
|
||||||||||||||||
2015
|
2014
|
2015
|
2014
|
||||||||||||||
California Utilities:
|
|||||||||||||||||
SDG&E
|
$
|
126
|
43
|
%
|
$
|
123
|
46
|
%
|
$
|
273
|
37
|
%
|
$
|
222
|
43
|
%
|
|
SoCalGas(1)
|
70
|
24
|
80
|
30
|
284
|
39
|
158
|
31
|
|||||||||
Sempra International:
|
|||||||||||||||||
Sempra South American Utilities
|
45
|
15
|
42
|
15
|
86
|
12
|
77
|
15
|
|||||||||
Sempra Mexico
|
50
|
17
|
34
|
13
|
97
|
13
|
76
|
15
|
|||||||||
Sempra U.S. Gas & Power:
|
|||||||||||||||||
Sempra Renewables
|
19
|
6
|
18
|
7
|
32
|
4
|
46
|
9
|
|||||||||
Sempra Natural Gas
|
40
|
14
|
4
|
1
|
42
|
6
|
13
|
2
|
|||||||||
Parent and other(2)
|
(55)
|
(19)
|
(32)
|
(12)
|
(82)
|
(11)
|
(76)
|
(15)
|
|||||||||
Earnings
|
$
|
295
|
100
|
%
|
$
|
269
|
100
|
%
|
$
|
732
|
100
|
%
|
$
|
516
|
100
|
%
|
|
(1)
|
After preferred dividends.
|
||||||||||||||||
(2)
|
Includes after-tax interest expense ($39 million and $34 million for the three months ended June 30, 2015 and 2014, respectively, and $77 million and $69 million for the six months ended June 30, 2015 and 2014, respectively), intercompany eliminations recorded in consolidation and certain corporate costs.
|
EARNINGS BY SEGMENT – CALIFORNIA UTILITIES
|
(Dollars in millions)
|
§
|
$126 million in the three months ended June 30, 2015
|
§
|
$123 million in the three months ended June 30, 2014
|
§
|
$273 million for the first six months of 2015
|
§
|
$222 million for the first six months of 2014
|
§
|
$10 million favorable resolution of prior years’ income tax items;
|
§
|
$8 million higher CPUC base operating margin authorized for 2015, net of higher non-refundable operating costs; and
|
§
|
$7 million higher earnings from electric transmission operations primarily due to higher rate base; offset by
|
§
|
$8 million higher earnings in 2014 associated with SDG&E’s annual Federal Energy Regulatory Commission (FERC) formulaic rate adjustment;
|
§
|
$4 million favorable settlement in 2014 associated with a long-term service agreement (LTSA);
|
§
|
$2 million higher generation major maintenance costs; and
|
§
|
$2 million higher litigation expenses.
|
§
|
$13 million reduction to the loss from plant closure in 2015 based on the CPUC approval of a compliance filing related to SDG&E’s authorized recovery of its investment in SONGS compared to a $9 million increase to the loss in 2014 as a result of reaching a preliminary settlement agreement on the closure;
|
§
|
$21 million higher CPUC base operating margin authorized for 2015, and lower non-refundable operating costs;
|
§
|
$12 million higher earnings from electric transmission operations primarily due to higher rate base; and
|
§
|
$10 million favorable resolution of prior years’ income tax items; offset by
|
§
|
$7 million higher earnings in 2014 associated with SDG&E’s FERC formulaic rate adjustment; and
|
§
|
$3 million favorable settlement in 2014 associated with an LTSA.
|
§
|
$70 million in the three months ended June 30, 2015 ($71 million before preferred dividends)
|
§
|
$80 million in the three months ended June 30, 2014 ($81 million before preferred dividends)
|
§
|
$284 million for the first six months of 2015 ($285 million before preferred dividends)
|
§
|
$158 million for the first six months of 2014 ($159 million before preferred dividends)
|
§
|
$48 million lower earnings resulting from the seasonalization of interim period recognition of annual core gas authorized revenue starting in 2015 (after-tax impact is based on SoCalGas’ effective tax rate); offset by
|
§
|
$13 million of earnings from a CPUC-approved retroactive increase in authorized GRC revenue requirement for years 2012 through 2014 and the first quarter of 2015 due to increased rate base, as we discuss in Note 10 of the Notes to Condensed Consolidated Financial Statements herein;
|
§
|
$7 million due primarily to a lower effective tax rate, as we discuss under “Income Taxes” below, including $3 million favorable resolution of prior years’ income tax items in 2015;
|
§
|
$6 million higher CPUC base operating margin authorized for 2015, and lower non-refundable operating costs;
|
§
|
$6 million write-off in 2014 of certain costs incurred that were disallowed for recovery in the final PSEP decision, as we discuss in Note 10 of the Notes to Condensed Consolidated Financial Statements herein;
|
§
|
$6 million from the favorable resolution of a legal settlement in 2015, including $2 million of related interest income; and
|
§
|
$4 million increase in allowance for funds used during construction (AFUDC) related to equity.
|
§
|
$65 million incremental earnings resulting from the seasonalization of interim period recognition of annual core gas authorized revenue starting in 2015 (after-tax impact is based on SoCalGas’ effective tax rate);
|
§
|
$16 million higher CPUC base operating margin authorized for 2015, and lower non-refundable operating costs;
|
§
|
$11 million of earnings from a CPUC-approved retroactive increase in authorized GRC revenue requirement for years 2012 through 2014 due to increased rate base;
|
§
|
$11 million due primarily to a lower effective tax rate, as we discuss under “Income Taxes” below, including $3 million favorable resolution of prior years’ income tax items in 2015;
|
§
|
$8 million from the GCIM award approved by the CPUC in February 2015;
|
§
|
$8 million increase in AFUDC related to equity;
|
§
|
$6 million write-off in 2014 of certain costs incurred that were disallowed for recovery in the final PSEP decision; and
|
§
|
$6 million from the favorable resolution of a legal settlement in 2015, including $2 million of related interest income.
|
EARNINGS BY SEGMENT – SEMPRA INTERNATIONAL
|
(Dollars in millions)
|
§
|
$45 million in the three months ended June 30, 2015
|
§
|
$42 million in the three months ended June 30, 2014
|
§
|
$86 million for the first six months of 2015
|
§
|
$77 million for the first six months of 2014
|
§
|
$6 million higher earnings from operations mainly in Peru due to an increase in rates and volumes; offset by
|
§
|
$5 million lower earnings from foreign currency effects.
|
§
|
$10 million higher earnings from operations mainly in Peru due to an increase in rates and volumes; and
|
§
|
$4 million lower interest expense mainly in Chile related to inflationary effect on local bonds; offset by
|
§
|
$9 million lower earnings from foreign currency effects.
|
§
|
$50 million in the three months ended June 30, 2015
|
§
|
$34 million in the three months ended June 30, 2014
|
§
|
$97 million for the first six months of 2015
|
§
|
$76 million for the first six months of 2014
|
§
|
$17 million higher pipeline earnings, primarily due to the start of operations of the Los Ramones I pipeline and a section of the Sonora pipeline in the fourth quarter of 2014; and
|
§
|
$6 million income tax variance primarily due to the effects from foreign currency and inflation; offset by
|
§
|
$5 million increase in earnings attributable to noncontrolling interests at IEnova; and
|
§
|
$3 million unfavorable translation effect primarily on Peso-denominated receivables.
|
§
|
$31 million higher pipeline earnings, primarily due to the start of operations of the Los Ramones I pipeline and a section of the Sonora pipeline in the fourth quarter of 2014; and
|
§
|
$9 million income tax variance primarily due to the effects from foreign currency and inflation; offset by
|
§
|
$6 million increase in earnings attributable to noncontrolling interests at IEnova;
|
§
|
$5 million lower earnings from LNG marketing operations;
|
§
|
$5 million unfavorable translation effect primarily on Peso-denominated receivables; and
|
§
|
$4 million lower earnings from operations at our Mexicali power plant from lower prices and volumes in 2015.
|
EARNINGS BY SEGMENT – SEMPRA U.S. GAS & POWER
|
(Dollars in millions)
|
§
|
$19 million in the three months ended June 30, 2015
|
§
|
$18 million in the three months ended June 30, 2014
|
§
|
$32 million for the first six months of 2015
|
§
|
$46 million for the first six months of 2014
|
§
|
$40 million in the three months ended June 30, 2015
|
§
|
$4 million in the three months ended June 30, 2014
|
§
|
$42 million for the first six months of 2015
|
§
|
$13 million for the first six months of 2014
|
§
|
$36 million gain on the April 2015 sale of the remaining 625-MW block of the Mesquite Power plant, net of related expenses;
|
§
|
$5 million higher earnings from mark-to-market gains on commodity contracts and lower costs from the Mesquite Power plant due to the sale of the remaining block in April 2015; and
|
§
|
$3 million improved results from midstream activities; offset by
|
§
|
$14 million lower results from LNG marketing operations, including the effect of lower gas prices.
|
§
|
$36 million gain on the April 2015 sale of the remaining 625-MW block of the Mesquite Power plant, net of related expenses;
|
§
|
$6 million higher earnings from the power sales contract associated with the Mesquite Power plant and lower costs at the plant due to the sale of the remaining block in April 2015; and
|
§
|
$5 million improved results from midstream activities; offset by
|
§
|
$20 million lower results from LNG marketing operations, including the effect of lower gas prices; and
|
§
|
$5 million in development expense associated with the potential expansion of our LNG business.
|
§
|
$55 million in the three months ended June 30, 2015
|
§
|
$32 million in the three months ended June 30, 2014
|
§
|
$82 million for the first six months of 2015
|
§
|
$76 million for the first six months of 2014
|
§
|
$1 million investment loss in 2015 compared to $10 million investment gain in 2014 on dedicated assets in support of our executive retirement and deferred compensation plans, net of the decrease in deferred compensation liability associated with the investments; and
|
§
|
$7 million lower income tax benefits, including $6 million of income tax expense associated with the resolution of prior years’ income tax items in 2015.
|
§
|
$8 million lower investment gains on dedicated assets in support of our executive retirement and deferred compensation plans, net of the decrease in deferred compensation liability associated with the investments; offset by
|
§
|
$4 million higher income tax benefits, including
|
□
|
$5 million in net state income tax refunds related to our former commodities-marketing businesses, offset by
|
□
|
$6 million of income tax expense associated with the resolution of prior years’ income tax items in 2015.
|
§
|
SDG&E
|
§
|
SoCalGas
|
§
|
Sempra Mexico’s Ecogas México, S. de R.L. de C.V. (Ecogas)
|
§
|
Sempra Natural Gas’ Mobile Gas Service Corporation (Mobile Gas) and Willmut Gas Company (Willmut Gas)
|
§
|
SDG&E
|
§
|
Sempra South American Utilities’ Chilquinta Energía S.A. (Chilquinta Energía) and Luz del Sur S.A.A. (Luz del Sur)
|
UTILITIES REVENUES AND COST OF SALES
|
|||||||||
(Dollars in millions)
|
|||||||||
Three months ended June 30,
|
Six months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
||||||
Electric revenues:
|
|||||||||
SDG&E
|
$
|
874
|
$
|
948
|
$
|
1,679
|
$
|
1,759
|
|
Sempra South American Utilities
|
363
|
364
|
726
|
718
|
|||||
Eliminations and adjustments
|
(2)
|
(3)
|
(4)
|
(5)
|
|||||
Total
|
1,235
|
1,309
|
2,401
|
2,472
|
|||||
Natural gas revenues:
|
|||||||||
SoCalGas
|
780
|
917
|
1,828
|
2,002
|
|||||
SDG&E
|
98
|
115
|
259
|
291
|
|||||
Sempra Mexico
|
19
|
26
|
44
|
59
|
|||||
Sempra Natural Gas
|
18
|
20
|
60
|
67
|
|||||
Eliminations and adjustments
|
(17)
|
(17)
|
(37)
|
(36)
|
|||||
Total
|
898
|
1,061
|
2,154
|
2,383
|
|||||
Total utilities revenues
|
$
|
2,133
|
$
|
2,370
|
$
|
4,555
|
$
|
4,855
|
|
Cost of electric fuel and purchased power:
|
|||||||||
SDG&E
|
$
|
251
|
$
|
329
|
$
|
479
|
$
|
595
|
|
Sempra South American Utilities
|
247
|
242
|
500
|
486
|
|||||
Total
|
$
|
498
|
$
|
571
|
$
|
979
|
$
|
1,081
|
|
Cost of natural gas:
|
|||||||||
SoCalGas
|
$
|
196
|
$
|
321
|
$
|
463
|
$
|
829
|
|
SDG&E
|
31
|
51
|
85
|
126
|
|||||
Sempra Mexico
|
11
|
18
|
26
|
40
|
|||||
Sempra Natural Gas
|
5
|
7
|
20
|
27
|
|||||
Eliminations and adjustments
|
(4)
|
(2)
|
(9)
|
(7)
|
|||||
Total
|
$
|
239
|
$
|
395
|
$
|
585
|
$
|
1,015
|
§
|
$74 million decrease at SDG&E, which included
|
□
|
$78 million lower cost of electric fuel and purchased power, which we discuss below, and
|
□
|
$14 million lower recovery of costs associated with CPUC-authorized refundable programs, which revenues are fully offset in operation and maintenance expenses, offset by
|
□
|
$22 million higher revenues from CPUC-authorized 2015 attrition and, starting in 2015, authorized revenues for the recovery of the SONGS regulatory assets pursuant to an amended settlement agreement approved by the CPUC in 2014. The GRC decision for years 2012 through 2015 established a revenue attrition mechanism for the escalation of adopted revenue requirements based on fixed annual factors, and
|
□
|
$4 million higher authorized revenues from electric transmission
|
§
|
$78 million decrease at SDG&E, which we discuss below; offset by
|
§
|
$5 million increase at Sempra South American Utilities driven primarily by higher rates and volumes at both Luz del Sur and Chilquinta Energía, offset by foreign currency exchange rate effects.
|
§
|
$80 million decrease at SDG&E, which included
|
□
|
$116 million lower cost of electric fuel and purchased power, which we discuss below, and
|
□
|
$15 million lower recovery of costs associated with CPUC-authorized refundable programs, which revenues are fully offset in operation and maintenance expenses, offset by
|
□
|
$43 million higher revenues from CPUC-authorized 2015 attrition and, starting in 2015, authorized revenues for the recovery of the SONGS regulatory assets pursuant to an amended settlement agreement approved by the CPUC in 2014, and
|
□
|
$17 million higher authorized revenues from electric transmission, offset by
|
§
|
$8 million increase at Sempra South American Utilities, primarily due to higher rates and volumes at both Luz del Sur and Chilquinta Energía, offset by foreign currency exchange rate effects.
|
§
|
$116 million decrease at SDG&E, which we discuss below; offset by
|
§
|
$14 million increase at Sempra South American Utilities driven primarily by higher rates and volumes at both Luz del Sur and Chilquinta Energía, offset by foreign currency exchange rate effects.
|
§
|
decreases in cost of natural gas sold at SoCalGas and SDG&E, as we discuss below; and
|
§
|
$72 million decrease resulting from the seasonalization of interim period recognition of annual core gas authorized revenue at SoCalGas starting in 2015; offset by
|
§
|
$21 million higher revenues from CPUC-authorized 2015 attrition at the California Utilities;
|
§
|
$21 million increase at SoCalGas from a CPUC-approved retroactive increase in authorized GRC revenue requirement for years 2012 through 2014 and the first quarter of 2015 due to increased rate base; and
|
§
|
$18 million higher recovery of costs at SoCalGas associated with CPUC-authorized refundable programs, which revenues are fully offset in operation and maintenance expenses.
|
§
|
decreases in cost of natural gas sold at SoCalGas and SDG&E, as we discuss below; offset by
|
§
|
$91 million increase resulting from the seasonalization of interim period recognition of annual core gas authorized revenue at SoCalGas starting in 2015;
|
§
|
$36 million higher revenues from CPUC-authorized 2015 attrition at the California Utilities;
|
§
|
$31 million higher recovery of costs at SoCalGas associated with CPUC-authorized refundable programs, which revenues are fully offset in operation and maintenance expenses;
|
§
|
$19 million increase at SoCalGas from a CPUC-approved retroactive increase in authorized GRC revenue requirement for years 2012 through 2014 due to increased rate base; and
|
§
|
$14 million GCIM award approved by the CPUC in February 2015 at SoCalGas.
|
SDG&E
|
|||||||
ELECTRIC DISTRIBUTION AND TRANSMISSION
|
|||||||
(Volumes in millions of kilowatt-hours, dollars in millions)
|
|||||||
Six months ended
June 30, 2015
|
Six months ended
June 30, 2014
|
||||||
Customer class
|
Volumes
|
Revenue
|
Volumes
|
Revenue
|
|||
Residential
|
3,227
|
$
|
610
|
3,383
|
$
|
581
|
|
Commercial
|
3,223
|
656
|
3,311
|
606
|
|||
Industrial
|
985
|
162
|
986
|
147
|
|||
Direct access(1)
|
1,696
|
106
|
1,704
|
88
|
|||
Street and highway lighting
|
41
|
8
|
44
|
7
|
|||
9,172
|
1,542
|
9,428
|
1,429
|
||||
CAISO shared transmission revenue - net(2)
|
126
|
115
|
|||||
Other revenues
|
101
|
81
|
|||||
Balancing accounts
|
(90)
|
134
|
|||||
Total(3)
|
$
|
1,679
|
$
|
1,759
|
|||
(1)
|
The Direct Access (DA) program, which offered all customers the option to purchase their electric commodity services from a third-party Energy Service Provider instead of continuing to receive these services from SDG&E, was implemented in 1998 and suspended in 2001. In 2009, Senate Bill 695 required the CPUC to develop a process and rules for a limited re-opening of DA to be phased in over a period of time. In 2010, the CPUC adopted the process and rules for the limited re-opening of DA for non-residential customers under a 4-year phase-in schedule.
|
||||||
(2)
|
California Independent System Operator (CAISO).
|
||||||
(3)
|
Includes sales to affiliates of $4 million in 2015 and $5 million in 2014.
|
§
|
$78 million decrease in cost of electric fuel and purchased power, including:
|
□
|
a decrease in the cost of purchased power due to declining natural gas prices, and
|
□
|
lower demand mainly due to cooler weather, and, to a lesser extent, an increase in rooftop solar use, in the second quarter of 2015 compared to the same period in 2014, offset by
|
□
|
an increase from the incremental purchase of renewable energy at higher prices; and
|
§
|
$14 million lower recovery of costs associated with CPUC-authorized refundable programs, which revenues are fully offset in operation and maintenance expenses; offset by
|
§
|
$22 million higher revenues from CPUC-authorized 2015 attrition and, starting in 2015, authorized revenues for the recovery of the SONGS regulatory assets pursuant to an amended settlement agreement approved by the CPUC in 2014; and
|
§
|
$4 million higher authorized revenues from electric transmission.
|
§
|
$116 million decrease in cost of electric fuel and purchased power, including:
|
□
|
a decrease in the cost of purchased power due to declining natural gas prices, and
|
□
|
lower demand mainly due to cooler weather, and, to a lesser extent, an increase in rooftop solar use, in 2015 compared to the same period in 2014, offset by
|
□
|
an increase from the incremental purchase of renewable energy at higher prices; and
|
§
|
$15 million lower recovery of costs associated with CPUC-authorized refundable programs, which revenues are fully offset in operation and maintenance expenses; offset by
|
§
|
$43 million higher revenues from CPUC-authorized 2015 attrition and, starting in 2015, authorized revenues for the recovery of the SONGS regulatory assets pursuant to an amended settlement agreement approved by the CPUC in 2014; and
|
§
|
$17 million higher authorized revenues from electric transmission.
|
SDG&E
|
||||||||||
NATURAL GAS SALES AND TRANSPORTATION
|
||||||||||
(Volumes in billion cubic feet, dollars in millions)
|
||||||||||
Natural gas sales
|
Transportation
|
Total
|
||||||||
Customer class
|
Volumes
|
Revenue
|
Volumes
|
Revenue
|
Volumes
|
Revenue
|
||||
Six months ended June 30, 2015:
|
||||||||||
Residential
|
14
|
$
|
175
|
―
|
$
|
2
|
14
|
$
|
177
|
|
Commercial and industrial
|
8
|
53
|
4
|
7
|
12
|
60
|
||||
Electric generation plants
|
―
|
―
|
11
|
―
|
11
|
―
|
||||
22
|
$
|
228
|
15
|
$
|
9
|
37
|
237
|
|||
Other revenues
|
21
|
|||||||||
Balancing accounts
|
1
|
|||||||||
Total(1)
|
$
|
259
|
||||||||
Six months ended June 30, 2014:
|
||||||||||
Residential
|
15
|
$
|
188
|
―
|
$
|
―
|
15
|
$
|
188
|
|
Commercial and industrial
|
8
|
61
|
4
|
6
|
12
|
67
|
||||
Electric generation plants
|
―
|
―
|
13
|
1
|
13
|
1
|
||||
23
|
$
|
249
|
17
|
$
|
7
|
40
|
256
|
|||
Other revenues
|
22
|
|||||||||
Balancing accounts
|
13
|
|||||||||
Total(1)
|
$
|
291
|
||||||||
(1)
|
Includes sales to affiliates of $1 million in each of 2015 and 2014.
|
§
|
lower cost of natural gas sold, as we discuss below; offset by
|
§
|
$4 million increase in revenues from CPUC-authorized 2015 attrition.
|
§
|
lower cost of natural gas sold, and lower demand, as we discuss below; offset by
|
§
|
$5 million increase in revenues from CPUC-authorized 2015 attrition; and
|
§
|
$5 million higher recovery of costs associated with CPUC-authorized refundable programs, which revenues are fully offset in operation and maintenance expenses.
|
SOCALGAS
|
||||||||||
NATURAL GAS SALES AND TRANSPORTATION
|
||||||||||
(Volumes in billion cubic feet, dollars in millions)
|
||||||||||
Natural gas sales
|
Transportation
|
Total
|
||||||||
Customer class
|
Volumes
|
Revenue
|
Volumes
|
Revenue
|
Volumes
|
Revenue
|
||||
Six months ended June 30, 2015:
|
||||||||||
Residential
|
102
|
$
|
1,036
|
2
|
$
|
10
|
104
|
$
|
1,046
|
|
Commercial and industrial
|
48
|
324
|
141
|
126
|
189
|
450
|
||||
Electric generation plants
|
―
|
―
|
69
|
16
|
69
|
16
|
||||
Wholesale
|
―
|
―
|
73
|
13
|
73
|
13
|
||||
150
|
$
|
1,360
|
285
|
$
|
165
|
435
|
1,525
|
|||
Other revenues
|
90
|
|||||||||
Balancing accounts
|
213
|
|||||||||
Total(1)
|
$
|
1,828
|
||||||||
Six months ended June 30, 2014:
|
||||||||||
Residential
|
109
|
$
|
1,189
|
1
|
$
|
6
|
110
|
$
|
1,195
|
|
Commercial and industrial
|
48
|
411
|
145
|
132
|
193
|
543
|
||||
Electric generation plants
|
―
|
―
|
85
|
20
|
85
|
20
|
||||
Wholesale
|
―
|
―
|
72
|
13
|
72
|
13
|
||||
157
|
$
|
1,600
|
303
|
$
|
171
|
460
|
1,771
|
|||
Other revenues
|
49
|
|||||||||
Balancing accounts
|
182
|
|||||||||
Total(1)
|
$
|
2,002
|
||||||||
(1)
|
Includes sales to affiliates of $36 million in 2015 and $34 million in 2014.
|
§
|
the decrease in the cost of natural gas sold, offset by higher sales volumes, as we discuss below; and
|
§
|
$72 million decrease resulting from the seasonalization of interim period recognition of annual core gas authorized revenue starting in 2015; offset by
|
§
|
$21 million increase from a CPUC-approved retroactive increase in authorized GRC revenue requirement for years 2012 through 2014 and the first quarter of 2015 due to increased rate base;
|
§
|
$18 million higher recovery of costs associated with CPUC-authorized refundable programs, which revenues are fully offset in operation and maintenance expenses;
|
§
|
$17 million increase in revenues from CPUC-authorized 2015 attrition; and
|
§
|
$9 million write-off in 2014 of certain costs incurred that were disallowed for recovery in the final PSEP decision.
|
§
|
the decrease in the cost of natural gas sold, as we discuss below; offset by
|
§
|
$91 million increase resulting from the seasonalization of interim period recognition of annual core gas authorized revenue starting in 2015;
|
§
|
$31 million higher recovery of costs associated with CPUC-authorized refundable programs, which revenues are fully offset in operation and maintenance expenses;
|
§
|
$31 million higher revenues from CPUC-authorized 2015 attrition;
|
§
|
$19 million increase from a CPUC-approved retroactive increase in authorized GRC revenue requirement for years 2012 through 2014 due to increased rate base;
|
§
|
$14 million GCIM award approved by the CPUC in February 2015; and
|
§
|
$9 million write-off in 2014 of certain costs incurred that were disallowed for recovery in the final PSEP decision.
|
OTHER UTILITIES
|
|||||||
NATURAL GAS AND ELECTRIC REVENUES
|
|||||||
(Dollars in millions)
|
|||||||
Six months ended
June 30, 2015
|
Six months ended
June 30, 2014
|
||||||
Volumes
|
Revenue
|
Volumes
|
Revenue
|
||||
Natural Gas Sales (billion cubic feet):
|
|||||||
Sempra Mexico – Ecogas
|
13
|
$
|
44
|
11
|
$
|
59
|
|
Sempra Natural Gas:
|
|||||||
Mobile Gas (including transportation)
|
24
|
49
|
20
|
52
|
|||
Willmut Gas
|
2
|
11
|
2
|
15
|
|||
Total
|
39
|
$
|
104
|
33
|
$
|
126
|
|
Electric Sales (million kilowatt hours):
|
|||||||
Sempra South American Utilities:
|
|||||||
Luz del Sur
|
3,841
|
$
|
440
|
3,668
|
$
|
428
|
|
Chilquinta Energía
|
1,496
|
266
|
1,496
|
265
|
|||
5,337
|
706
|
5,164
|
693
|
||||
Other service revenues
|
20
|
25
|
|||||
Total
|
$
|
726
|
$
|
718
|
ENERGY-RELATED BUSINESSES: REVENUES AND COST OF SALES
|
|||||||||
(Dollars in millions)
|
|||||||||
Three months ended June 30,
|
Six months ended June 30,
|
||||||||
2015
|
2014
|
2015
|
2014
|
||||||
Energy-related businesses revenues:
|
|||||||||
Sempra South American Utilities
|
$
|
26
|
$
|
26
|
$
|
52
|
$
|
50
|
|
Sempra Mexico
|
133
|
160
|
271
|
328
|
|||||
Sempra Renewables
|
10
|
9
|
18
|
15
|
|||||
Sempra Natural Gas
|
137
|
216
|
292
|
429
|
|||||
Intersegment revenues, adjustments
|
|||||||||
and eliminations(1)
|
(72)
|
(103)
|
(139)
|
(204)
|
|||||
Total energy-related businesses revenues
|
$
|
234
|
$
|
308
|
$
|
494
|
$
|
618
|
|
Cost of natural gas, electric fuel
|
|||||||||
and purchased power(2):
|
|||||||||
Sempra South American Utilities
|
$
|
7
|
$
|
4
|
$
|
16
|
$
|
7
|
|
Sempra Mexico
|
45
|
81
|
96
|
164
|
|||||
Sempra Natural Gas
|
87
|
143
|
192
|
294
|
|||||
Adjustments and eliminations(1)
|
(66)
|
(102)
|
(133)
|
(201)
|
|||||
Total cost of natural gas, electric fuel
|
|||||||||
and purchased power
|
$
|
73
|
$
|
126
|
$
|
171
|
$
|
264
|
|
Other cost of sales(2):
|
|||||||||
Sempra South American Utilities
|
$
|
18
|
$
|
19
|
$
|
29
|
$
|
33
|
|
Sempra Mexico
|
4
|
2
|
9
|
5
|
|||||
Sempra Natural Gas
|
23
|
23
|
43
|
46
|
|||||
Adjustments and eliminations(1)
|
(3)
|
(2)
|
(4)
|
(4)
|
|||||
Total other cost of sales
|
$
|
42
|
$
|
42
|
$
|
77
|
$
|
80
|
|
(1)
|
Includes eliminations of intercompany activity.
|
||||||||
(2)
|
Excludes depreciation and amortization, which are shown separately on the Condensed Consolidated Statements of Operations.
|
§
|
$79 million decrease at Sempra Natural Gas mainly from lower natural gas prices, as well as from the deconsolidation of Cameron LNG, LLC as of October 1, 2014; and
|
§
|
$27 million lower revenues at Sempra Mexico primarily due to lower natural gas and power prices and volumes, offset by higher transportation revenues from a section of the Sonora natural gas pipeline that commenced operations in the fourth quarter of 2014; offset by
|
§
|
$31 million primarily from lower intercompany eliminations associated with sales between Sempra Natural Gas and Sempra Mexico.
|
§
|
$56 million decrease at Sempra Natural Gas primarily due to lower natural gas costs; and
|
§
|
$36 million decrease at Sempra Mexico primarily due to lower natural gas costs and volumes; offset by
|
§
|
$36 million primarily from lower intercompany eliminations of costs associated with sales between Sempra Natural Gas and Sempra Mexico.
|
§
|
$137 million decrease at Sempra Natural Gas mainly from lower natural gas prices, as well as from the deconsolidation of Cameron LNG, LLC as of October 1, 2014; and
|
§
|
$57 million lower revenues at Sempra Mexico primarily due to lower natural gas and power prices and volumes, offset by higher transportation revenues from a section of the Sonora natural gas pipeline that commenced operations in the fourth quarter of 2014; offset by
|
§
|
$65 million primarily from lower intercompany eliminations associated with sales between Sempra Natural Gas and Sempra Mexico.
|
§
|
$102 million decrease at Sempra Natural Gas primarily due to lower natural gas costs; and
|
§
|
$68 million decrease at Sempra Mexico primarily due to lower natural gas costs and volumes; offset by
|
§
|
$68 million from lower intercompany eliminations of costs associated with sales between Sempra Natural Gas and Sempra Mexico.
|
§
|
$13 million lower expenses associated with CPUC-authorized refundable programs, for which all costs incurred are fully recovered in revenue (refundable program expenses); offset by
|
§
|
$5 million higher litigation expense; and
|
§
|
$5 million higher non-refundable operating costs, including labor, contract services and administrative and support costs.
|
§
|
$26 million lower non-refundable operating costs, including $12 million lower major maintenance costs at its electric generating facilities, as well as labor, contract services and administrative and support costs; and
|
§
|
$10 million lower expenses associated with CPUC-authorized refundable programs, for which all costs incurred are fully recovered in revenue (refundable program expenses).
|
§
|
$18 million higher expenses associated with CPUC-authorized refundable programs for which all costs incurred are fully recovered in revenue (refundable program expenses); offset by
|
§
|
$7 million lower non-refundable operating costs, including labor, contract services and administrative and support costs; and
|
§
|
$2 million lower litigation expense, including $6 million from the favorable resolution of a legal settlement in 2015, offset by $4 million higher other litigation expense.
|
§
|
$31 million higher expenses associated with CPUC-authorized refundable programs for which all costs incurred are fully recovered in revenue (refundable program expenses); offset by
|
§
|
$11 million lower non-refundable operating costs, including labor, contract services and administrative and support costs; and
|
§
|
$2 million lower litigation expense, including $6 million from the favorable resolution of a legal settlement in 2015, offset by $4 million higher other litigation expense.
|
§
|
$2 million investment losses in 2015 compared to $15 million gains in 2014 on dedicated assets in support of our executive retirement and deferred compensation plans; and
|
§
|
$3 million losses on interest rate and foreign exchange instruments in 2015 compared to $11 million gains in 2014; offset by
|
§
|
$7 million increase in equity-related AFUDC at the California Utilities; and
|
§
|
$6 million income from the sale of other investments.
|
§
|
$16 million lower investment gains on dedicated assets in support of our executive retirement and deferred compensation plans; and
|
§
|
$3 million losses on interest rate and foreign exchange instruments in 2015 compared to $16 million gains in 2014; offset by
|
§
|
$9 million increase in equity-related AFUDC, primarily at SoCalGas; and
|
§
|
$6 million income from the sale of other investments.
|
INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
|
|||||||||||
(Dollars in millions)
|
|||||||||||
Effective
|
Effective
|
||||||||||
Income tax
|
income
|
Income tax
|
income
|
||||||||
expense
|
tax rate
|
expense
|
tax rate
|
||||||||
Three months ended June 30,
|
|||||||||||
2015
|
2014
|
||||||||||
Sempra Energy Consolidated
|
$
|
98
|
25
|
%
|
$
|
93
|
25
|
%
|
|||
SDG&E
|
54
|
29
|
69
|
35
|
|||||||
SoCalGas
|
16
|
18
|
28
|
26
|
|||||||
Six months ended June 30,
|
|||||||||||
2015
|
2014
|
||||||||||
Sempra Energy Consolidated
|
$
|
261
|
26
|
%
|
$
|
220
|
29
|
%
|
|||
SDG&E
|
142
|
34
|
152
|
40
|
|||||||
SoCalGas
|
111
|
28
|
66
|
29
|
§
|
a $17 million charge in 2014 to reduce certain tax regulatory assets attributed to SDG&E’s investment in SONGS that we discuss in Note 9 of the Notes to Condensed Consolidated Financial Statements herein; and
|
§
|
favorable resolution of prior years’ income tax items in 2015.
|
§
|
a $17 million charge in 2014 to reduce certain tax regulatory assets attributed to SDG&E’s investment in SONGS that we discuss in Note 9 of the Notes to Condensed Consolidated Financial Statements herein; and
|
§
|
favorable resolution of prior years’ income tax items in 2015.
|
§
|
favorable resolution of prior years’ income tax items in 2015;
|
§
|
higher exclusions from taxable income of the equity portion of AFUDC; and
|
§
|
higher favorable impact of deductions for self-developed software expenditures.
|
MEXICAN CURRENCY IMPACT ON INCOME TAXES AND RELATED ECONOMIC HEDGING ACTIVITY
|
||||||||||
(Dollars in millions)
|
||||||||||
Three months ended June 30,
|
Six months ended June 30,
|
|||||||||
2015
|
2014
|
2015
|
2014
|
|||||||
Income tax benefit on currency exchange
|
||||||||||
rate movement of monetary assets and liabilities
|
$
|
4
|
$
|
―
|
$
|
8
|
$
|
―
|
||
Translation of non-U.S. deferred income tax balances
|
2
|
―
|
4
|
―
|
||||||
Income tax expense on inflation
|
―
|
―
|
―
|
(1)
|
||||||
Total impact included in Income Tax Benefit (Expense)
|
6
|
―
|
12
|
(1)
|
||||||
After-tax losses on Mexican peso exchange rate
|
||||||||||
instruments (included in Other Income, Net)
|
(1)
|
―
|
(1)
|
―
|
||||||
Net impacts on Sempra Energy Condensed
|
||||||||||
Consolidated Statements of Operations
|
$
|
5
|
$
|
―
|
$
|
11
|
$
|
(1)
|
AVAILABLE FUNDS AT JUNE 30, 2015
|
|||||||
(Dollars in millions)
|
|||||||
Sempra Energy
|
|||||||
Consolidated
|
SDG&E
|
SoCalGas
|
|||||
Unrestricted cash and cash equivalents(1)
|
$
|
636
|
$
|
23
|
$
|
231
|
|
Available unused credit(2)
|
3,493
|
618
|
658
|
||||
(1)
|
Amounts at Sempra Energy Consolidated include $372 million held in non-U.S. jurisdictions that are unavailable to fund U.S. operations unless repatriated, as we discuss below.
|
||||||
(2)
|
Available credit is the total available on Sempra Energy's, Sempra Global's and the California Utilities' credit facilities that we discuss in Note 6 of the Notes to Condensed Consolidated Financial Statements herein. Borrowings on the shared line of credit at SDG&E and SoCalGas are limited to $658 million for each utility and a combined total of $877 million. SDG&E's available funds reflect commercial paper outstanding of $40 million supported by the line. Some of Sempra Energy's subsidiaries, primarily our foreign operations, have additional general purpose credit facilities, aggregating $848 million at June 30, 2015. Available unused credit on these lines totaled $576 million at June 30, 2015.
|
§
|
finance capital expenditures
|
§
|
meet liquidity requirements
|
§
|
fund shareholder dividends
|
§
|
fund new business acquisitions or start-ups
|
§
|
repay maturing long-term debt
|
CASH PROVIDED BY OPERATING ACTIVITIES
|
||||||||
(Dollars in millions)
|
||||||||
Six months ended
June 30, 2015
|
2015 Change
|
Six months ended
June 30, 2014
|
||||||
Sempra Energy Consolidated
|
$
|
1,219
|
$
|
185
|
18
|
%
|
$
|
1,034
|
SDG&E
|
550
|
142
|
35
|
408
|
||||
SoCalGas
|
483
|
20
|
4
|
463
|
§
|
$300 million higher net income, adjusted for noncash items included in earnings, in 2015 compared to 2014, primarily due to improved operations and lower cost of electric fuel and purchased power at SDG&E, as well as the impact of the seasonalization during interim periods of authorized core customer revenue in 2015 at SoCalGas, as we discuss in “Results of Operations” above. The impact of seasonalization in net income is offset by working capital changes in regulatory balancing accounts;
|
§
|
$37 million net increase in net undercollected regulatory balancing accounts in 2015 at the California Utilities (including long-term amounts included in regulatory assets) compared to a $289 million net increase in 2014. Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized costs. These differences are required to be balanced over time. See further discussion of changes in regulatory balances at both SDG&E and SoCalGas below; and
|
§
|
$124 million decrease in inventories in 2015 compared to a $16 million decrease in 2014, primarily due to higher net withdrawal and lower prices of natural gas at SoCalGas; offset by
|
§
|
$198 million decrease in accounts payable in 2015 compared to a $29 million increase in 2014, primarily due to lower purchase volume and lower average cost of natural gas purchased at SoCalGas;
|
§
|
$112 million increase in greenhouse gas allowances ($79 million at SDG&E and $33 million at SoCalGas);
|
§
|
$41 million increase in the seasonal asset related to temporary LIFO liquidation in 2015 at SoCalGas, primarily due to changes in natural gas inventory value, as we discuss in Note 5 of the Notes to Condensed Consolidated Financial Statements herein; and
|
§
|
$216 million decrease in accounts receivable in 2015 compared to a $260 million decrease in 2014.
|
§
|
$102 million decrease in net undercollected regulatory balancing accounts in 2015 compared to a $152 million increase in 2014 (including long-term amounts included in regulatory assets). The impact of the change in the regulatory balancing accounts on cash provided by operating activities was primarily due to:
|
□
|
$13 million increase in 2015 compared to a $200 million increase in 2014 in the undercollected balance for electric commodity costs and costs at SDG&E's electric generating facilities; and
|
□
|
$31 million decrease in 2015 compared to a $44 million increase in 2014 in the undercollected balance in the electric rate design balancing account; and
|
§
|
$63 million higher net income, adjusted for noncash items included in earnings, in 2015 compared to 2014, primarily due to improved operations and lower cost of electric fuel and purchased power; offset by
|
§
|
$79 million increase in greenhouse gas allowances in 2015;
|
§
|
$60 million increase in income taxes receivable in 2015; and
|
§
|
$19 million decrease in accounts payable to affiliates in 2015.
|
§
|
$144 million higher net income, adjusted for noncash items included in earnings, in 2015 compared to 2014, primarily due to improved operations and the impact of the seasonalization during interim periods of authorized core customer revenue in 2015;
|
§
|
$124 million decrease in inventories in 2015 compared to a $5 million decrease in 2014, primarily due to higher net withdrawal and lower prices of natural gas in 2015; and
|
§
|
$21 million increase in income taxes payable in 2015 compared to a $12 million decrease in 2014; offset by
|
§
|
$224 million decrease in accounts payable in 2015 compared to a $31 million decrease in 2014. The decrease in 2015 was primarily due to lower volumes and average cost of natural gas purchased;
|
§
|
$41 million increase in the seasonal asset related to temporary LIFO liquidation in 2015, primarily due to changes in natural gas inventory value;
|
§
|
$33 million increase in greenhouse gas allowances in 2015; and
|
§
|
$139 million increase in net undercollected regulatory balancing accounts in 2015 (including long-term amounts included in regulatory assets) compared to a $137 million increase in 2014, primarily due to:
|
□
|
$127 million increase in 2015 compared to an $82 million increase in 2014 in the undercollected balance associated with the fixed cost balancing accounts, offset by
|
□
|
$56 million decrease in 2015 compared to a $93 million decrease in 2014 in the overcollected balance associated with public purpose programs.
|
CONTRIBUTIONS TO PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS
|
||||
(Dollars in millions)
|
||||
Six months ended June 30, 2015
|
||||
Other
|
||||
Pension
|
postretirement
|
|||
benefits
|
benefits
|
|||
Sempra Energy Consolidated
|
$
|
17
|
$
|
1
|
SDG&E
|
2
|
―
|
||
SoCalGas
|
1
|
―
|
CASH USED IN INVESTING ACTIVITIES
|
||||||||
(Dollars in millions)
|
||||||||
Six months ended
|
Six months ended
|
|||||||
June 30, 2015
|
2015 Change
|
June 30, 2014
|
||||||
Sempra Energy Consolidated
|
$
|
(1,201)
|
$
|
(420)
|
(26)
|
%
|
$
|
(1,621)
|
SDG&E
|
(606)
|
57
|
10
|
(549)
|
||||
SoCalGas
|
(882)
|
382
|
76
|
(500)
|
§
|
$347 million of net proceeds received from Sempra Natural Gas’ sale of the remaining 625-MW block of its Mesquite Power plant; and
|
§
|
$74 million repayments of advances to unconsolidated affiliates; offset by
|
§
|
in 2014, $66 million, net of $2 million cash sold, of proceeds received from the sale of a 50-percent equity interest in Copper Mountain Solar 3.
|
§
|
$279 million of advances to Sempra Energy; and
|
§
|
$103 million increase in capital expenditures.
|
§
|
$2.4 billion at the California Utilities for capital projects and plant improvements ($1.1 billion at SDG&E and $1.3 billion at SoCalGas)
|
§
|
$1.1 billion at our other subsidiaries for capital projects in Mexico and South America, and development of LNG, natural gas and renewable generation projects
|
§
|
$700 million for improvements to natural gas and electric distribution systems
|
§
|
$400 million for improvements to electric transmission systems
|
§
|
$1.1 billion for improvements to distribution, transmission and storage systems, and for pipeline safety
|
§
|
$210 million for advanced metering infrastructure
|
§
|
$30 million for other natural gas projects
|
§
|
approximately $210 million for capital projects in South America (approximately $160 million and $50 million in Peru and Chile, respectively), primarily related to improvements to electric transmission and distribution systems
|
§
|
approximately $430 million for capital projects in Mexico, net of project financing, including approximately $380 million for the development of the Sonora, Ojinaga, and San Isidro - Samalayuca pipeline projects, all developed solely by Sempra Mexico. These amounts exclude the pending acquisition of our joint venture partner’s 50-percent interest in GdC, as we discuss in Note 13 of the Notes to Condensed Consolidated Financial Statements herein. Also, following the pending acquisition, Sempra Mexico would fund 100 percent of the joint venture’s projects, excluding the Los Ramones Norte pipeline project
|
§
|
approximately $120 million for the development of wind and solar renewable projects, including the Black Oak Getty wind project, Mesquite Solar 2, Mesquite Solar 3 and Copper Mountain Solar 4
|
§
|
approximately $320 million for development of LNG and natural gas transportation projects, including
|
□
|
approximately $160 million equity investment in Rockies Express
|
□
|
approximately $50 million capitalized interest related to our investment in the Cameron LNG JV project, and $60 million for development of the Cameron Interstate Pipeline
|
§
|
approximately $40 million related to the build-to-suit lease for Sempra Energy’s new headquarters
|
CASH FLOWS FROM FINANCING ACTIVITIES
|
|||||||
(Dollars in millions)
|
|||||||
Six months ended
|
Six months ended
|
||||||
June 30, 2015
|
2015 Change
|
June 30, 2014
|
|||||
Sempra Energy Consolidated
|
$
|
50
|
$
|
(422)
|
$
|
472
|
|
SDG&E
|
71
|
(64)
|
135
|
||||
SoCalGas
|
545
|
519
|
26
|
§
|
$798 million lower issuances of debt, including a decrease in commercial paper and other short-term debt borrowings with maturities greater than 90 days of $1.2 billion ($19 million increase in 2015 compared to $1.2 billion in 2014), offset by an increase in issuances of long-term debt of $373 million ($1.5 billion in 2015 compared to $1.2 billion in 2014); and
|
§
|
$339 million decrease in short-term debt in 2015 compared to a $54 million decrease in 2014; offset by
|
§
|
$629 million lower payments on debt, including lower payments of long-term debt of $931 million ($172 million in 2015 compared to $1.1 billion in 2014), offset by higher payments of commercial paper and other short-term debt with maturities greater than 90 days of $302 million ($674 million in 2015 compared to $372 million in 2014).
|
§
|
$206 million decrease in short-term debt in 2015 compared to a $68 million increase in 2014; and
|
§
|
$85 million higher payments on long-term debt in 2015; offset by
|
§
|
$288 million higher issuances of long-term debt in 2015.
|
§
|
$351 million higher issuances of long-term debt in 2015; and
|
§
|
$250 million payments on long-term debt in 2014; offset by
|
§
|
$50 million decrease in short-term debt in 2015 compared to a $31 million increase in 2014.
|
§
|
SONGS Outage and Retirement
|
§
|
Settlement Agreement to Resolve the CPUC’s Order Instituting Investigation (OII) into the SONGS Outage (SONGS OII)
|
§
|
Nuclear Regulatory Commission Proceedings
|
§
|
Nuclear Decommissioning and Funding
|
§
|
Nuclear Decommissioning Trusts
|
§
|
Legal Proceedings – SDG&E – Lawsuit Against Mitsubishi Heavy Industries, Ltd.
|
§
|
Nuclear Insurance
|
§
|
U.S. Department of Energy (DOE) Nuclear Fuel Disposal
|
§
|
Bay Gas, a facility located 40 miles north of Mobile, Alabama, that provides underground storage and delivery of natural gas. Sempra Natural Gas owns 91 percent of the project. It is the easternmost salt dome storage facility on the Gulf Coast, with direct service to the Florida market and markets across the Southeast, Mid-Atlantic and Northeast regions.
|
§
|
Mississippi Hub, located 45 miles southeast of Jackson, Mississippi, an underground salt dome natural gas storage project with access to shale basins of East Texas and Louisiana, traditional gulf supplies and LNG, with multiple interconnections to serve the Southeast and Northeast regions.
|
§
|
LA Storage, a salt cavern development project in Cameron Parish, Louisiana. Sempra Natural Gas owns 75 percent of the project and ProLiance Transportation LLC owns the remaining 25 percent. The project’s location provides access to several LNG facilities in the area.
|
NOMINAL AMOUNT AND ONE-YEAR VALUE AT RISK OF LONG-TERM DEBT(1)
|
|||||||||||||||
(Dollars in millions)
|
|||||||||||||||
Sempra Energy
|
|||||||||||||||
Consolidated
|
SDG&E
|
SoCalGas
|
|||||||||||||
Nominal
|
One-year
|
Nominal
|
One-year
|
Nominal
|
One-year
|
||||||||||
debt
|
VaR(2)
|
debt
|
VaR(2)
|
debt
|
VaR(2)
|
||||||||||
At June 30, 2015:
|
|||||||||||||||
California Utilities fixed-rate
|
$
|
6,799
|
$
|
1,007
|
$
|
4,287
|
$
|
656
|
$
|
2,512
|
$
|
351
|
|||
California Utilities variable-rate
|
460
|
12
|
460
|
12
|
―
|
―
|
|||||||||
All other, fixed-rate and variable-rate
|
6,310
|
461
|
―
|
―
|
―
|
―
|
|||||||||
At December 31, 2014:
|
|||||||||||||||
California Utilities fixed-rate
|
$
|
6,049
|
$
|
502
|
$
|
4,136
|
$
|
341
|
$
|
1,913
|
$
|
161
|
|||
California Utilities variable-rate
|
325
|
13
|
325
|
13
|
―
|
―
|
|||||||||
All other, fixed-rate and variable-rate
|
5,973
|
306
|
―
|
―
|
―
|
―
|
|||||||||
(1)
|
Excluding capital lease obligations, build-to-suit lease and interest rate swaps, and before reductions/increases for unamortized discount/premium.
|
||||||||||||||
(2)
|
After the effects of interest rate swaps.
|
EXHIBIT 10 -- MATERIAL CONTRACTS
|
|||
Compensation
|
|||
Sempra Energy
|
|||
10.1
|
Amendment to the Amended and Restated Sempra Energy 2005 Deferred
|
||
Compensation Plan, now known as Sempra Energy Employee and Director Retirement
|
|||
Savings Plan.
|
|||
EXHIBIT 12 -- STATEMENTS RE: COMPUTATION OF RATIOS
|
|||
Sempra Energy
|
|||
12.1
|
Sempra Energy Computation of Ratio of Earnings to Combined Fixed Charges and Preferred
|
||
Stock Dividends.
|
|||
San Diego Gas & Electric Company
|
|||
12.2
|
San Diego Gas & Electric Computation of Ratio of Earnings to Combined Fixed Charges and
|
||
Preferred Stock Dividends.
|
|||
Southern California Gas Company
|
|||
12.3
|
Southern California Gas Company Computation of Ratio of Earnings to Combined Fixed
|
||
Charges and Preferred Stock Dividends.
|
|||
EXHIBIT 31 -- SECTION 302 CERTIFICATIONS
|
|||
Sempra Energy
|
|||
31.1
|
Statement of Sempra Energy’s Chief Executive Officer pursuant to Rules 13a-14 and 15d-14
|
||
of the Securities Exchange Act of 1934.
|
|||
31.2
|
Statement of Sempra Energy’s Chief Financial Officer pursuant to Rules 13a-14 and 15d-14
|
||
of the Securities Exchange Act of 1934.
|
|||
San Diego Gas & Electric Company
|
|||
31.3
|
Statement of San Diego Gas & Electric Company’s Chief Executive Officer pursuant to Rules
|
||
13a-14 and 15d-14 of the Securities Exchange Act of 1934.
|
|||
31.4
|
Statement of San Diego Gas & Electric Company’s Chief Financial Officer pursuant to Rules
|
||
13a-14 and 15d-14 of the Securities Exchange Act of 1934.
|
|||
Southern California Gas Company
|
|||
31.5
|
Statement of Southern California Gas Company’s Chief Executive Officer pursuant to Rules
|
||
13a-14 and 15d-14 of the Securities Exchange Act of 1934.
|
|||
31.6
|
Statement of Southern California Gas Company’s Chief Financial Officer pursuant to Rules
|
||
13a-14 and 15d-14 of the Securities Exchange Act of 1934.
|
|||
EXHIBIT 32 -- SECTION 906 CERTIFICATIONS
|
|||
Sempra Energy
|
|||
32.1
|
Statement of Sempra Energy’s Chief Executive Officer pursuant to 18 U.S.C. Sec. 1350.
|
||
32.2
|
Statement of Sempra Energy’s Chief Financial Officer pursuant to 18 U.S.C. Sec. 1350.
|
||
San Diego Gas & Electric Company
|
|||
32.3
|
Statement of San Diego Gas & Electric Company’s Chief Executive Officer pursuant to 18
|
||
U.S.C. Sec. 1350.
|
|||
32.4
|
Statement of San Diego Gas & Electric Company’s Chief Financial Officer pursuant to 18
|
||
U.S.C. Sec. 1350.
|
|||
Southern California Gas Company
|
|||
32.5
|
Statement of Southern California Gas Company’s Chief Executive Officer pursuant to 18
|
||
U.S.C. Sec. 1350.
|
|||
32.6
|
Statement of Southern California Gas Company’s Chief Financial Officer pursuant to 18
|
||
U.S.C. Sec. 1350.
|
|||
EXHIBIT 101 -- INTERACTIVE DATA FILE
|
|||
Sempra Energy / San Diego Gas & Electric Company / Southern California Gas Company
|
|||
101.INS
|
XBRL Instance Document
|
||
101.SCH
|
XBRL Taxonomy Extension Schema Document
|
||
101.CAL
|
XBRL Taxonomy Extension Calculation Linkbase Document
|
||
101.DEF
|
XBRL Taxonomy Extension Definition Linkbase Document
|
||
101.LAB
|
XBRL Taxonomy Extension Label Linkbase Document
|
||
101.PRE
|
XBRL Taxonomy Extension Presentation Linkbase Document
|
SIGNATURES
|
|
Sempra Energy:
|
|
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
|
|
SEMPRA ENERGY,
(Registrant)
|
|
Date: August 4, 2015
|
By: /s/ Trevor I. Mihalik
|
Trevor I. Mihalik
Senior Vice President, Controller and
Chief Accounting Officer
|
San Diego Gas & Electric Company:
|
|
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
|
|
SAN DIEGO GAS & ELECTRIC COMPANY,
(Registrant)
|
|
Date: August 4, 2015
|
By: /s/ Bruce A. Folkmann
|
Bruce A. Folkmann
Vice President, Controller, Chief Financial Officer and Chief Accounting Officer
|
Southern California Gas Company:
|
|
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
|
|
SOUTHERN CALIFORNIA GAS COMPANY,
(Registrant)
|
|
Date: August 4, 2015
|
By: /s/ Bruce A. Folkmann
|
Bruce A. Folkmann
Vice President, Controller, Chief Financial Officer and Chief Accounting Officer
|
Exhibit 10.1
|
AND DIRECTOR SAVINGS PLAN
(As Amended and Restated Effective as of June 16, 2015)
|
TABLE OF CONTENTS
ARTICLE I. TITLE AND DEFINITIONS
1.1
Title.
1.2
Definitions.
ARTICLE II. PARTICIPATION
2.1
Commencement of Participation
2.2
Newly Appointed or Elected Directors
ARTICLE III. CONTRIBUTIONS
3.1
Elections to Defer Compensation
3.2
Distribution Elections.
3.3
Employer Matching Contributions
3.4
FICA and Other Taxes.
ARTICLE IV. INVESTMENTS
4.1
Measurement Funds.
4.2
Investment Elections.
4.3
Compliance with Section 16 of the Exchange Act.
ARTICLE V. ACCOUNTS
5.1
Accounts.
5.2
Subaccounts.
ARTICLE VI. VESTING
ARTICLE VII. DISTRIBUTIONS
7.1
Distribution of Accounts.
7.2
Hardship Distribution.
7.3
Effect of a Change in Control.
7.4
Inability to Locate Participant.
7.5
Prohibition on Acceleration of Distributions.
ARTICLE VIII. ADMINISTRATION
8.1
Committee.
8.2
Administrator.
8.3
Committee Action.
8.4
Powers and Duties of the Committee.
8.5
Construction and Interpretation.
8.6
Information.
8.7
Compensation, Expenses and Indemnity.
8.8
Quarterly Statements.
8.9
Disputes.
ARTICLE IX. MISCELLANEOUS
9.1
Unsecured General Creditor.
9.2
Restriction Against Assignment.
9.3
Withholding.
9.3
Amendment, Modification, Suspension or Termination.
9.5
Designation of Beneficiary.
9.6
Insurance.
9.7
Governing Law.
9.8
Receipt of Release.
9.9
Compliance with Code Section 162(m)
9.10
Payments on Behalf of Persons Under Incapacity.
9.11
Limitation of Rights
9.12
Exempt ERISA Plan
9.13
Notice
9.14
Errors and Misstatements
9.15
Pronouns and Plurality
9.16
Severability
9.17
Status
9.18
Headings.
ARTICLE X. EMPLOYEES OF SEMPRA ENERGY TRADING CORPORATION AND SEMPRA ENERGY SOLUTIONS LLC
ARTICLE XI. SECTION 409A OF THE CODE
|
THE SEMPRA ENERGY EMPLOYEE AND DIRECTOR SAVINGS PLAN
(As Amended and Restated Effective as of June 16, 2015)
Effective as of January 1, 2005, Sempra Energy, a California corporation, established the Sempra Energy 2005 Deferred Compensation Plan (the Plan) which was designed to provide supplemental retirement income benefits for certain directors of Sempra Energy and for a select group of management and highly compensated employees of the Company (as defined herein) through deferrals of salary and incentive compensation and employer matching contributions. The Plan has been amended from time to time and, effective as of January 1, 2011, the name of the Plan was changed to The Sempra Energy Employee and Director Retirement Savings Plan. Effective as of June 29, 2012, the name of the Plan was changed to The Sempra Energy Employee and Director Savings Plan. The following provisions constitute an amendment, restatement and continuation of the Plan as in effect immediately prior to June 16, 2015.
ARTICLE I.
TITLE AND DEFINITIONS
1.1
Title.
This Plan shall be known as the Sempra Energy Employee and Director Savings Plan.
1.2
Definitions.
Whenever the following words and phrases are used in this Plan, with the first letter capitalized, they shall have the meanings specified below.
(a)
Account or Accounts shall mean a Participants Deferral Account and/or Employer Matching Account.
(b)
Administrator shall mean the individual(s) designated by the Committee (who need not be a member of the Committee) to handle the day-to-day Plan administration. If the Committee does not make such a designation, the Administrator shall be the most senior officer of Human Resources of Sempra Energy.
(c)
Affiliate has the meaning ascribed to such term in Rule 12b-2 promulgated under the Exchange Act.
(d)
Base Salary shall mean, with respect to any Participant, the Participants annual base salary, excluding bonus, incentive and all other remuneration for services rendered to the Company, prior to reduction for any salary contributions to a plan established pursuant to Section 125 of the Code or qualified pursuant to Section 401(k) of the Code and prior to reduction for deferrals under this Plan.
(e)
Beneficial Owner has the meaning set forth in Rule 13d-3 under the Exchange Act.
(f)
Beneficiary or Beneficiaries shall mean the person or persons, including a trustee, personal representative or other fiduciary, last designated in writing by a Participant to receive the benefits specified hereunder in the event of the Participants death in accordance with Section 9.5.
(g)
Board of Directors or Board shall mean the Board of Directors of Sempra Energy.
(h)
Bonus shall mean the annual cash incentive award earned by a Participant under the Companys short-term incentive plans and other special cash payments or cash awards that may be granted by the Company from time to time to the extent that such other special cash payments or cash awards are permitted by the Committee to be deferred under the Plan.
(i)
Change in Control shall be deemed to have occurred when any event or transaction described in paragraph (1), (2), (3) or (4) occurs, subject to paragraph (5):
(1)
Any Person is or becomes the Beneficial Owner, directly or indirectly, of securities of Sempra Energy representing twenty percent (20%) or more of the combined voting power of Sempra Energys then outstanding securities; or
(2)
The following individuals cease for any reason to constitute a majority of the number of directors then serving: individuals who, on the Effective Date, constitute the Board and any new director (other than a director whose initial assumption of office is in connection with an actual or threatened election contest, including, but not limited to, a consent solicitation, relating to the election of directors of Sempra Energy) whose appointment or election by the Board or nomination for election by Sempra Energys shareholders was approved or recommended by a vote of at least two-thirds (2/3) of the directors then still in office who either were directors on the date hereof or whose appointment, election or nomination for election was previously so approved or recommended; or
(3)
There is consummated a merger or consolidation of Sempra Energy or any direct or indirect subsidiary of Sempra Energy with any other corporation, other than (A) a merger or consolidation which would result in the voting securities of Sempra Energy outstanding immediately prior to such merger or consolidation continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity or any parent thereof), in combination with the ownership of any trustee or other fiduciary holding securities under an employee benefit plan of Sempra Energy or any subsidiary of Sempra Energy, at least sixty percent (60%) of the combined voting power of the securities of Sempra Energy or such surviving entity or any parent thereof outstanding immediately after such merger or consolidation, or (B) a merger or consolidation effected to implement a recapitalization of Sempra Energy (or similar transaction) in which no Person is or becomes the Beneficial Owner, directly or indirectly, of securities of Sempra Energy (not including in the securities beneficially owned by such Person any securities acquired directly from Sempra Energy or its affiliates other than in connection with the acquisition by Sempra Energy or its affiliates of a business) representing twenty percent (20%) or more of the combined voting power of Sempra Energys then outstanding securities; or
(4)
The shareholders of Sempra Energy approve a plan of complete liquidation or dissolution of Sempra Energy or there is consummated an agreement for the sale or disposition by Sempra Energy of all or substantially all of Sempra Energys assets, other than a sale or disposition by Sempra Energy of all or substantially all of Sempra Energys assets to an entity, at least sixty percent (60%) of the combined voting power of the voting securities of which are owned by shareholders of Sempra Energy in substantially the same proportions as their ownership of Sempra Energy immediately prior to such sale.
(5)
An event or transaction described in paragraph (1), (2), (3), or (4) shall be a Change in Control only if such event or transaction is also a change in the ownership or effective control of the corporation, or in the ownership of a substantial portion of the assets of the corporation, within the meaning of Section 409A of the Code.
(j)
Code shall mean the Internal Revenue Code of 1986, as amended, and all applicable rules and regulations thereunder
(k)
Committee shall mean the compensation committee of the Board of Directors.
(l)
Company shall mean Sempra Energy and any successor corporations. The term Company shall also include each corporation which is a member of a controlled group of corporations (within the meaning of Section 414(b) of the Code) of which Sempra Energy is a component member if the Committee provides that such corporation shall participate in the Plan and such corporations governing board of directors adopts the Plan. Any corporation described in the preceding sentence which participates in the Plan immediately prior to the Effective Date shall be deemed to participate in the Plan and to have adopted the Plan without any further action of either such corporation or Sempra Energy, subject to the terms and conditions of the Plan.
(m)
Compensation shall mean, with respect to a Participant, the following:
(1)
with respect to any Participant who is an employee, Base Salary and Bonus that the Participant is entitled to receive for services rendered to the Company. In addition, for any Participant who is an Executive Officer Compensation includes (i) SERP Lump Sum, (ii) Restricted Stock Units and (iii) Severance Payments. The Committee may also permit Eligible Individuals who are not Executive Officers to defer Restricted Stock Units (or any other compensation specifically designated by the Committee) provided that such Eligible Individual shall not be an Executive Officer for purposes of the Plan solely as a result of such deferral unless such Eligible Individual is otherwise designated as such by the Committee; and
(2)
with respect to any Director, retainer payments and/or meeting and other fees (including Elective Phantom Share Amounts and Nonelective Phantom Share Amounts), received from Sempra Energy for services performed by the Participant as a Director.
(n)
Deferral Account shall mean the bookkeeping account maintained under the Plan for each Participant that is credited with amounts equal to the portion of the Participants Compensation that he elects to defer pursuant to Section 3.1, debited by amounts equal to all distributions to and withdrawals made by the Participant and/or his Beneficiary and adjusted for investment earnings and losses pursuant to Article V. The Deferral Account may be further subdivided into subaccounts as determined by the Administrator.
(o)
Deferral Election Form shall mean the form designated by the Administrator for purposes of making deferrals under Section 3.1.
(p)
Director shall mean an individual who is a non-employee member of the Board.
(q)
Disability or Disabled means, with respect to a Participant, that the Participant:
(1)
is unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, or
(2)
is, by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, receiving income replacement benefits for a period of not less than three (3) months under an accident or health plan covering employees of such Participants employer,
in either case, as determined in accordance with Section 409A of the Code.
(r)
Distributable Amount of a Participants subaccounts with respect to a Plan Year shall mean the sum of the vested balance of the subaccount in a Participants Deferral Account and Employer Matching Account with respect to such Plan Year.
(s)
Effective Date shall mean June 16, 2015.
(t)
(1)
Election Period with respect to a Plan Year shall mean the period designated by the Administrator; provided, however, that such period shall be no less than ten (10) business days. The Election Period with respect to a Plan Year shall end not later than the last day of the prior Plan Year; provided, however, that, in the case of an Eligible Individual who first becomes eligible to participate in the Plan during a Plan Year, the Election Period may be the thirty (30) calendar day period (or such shorter period specified by the Administrator) commencing on the date such Eligible Individual first becomes eligible to participate in accordance with Section 409A of the Code; and provided, further, in the case of an Eligible Individuals election to defer a Bonus (or portion thereof) for a Plan Year that is performance-based compensation within the meaning of Section 409A of the Code, the Election Period may be a period designated by the Administrator during such Plan Year that satisfies the requirements of Section 409A of the Code.
(2)
Notwithstanding paragraph (1), in the case of a Director who becomes a Participant in accordance with Section 2.2, with respect to the Plan Year in which such Director first becomes eligible to participate in the Plan by reason of appointment or election as a Director, Election Period, for purposes of: (A) such Directors election under paragraph 3.1(b)(4) to defer any Elective Phantom Share Amount with respect to an initial equity award granted during the Plan Year shall be the thirty (30) calendar day period (or such shorter period designated by the Administrator) after the date such Director first becomes eligible to participate in the Plan (which period shall end not later than the day next preceding the grant date of such initial equity award), and (B) such Directors election under Section 3.1(f) of the time and form of payment of any Nonelective Phantom Share Account (or any prorated Nonelective Phantom Share Amount) credited during such Plan Year shall be the thirty (30) calendar day period (or such shorter period designated by the Administrator) after such appointment or election (which period shall end not later than the day next preceding the first day of the calendar quarter with respect to such Nonelective Phantom Share Amount (or such prorated Nonelective Phantom Share Amount) as determined under Section 3.1(f)); provided that any such election under clause (A) or (B) satisfies the requirements of Section 409A of the Code.
(u)
Elective Phantom Share Amount shall mean, with respect to an initial or annual equity award by Sempra Energy to a Participant who is a Director, which the Director may elect to receive in the form of (1) an award of Restricted Stock Units, or (2) an amount credited to such Participants Deferral Account in the Sempra Energy Stock Fund, the dollar value designated by the Board for such equity award that is used for purposes of determining the number of Restricted Stock Units subject to such award, or the amount to be credited to such Participants Deferral Account. In the case of a Director who first becomes a Director by reason of appointment or election as a Director, any such initial equity award shall be granted on the tenth (10th) New York Stock Exchange trading day after such appointment or election.
(v)
Eligible Individual shall mean those individuals selected by the Committee from (1) those employees of the Company who either (A) are Executive Officers or (B) have Base Salary for a calendar year that is at least $165,000, as adjusted by the Committee from time to time and (2) those Directors who are not employees of the Company. The Committee may, in its sole discretion, select such other individuals to participate in the Plan who do not otherwise meet the foregoing criteria.
(w)
Employer Matching Account shall mean the bookkeeping account maintained under the Plan for each Participant that is credited with an amount equal to the Employer Matching Contribution, if any, debited by amounts equal to all distributions to and withdrawals made by the Participant and/or his Beneficiary and adjusted for investment earnings and losses pursuant to Article V.
(x)
Employer Matching Contributions shall mean the employer matching contribution made to the Plan pursuant to Section 3.3.
(y)
ERISA shall mean the Employee Retirement Income Security Act of 1974, as amended, and all applicable rules and regulations thereunder.
(z)
Exchange Act shall mean the Securities Exchange Act of 1934, as amended, and the applicable rules and regulations thereunder.
(aa)
Executive Officer shall mean an employee of the Company who holds a position as an executive officer of Sempra Energy, is eligible to participate in the Sempra Energy Supplemental Executive Retirement Plan or who is otherwise designated as an Executive Officer by the Committee.
(bb)
401(k) Plan shall mean the Sempra Energy Savings Plan, as in effect from time to time, maintained by Sempra Energy under Section 401(k) of the Code.
(cc)
Manager shall mean an employee of the Company who is an Eligible Individual, other than an Executive Officer or a Director.
(dd)
Measurement Fund shall mean one or more of the investment funds selected by the Committee pursuant to Section 4.1.
(ee)
Moodys Plus Rate shall mean the Moodys Rate (as defined below) plus the greater of (1) 10% of the Moodys Corporate Bond Yield Average Monthly Average Corporates as published by Moodys Investors Service, Inc. (or any successor) or (2) one percentage point per annum. The Moodys Rate for a month means the average of the daily Moodys Corporate Bond Yield Average Monthly Average Corporates for the applicable month.
(ff)
Nonelective Phantom Share Amount shall mean the dollar amount designated by the Board for purposes of Section 3.1(f) to be invested in the Sempra Energy Stock Fund.
(gg)
Participant shall mean any Eligible Individual who becomes a Participant in accordance with Article II and who has not received a complete distribution of the amounts credited to his Accounts.
(hh)
Payroll Date shall mean, with respect to any Participant, the date on which he would otherwise be paid Compensation.
(ii)
Payment Date shall mean the date determined by the Administrator that is on or within thirty (30) calendar days after one of the following dates as designated by the Participant in his distribution form election with respect to a Plan Year:
(1)
the first day of the first calendar month on or next following thirty (30) calendar days after the date of the Participant's Separation from Service or Disability, or
(2)
the first day of the first, second, third, fourth or fifth calendar year next following the date of the Participants Separation from Service or Disability.
Payment Date shall also mean the Scheduled Withdrawal Date elected in accordance with the provisions of Section 7.1(b).
(jj)
Person means any person, entity or group within the meaning of Section 13(d)(3) or Section 14(d)(2) of the Exchange Act, except that such term shall not include (1) Sempra Energy or any of its Affiliates, (2) a trustee or other fiduciary holding securities under an employee benefit plan of Sempra Energy or any of its Affiliates, (3) an underwriter temporarily holding securities pursuant to an offering of such securities, (4) a corporation owned, directly or indirectly, by the shareholders of Sempra Energy in substantially the same proportions as their ownership of stock of Sempra Energy, or (5) a person or group as used in Rule 13d-1(b) under the Exchange Act.
(kk)
Plan shall mean the Sempra Energy Employee and Director Savings Plan set forth herein, as amended from time to time.
(ll)
Plan Year shall mean the twelve (12) consecutive month period beginning on each January 1 and ending on each December 31.
(mm)
Restricted Stock Units shall mean restricted stock units granted to a Participant under the Sempra Energy 2008 Long Term Incentive Plan, Sempra Energy 2013 Long-Term Incentive Plan, and any successor plan(s) thereto.
(nn)
Rule 16b-3 shall mean that certain Rule 16b-3 under the Exchange Act, as such Rule may be amended from time to time.
(oo)
Scheduled Withdrawal Date shall be in January in the year elected by the Participant for an in-service withdrawal of all amounts of Compensation deferred in a given Plan Year, but excluding earnings and losses attributable thereto, as set forth on the election forms for such Plan Year.
(pp)
Sempra Energy Stock Fund shall mean the Measurement Fund in which investment earnings and losses parallel the investment return on the common stock of Sempra Energy.
(qq)
Separation from Service shall mean, with respect to a Participant, the Participants separation from service, as defined in Treasury Regulation Section 1.409A-1(h).
(rr)
SERP Lump Sum shall mean the lump sum retirement benefit that would be payable to an Executive Officer who is a Plan Participant under either the Sempra Energy Supplemental Executive Retirement Plan or the Sempra Energy Excess Cash Balance Plan.
(ss)
Severance Payment shall mean any cash severance payments payable to a Participant under an executive employment agreement or severance agreement with the Company.
(tt)
Specified Employee shall mean a specified employee determined in accordance with the requirements of Section 409A of the Code.
(uu)
Subaccount or Subaccounts shall mean the subaccount or subaccounts maintained with respect to a Participants Deferral Account or Employer Matching Account.
(vv)
Valuation Date, with respect to the Measurement Funds that are available under the 401(k) Plan, shall have the same meaning as under the 401(k) Plan. For purposes of the Moodys Plus Rate, Valuation Date shall mean the last day of the calendar month.
ARTICLE II.
PARTICIPATION
2.1
Commencement of Participation
Subject to Section 2.2, an Eligible Individual shall become a Participant in the Plan by (1) electing to make deferrals in accordance with Section 3.1 and (2) filing such other forms as the Administrator may reasonably require for participation hereunder.
2.2
Newly Appointed or Elected Directors
A Director who first becomes an Eligible Individual during a Plan Year by reason of appointment or election as a Director shall become a Participant on the date of such appointment or election. Such Eligible Individual may elect to make deferrals in accordance with Section 3.1 and shall file such forms as the Administrator reasonably requires.
ARTICLE III.
CONTRIBUTIONS
3.1
Elections to Defer Compensation
(a)
General Rule. Each Eligible Individual may defer Compensation for a Plan Year by filing with the Administrator a Deferral Election Form for such Plan Year that conforms to the requirements of this Section 3.1, no later than the last day of the applicable Election Period for such Plan Year, and such deferral election shall become irrevocable on the last day of the applicable Election Period for such Plan Year (or such later date permitted by the Administrator consistent with the requirements of Section 409A of the Code). Unless otherwise provided by the Committee, an Eligible Individual who first becomes eligible to participate in the Plan during a Plan Year may elect to defer Compensation for such Plan Year; provided, however, that any such election to defer Compensation for such Plan Year must be filed during the Election Period prior to the effective date of such election, shall be irrevocable when made, and shall be effective only for Compensation that constitutes compensation for services performed during periods during the Plan Year beginning after the effective date of such election. Notwithstanding the previous sentence, if an Eligible Individuals Bonus (or portion thereof) is a performance-based compensation within the meaning of Section 409A of the Code, the Administrator may permit such Eligible Individual to file an election to defer such Bonus (or such portion thereof), or change such Eligible Individuals prior election to defer such Bonus (or such portion thereof), no later than the date that is six (6) months before the end of the performance period over which such services are to be performed, under the terms and conditions that may be specified by the Administrator, in accordance with Section 409A of the Code, and such deferral election shall become irrevocable on the date that is six (6) months before the end of the performance period.
(b)
Special Rules. Notwithstanding the above, the following restrictions apply to deferrals of certain elements of Compensation:
(1)
Severance Payments. A Participant may elect to defer Severance Payments (or a portion thereof), to the extent permitted by the Committee. The Participants election to defer Severance Payments (or a portion thereof) shall be irrevocable when made, shall be made at least twelve (12) months prior to the first date on which Severance Payments are scheduled to be paid (or, in the case of installment payments, twelve (12) months prior to the date on which the first amount is to be paid), and shall not take effect until at least twelve (12) months after the date on which the election is made. Such deferral election shall provide that the amount deferred shall be deferred for a period of not less than five (5) years from the date the payment of the amount deferred would otherwise have been made (or, in the case of installment payments treated as a single payment as determined under Section 409A of the Code, five (5) years from the date the first amount was scheduled to be paid).
(2)
Restricted Stock Units. Each Eligible Individual designated by the Committee as so eligible to defer, may elect to defer Restricted Stock Units (or a portion thereof), in accordance with such rules as the Committee may establish, which such rules shall not be inconsistent with the deferral election rules set forth in Sections 3.1 and 3.2 or the distribution provisions of Section 7.1. In order to defer Restricted Stock Units (or a portion thereof), an eligible Participant must file the appropriate Deferral Election Form no later than the election date required under Section 409A of the Code. The Participants election to defer Restricted Stock Units (or a portion thereof) shall apply only if the Restricted Stock Units (or portion thereof) constitute a legally binding right to a payment of compensation in a subsequent taxable year and, absent a deferral election, would be treated as a short-term deferral, within the meaning of Section 409A of the Code. Any deferral election that does not satisfy the requirements for an initial deferral election under Section 409A of the Code shall be irrevocable when made and shall be made in accordance with Section 409A of the Code, applied as if the amount were a deferral of compensation and the scheduled payment date for the amount were the date the substantial risk of forfeiture lapses. Such subsequent deferral election shall be irrevocable when made, shall be made at least twelve (12) months prior to the first date on which Restricted Stock Units are scheduled to be paid (or, in the case of installment payments, twelve (12) months prior to the date on which the first amount is to be paid), and shall not take effect until at least twelve (12) months after the date on which the election is made. Such deferral election shall provide that the amount deferred shall be deferred for a period of not less than five (5) years from the date the payment of the amount deferred would otherwise have been made (or, in the case of installment payments treated as a single payment as determined under Section 409A of the Code, five (5) years from the date the first amount was scheduled to be paid); provided, however, that such deferral election may provide that the deferred amounts will be payable upon a change in control event (within the meaning of Section 409A of the Code) without regard to the five (5) year additional deferral requirement. Deferrals of Restricted Stock Units shall be invested in the Sempra Energy Stock Fund and may not be moved to any other Measurement Fund. Notwithstanding anything contained in the Plan to the contrary, a Participant may not elect a Scheduled Withdrawal Date with respect to the deferral of any Restricted Stock Units.
(3)
SERP Lump Sum. A Participant may elect to defer a SERP Lump Sum (or a portion thereof), to the extent permitted by the Committee. In order to defer a SERP Lump Sum (or a portion thereof), an eligible Participant must file the appropriate Deferral Election Form no later than the election date required under Section 409A of the Code. The Participants election to defer a SERP Lump Sum (or a portion thereof) shall satisfy the requirements of Section 409A of the Code as a subsequent deferral. Such deferral election shall be irrevocable when made, and shall not take effect until at least twelve (12) months after the date on which the election is made. Such deferral election shall provide that the amount deferred shall be deferred for a period of not less than five (5) years from the date the payment of the amount deferred would otherwise have been made (or, in the case of installment payments treated as a single payment, five years from the date the first amount was scheduled to be paid) in accordance with Section 409A of the Code.
(4)
Elective Phantom Share Amounts. A Participant who is a Director and is entitled to receive an initial or annual equity award from Sempra Energy, in the form of an award of Restricted Stock Units or an amount credited to his Deferral Account, may elect to have the Elective Phantom Share Amount with respect to such award credited to his Deferral Account (in lieu of such award of Restricted Stock Units) and defer such Elective Phantom Share Amount. In order to elect such credit and deferral of the Elective Phantom Share Amount with respect to such an equity award, an eligible Participant must file the appropriate Deferral Election Form no later than the last day of the applicable Election Period for the Plan Year during which such equity award is granted, and such deferral election shall become irrevocable on the last day of the applicable Election Period for such Plan Year. A Director who first becomes a Participant during a Plan Year may make a deferral election during such Plan Year in accordance with subparagraph 1.2(t)(2)(A). Such an election to defer an Elective Phantom Share Amount with respect to an equity award granted during a Plan Year must be filed during the Election Period prior to the effective date of such election and shall be irrevocable when made and shall be effective only for an Elective Phantom Share Amount that constitutes compensation for services performed after the effective date of such election. If a Participant fails to elect such credit and deferral of the Elective Phantom Share Amount with respect to such an equity award, the Participants equity award shall be made in the form of an award of Restricted Stock Units. A Participant shall make a separate election to defer Elective Phantom Share Amounts for each Plan Year.
(c)
Deferral Amounts. The amount of Compensation which a Participant may elect to defer for a Plan Year is such Compensation earned on or after the time at which the Participant elects to defer each Plan Year in accordance with Section 3.1(a), and which is earned during such Plan Year (other than with respect to subsequent deferrals of previously deferred amounts or other amounts that are treated as subsequent deferrals for purposes of Section 409A of the Code).
(1)
Each Participant who is a Manager shall be permitted to defer, in any whole percentage: (A) from 6% to 85% of Base Salary, (B) from 6% to 85% of his Bonus, and (C) if permitted by the Committee, between 10% and 100% of such Participants Restricted Stock Units, subject to Section 3.1(b).
(2)
Each Participant who is an Executive Officer shall be permitted to defer, in any whole percentage: (A) from 6% to 85% of Base Salary, (B) from 6% to 85% of his Bonus and (c) from 10% to 100% of such Participants Restricted Stock Units, Severance Payments and SERP Lump Sum, subject to Section 3.1(b).
(3)
Each Participant who is a Director: (A) shall be permitted to defer, in any whole percentage, from 10% to 100% of his Compensation (other than Elective Phantom Share Amounts and Nonelective Phantom Share Amounts), and (B) shall be permitted to defer 100% of his Elective Phantom Share Amounts. In the case of a Participant who is a Director, 100% of such Participants Nonelective Phantom Share Amounts shall be deferred under Section 3.1(f).
Notwithstanding the limitations established above, the total amount deferred by a Participant shall be limited in any calendar year, if necessary, to satisfy the Participants income and employment tax withholding obligations (including Social Security, unemployment and Medicare), and the Participants employee benefit plan contribution requirements, determined on the first day of the Election Period for such Plan Year, in any case as determined by the Administrator or the Committee, as applicable.
(d)
Duration of Deferral Election.
(1)
A Participant shall not modify or suspend his election to defer Compensation during a Plan Year.
(2)
A Participant must file a new deferral election for each subsequent Plan Year. In the event a Participant fails to file a timely deferral election for the next Plan Year, he shall be deemed to have elected not to defer any Compensation for such Plan Year.
(3)
A Participants election to defer all or any portion of his SERP Lump Sum shall automatically become void in the event the Participant dies or becomes disabled while employed by the Company.
(4)
A Participant who is a Director must file a new deferral election for the Elective Phantom Share Amounts for the equity awards granted during each Plan Year. In the event a Participant fails to file a timely deferral election for the next Plan Year, he shall be deemed to have elected not to defer the Elective Phantom Share Amounts for the equity awards granted during such Plan Year.
(e)
Elections. Any Eligible Individual who does not elect to defer Compensation during his Election Period for a Plan Year may subsequently participate in the Plan in accordance with the terms and conditions of the Plan.
(f)
Nonelective Compensation Deferrals for Directors. The Board may determine from time to time whether deferrals of Nonelective Phantom Share Amounts shall be credited to the Deferral Accounts of one or more Participants who are Directors. The Board shall designate the Nonelective Phantom Share Amounts and any conditions under which a Director shall be entitled to have Nonelective Phantom Share Amounts credited to his Deferral Account. A Nonelective Phantom Share Amount credited to a Directors Deferral Account shall constitute compensation for services to be performed by the Director during a calendar quarter, and the Nonelective Phantom Share Amount for such calendar quarter shall be credited to the Directors Deferral Account on the first New York Stock Exchange trading day of such calendar quarter; provided, however, that, in the case of a Director who first becomes a Director by reason of appointment or election as a Director, for purposes of the calendar quarter during which such appointment or election occurs, such Directors Deferral Account shall be credited with a prorated portion of the Nonelective Phantom Share Amount for the portion of such calendar quarter (if any), commencing on the tenth (10th) New York Stock Exchange trading day after such Directors appointment or election and ending on the last day of the calendar quarter, and any such prorated portion of the Nonelective Phantom Share Amount shall constitute compensation for services to be performed by the Director during the period commencing on such tenth (10th) New York Stock Exchange trading day and ending on the last day of such calendar quarter and shall be determined based on the portion of such calendar quarter that comprises such period and such prorated portion of the Nonelective Phantom Share Amount shall be credited to the Directors Deferral Account on the New York Stock Exchange trading day next following the last day of such calendar quarter. The service period for a Nonelective Phantom Share Amount (or a prorated Nonelective Phantom Share Amount) shall be the calendar quarter, or portion thereof, during which the Director performs services for which such Nonelective Phantom Share Amount (or prorated Phantom Share Amount) constitutes compensation. Such Nonelective Phantom Share Amounts shall be deferred on a nonelective basis. An eligible Participant must file the appropriate Deferral Election Form with respect to the Nonelective Phantom Share Amounts that constitute compensation for services performed during periods during the Plan Year beginning after the effective date of such election, for purposes of electing the Payment Date and the form of distribution of such Nonelective Phantom Share Amounts, no later than the last day of the applicable Election Period for the Plan Year during which such Nonelective Phantom Share Amounts are credited, and such deferral election shall become irrevocable on the last day of the applicable Election Period for such Plan Year. The Administrator shall permit such a Participant who first becomes a Participant during a Plan Year to have his first Election Period with respect to such election of the Payment Date and the form of distribution during such Plan Year in accordance with subparagraph 1.2(v)(2)(B). Such an election as to the Payment Date and the form of distribution must be filed during the Election Period prior to the effective date of such election and shall be irrevocable when made and shall be effective only for a Nonelective Phantom Share Amount that constitutes compensation for services performed after the date of such election.
(g)
Termination of Participation and/or Deferrals. If the Committee and/or the Administrator determines in good faith that a Participant no longer qualifies as a Director or a member of a select group of management or highly compensated employees, as membership in such group is determined in accordance with Sections 201(2), 301(a)(3) and 401(a)(1) of ERISA, the Committee and/or the Administrator shall have the right, in its sole discretion and only for purposes of preserving the Plans exemption from Title I of ERISA, to prevent the Participant from making deferral elections for future Plan Years.
3.2
Distribution Elections.
(a)
General Rule. Each Participant shall make a separate distribution election with respect to each Plan Year for which such Participant elects to defer Compensation in accordance with Section 3.1. In the case of each Participant who is a Director, such Participant shall make a separate distribution election with respect to each Plan Year without regard to whether such Participant elects to defer Compensation in accordance with Section 3.1. A Participants distribution election with respect to a Plan Year shall apply to: (1) the subaccount in his Deferral Account to which shall be credited the amount equal to the portion of his Compensation earned during such Plan Year that he elects to defer pursuant to Section 3.1, (2) in the case of a Participant who is a Director, the subaccount in his Deferred Account to which shall be credited any Elective Phantom Share Amounts for equity awards granted during such Plan Year that he elects to defer pursuant to Section 3.1, and the subaccount in his Deferral Account to which shall be credited any Nonelective Phantom Share Amounts during such Plan Year pursuant to Section 3.1(f), and (3) the subaccount in his Employer Matching Account to which shall be credited the amount equal to the Employer Matching Contribution for such Plan Year. A Participant may elect any Payment Date described in Section 1.2(ii), and may elect distribution in the normal form, as described in paragraph 7.1(a)(1), or an optional form described in paragraph 7.1(a)(2). Such Payment Date and distribution form elections shall be made on such Participants Deferral Election Form during the Election Period for which such Participant elects to defer Compensation under Section 3.1 for such Plan Year, and such Payment Date and distribution form elections with respect to such Plan Year shall be irrevocable, except as provided in subsection (b). A Participant may elect any Payment Date described in Section 1.2(ii), and may elect distribution in the normal form, as described in paragraph 7.1(a)(1), or an optional form described in subparagraphs 7.1(a)(2)(A), (B) or (C). In the event a Participant fails to elect a Payment Date for his Distributable Amount with respect to a Plan Year, his Payment Date for his Distributable Amount with respect to such Plan Year shall be the date described in paragraph 1.2(ii)(1). In the event a Participant fails to make a distribution form election for his Distributable Amount with respect to a Plan Year, his Distributable Amount with respect to such Plan Year shall be distributed in the normal form, as described in paragraph 7.1(a)(1) in the event of his Separation from Service or Disability, except as provided in subsection (b). Except as provided in subsection (b), a Participants distribution for his Distributable Amount with respect to a Plan Year shall be made or commence on such Participants Payment Date.
(b)
Changes to Distribution Form Election. Subject to subsection (e), a Participant may change his distribution form election for his Distributable Amount with respect to a Plan Year in accordance with this subsection (b) as follows:
(1)
Change from Lump Sum. If such Participant elected to receive the distribution of his Distributable Amount with respect to a Plan Year in the event of his Separation from Service or Disability in a lump sum, such Participant may change such distribution form election by making a new distribution form election for his Distributable Amount with respect to such Plan Year providing for distribution in one of the following forms, with such distribution made or commencing on the fifth anniversary of his Payment Date:
(A)
a lump sum,
(B)
annual installments (calculated as set forth at paragraph 7.1(a)(6)) over five years,
(C)
annual installments (calculated as set forth at paragraph 7.1(a)(6) over ten (10) years, or
(D)
annual installments (calculated as set forth at paragraph 7.1(a)(6)) over fifteen (15) years.
(2)
Change from Installments. If such Participant elected to receive the distribution of his Distributable Amount with respect to a Plan Year in the event of his Separation from Service or Disability in annual installments over five, ten or fifteen years, such Participant may change such distribution form election by making a new distribution form election for his Distributable Amount with respect to such Plan Year providing for distribution in one of the following forms, with such distribution commencing on the fifth anniversary of his Payment Date:
(i)
annual installments (calculated as set forth at paragraph 7.1(a)(6)) over the period of years specified in such Participants initial distribution form election, or
(ii)
annual installments (calculated as set forth at paragraph 7.1(a)(6)) over a period of either ten (10) years or fifteen (15) years, provided that such period exceeds the period of years specified in such Participants initial distribution form election.
(3)
A Participant may make only one change to his distribution form election with respect to a Plan Year under this subsection (b).
(c)
Election of Scheduled Withdrawal Date. A Participant may elect a Scheduled Withdrawal Date with respect to his deferrals of Compensation (but excluding any investment earnings on such amounts) (the Withdrawal Amount) with respect to a Plan Year. Such election of a Scheduled Withdrawal Date for such Participants Withdrawal Amount with respect to a Plan Year shall be made by such Participant during the Election Period for which such Participant elects to defer Compensation under Section 3.1 for such Plan Year, and such election of a Scheduled Withdrawal Date shall be irrevocable, except as provided in subsection (d). A Participant may make separate Scheduled Withdrawal Date elections for his deferrals of Compensation (excluding any investment earnings on such amounts) with respect to different Plan Years. A Participants Withdrawal Amount with respect to a Plan Year shall be credited to subaccounts under such Participants Accounts for such Plan Year. A Participant shall not be required to elect a Scheduled Withdrawal Date with respect to his deferrals of Compensation for a Plan Year and, if a Participant fails to make an election of a Scheduled Withdrawal Date for a Plan Year, no Scheduled Withdrawal Date shall apply with respect to his deferrals of Compensation for such Plan Year.
(d)
Change of Scheduled Withdrawal Date. Subject to subsection (e), if a Participant elected a Scheduled Withdrawal Date with respect to his deferrals of Compensation (excluding any investment earnings on such amounts) with respect to a Plan Year, such Participant may change such Scheduled Withdrawal Date for the Withdrawal Amount with respect to such Plan Year by electing a new Scheduled Withdrawal Date for the Withdrawal Amount with respect to such Plan Year that is not less than five years later than the Scheduled Withdrawal Date previously elected by such Participant for such Plan Year. A Participant who has not elected a Scheduled Withdrawal Date for his deferrals of Compensation (excluding any investment earnings on such amounts) for a Plan Year may not subsequently elect a Scheduled Withdrawal Date for his deferrals of Compensation (excluding any investment earnings on such amounts) for such Plan Year. A Participant may make only one change to the Scheduled Withdrawal Date with respect to each Plan Year under this subsection (d).
(e)
Limitation on Distribution Changes. A Participants election to change to his distribution form election with respect to a Plan Year under subsection (b), or change of a Scheduled Withdrawal Date with respect to a Plan Year under subsection (d), shall be subject to the following limitations:
(1)
The Participants election to change his distribution election form with respect to a Plan Year, or change his Scheduled Withdrawal Date with respect to a Plan Year, shall not take effect until at least twelve (12) months after his election to change the distribution form election, or Scheduled Withdrawal Date, is made. If the distribution of such Participants Distributable Amount with respect to a Plan Year (in the case of a change in his distribution election form), or the distribution of the Withdrawal Amount with respect to such Plan Year (in the case of a change in his Scheduled Withdrawal Date), is made or commence before the election to change his distribution form election or Scheduled Withdrawal Date, as the case may be, becomes effective, the election to change his distribution form election or Scheduled Withdrawal Date shall not thereafter become effective, and distributions shall be made in accordance with the distribution form election, and Scheduled Withdrawal Date (if any), as applicable, in effect prior to the Participants election to change.
(2)
The Participants election to change his distribution election form with respect to a Plan Year, or change his Scheduled Withdrawal Date with respect to a Plan Year, shall provide that each payment with respect to such new distribution form election, or new Scheduled Withdrawal Date, shall be deferred for a period of not less than five years from the date such payment would otherwise have been made.
(3)
The Participants election to change his Scheduled Withdrawal Date with respect to a Plan Year shall not be made less than twelve (12) months prior to the date of the first scheduled payment under the Participants initial election of the Scheduled Withdrawal Date with respect to such Plan Year.
The limitations under this subsection (e) shall be applied in accordance with Section 409A of the Code
3.3
Employer Matching Contributions
(a)
The Company shall make an Employer Matching Contribution for each payroll date during a Plan Year, on behalf of each Participant who is employed by the Company on such payroll date, who has been employed by the Company for at least one year as of such payroll date, and who makes deferrals of Base Salary and/or Bonus under Article III, in an amount equal to:
(1)
the product of (A) 3% and (B) the sum of the deferrals of Base Salary and/or Bonus deferred under Article III for such payroll period; plus
(2)
the product of (A) 3% and (B) the difference between (I) the Participants Compensation for such payroll period and (II) the sum of the deferrals of Base Salary and/or Bonus deferred under Article III for such payroll period, reduced by (C) the amount of the matching contribution made under the 401(k) Plan for such payroll period not in excess of 3% of the Participants eligible 401(k) Plan compensation. Notwithstanding any other provision of the Plan to the contrary, no Employer Matching Contributions shall be made under this paragraph (2) unless and until the Participant has made to the 401(k) Plan the maximum elective contributions permitted under section 402(g) or the maximum pre-tax elective contributions permitted under the terms of the 401(k) Plan and in no event shall the Employer Matching Contributions made pursuant to this paragraph (2) exceed 100% of the matching contributions that would be provided under the 401(k) Plan absent any plan-based restrictions on contributions to qualified plans under the Code.
If a Participant is employed by more than one corporation that is included in the Company, the foregoing computation shall be applied to each such corporation based on the portion of the Plan Year during which the Participant was employed by such corporation. Notwithstanding the above, the Committee reserves the right to change or eliminate the Employer Matching Contribution in its sole discretion for any subsequent Plan Year.
(b)
The Employer Matching Contribution for a Plan Year shall be credited to a Participants Employer Matching Account in the manner determined by the Administrator.
3.4
FICA and Other Taxes.
(a)
Withholding, Generally. The Company shall have the right to withhold from any payments due under the Plan (or with respect to amounts credited to the Plan) any taxes required by law to be withheld in respect of such payment (or credit).
(b)
Annual Deferral Amounts. For each Plan Year in which a Participant who is an employee makes a deferral under Section 3.1, the Participants employer shall withhold from that portion of the Participants Compensation that is not being deferred, in a manner determined by the employer, the Participants share of FICA and other employment taxes on such amount. If necessary, the Administrator may reduce the Participant's deferrals under Section 3.1 or make deductions from his Deferral Account in order to comply with this Section 3.4, to the extent permitted under Section 409A of the Code.
(c)
Employer Matching Amounts. For each Plan Year in which a Participant is credited with a contribution to his Employer Matching Account under Section 3.3, the Participants employer shall withhold from the Participants Compensation that is not deferred, in a manner determined by the employer, the Participants share of FICA and other employment taxes. If necessary, the Administrator may reduce the Participants Employer Matching Account in order to comply with this Section 3.4, to the extent permitted under Section 409A of the Code.
(d)
Sempra Energy Stock Fund. With respect to distributions of all or a portion of balances invested in the Sempra Energy Stock Fund, withholding obligations shall be satisfied through the surrender of the applicable withholding percentage of such distributed balances (or portion thereof) in the Sempra Energy Stock Fund. Unless otherwise approved by the Committee, withholding obligations for Restricted Stock Units deferred into the Plan shall be satisfied by payment by the applicable Participant, deducted from other Compensation payable to such Participant which has not been deferred under the Plan, or a combination of these methods.
ARTICLE IV.
INVESTMENTS
4.1
Measurement Funds.
(a)
Election of Measurement Funds, In the manner designated by the Administrator, Participants may elect one or more Measurement Funds to be used to determine the additional amounts to be credited to their Accounts. Although the Participant may designate the Measurement Funds, the Committee shall not be bound by such designation; provided, however, that any substitute Measurement Funds designated by the Committee for a Participant must provide the Participant with an investment opportunity comparable to the original Measurement Funds designated by the Participant. The Committee shall select from time to time, in its sole discretion, the Measurement Funds to be available under the Plan; provided, however, that such Measurement Funds shall be the same as the investment funds which are available from time to time under the 401(k) Plan, except to the extent prohibited by law.
(b)
No Actual Investment. Notwithstanding any other provision of this Plan that may be interpreted to the contrary, the Measurement Funds are to be used for measurement purposes only, and a Participants election of any such Measurement Fund, the allocation to his Accounts thereto, the calculation of additional amounts and the crediting or debiting of such amounts to a Participants Accounts shall not be considered or construed in any manner as an actual investment of his Accounts in any such Measurement Fund. In the event that the Administrator, the Committee, or the trustee, as applicable, in its own discretion, decides to invest funds in any or all of the Measurement Funds, no Participant shall have any rights in or to such investments themselves. Without limiting the foregoing, a Participants Accounts shall at all times be a bookkeeping entry only and shall not represent any investment made on his behalf by the Company. The Participant shall at all times remain an unsecured creditor of the Company
4.2
Investment Elections.
(a)
Participants.
(1)
Deferral Accounts. Except as provided in paragraph 4.2(a)(2) and Section 4.3, Participants may designate how their Deferral Accounts shall be deemed to be invested under the Plan.
(A)
Such Participants may make separate investment elections for (I) their future deferrals of Compensation and (II) the existing balances of their Deferral Accounts.
(B)
Such Participants may make and change their investment elections by choosing from the Measurement Funds designated by the Committee in accordance with the procedures established by the Administrator.
(C)
Except as otherwise designated by the Committee, the available Measurement Funds under this paragraph 4.2(a)(1) shall be the investment funds under the 401(k) Plan (excluding the Stable Value Fund and any brokerage account option).
(D)
If a Participant fails to elect a Measurement Fund under this Section 4.2(a), he shall be deemed to have elected the Measurement Fund based on the Moodys Plus Rate (unless a different default fund is designated by the Committee) for all of his Accounts.
(2)
Employer Matching Account and Certain Deferral Subaccounts.
(A)
(2)
Employer Matching Account and Certain Deferral Subaccounts. Unless otherwise provided by the Administrator, Employer Matching Contributions credited to a Participants Employer Matching Account shall be invested in Measurement Funds in the same proportion as the corresponding deferrals of Compensation that are credited to his Deferral Account. A Participant may, however, transfer the investment of the Employer Matching Contributions credited to his Employer Matching Account into any Measurement Fund, as permitted by the Committee, and may change their investment elections by choosing from the Measurement Funds designated by the Committee in accordance with the procedures established by the Administrator. The deferrals of a Participants Restricted Stock Units credited to such Participants Deferral Account shall be deemed invested in the Sempra Energy Stock Fund and may not be moved into any other Measurement Fund.
(B)
The deferrals of Elective Phantom Share Amounts and Nonelective Phantom Share Amounts credited to a Participants Deferral Account shall be initially deemed invested in the Sempra Energy Stock Fund and shall remain deemed invested in the Sempra Energy Stock Fund until the Participants Separation from Service. After the Participants Separation from Service, a Participant may direct the investment of the Elective Phantom Share Amount subaccounts or Nonelective Phantom Share Amount subaccounts of the Participants Deferral Account into any other Measurement Fund, as permitted by the Committee.
(b)
Continuing Investment Elections. Participants who have had a Separation From Service but not yet commenced distributions under Article VII or Participants or Beneficiaries who are receiving installment payments may continue to make investment elections pursuant to subsection (a) above, as applicable, except as otherwise determined by the Committee.
4.3
Compliance with Section 16 of the Exchange Act.
(a)
Any Participant or Beneficiary who is subject to Section 16 of the Exchange Act shall have his Measurement Fund elections under the Plan subject to the requirements of the Exchange Act, as interpreted by the Committee. Any such Participant or Beneficiary who elects to have any portion of his Deferral Account or his future deferrals (pursuant to Section 3.1) either (i) invested in the Sempra Energy Stock Fund or (ii) transferred from the Sempra Energy Stock Fund to another available Measurement Fund under the Plan may not make an election with the opposite effect under this Plan or any other plan sponsored by Sempra Energy or any of its Affiliates until six (6) months and one (1) day following the original election.
(b)
Notwithstanding any other provision of the Plan or any rule, instruction, election form or other form, the Plan and any such rule, instruction or form shall be subject to any additional conditions or limitations set forth in any applicable exemptive rule under Section 16 of the Exchange Act (including any amendment to Rule 16b-3) that are requirements for the application of such exemptive rule. To the extent permitted by applicable law, such Plan provision, rule, instruction or form shall be deemed amended to the extent necessary to conform to such applicable exemptive rule.
ARTICLE V.
ACCOUNTS
5.1
Accounts.
(a)
The Administrator shall establish and maintain a Deferral Account, and an Employer Matching Account for each Participant under the Plan. Each Participants Accounts shall be divided into separate subaccounts in accordance with Section 5.2. Each such subaccount shall be further divided into separate investment fund subaccounts, each of which corresponds to a Measurement Fund elected by the Participant pursuant to Section 4.2. In addition, Participants Deferral Accounts shall be further divided into subaccounts consisting of deferred Restricted Stock Units, Elective Phantom Share Amounts, and Nonelective Phantom Share Amounts. A separate subaccount shall be maintained for each deferral of Restricted Stock Units, Nonelective Phantom Share Amount and Elective Phantom Share Amount.
(b)
The performance of each elected Measurement Fund (either positive or negative) shall be determined by the Administrator, in its reasonable discretion, based on the performance of the Measurement Funds themselves. A Participants Accounts shall be credited or debited on each Valuation Date, as determined by the Administrator in its reasonable discretion, based on the performance of each Measurement Fund selected by the Participant as though (i) a Participants Accounts were invested in the Measurement Fund(s) selected by the Participant, in the percentages applicable to such period, as of the close of business on the first business day of such period, at the closing price on such date; (ii) the portion of the Participant's Compensation that was actually deferred pursuant to Section 3.1 during any period were invested in the Measurement Fund(s) selected by the Participant, in the percentages applicable to such period, no later than the close of business on the first business day after the day on which such amounts are actually deferred from the Participants Compensation, at the closing price on such date; and (iii) any withdrawal or distribution made to a Participant that decreases such Participants Accounts ceased being invested in the Measurement Fund(s), in the percentages applicable to such period, no earlier than one (1) business day prior to the distribution, at the closing price on such date. The Participants Employer Matching Contribution for a Plan Year shall be credited to his Employer Matching Account for purposes of this Section 5.1(b), in the manner determined on the first day of the Election Period for such Plan Year, as determined by the Administrator.
5.2
Subaccounts.
(a)
The Administrator shall establish and maintain, with respect to a Participants Deferral Account, a subaccount with respect to each Plan Year, to which shall be credited the amount equal to the portion of the Participants Compensation earned during such Plan Year that he elects to defer pursuant to Section 3.1, debited by amounts equal to distributions to and withdrawals made by the Participant and/or his Beneficiary and adjusted for investment earnings and losses pursuant to Article V.
(b)
The Administrator shall establish and maintain, with respect to a Participants Employer Matching Account, a subaccount with respect to each Plan Year, to which shall be credited the amount equal to the Employer Matching Contributions made pursuant to Section 3.3 on behalf of such Participant in respect of such Participants Compensation earned during such Plan Year that he elects to defer pursuant to Section 3.1, debited by amounts equal to distributions to and withdrawals made by the Participant and/or his Beneficiary and adjusted for investment earnings and losses pursuant to Article V.
ARTICLE VI.
VESTING
(a)
Subject to subsections (b) and (c), each Participant shall be 100% vested in his Deferral Account and his Matching Account at all times.
(b)
A Participants deferred Restricted Stock Units credited to a subaccount of such Deferred Account shall be subject to the vesting conditions applicable to the Restricted Stock Unit award. The subaccount of such Participants Deferral Amount for a deferred Restricted Stock Unit award shall become vested in accordance with the vesting conditions applicable to such Restricted Stock Unit award. To the extent such Restricted Stock Unit award is forfeited, the subaccount of such Participants Deferral Account for such award shall be forfeited immediately following the event causing such forfeiture and the amount of such subaccount shall be debited from such Deferral Account.
(c)
A Participants deferred Elective Phantom Share Amount credited to a subaccount of such Participants Deferral Account shall be subject to the vesting conditions applicable to the initial or annual equity award for which such Elective Phantom Share Amount is credited. The subaccount of such Participants Deferral Account for a deferred Elective Phantom Share Amount shall become vested in accordance with the vesting conditions applicable to such equity award. To the extent such equity award is forfeited, the subaccount of such Participants Deferral Account for such Elective Phantom Share Amount shall be forfeited immediately following the event causing such forfeiture and the amount of such subaccount shall be debited from such Deferral Account.
ARTICLE VII.
DISTRIBUTIONS
7.1
Distribution of Accounts.
(a)
Distribution at Separation from Service or Disability.
(1)
Normal Form.
(A)
Except as provided in subparagraph (B), paragraph (2), paragraph (3) or Section 7.3, upon the Separation from Service or Disability of a Participant, a Participants Distributable Amount with respect to each Plan Year beginning on or after January 1, 2011 shall be paid to the Participant in a lump sum in cash (or shares of Sempra Energy common stock for Restricted Stock Unit subaccounts) on the Participants Payment Date. Except as provided in subparagraph (B), paragraph (2), paragraph (3) or Section 7.3, upon the Separation from Service or Disability of a Participant, a Participants Distributable Amount with respect to each Plan Year beginning prior to January 1, 2011 shall be paid to the Participant in substantially equal annual installments in cash (calculated as set forth in paragraph 7.1(a)(6) over ten (10) years beginning on the Participants Payment Date.
(B)
Upon the Separation from Service of a Participant who is a Specified Employee (determined as of the date of Separation from Service), the distribution of the Participants Distributable Amount with respect each Plan Year shall not be made before the date which is six (6) months after the date of such Participants Separation from Service (or, if earlier, the date of such Participants death) in accordance with Section 409A of the Code.
(2)
Optional Forms. Instead of receiving his Distributable Amount with respect to each Plan Year as described at subparagraph 7.1(a)(1)(A), the Participant may elect in accordance with Section 3.2 one of the following optional forms of payment (on the form provided by Administrator) (or shares of Sempra Energy common stock for Restricted Stock Unit subaccounts) at the time of his deferral election for such Plan Year:
(i)
equal annual installments in cash (or shares of Sempra Energy common stock for Restricted Stock Unit subaccounts) (calculated as set forth in paragraph 7.1(a)(6)) over five years beginning on the Participants Payment Date,
(ii)
equal annual installments in cash (or shares of Sempra Energy common stock for Restricted Stock Unit subaccounts) (calculated as set forth in paragraph 7.1a(a)(6)) over ten (10) years beginning on the Participants Payment Date, or
(iii)
equal annual installments in cash (or shares of Sempra Energy common stock for Restricted Stock Unit subaccounts) (calculated as set forth in paragraph 7.1(a)(6)) over fifteen (15) years beginning on the Participants Payment Date, or
(iv)
a lump sum in cash (or shares of Sempra Energy common stock for Restricted Stock Unit subaccounts) .
The payment of such Participants Distributable Amount with respect each Plan Year shall be made or commence on such Participants Payment Date (or, if applicable, the date determined under subparagraph (a)(1)(B)).
(3)
Distribution Election Changes. In the event that a Participant changes his distribution form election with respect to a Plan Year in accordance with Section 3.2(b), and such new distribution form election becomes effective, upon the Separation from Service or Disability of such Participant, the Distributable Amount with respect to such Plan Year shall be paid to the Participant in accordance with such new distribution form election.
(4)
Small Accounts. Notwithstanding provision to the contrary, in the event the total of a Participants Distributable Amounts with respect to all Plan Years is equal to or less than $25,000, such Distributable Amounts shall be distributed to the Participant (or his Beneficiary, as applicable) in a lump sum.
(5)
Investment Adjustments. The Participants Accounts shall continue to be adjusted for investment earnings and losses pursuant to Section 4.2 and Section 4.3 of the Plan until all amounts credited to his Accounts under the Plan have been distributed.
(6)
Calculating Installments. All installment payments made under the Plan shall be determined in accordance with the annual fractional payment method, calculated as follows: the balance of subaccounts in the Participants Accounts with respect to a Plan Year shall be calculated as of the close of business on the last business day of the year. The annual installment shall be calculated by multiplying this balance by a fraction, the numerator of which is one, and the denominator of which is the remaining number of annual payments due the Participant. By way of example, if the Participant elects 10 year installments for the distribution of the subaccounts in his Accounts with respect to a Plan Year, the first payment shall be 1/10 of the balance of such subaccounts in his Accounts calculated as described in this definition. The following year, the payment shall be 1/9 of such subaccounts in the balance of the Participants Accounts, calculated as described in this definition. Each annual installment shall be paid on or as soon as practicable after the last business day of the applicable year.
(b)
Distribution on a Scheduled Withdrawal Date.
(1)
In the case of a Participant who has elected a Scheduled Withdrawal Date for a distribution to be made prior to the Participants Separation from Service or while still a Director, such Participant shall receive his deferrals of Compensation (but excluding any investment earnings on such amounts) (the Withdrawal Amount) as shall have been elected by the Participant to be subject to the Scheduled Withdrawal Date. A Participants Scheduled Withdrawal Date with respect to amounts of Compensation deferred in a given Plan Year must be at least three years from the last day of the Plan Year for which such deferrals are made.
(2)
The Withdrawal Amount shall be paid in a lump sum in cash.
(3)
A Participant may elect to change the Scheduled Withdrawal Date for the Withdrawal Amount for any Plan Year in accordance with Section 3.2(d).
(4)
In the event of Participants Separation from Service or Disability prior to a Scheduled Withdrawal Date, the Participants entire Withdrawal Amount shall be paid in accordance with the Participants election with respect to such Plan Year under Section 7.1(a). In the event of a Participants death prior to a Scheduled Withdrawal Date, the Participants entire Withdrawal Amount shall be paid as soon as practicable after the Participants death in a lump sum in cash.
(c)
Distribution upon Death. In the event a Participant dies before he has begun receiving distributions under Section 7.1(a), his Accounts shall be paid to his Beneficiary in the same manner elected by the Participant. In the event a Participant dies after he has begun receiving distributions under Section 7.1(a) with a remaining balance in his Accounts, the balance shall continue to be paid to his Beneficiary in the same manner.
7.2
Hardship Distribution.
A Participant shall be permitted to elect a Hardship Distribution of all or a portion of his Accounts under the Plan prior to the Payment Date, subject to the following restrictions:
(a)
The election to take a Hardship Distribution shall be made by filing the form provided by the Administrator before the date established by the Administrator.
(b)
The Administrator shall have made a determination that the requested distribution constitutes a Hardship Distribution in accordance with subsection (d).
(c)
The amount determined by the Administrator as a Hardship Distribution shall be paid in a single lump sum in cash as soon as practicable after the end of the calendar month in which the Hardship Distribution election is made and approved by the Administrator. The Hardship Distribution shall be distributed proportionately from the subaccounts in the Participants Accounts.
(d)
If a Participant receives a Hardship Distribution, the Participant shall be ineligible to contribute deferrals to the Plan for the remainder of the Plan Year in which the Hardship Distribution is received or the immediately following Plan Year. Hardship Distribution shall mean a severe financial hardship to the Participant resulting from (i) an illness or accident of the Participant, the Participants spouse or of his dependent (as defined in Section 152(a) of the Code), (ii) loss of a Participants property due to casualty, or (iii) other similar extraordinary and unforeseeable circumstances arising as a result of events beyond the control of the Participant, as determined by the Administrator in accordance with Section 409A of the Code. The amount of the Hardship Distribution with respect to a severe financial hardship shall not exceed the amounts necessary to satisfy such hardship, plus amounts necessary to pay taxes reasonably anticipated as a result of the distribution, after taking into account the extent to which such hardship is or may be relieved through reimbursement or compensation by insurance or otherwise or by liquidation of the Participants assets (to the extent the liquidation of such assets would not itself cause severe financial hardship), as determined by the Administrator in accordance with Section 409A of the Code.
7.3
Effect of a Change in Control.
(a)
In the event there is a Change in Control, the person who is the chief executive officer (or, if not so identified, Sempra Energys highest ranking officer) shall name a third-party fiduciary as the sole member of the Committee immediately prior to such Change in Control. The appointed fiduciary, shall provide for the immediate distributions of the accounts under the Plan in lump sum payments and cash to the extent permitted under Section 409A of the Code.
(b)
Upon and after the occurrence of a Change in Control, the Company must (i) pay all reasonable administrative fees and expenses of the appointed fiduciary, (ii) indemnify the appointed fiduciary against any costs, expenses and liabilities including, without limitation, attorneys fees and expenses arising in connection with the appointed fiduciary's duties hereunder, other than with respect to matters resulting from the gross negligence of the appointed fiduciary or its agents or employees and (iii) timely provide the appointed fiduciary with all necessary information related to the Plan, the Participants and Beneficiaries.
(c)
Notwithstanding Section 9.3, in the event there is a Change in Control no amendment may be made to this Plan except as approved by the third-party fiduciary; provided, however, that in no event shall any amendment approved by the third-party fiduciary have any retroactive effect to reduce any vested amounts allocated to a Participants Accounts. Upon a Change in Control, assets shall be placed in a rabbi trust in an amount which shall equal the full accrued liability under this Plan as determined by Towers Perrin, or a successor actuarial firm.
7.4
Inability to Locate Participant.
In the event that the Administrator is unable to locate a Participant or Beneficiary within two years following the required Payment Date, the amount allocated to the Participants Accounts shall be forfeited. If, after such forfeiture, the Participant or Beneficiary later claims such benefit, such benefit shall be reinstated without interest or earnings from the date of forfeiture, subject to applicable escheat laws.
7.5
Prohibition on Acceleration of Distributions.
The time or schedule of payment of any withdrawal or distribution under the Plan shall not be subject to acceleration, except as provided or permitted under Section 409A of the Code (including, without limitation, acceleration on termination of the Plan or in connection with a change in control event within the meaning of Section 409A of the Code).
ARTICLE VIII.
ADMINISTRATION
8.1
Committee.
The Committee shall administer the Plan in accordance with this Article.
8.2
Administrator.
The Administrator, unless restricted by the Committee, shall exercise the powers under Sections 8.4 and 8.5 except when the exercise of such authority would materially affect the cost of the Plan to the Company or materially increase benefits to Participants.
8.3
Committee Action.
The Committee shall act at meetings by affirmative vote of a majority of the members of the Committee. Any action permitted to be taken at a meeting may be taken without a meeting if, prior to such action, a written consent to the action is signed by all members of the Committee and such written consent is filed with the minutes of the proceedings of the Committee. A member of the Committee shall not vote or act upon any matter which relates solely to himself or herself as a Participant. The chairman or any other member or members of the Committee designated by the chairman may execute any certificate or other written direction on behalf of the Committee.
8.4
Powers and Duties of the Committee.
The Committee, on behalf of the Participants and their Beneficiaries, shall enforce the Plan in accordance with its terms and shall have all powers necessary to accomplish its purposes as set forth herein, including, but not by way of limitation, the following:
(a)
To select the Measurement Funds in accordance with Section 4.1 hereof;
(b)
To conclusively construe and interpret the terms and provisions of the Plan and to remedy any inconsistencies or ambiguities hereunder;
(c)
To select employees eligible to participate in the Plan;
(d)
To compute and certify to the amount and kind of benefits payable to Participants and their Beneficiaries;
(e)
To maintain all records that may be necessary for the administration of the Plan;
(f)
To provide for the disclosure of all information and the filing or provision of all reports and statements to Participants, Beneficiaries or governmental agencies as shall be required by law;
(g)
To make and publish such rules for the regulation and operation of the Plan and procedures for the administration of the Plan as are not inconsistent with the terms hereof;
(h)
To appoint a plan administrator or any other agent, and to delegate to them such powers and duties in connection with the administration of the Plan as the Committee may from time to time prescribe; and
(i)
To take all actions necessary for the administration of the Plan.
8.5
Construction and Interpretation.
The Committee shall have full discretion to conclusively construe and interpret the terms and provisions of this Plan, which interpretations or construction shall be final and binding on all parties, including but not limited to the Company and any Participant or Beneficiary. The Committee shall administer such terms and provisions in accordance with any and all laws applicable to the Plan. The Committee or the Administrator may provide for different rules, rights and procedures for different Participants or Eligible Individuals and there is no requirement under the Plan that all Participants or Eligible Individuals receive the same benefits, payment rights, election rights or any other benefits or rights, subject to the requirements of applicable law.
8.6
Information.
The Company shall furnish the Administrator with such data and information as may be required for it to discharge its duties. Participants and other persons entitled to benefits under the Plan must furnish the Administrator such evidence, data or information as the Administrator considers necessary or desirable to carry out the terms of the Plan.
8.7
Compensation, Expenses and Indemnity.
(a)
The members of the Committee shall serve without compensation for their services hereunder.
(b)
The Committee is authorized at the expense of the Company to employ such legal counsel and other advisors as it may deem advisable to assist in the performance of its duties hereunder. Expenses and fees in connection with the administration of the Plan shall be paid by the Company.
(c)
To the extent permitted by applicable state law, the Company shall indemnify and save harmless the Committee and each member thereof, the Board of Directors and any delegate of the Committee who is an employee of the Company or any Affiliate and the Administrator against any and all expenses, liabilities and claims, including legal fees to defend against such liabilities and claims arising out of their discharge in good faith of responsibilities under or incident to the Plan, other than expenses and liabilities arising out of willful misconduct. This indemnity shall not preclude such further indemnities as may be available under insurance purchased by the Company or provided by the any bylaw, agreement or otherwise, of the Company as such indemnities are permitted under state law.
8.8
Quarterly Statements.
Under procedures established by the Administrator, a Participant shall receive a statement with respect to such Participants Accounts on a quarterly basis as of each March 31, June 30, September 30 and December 31.
8.9
Disputes.
(a)
Claim.
A person who believes that he is being denied a benefit to which he is entitled under the Plan (hereinafter referred to as Claimant) may file a written request for such benefit with the Administrator, setting forth his claim. The request must be addressed to the Administrator at Sempra Energy at its then principal place of business.
(b)
Claim Decision.
Upon receipt of a claim, the Administrator shall advise the Claimant that a reply shall be forthcoming within ninety (90) days and shall, in fact, deliver such reply within such period. The Administrator may, however, extend the reply period for an additional ninety (90) days for special circumstances.
If the claim is denied in whole or in part, the Administrator shall inform the Claimant in writing, using language calculated to be understood by the Claimant, setting forth: (i) the specified reason or reasons for such denial; (ii) the specific reference to pertinent provisions of this Agreement on which such denial is based; (iii) a description of any additional material or information necessary for the Claimant to perfect his claim and an explanation of why such material or such information is necessary; (iv) appropriate information as to the steps to be taken if the Claimant wishes to submit the claim for review; and (v) the time limits for requesting a review under subsection (c).
(c)
Request For Review.
With sixty (60) days after the receipt by the Claimant of the written opinion described above, the Claimant may request in writing a review the determination of the Administrator. Such review shall be completed by the most senior officer of Human Resources of Sempra Energy for Participants who are Managers and by the Committee for Participants who are Executive Officers or Directors. Such request must be addressed to the Secretary of Sempra Energy, at its then principal place of business. The Claimant or his duly authorized representative may, but need not, review the pertinent documents and submit issues and comments in writing for consideration by the most senior officer of Human Resources of Sempra Energy or the Committee, as applicable. If the Claimant does not request a review within such sixty (60)-day period, he shall be barred and estopped from challenging the Administrators determination.
(d)
Review of Decision.
Within sixty (60) days after the receipt of a request for review by the most senior officer of Human Resources of Sempra Energy or the Committee, as applicable, after considering all materials presented by the Claimant, the most senior officer of Human Resources of Sempra Energy or the Committee, as applicable, shall inform the Participant in writing, in a manner calculated to be understood by the Claimant, the decision setting forth the specific reasons for the decision contained specific references to the pertinent provisions of this Plan on which the decision is based. If special circumstances require that the sixty (60) day time period be extended, the most senior officer of Human Resources of Sempra Energy or the Committee, as applicable, shall so notify the Claimant and shall render the decision as soon as possible, but no later than one hundred and twenty (120) days after receipt of the request for review.
ARTICLE IX.
MISCELLANEOUS
9.1
Unsecured General Creditor.
Participants and their Beneficiaries, heirs, successors, and assigns shall have no legal or equitable rights, claims, or interest in any specific property or assets of the Company. No assets of the Company shall be held in any way as collateral security for the fulfilling of the obligations of the Company under this Plan. Any and all of the Companys assets shall be, and remain, the general unpledged, unrestricted assets of the Company. The Companys obligation under the Plan shall be merely that of an unfunded and unsecured promise of the Company to pay money in the future, and the rights of a Participant or Beneficiary shall be no greater than those of an unsecured general creditor of the Company. It is the intention of the Company that this Plan be unfunded for purposes of the Code and Title I of ERISA.
9.2
Restriction Against Assignment.
(a)
The Company shall pay all amounts payable hereunder only to the person or persons designated by the Plan and not to any other person or entity. No right, title or interest in the Plan or in any account may be sold, pledged, assigned or transferred in any manner other than by will or the laws of descent and distribution. No right, title or interest in the Plan or in any Account shall be liable for the debts, contracts or engagements of the Participant or his successors in interest or shall be subject to disposition by transfer, alienation, anticipation, pledge, encumbrance, assignment or any other means whether such disposition be voluntary or involuntary or by operation of law by judgment, levy, attachment, garnishment or any other legal or equitable proceedings (including bankruptcy), and any attempted disposition thereof shall be null and void and of no effect, except to the extent that such disposition is permitted by the preceding sentence.
(b)
Notwithstanding the provisions of subsection (a), a Participants interest in his Account may be transferred by the Participant pursuant to a domestic relations order that constitutes a qualified domestic relations order as defined by the Code or Title I of ERISA.
9.3
Amendment, Modification, Suspension or Termination.
(a)
Subject to Section 7.3, the Committee may amend, modify, suspend or terminate the Plan in whole or in part, except that no amendment, modification, suspension or termination shall have any retroactive effect to reduce any vested amounts allocated to a Participants Accounts. In the event of Plan termination, distributions shall continue to be made in accordance with the terms of the Plan, subject to the provisions of Section 7.3(a).
(b)
Notwithstanding anything to the contrary in the Plan, if and to the extent Sempra Energy shall determine that the terms of the Plan may result in the failure of the Plan, or amounts deferred by or for any Participant under the Plan, to comply with the requirements of Section 409A of the Code, Sempra Energy shall have authority to take such action to amend, modify, cancel or terminate the Plan or distribute any or all of the amounts deferred by or for a Participant, as it deems necessary or advisable, including without limitation:
(1)
Any amendment or modification of the Plan to conform the Plan to the requirements of Section 409A of the Code (including, without limitation, any amendment or modification of the terms of any applicable to any Participants Accounts regarding the timing or form of payment).
(2)
Any cancellation or termination of any unvested interest in a Participants Accounts without any payment to the Participant.
(3)
Any cancellation or termination of any vested interest in any Participants Accounts, with immediate payment to the Participant of the amount otherwise payable to such Participant.
Any such amendment, modification, cancellation, or termination of the Plan may adversely affect the rights of a Participant without the Participants consent.
9.4
Designation of Beneficiary.
(a)
Each Participant shall have the right to designate, revoke and redesignate Beneficiaries hereunder and to direct payment of his Distributable Amount to such Beneficiaries upon his death.
(b)
Designation, revocation and redesignation of Beneficiaries must be made in writing in accordance with the procedures established by the Administrator and shall be effective upon delivery to the Committee.
(c)
No designation of a Beneficiary other than the Participants spouse shall be valid unless consented in writing by such spouse. If there is no Beneficiary designation in effect, or the designated beneficiary does not survive the Participant, then the Participants spouse shall be the Beneficiary. If there is no surviving spouse, the duly appointed and currently acting personal representative of the Participants estate (which shall include either the Participants probate estate or living trust) shall be the Beneficiary.
(d)
After the Participants death, any Beneficiary (other than the Participants estate) who is to receive installment payments may designate a secondary beneficiary to receive amounts due under this Plan to the Beneficiary in the event of the Beneficiarys death prior to receiving full payment from the Plan. If no secondary beneficiary is designated, it shall be the Beneficiarys estate.
9.5
Insurance.
(a)
As a condition of participation in this Plan, each Participant shall, if requested by the Administrator, the Committee or the Company, undergo such examination and provide such information as may be required by the Company with respect to any insurance contracts on the Participants life and shall authorize the Company to purchase life insurance on his life, payable to the Company
(b)
If the Company maintains an insurance policy on a Participants life to fund benefits under the Plan and such insurance policy is invalidated because (i) the Participant commits suicide during the two-year period beginning on the first day of the first Plan Year of such Participants participation in the Plan or because (ii) the Participant makes any material misstatement of information or nondisclosure of medical history, then, to the extent determined by the Administrator in its sole discretion, the only benefits that shall be payable hereunder to such Participant, his Beneficiary or his surviving spouse, are the payment of the amount of deferrals of Compensation then credited to the Participants Accounts but without any interest including interest theretofore credited under this Plan.
9.6
Governing Law.
Subject to ERISA, this Plan shall be construed, governed and administered in accordance with the laws of the State of California.
9.7
Receipt of Release.
Any payment to a Participant or the Participants Beneficiary in accordance with the provisions of the Plan shall, to the extent thereof, be in full satisfaction of all claims against the Administrator, the Committee and the Company. The Administrator may require such Participant or Beneficiary, as a condition precedent to such payment, to execute a receipt and release to such effect prior to the payment date specified under the Plan.
9.8
Payments Subject to Section 162(m) of the Code
To the extent Sempra Energy reasonably anticipates that, if a distribution under the Plan were made as scheduled, Sempra Energys deduction with respect to such payment would not be permitted due to the application of Section 162(m) of the Code, Sempra Energy, in the discretion of the Committee, may delay the distribution; provided, however, that any such delayed distribution shall be made either (a) during the Participants first taxable year in which Sempra Energy reasonably anticipates, or should reasonably anticipate, that, if the payment is made during such year, the deduction of such payment will not be barred by application of Section 162(m) of the Code or (b) during the period beginning with the date of the Participants Separation from Service and ending on the later of (i) the last day of the year in which the Participants Separation from Service occurs or (ii) within 2-1/2 months following the Participants Separation from Service; and provided further that, where any scheduled payment to a specific Participant is delayed in Sempra Energys taxable year accordance with this Section 9.9, the delay in payment will be treated as a subsequent deferral election under Section 409A of the Code unless all scheduled payments to that Participant that could be delayed in accordance with this Section 9.9 are also delayed. Any amounts deferred pursuant to this limitation shall continue to be credited/debited with additional amounts in accordance with Article IV, even if such amount is being paid out in installments. Notwithstanding anything to the contrary in this Plan, this Section 9.9 shall not apply to any distributions made after a Change in Control.
9.9
Payments on Behalf of Persons Under Incapacity.
In the event that any amount becomes payable under the Plan to a person who, in the sole judgment of the Administrator, is considered by reason of physical or mental condition to be unable to give a valid receipt therefore, the Administrator may direct that such payment be made to any person found by the Administrator, in its sole judgment, to have assumed the care of such person. Any payment made pursuant to such termination shall constitute a full release and discharge of the Administrator, the Committee and the Company.
9.10
Limitation of Rights
Neither the establishment of the Plan nor any modification thereof, nor the creating of any fund or account, nor the payment of any benefits shall be construed as giving to any Participant or other person any legal or equitable right against the Company except as provided in the Plan. In no event shall the terms of employment of, or membership on the Board by, any Participant be modified or in any be effected by the provisions of the Plan.
9.11
Exempt ERISA Plan
The Plan is intended to be an unfunded plan maintained primarily to provide deferred compensation benefits for directors and a select group of management or highly compensated employees within the meaning of Sections 201, 301 and 401 of ERISA and therefore to be exempt from Parts 2, 3 and 4 of Title I of ERISA.
9.12
Notice
Any notice or filing required or permitted to be given to the Administrator or the Committee under the Plan shall be sufficient if in writing and hand delivered, or sent by registered or certified mail, to the principal office of Sempra Energy, directed, in the case of the Committee, to the attention of the General Counsel and Secretary of Sempra Energy and in the case of the Administrator, to the Administrator. Such notice shall be deemed given as of the date of delivery or, if delivery is made by mail, as of the date shown on the postmark on the receipt for registration or certification.
9.13
Errors and Misstatements
In the event of any misstatement or omission of fact by a Participant to the Committee or the Administrator or any clerical error resulting in payment of benefits in an incorrect amount, the Committee or the Administrator, as applicable, shall promptly cause the amount of future payments to be corrected upon discovery of the facts and shall pay or, if applicable, cause the Plan to pay, the Participant or any other person entitled to payment under the Plan any underpayment in a lump sum or to recoup any overpayment from future payments to the Participant or any other person entitled to payment under the Plan in such amounts as the Committee or the Administrator shall direct or to proceed against the Participant or any other person entitled to payment under the Plan for recovery of any such overpayment.
9.14
Pronouns and Plurality
The masculine pronoun shall include the feminine pronoun, and the singular the plural where the context so indicates.
9.15
Severability
In the event that any provision of the Plan shall be declared unenforceable or invalid for any reason, such unenforceability or invalidity shall not affect the remaining provisions of the Plan but shall be fully severable, and the Plan shall be construed and enforced as if such unenforceable or invalid provision had never been included herein.
9.16
Status
The establishment and maintenance of, or allocations and credits to, the Accounts of any Participant shall not vest in any Participant any right, title or interest in and to any Plan assets or benefits except at the time or times and upon the terms and conditions and to the extent expressly set forth in the Plan.
9.17
Headings.
Headings and subheadings in this Plan are inserted for convenience of reference only and are not to be considered in the construction of the provisions hereof.
ARTICLE X.
EMPLOYEES OF SEMPRA ENERGY TRADING CORPORATION
AND SEMPRA ENERGY SOLUTIONS LLC
This Article X includes special provisions relating to the benefits of the Participants in the Plan who are employed by Sempra Energy Trading Corporation (SET) and Sempra Energy Solutions LLC (SES).
(a)
Background. Certain SET and SES employees are Participants in this Plan.
On July 9, 2007, Sempra Energy, Sempra Global, Sempra Energy Trading International, B.V. (SETI) and The Royal Bank of Scotland plc (RBS) entered into the Master Formation and Equity Interest Purchase Agreement, dated as of July 9, 2007 (the Master Formation Agreement), which provides for the formation of a partnership, RBS Sempra Commodities LLP (RBS Sempra Commodities), to purchase and operate Sempra Energys commodity-marketing businesses. Pursuant to a Master Formation Agreement, RBS Sempra Commodities will be formed as a United Kingdom limited liability partnership and RBS Sempra Commodities will purchase Sempra Energys commodity-marketing subsidiaries.
Prior to the Closing, SET will be converted into a limited liability company (SET LLC). Following such conversion, SET employees will be employed by SET LLC. Prior to the Closing, SES will become a wholly-owned subsidiary of SET LLC.
Also, prior to the Closing, Sempra Energy will own, directly or indirectly through wholly-owned subsidiaries, 100% of the membership interests in SET LLC and SES. Prior to the Closing, SET LLC and SES will be disregarded entities for federal income tax purposes.
Effective as of the Closing, RBS Sempra Commodities will purchase 100% of the membership interests in SET LLC.
As provided in the Master Formation Agreement, an employee of SET LLC who is actively at work on the Closing Date will continue to be employed by SET LLC immediately after the Closing Date, and an employee of SES who is actively at work on the Closing Date will continue to be employed by SES (each such employee is referred to as a Transferred Employee).
Also, as provided in the Master Formation Agreement, with respect to an employee of SET LLC or SES who is not actively at work on the Closing Date because such employee is on approved short-term disability or long-term disability leave in accordance with the Sempra Plans (such employee is referred to as an Inactive Employee), if such Inactive Employee returns to active work at the conclusion of such leave, and in any case within six (6) months following the Closing Date (or such longer period as is required by applicable law), such Inactive Employee shall become a Transferred Employee as of the date of such persons return to active employment with the SET LLC or SES (such date is referred to as the Transfer Date).
Effective as of the Closing, SET LLC will be a wholly-owned subsidiary of RBS Sempra Commodities, SES will be an indirect, wholly-owned subsidiary of RBS Commodities, Sempra Global and SETI will be partners in RBS Sempra Commodities, and Sempra Energy will own, indirectly through wholly-owned subsidiaries, at least a 50% profits interest in RBS Sempra Commodities.
(b)
Separation from Service
(1)
Effective as of the Closing, RBS Sempra Commodities will be a member of a group of trades or businesses (whether or not incorporated) under common control for purposes of Section 414(c) of the Code and Treasury Regulation Section 1.414(c)-2, as determined under Section 409A of the Code, that includes Sempra Energy and its wholly-owned subsidiaries. Consequently, effective as of the Closing, RBS Sempra Commodities will be included in the service recipient that includes Sempra Energy and its wholly-owned subsidiaries, as defined under Section 409A of the Code.
(2)
A Participant who is an employee of SET LLC or SES, and who is a Transferred Employee effective as of the Closing Date, will not have a Separation from Service solely as a result of the purchase of the membership interests of SET LLC by RBS Sempra Commodities effective as of the Closing.
(3)
A Participant who is an employee of SET LLC or SES, who is an Inactive Employee, and who becomes a Transferred Employee effective on a Transfer Date after the Closing Date, will not have a Separation from Service solely as a result of the purchase of the membership interests of SET LLC by RBS Sempra Commodities or becoming a Transferred Employee on a Transfer Date after the Closing Date.
(4)
For purposes of the Plan, a participant in the Plan who is an employee of SET LLC or SES, and who is or becomes a Transferred Employee, will have a Separation from Service on or after the Closing Date (or the Transfer Date, if applicable), as determined under Section 1.2(pp) and Section 409A of the Code.
(c)
Certain Defined Terms.
For purposes of this Article X, the terms Closing, Closing Date, Inactive Employee, Sempra Plans, Transferred Employees and Transfer Date shall have the meanings ascribed to such terms under the Master Formation Agreement.
ARTICLE XI.
SECTION 409A OF THE CODE
Anything in this Plan to the contrary notwithstanding, it is intended that any amounts payable under this Agreement shall either be exempt from or comply with Section 409A of the Code so as not to subject any Participant to payment of any additional tax, penalty or interest imposed under Section 409A of the Code. The provisions of this Agreement shall be construed and interpreted to avoid the imputation of any such additional tax, penalty or interest under Section 409A of the Code yet preserve (to the nearest extent reasonably possible) the intended benefit payable to Participant. In no event shall the Company guarantee the tax treatment of participation in the Plan or any benefit provided hereunder. Notwithstanding any other provision of the Plan, in the event any of the amounts deferred or payable under the Plan are grandfathered for purposes of Section 409A of the Code, such amounts shall be subject to the terms and conditions that applied to such amounts prior to the effective date of Section 409A of the Code.
Executed at San Diego, California this ___ day of __________, 2015.
SEMPRA ENERGY
By:
______________________________
Title:
Sr. Vice President, Human Resources
Date:
______________________, 2015
EXHIBIT 12.2 | |||||||||||||||||||
SAN DIEGO GAS & ELECTRIC COMPANY | |||||||||||||||||||
COMPUTATION OF RATIO OF EARNINGS TO COMBINED FIXED CHARGES | |||||||||||||||||||
AND PREFERRED STOCK DIVIDENDS | |||||||||||||||||||
(Dollars in millions) | |||||||||||||||||||
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| |
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|
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|
|
|
|
|
|
|
|
| June 30, | |
|
|
| 2010 |
|
| 2011 |
|
| 2012 |
|
| 2013 |
|
| 2014 |
|
| 2015 | |
Fixed charges and preferred |
|
|
|
|
|
|
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|
|
|
|
|
|
|
|
|
|
| |
stock dividends: |
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
Interest |
| $ | 153 |
| $ | 193 |
| $ | 220 |
| $ | 231 |
| $ | 238 |
| $ | 122 | |
Interest portion of annual rentals |
|
| 1 |
|
| 1 |
|
| 1 |
|
| 1 |
|
| 1 |
|
| - | |
Total fixed charges |
|
| 154 |
|
| 194 |
|
| 221 |
|
| 232 |
|
| 239 |
|
| 122 | |
Preferred stock dividends (1) |
|
| 7 |
|
| 7 |
|
| 7 |
|
| 5 |
|
| - |
|
| - | |
Combined fixed charges and preferred stock dividends for purpose of ratio |
| $ | 161 |
| $ | 201 |
| $ | 228 |
| $ | 237 |
| $ | 239 |
| $ | 122 | |
Earnings: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
Pretax income from continuing operations |
| $ | 531 |
| $ | 692 |
| $ | 705 |
| $ | 626 |
| $ | 797 |
| $ | 423 | |
Add: Total fixed charges (from above) |
|
| 154 |
|
| 194 |
|
| 221 |
|
| 232 |
|
| 239 |
|
| 122 | |
Less: Interest capitalized |
|
| 1 |
|
| 1 |
|
| - |
|
| - |
|
| 1 |
|
| - | |
Total earnings for purpose of ratio |
| $ | 684 |
| $ | 885 |
| $ | 926 |
| $ | 858 |
| $ | 1,035 |
| $ | 545 | |
Ratio of earnings to combined fixed charges and preferred stock dividends |
|
| 4.25 |
|
| 4.40 |
|
| 4.06 |
|
| 3.62 |
|
| 4.33 |
|
| 4.47 | |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
Ratio of earnings to fixed charges |
|
| 4.44 |
|
| 4.56 |
|
| 4.19 |
|
| 3.70 |
|
| 4.33 |
|
| 4.47 | |
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(1) | In computing this ratio, Preferred stock dividends represents the before-tax earnings necessary to pay such dividends, computed at the effective tax rates for the applicable periods. |
EXHIBIT 12.3 |
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SOUTHERN CALIFORNIA GAS COMPANY |
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| |||||||||||||||||
COMPUTATION OF RATIO OF EARNINGS TO COMBINED FIXED CHARGES |
|
| |||||||||||||||||
AND PREFERRED STOCK DIVIDENDS |
|
| |||||||||||||||||
(Dollars in millions) |
|
| |||||||||||||||||
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| June 30, | |
|
|
| 2010 |
|
| 2011 |
|
| 2012 |
|
| 2013 |
|
| 2014 |
|
| 2015 | |
Fixed charges and preferred stock dividends: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
Interest |
| $ | 72 |
| $ | 77 |
| $ | 77 |
| $ | 76 |
| $ | 77 |
| $ | 44 | |
Interest portion of annual rentals |
|
| 2 |
|
| 1 |
|
| 1 |
|
| 1 |
|
| 2 |
|
| 1 | |
Total fixed charges |
|
| 74 |
|
| 78 |
|
| 78 |
|
| 77 |
|
| 79 |
|
| 45 | |
Preferred stock dividends (1) |
|
| 2 |
|
| 2 |
|
| 2 |
|
| 2 |
|
| 2 |
|
| 1 | |
Combined fixed charges and preferred stock dividends for purpose of ratio |
| $ | 76 |
| $ | 80 |
| $ | 80 |
| $ | 79 |
| $ | 81 |
| $ | 46 | |
Earnings: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
Pretax income from continuing operations |
| $ | 463 |
| $ | 431 |
| $ | 369 |
| $ | 481 |
| $ | 472 |
| $ | 396 | |
Add: Total fixed charges (from above) |
|
| 74 |
|
| 78 |
|
| 78 |
|
| 77 |
|
| 79 |
|
| 45 | |
Less: Interest capitalized |
|
| 1 |
|
| 1 |
|
| 1 |
|
| 1 |
|
| 1 |
|
| - | |
Total earnings for purpose of ratio |
| $ | 536 |
| $ | 508 |
| $ | 446 |
| $ | 557 |
| $ | 550 |
| $ | 441 | |
Ratio of earnings to combined fixed charges and preferred stock dividends |
|
| 7.05 |
|
| 6.35 |
|
| 5.58 |
|
| 7.05 |
|
| 6.79 |
|
| 9.59 | |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| |
Ratio of earnings to fixed charges |
|
| 7.24 |
|
| 6.51 |
|
| 5.72 |
|
| 7.23 |
|
| 6.96 |
|
| 9.80 | |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) | In computing this ratio, Preferred stock dividends represents the before-tax earnings necessary to pay such dividends, computed at the effective tax rates for the applicable periods. |
EXHIBIT 31.1
CERTIFICATION
I, Debra L. Reed, certify that:
1.
I have reviewed this report on Form 10-Q of Sempra Energy;
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.
The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c)
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and
d)
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.
The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
August 4, 2015
/s/ Debra L. Reed |
Debra L. Reed |
Chief Executive Officer |
EXHIBIT 31.2
CERTIFICATION
I, Joseph A. Householder, certify that:
1.
I have reviewed this report on Form 10-Q of Sempra Energy;
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.
The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c)
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and
d)
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.
The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
August 4, 2015
/s/ Joseph A. Householder |
Joseph A. Householder |
Chief Financial Officer |
EXHIBIT 31.3
CERTIFICATION
I, J. Walker Martin, certify that:
1.
I have reviewed this report on Form 10-Q of San Diego Gas & Electric Company;
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.
The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c)
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and
d)
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.
The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
August 4, 2015
/s/ J. Walker Martin |
J. Walker Martin |
Chief Executive Officer |
EXHIBIT 31.4
CERTIFICATION
I, Bruce A. Folkmann, certify that:
1.
I have reviewed this report on Form 10-Q of San Diego Gas & Electric Company;
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.
The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c)
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and
d)
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.
The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
August 4, 2015
/s/ Bruce A. Folkmann |
Bruce A. Folkmann |
Chief Financial Officer |
EXHIBIT 31.5
CERTIFICATION
I, Dennis V. Arriola, certify that:
1.
I have reviewed this report on Form 10-Q of Southern California Gas Company;
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.
The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c)
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and
d)
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.
The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
August 4, 2015
/s/ Dennis V. Arriola |
Dennis V. Arriola |
Chief Executive Officer |
EXHIBIT 31.6
CERTIFICATION
I, Bruce A. Folkmann, certify that:
1.
I have reviewed this report on Form 10-Q of Southern California Gas Company;
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.
The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15d-15(f)) for the registrant and have:
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c)
Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report, based on such evaluation; and
d)
Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.
The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.
August 4, 2015
/s/ Bruce A. Folkmann |
Bruce A. Folkmann |
Chief Financial Officer |
Exhibit 32.1
Statement of Chief Executive Officer
Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Executive Officer of Sempra Energy (the "Company") certifies that:
(i)
the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2015 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and
(ii)
the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
August 4, 2015
/s/ Debra L. Reed |
Debra L. Reed |
Chief Executive Officer |
Exhibit 32.2
Statement of Chief Financial Officer
Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Financial Officer of Sempra Energy (the "Company") certifies that:
(i)
the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2015 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and
(ii)
the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
August 4, 2015
Exhibit 32.3
Statement of Chief Executive Officer
Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Executive Officer of San Diego Gas & Electric Company (the "Company") certifies that:
(i)
the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2015 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and
(ii)
the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
August 4, 2015
/s/ J. Walker Martin |
J. Walker Martin |
Chief Executive Officer |
Exhibit 32.4
Statement of Chief Financial Officer
Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Financial Officer of San Diego Gas & Electric Company (the "Company") certifies that:
(i)
the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2015 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and
(ii)
the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
August 4, 2015
/s/ Bruce A. Folkmann |
Bruce A. Folkmann |
Chief Financial Officer |
Exhibit 32.5
Statement of Chief Executive Officer
Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Executive Officer of Southern California Gas Company (the "Company") certifies that:
(i)
the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2015 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and
(ii)
the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
August 4, 2015
/s/ Dennis V. Arriola |
Dennis V. Arriola |
Chief Executive Officer |
Exhibit 32.6
Statement of Chief Financial Officer
Pursuant to 18 U.S.C. Sec 1350, as created by Section 906 of the Sarbanes-Oxley Act of 2002, the undersigned Chief Financial Officer of Southern California Gas Company (the "Company") certifies that:
(i)
the Quarterly Report on Form 10-Q of the Company filed with the Securities and Exchange Commission for the quarter ended June 30, 2015 (the "Quarterly Report") fully complies with the requirements of Section 13(a) or Section 15(d), as applicable, of the Securities Exchange Act of 1934, as amended; and
(ii)
the information contained in the Quarterly Report fairly presents, in all material respects, the financial condition and results of operations of the Company.
August 4, 2015
/s/ Bruce A. Folkmann |
Bruce A. Folkmann |
Chief Financial Officer |