UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
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| (Mark One) |
| þ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
| | For the quarterly period ended March 31, 20162017 |
| o | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
| | For the transition period from to |
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Commission File Number | | Exact Name of Registrant as specified in its charter | | State or Other Jurisdiction of Incorporation or Organization | | IRS Employer Identification Number |
| 1-9936 | | EDISON INTERNATIONAL | | California | | 95-4137452 |
| 1-2313 | | SOUTHERN CALIFORNIA EDISON COMPANY | | California | | 95-1240335 |
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| EDISON INTERNATIONAL | | SOUTHERN CALIFORNIA EDISON COMPANY |
2244 Walnut Grove Avenue (P.O. Box 976) Rosemead, California 91770 (Address of principal executive offices) | | 2244 Walnut Grove Avenue (P.O. Box 800) Rosemead, California 91770 (Address of principal executive offices) |
(626) 302-2222 (Registrant's telephone number, including area code) | | (626) 302-1212 (Registrant's telephone number, including area code) |
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Edison International Yes þ No o Southern California Edison Company Yes þ No o
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).
Edison International Yes þ No o Southern California Edison Company Yes þ No ¨
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Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company, or an emerging growth company. See the definitions of "accelerated filer," "large accelerated filer," andaccelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-12 of the Exchange Act. (Check One): |
| Edison International | Large Accelerated Filer þ | Accelerated Filer ¨ | Non-accelerated Filer ¨ | Smaller Reporting Company ¨ | Emerging growth company ¨ |
| Southern California Edison Company | Large Accelerated Filer ¨ | Accelerated Filer ¨ | Non-accelerated Filer þ | Smaller Reporting Company ¨ | Emerging growth company ¨ |
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| If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. |
| Edison International | ¨ | Southern California Edison Company | ¨ |
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Edison International Yes ¨ No þ Southern California Edison Company Yes ¨ No þ
Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date:
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Common Stock outstanding as of April 28, 2016:2017: | | |
| Edison International | | 325,811,206 shares |
| Southern California Edison Company | | 434,888,104 shares |
TABLE OF CONTENTS
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| | | | | | | SEC Form 10-Q Reference Number |
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| | Part I, Item 2 |
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| | Part II, Item 1 |
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| | Part II, Item 6 |
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This is a combined Form 10-Q separately filed by Edison International and Southern California Edison Company. Information contained herein relating to an individual company is filed by such company on its own behalf. Each company makes representations only as to itself and makes no other representation whatsoever as to any other company.
GLOSSARY
The following terms and abbreviations appearing in the text of this report have the meanings indicated below.
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AFUDC | | allowance for funds used during construction |
20152016 Form 10-K | | Edison International's and SCE's combined Annual Report on Form 10-K for the year-ended December 31, 20152016 |
| AFUDC | | allowance for funds used during construction |
| ALJ | | administrative law judge |
APS | | Arizona Public Service Company |
| ARO(s) | | asset retirement obligation(s) |
| Bcf | | billion cubic feet |
| Bonus Depreciation | | Current federal tax deduction of a percentage of the qualifying property placed in service during periods permitted under tax laws |
CAABRRBA | | Clean Air ActBase Revenue Requirement Balancing Account |
| CAISO | | California Independent System Operator |
CARB | | California Air Resources Board |
Competitive Businesses | | businesses focused on providing energy services, including distributed generation and/or storage, to commercial and industrial customers; engaging in competitive transmission opportunities; and exploring distributed water treatment and recycling. |
| CPUC | | California Public Utilities Commission |
CRRsDERs | | congestion revenue rightsdistributed energy resources |
| DOE | | U.S. Department of Energy |
| DRP | | Distributed Resources Plan |
| Edison Energy | | Edison Energy, LLC, a wholly-owned subsidiary of Edison Energy Group that advises and one of the Competitive Businessesprovides energy solutions to large energy users |
| Edison Energy Group | | Edison Energy Group, Inc., the holding company for the Competitive Businessessubsidiaries engaged in competitive businesses focused on providing energy services, including distributed generation, and/or storage to commercial and industrial customers |
| EME | | Edison Mission Energy |
EME Settlement Agreement | | Settlement Agreement entered into by Edison International, EME, and the Consenting Noteholders in February 2014 |
| EMG | | Edison Mission Group Inc. |
EPS | | earnings per share, a wholly owned subsidiary of Edison International and the parent company of EME and Edison Capital |
| ERRA | | energy resource recovery account |
| FERC | | Federal Energy Regulatory Commission |
Four Corners | | coal fueled electric generating facility located in Farmington, New Mexico in
which SCE held a 48% ownership interest
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| GAAP | | generally accepted accounting principles used in the United States |
| GHG | | greenhouse gas |
| GRC | | general rate case |
| GWh | | gigawatt-hours |
| HLBV | | hypothetical liquidation at book value |
| IRS | | Internal Revenue Service |
| Joint Proxy Statement | | Edison International's and SCE's definitive Proxy Statement to be filed with the SEC in connection with Edison International's and SCE's Annual Shareholders' Meeting to be held on April 28, 201627, 2017 |
| MD&A | | Management's Discussion and Analysis of Financial Condition and Results of Operations in this report |
| MHI | | Mitsubishi Heavy Industries, Ltd.Inc. and a related company |
Moody's | | Moody's Investors Servicecompanies |
| MW | | megawatts |
MWhMWdc | | megawatt-hours |
NAAQS | | national ambient air quality standardsmegawatts measured for solar projects representing the accumulated peak capacity of all the solar modules |
| NEIL | | Nuclear Electric Insurance Limited |
| NEM | | net energy metering |
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| NERC | | North American Electric Reliability Corporation |
| NRC | | Nuclear Regulatory Commission |
| ORA | | CPUC's Office of Ratepayers Advocates |
| OII | | Order Instituting Investigation |
| Palo Verde | | large pressurized water nuclear electric generating facility located near
Phoenix, Arizona in which SCE holds a 15.8% ownership interest |
| PBOP(s) | | postretirement benefits other than pension(s) |
PG&E | | Pacific Gas & Electric Company |
| QF(s) | | qualifying facility(ies) |
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| ROE | | return on common equity |
| S&P | | Standard & Poor's Ratings Services |
| San Onofre | | retired nuclear generating facility located in south San Clemente, California in which SCE holds a 78.21% ownership interest |
| San Onofre OII Settlement Agreement | | Settlement Agreement by and among SCE, The Utility Reform Network, the CPUC's Office of Ratepayer Advocates andTURN, ORA, SDG&E, which was later joined by the Coalition of California Utility Employees, and Friends of the Earth, (together, the "Settling Parties"), dated November 20, 2014 |
| SCE | | Southern California Edison Company |
| SDG&E | | San Diego Gas & Electric |
| SEC | | U.S. Securities and Exchange Commission |
| SED | | Safety and Enforcement Division of the CPUC, formerly known as the Consumer Protection and Safety Division or CPSD |
| SoCalGas | | Southern California Gas Company |
| SoCore Energy | | SoCore Energy LLC, a subsidiary of Edison Energy Group that provides solar energy and energy storage solutions |
| TURN | | The Utility Reform Network |
| US EPA | | U.S. Environmental Protection Agency |
VIE(s) | | variable interest entity(ies) |
FORWARD-LOOKING STATEMENTS
This quarterly report on Form 10-Q contains "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements reflect Edison International's and SCE's current expectations and projections about future events based on Edison International's and SCE's knowledge of present facts and circumstances and assumptions about future events and include any statementstatements that doesdo not directly relate to a historical or current fact. Other information distributed by Edison International and SCE that is incorporated in this report, or that refers to or incorporates this report, may also contain forward-looking statements. In this report and elsewhere, the words "expects," "believes," "anticipates," "estimates," "projects," "intends," "plans," "probable," "may," "will," "could," "would," "should," and variations of such words and similar expressions, or discussions of strategy or of plans, are intended to identify forward-looking statements. Such statements necessarily involve risks and uncertainties that could cause actual results to differ materially from those anticipated. Some of the risks, uncertainties and other important factors that could cause results to differ from those currently expected, or that otherwise could impact Edison International and SCE, include, but are not limited to the:
ability of SCE to recover its costs in a timely manner from its customers through regulated rates, including regulatory assetscosts related to San Onofre;Onofre and proposed spending on grid modernization;
decisions and other actions by the CPUC, the FERC, the NRC and other regulatory authorities, including determinations of authorized rates of return or return on equity, approval of proposed spending on grid modernization, the outcome of San Onofre CPUC proceedings, and delays in regulatory actions;
ability of Edison International or SCE to borrow funds and access the capital markets on reasonable terms;
risks associated with cost allocation, including the potential movement of costs to certain customers, caused by the ability of cities, counties, and certain other public agencies to generate and/or purchase electricity for their local residents and businesses, along with other possible customer bypass or departure due to increased adoption of DERs or technological advancements in the generation, storage, transmission, distribution, and use of electricity, and supported by public policy, government regulations and incentives;
risks inherent in the construction ofSCE's transmission and distribution infrastructure replacement and expansion projects,investment program, including those related to project site identification, public opposition, environmental mitigation, construction, permitting, power curtailment costs (payments due under power contracts in the event there is insufficient transmission to enable acceptance of power delivery), and governmental approvals;
risks associated with the operation of transmission and distribution assets and power generating facilities, including:including public safety issues, failure, availability, efficiency, and output of equipment and availability and cost of spare parts;
risks associated with the retirement and decommissioning of nuclear generating facilities;San Onofre, including those related to public opposition, permitting, governmental approvals, and cost overruns;
physical security of Edison International's and SCE's critical assets and personnel and the cybersecurity of Edison International's and SCE's critical information technology systems for grid control, and business and customer data;
abilitythe outcome of the strategic review of Edison InternationalEnergy Group, which may include changes to develop its Competitive Businesses, manage newexisting competitive business risks, and recover and earn a return on its investment in newly developed models and/or acquired businesses;exit of certain business activities;
cost and availability of electricity, including the ability to procure sufficient resources to meet expected customer needs in the event of power plant outages or significant counterparty defaults under power-purchasepower purchase agreements;
environmental laws and regulations, at both the state and federal levels, or changes in the application of those laws, that could require additional expenditures or otherwise affect the cost and manner of doing business;
changes in tax laws and regulations, at both the state and federal levels, or changes in the application of those laws, that could affect recorded deferred tax assets and liabilities and effective tax rate;
changes in the fair value of investments and other assets;
changes in interest rates and rates of inflation, including escalation rates, which may be adjusted by public utility regulators;
governmental, statutory, regulatory, or administrative changes or initiatives affecting the electricity industry, including the market structure rules applicable to each market adopted by the NERC, CAISO, WECC, NERC,Western Electricity Coordination Council, and similar regulatory bodies in adjoining regions;
availability and creditworthiness of counterparties and the resulting effects on liquidity in the power and fuel markets and/or the ability of counterparties to pay amounts owed in excess of collateral provided in support of their obligations;
cost and availability of labor, equipment, and materials;
ability to obtain sufficient insurance, including insurance relating to SCE's nuclear facilities and wildfire-related liability, and to recover the costs of such insurance or in the absence of insurance the ability to recover uninsured losses;
potential for penalties or disallowance for non-compliance with applicable laws and regulations;
cost of fuel for generating facilities and related transportation, which could be impacted by, among other things, disruption of natural gas storage facilities, to the extent not recovered through regulated rate cost escalation provisions or balancing accounts;
disruption of natural gas supply due to unavailability of storage facilities, which could lead to electricity service interruptions; and
weather conditions and natural disasters.
Additional information about risks and uncertainties, including more detail about the factors described in this report, is contained throughout this MD&Areport and in Edison International's and SCE's combined 2015the 2016 Form 10-K, including the "Risk Factors" section. Readers are urged to read this entire report, including the information incorporated by reference, as well as the 20152016 Form 10-K, and carefully consider the risks, uncertainties, and other factors that affect Edison International's and SCE's businesses. Forward-looking statements speak only as of the date they are made and neither Edison International nor SCE are obligated to publicly update or revise forward-looking statements. Readers should review future reports filed by Edison International and SCE with the SEC. Additionally, Edison International and SCE provide direct links to SCE's regulatory filings with the CPUC and the FERC in open proceedings most important to investors at www.edisoninvestor.com (SCE Regulatory Highlights) so that such filings are available to all investors upon SCE filing with the relevant agency. Edison International and SCE also routinely post or provide direct links to presentations, documents and other information that may be of interest to investors at www.edisoninvestor.com (Events and Presentations) in order to publicly disseminate such information.
The MD&A for the three months ended March 31, 20162017 discusses material changes in the consolidated financial condition, results of operations and other developments of Edison International and SCE since December 31, 2015,2016, and as compared to the three months ended March 31, 2015.2016. This discussion presumes that the reader has read or has access to Edison International's and SCE's MD&A for the calendar year 20152016 (the "year-ended 20152016 MD&A"), which was included in the 20152016 Form 10-K.
Except when otherwise stated, references to each of Edison International, SCE, EMG, Edison Energy Group, EME or Edison Capital mean each such company with its subsidiaries on a consolidated basis. References to "Edison International Parent and Other" mean Edison International Parent and its consolidated competitive subsidiaries.
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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
MANAGEMENT OVERVIEW
Highlights of Operating Results
Edison International is the parent holding company of SCE. SCE is a public utility primarily engaged in the business of supplying and delivering electricity to an approximately 50,000 square mile area of southern California. Edison International is also the parent company of Edison Energy Group, a holding company for subsidiaries that are engaged in pursing competitive businesses focused on providingbusiness opportunities across energy services and distributed solar to commercial and industrial customers, including distributed resources, engaging in transmission opportunities, and exploring distributed water treatment and recycling (the "Competitive Businesses").customers. Such business activities are currently not material to report as a separate business segment. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to Edison International Parent and Other refer to Edison International Parent and its competitive subsidiaries. Unless otherwise described, all of the information contained in this report relates to both filers.
| | | | | Three months ended March 31, | | | | Three months ended March 31, | | |
| (in millions) | | 2016 | | 2015 | | Change | | 2017 | | 20161 | | Change |
| Net income (loss) attributable to Edison International | | | | | | | Net income (loss) attributable to Edison International | | | | |
| Continuing operations | | | | | | | | | | | | |
| SCE | | $ | 287 |
| | $ | 305 |
| | $ | (18 | ) | | $ | 349 |
| | $ | 295 |
| | $ | 54 |
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| Edison International Parent and Other | | (17 | ) | | (6 | ) | | (11 | ) | | 13 |
| | (15 | ) | | 28 |
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| Discontinued operations | | 1 |
| | — |
| | 1 |
| | — |
| | 1 |
| | (1 | ) |
| Edison International | | 271 |
| | 299 |
| | (28 | ) | | 362 |
| | 281 |
| | 81 |
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| Less: Non-core items | | | | | | | | | | | | |
| SCE | | — |
| | — |
| | — |
| | — |
| | — |
| | — |
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| Edison International Parent and Other | | 2 |
| | 5 |
| | (3 | ) | | — |
| | 2 |
| | (2 | ) |
| Discontinued operations | | 1 |
| | — |
| | 1 |
| | — |
| | 1 |
| | (1 | ) |
| Total non-core items | | 3 |
| | 5 |
| | (2 | ) | | — |
| | 3 |
| | (3 | ) |
| Core earnings (losses) | | | | | | | | | | | | |
| SCE | | 287 |
| | 305 |
| | (18 | ) | | 349 |
| | 295 |
| | 54 |
|
| Edison International Parent and Other | | (19 | ) | | (11 | ) | | (8 | ) | | 13 |
| | (17 | ) | | 30 |
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| Edison International | | $ | 268 |
| | $ | 294 |
| | $ | (26 | ) | | $ | 362 |
| | $ | 278 |
| | $ | 84 |
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1 | First quarter 2016 earnings were updated to reflect the implementation of the accounting standard for share-based payments effective January 1, 2016. See "Notes to Consolidated Financial Statements—Note 1" for further information. |
Edison International's earnings are prepared in accordance with GAAP used in the United States.GAAP. Management uses core earnings internally for financial planning and for analysis of performance. Core earnings (losses) are also used when communicating with investors and analysts regarding Edison International's earnings results to facilitate comparisons of the Company'scompany's performance from period to period. Core earnings (losses) are a non-GAAP financial measure and may not be comparable to those of other companies. Core earnings (losses) are defined as earnings attributable to Edison International shareholders less non-core items. Non-core items include income or loss from discontinued operations, income resulting from allocation of losses to tax equity investors under the hypothetical liquidation at book value ("HLBV")HLBV accounting method, and income or loss from significant discrete items that management does not consider representative of ongoing earnings, such as:as exit activities, including sale of certain assets and other activities that are no longer continuing;continuing, write downs, asset impairments and other gains and losses related to certain tax, regulatory, or legal settlements or proceedings.
SCE's coreEdison International's first quarter 2017 earnings for the three months ended March 31, 2016 decreased by $18increased $81 million primarily due to the timing of revenue recognized in 2015 due to the delay in receiving the 2015 GRC decision, higher operation and maintenance costs and lower incremental income tax benefits.
Duringfrom the first quarter of 2015, pending the outcome2016, comprised of the 2015 GRC decision, SCE recognized GRC-related revenue largely based on the 2014 authorized revenue requirement. During 2015, SCE recorded an estimated revenue refund to customersincrease in SCE's earnings of $451$54 million, to reflect the final decisionan increase in the 2015 GRC. The estimated amount of the refund to customers attributable to the first quarter of 2015 but recorded subsequently in 2015 was approximately $35 million ($21 million after-tax). See "Results of Operations" for further information.
Edison International Parent and Other core losses forearnings of $28 million, and a decrease in income from discontinued operations of $1 million. SCE's increase in earnings was due to an increase in revenue from the three months ended March 31, 2016 increasedescalation mechanism set forth in the 2015 GRC decision, lower operation and maintenance expenses and higher income tax benefits partially offset by $8 million primarilyhigher net financing costs. Edison International Parent and Other increase in net income was due to higher developmentcore earnings of $30 million and operating costs at Edison Energy Group and subsidiaries andincome in the first quarter of 2015 from Edison Capital's investments in affordable housing projects.
Consolidated non-core items included income of $2 million and $5 million for the three months ended March 31, 2016 and 2015, respectively, related to losses allocated to tax equity investors under the HLBV accounting method. Edison International reflectedof lower non-core earnings. The increase in core earnings the operating results of the solar rooftop projects, related financings and the priority return to the tax equity investor. The losses allocated to the tax equity investor under HLBV accounting method results in income allocated to subsidiaries of Edison International, neither of which iswas due to the operating performance of the projects but rather due to the allocation ofhigher income tax attributes under the tax equity financing. Accordingly, Edison International has included the non-operating allocation of income as a non-core item. For further information on HLBV, see the 2015 Form 10-K, "Notesbenefits related to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies."stock option exercises.
Capital Program
Total capital expenditures (including accruals) were $729$647 million and $825$729 million for the first three months of 2017 and 2016, and 2015, respectively. In the year-ended 2016 MD&A, SCE projects that 2016projected 2017 capital expenditures of approximately $4.2 billion. Those expenditures included $182 million of grid modernization capital spending that will be approximately $4 billion.promote increased safety and reliability and will also allow for a timely ramp-up of grid modernization capital expenditures in subsequent years. SCE has requested CPUC approval of a memorandum account to facilitate recovery in rates of such expenditures. The memorandum account has not yet been approved by the CPUC. SCE may receive further guidance on grid modernization spending from the CPUC as part of the DRP proceeding in the second half of 2017. SCE currently projects 2017 capital expenditures of $4.0 billion, reflecting the lack of approval of a grid modernization memorandum account and minor delays on the start of construction for the Mesa Substation Project. Actual capital spending may be affected by: changes in regulatory, environmental and engineering design requirements; permitting and project delays; cost and availability of labor, equipment, and materials; and other factors. SCE will file its 2018 GRC application in September 2016, which will include a forecast of capital expenditures and rate base for 2018 – 2020. For further information regarding the capital program see "Liquidity and Capital Resources—Capital Investment Plan" and the year-ended 20152016 MD&A, "Management Overview—Capital Program."
Regulatory Proceedings
2018 General Rate Case
As discussed in the year-ended 2016 MD&A, in September 2016, SCE filed its 2018 GRC application for the three-year period 2018 – 2020, which requested a 2018 revenue requirement of $5.885 billion, an increase of $222 million over the projected 2017 GRC authorized revenue requirement.
In April 2017, ORA recommended that SCE's requested 2018 base revenue requirement be decreased by approximately $208 million, comprised of approximately $164 million in operations and maintenance expense reductions and approximately $44 million in capital-related revenue requirement reductions largely related to the proposed reduction of 100% of grid modernization capital spending. ORA proposed capturing grid modernization spending in a memorandum account for review in the 2021 GRC if any spending is authorized by the CPUC. Testimony from other parties related to SCE's 2018 GRC application is due in May 2017.
SCE requested that the CPUC issue a final decision by the end of 2017. If the schedule for a final decision is delayed, SCE will request the CPUC to issue an order directing that the authorized revenue requirement changes be effective January 1, 2018. SCE cannot predict the revenue requirement the CPUC will ultimately authorize for 2018 through 2020 or forecast the timing of a final decision.
Permanent Retirement of San Onofre
Replacement steam generators were installed at San Onofre in 2010 and 2011. On January 31, 2012, a leak suddenly occurred in one of the heat transfer tubes in San Onofre's Unit 3 steam generators. The Unit was safely taken off-line and subsequent inspections revealed excessive tube wear. Unit 2 was off-line for a planned outage when areas of unexpected tube wear were also discovered. On June 6, 2013, SCE decided to permanently retire Units 2 and 3.
MHI Claims
In March 2017, SCE received a decision from the International Chamber of Commerce International Court of Arbitration on claims against MHI regarding failure of the replacement steam generators that MHI supplied for San Onofre. The net recovery awarded to SCE was initially determined to be $52 million. An adjustment to the interest awarded to SCE subsequently reduced the net recovery to $47 million. SCE has determined that it will not appeal the decision. As a result of uncertainty associated with the allocation of the award under the San Onofre OII Settlement Agreement, SCE recorded a regulatory liability for the net recovery.
For more information on the challenges to the settlement of the San Onofre OII and the arbitration tribunal decision on MHI, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Contingencies—San Onofre Related Matters."
Cost of Capital
In April 2017, the CPUC issued a proposed decision that would have adopted the petition previously filed by SCE, Pacific Gas & Electric Company, SDG&E, and SoCalGas (collectively, the "Investor-Owned Utilities"), ORA, and TURN to modify the prior CPUC decisions addressing the Investor-Owned Utilities' costs of capital. The decision, if adopted by the CPUC, would have established SCE's authorized ROE at 10.30%, beginning January 1, 2018. Subsequently in April 2017, the CPUC withdrew the proposed decision from the agenda of its April 27 meeting. Timing for additional action on the settling parties’ petition has not been defined. For more information on the terms of the settling parties' petition, see "Management Overview—Regulatory Proceedings" in the year-ended 2016 MD&A.
RESULTS OF OPERATIONS
Southern California Edison Company
SCE's results of operations are derived mainly through two sources:
Earning activities – representing revenue authorized by the CPUC and FERC which is intended to provide SCE a reasonable opportunity to recover its costs and earn a return on its net investment in generation, transmission, and distribution assets. The annual revenue requirements are comprised of authorized operation and maintenance costs, depreciation, taxes, and a return consistent with the capital structure. Also, included in earnings activities are revenuerevenues or penalties related to incentive mechanisms, other operating revenue, and regulatory charges or disallowances.
Cost-recovery activities – representing CPUC- and FERC-authorizedFERC- authorized balancing accounts which allow for recovery of specific project or program costs, subject to reasonableness review or compliance with upfront standards. Cost-recovery activities include rates which provide recovery, subject to reasonableness review of, among other things, fuel costs, purchased power costs, public purpose related-program costs (including energy efficiency and demand-side management programs), and certain operation and maintenance expenses. SCE earns no return on these activities.
The following table is a summary of SCE's results of operations for the periods indicated.
Three months ended March 31, 20162017 versus March 31, 20152016
| | | | Three months ended March 31, 2016 | Three months ended March 31, 2015 | Three months ended March 31, 2017 | Three months ended March 31, 2016 |
| (in millions) | Earning
Activities | Cost-
Recovery
Activities | Total
Consolidated | Earning
Activities | Cost-
Recovery
Activities | Total
Consolidated | Earning
Activities | Cost-
Recovery
Activities | Total
Consolidated | Earning
Activities | Cost-
Recovery
Activities | Total
Consolidated |
| Operating revenue | $ | 1,522 |
| $ | 913 |
| $ | 2,435 |
| $ | 1,563 |
| $ | 945 |
| $ | 2,508 |
| $ | 1,552 |
| $ | 904 |
| $ | 2,456 |
| $ | 1,522 |
| $ | 913 |
| $ | 2,435 |
|
| Purchased power and fuel | — |
| 794 |
| 794 |
| — |
| 786 |
| 786 |
| — |
| 784 |
| 784 |
| — |
| 794 |
| 794 |
|
| Operation and maintenance | 484 |
| 119 |
| 603 |
| 462 |
| 159 |
| 621 |
| 451 |
| 120 |
| 571 |
| 484 |
| 119 |
| 603 |
|
| Depreciation, decommissioning and amortization | 475 |
| — |
| 475 |
| 463 |
| — |
| 463 |
| 497 |
| — |
| 497 |
| 475 |
| — |
| 475 |
|
| Property and other taxes | 91 |
| — |
| 91 |
| 88 |
| — |
| 88 |
| 97 |
| — |
| 97 |
| 91 |
| — |
| 91 |
|
| Total operating expenses | 1,050 |
| 913 |
| 1,963 |
| 1,013 |
| 945 |
| 1,958 |
| 1,045 |
| 904 |
| 1,949 |
| 1,050 |
| 913 |
| 1,963 |
|
| Operating income | 472 |
| — |
| 472 |
| 550 |
| — |
| 550 |
| 507 |
| — |
| 507 |
| 472 |
| — |
| 472 |
|
| Interest expense | (131 | ) | — |
| (131 | ) | (136 | ) | — |
| (136 | ) | (141 | ) | — |
| (141 | ) | (131 | ) | — |
| (131 | ) |
| Other income and expenses | 26 |
| — |
| 26 |
| 26 |
| — |
| 26 |
| 26 |
| — |
| 26 |
| 26 |
| — |
| 26 |
|
| Income before income taxes | 367 |
| — |
| 367 |
| 440 |
| — |
| 440 |
| 392 |
| — |
| 392 |
| 367 |
| — |
| 367 |
|
| Income tax expense | 50 |
| — |
| 50 |
| 107 |
| — |
| 107 |
| 12 |
| — |
| 12 |
| 42 |
| — |
| 42 |
|
| Net income | 317 |
| — |
| 317 |
| 333 |
| — |
| 333 |
| 380 |
| — |
| 380 |
| 325 |
| — |
| 325 |
|
| Preferred and preference stock dividend requirements | 30 |
| — |
| 30 |
| 28 |
| — |
| 28 |
| 31 |
| — |
| 31 |
| 30 |
| — |
| 30 |
|
| Net income available for common stock | $ | 287 |
| $ | — |
| $ | 287 |
| $ | 305 |
| $ | — |
| $ | 305 |
| $ | 349 |
| $ | — |
| $ | 349 |
| $ | 295 |
| $ | — |
| $ | 295 |
|
| Net income available for common stock | | | | $ | 349 |
| | $ | 295 |
|
| Less: | | | | | | |
| Non-core earnings | | | | — |
| | — |
|
Core earnings1 | | $ | 287 |
| | $ | 305 |
| | | $ | 349 |
| | $ | 295 |
|
| Non-core earnings | | — |
| | — |
| |
| Total SCE GAAP earnings | | $ | 287 |
| | $ | 305 |
| |
| |
1 | See use of non-GAAP financial measures in "Management Overview—Highlights of Operating Results." |
Earning Activities
SCE's results of operations for the three months ended March 31, 2016 included an increase in revenue of approximately $46 million from the escalation mechanism set forth in the final 2015 GRC decision. The annual escalation increase implemented in customer rates for 2016 was $203 million. SCE's results of operations for the three months ended March 31, 2015 were largely based on 2014 authorized base revenue requirements included in customer rates.
During 2015, SCE recorded an estimated revenue refund to customers of $451 million to reflect the final decision in the 2015 GRC. The estimated amount of the refund to customers attributable to the first quarter of 2015 but recorded subsequently in 2015 was approximately $35 million ($21 million after-tax).
Earning activities were primarily affected by the following:
LowerHigher operating revenue of $41$30 million primarily due to the following:
A decreaseAn increase in CPUC revenue of approximately $59 million primarily due to the escalation mechanism as set forth in the 2015 GRC decision.
An increase in revenue of approximately $74$31 million forresulting from lower 2017 incremental tax benefits recognized through the tax accounting memorandum account ("TAMA") and the pole loading balancing account (offset in income taxes as discussed below) in.
The receipt of the first quarterMHI arbitration decision triggered a tax deduction for the abandonment of 2016.
An increaseSan Onofre. As a result, SCE recorded a decrease in CPUC revenue of approximately $11$65 million (offset in income taxes as discussed below) which will be credited to customers. See "Notes to Consolidated Financial Statements—Note 7. Income Taxes" for further information.
Lower operation and maintenance costs of $33 million primarily due to the implementationimpact of the 2015 GRC decision. During the first quarter of 2016, SCE increased authorized revenue based on the escalation mechanism set forth in the 2015 GRC decision. This increase was partially offset by the timing of finalizing the 2015 GRC decision discussed above.
An increase in FERC-related revenue of $13 million primarily due to higher depreciation expense.
Higher operationSCE's operational and maintenance expense of $22 million primarily due to transmission and distribution costs forservice excellence initiatives as well as lower storm-related activities and inspection costs, and higher severance costs.activities.
Higher depreciation, decommissioning, and amortization expense of $12$22 million due to an increase in depreciation primarily related to depreciation on transmission and distribution investments.
Higher interest expense of $10 million primarily due to increased borrowings.
Lower income taxes of $57$30 million primarily due to the following:
Lower pre-tax income in 2016, as discussed above.
Higher income tax benefits in 2016 primarilyof $39 million related to $43a tax deduction for the abandonment of San Onofre (offset with revenue above).
Lower tax expense of $10 million related to the settlement of repair deductionsopen tax positions with the IRS for taxable years 2007 through 2012.
Lower income tax benefits of $18 million related to incremental tax benefits for TAMA and the pole loading balancing accounts (offset in revenue above) for TAMA and pole loading balancing accounts partially offset by lowerhigher income tax benefits in 2017 on other property-related items, in 2016.including cost of removal and depreciation deductions.
Higher pre-tax income for the first quarter of 2017, as discussed above.
Cost-Recovery Activities
Cost-recovery activities were primarily affected by the following:
Lower operationpurchased power and maintenance expensefuel costs of $40$10 million primarily duedriven by lower realized losses on hedging activities ($2 million in 2017 compared to lower transmission access charges$27 million in 2016) partially offset by higher power and lower benefit costs.gas prices experienced in 2017 relative to 2016.
Supplemental Operating Revenue Information
SCE's retail billed and unbilled revenue (excluding wholesale sales and balancing account overcollections/undercollections) was $2.4 billion and $2.6 billion for both the three months ended March 31, 20162017 and 2015, respectively. 2016.
Retail billed and unbilled revenue for the three months ended March 31, 2016 were lower compared to the same period last year primarily due to2017 reflects a rate decreaseincrease of $137$113 million and a sales volume decrease of $55$79 million. The decrease in rates was primarily due to implementations of the 2016 ERRA rate decrease and the 2015 GRC decision in January 2016. The decrease in sales volumeincrease was due to lower load requirements relatedimplementation of the 2017 ERRA rate increase. The sales volume decrease was due to coolerunseasonably warm weather experienced in 2016 compared to the same period in prior year.first quarter of 2016.
As a result of the CPUC-authorized decoupling mechanism, SCE earnings are not affected by changes in retail electricity sales (see "Business—SCE—Overview of Ratemaking Process" in the 20152016 Form 10-K).
Income Taxes
SCE's income tax provisionexpense decreased by $57$30 million during the first quarter of 2016 compared to the same period in 2015.
The effective tax rates were 13.6% and 24.3% for the three months ended March 31, 2017 compared to the same period in 2016.
The effective tax rates were 3.1% and 11.4% for the three months ended March 31, 2017 and 2016, respectively. SCE's effective tax rate is lower than the statutory rate primarily due to CPUC's ratemaking treatment for the current tax benefit arising from certain property-related and 2015, respectively.other temporary differences, which reverse over time. The accounting treatment for these temporary differences results in recording regulatory assets and liabilities for amounts that would otherwise be recorded to deferred income tax expense. The effective tax rate decrease wasis primarily due to higher income tax benefits related to repair deductions, mainly due to flow-through incomethe ratemaking treatment on the San Onofre tax benefits recorded through balancing accounts as discussed above.abandonment.
See "Notes to Consolidated Financial Statements—Note 7. Income Taxes" for a reconciliation of the federal statutory rate of 35% to the effective income tax rates and "Liquidity and Capital Resources—SCE—Regulatory Proceedings—Tax Repair Deductions and Memorandum Account" below for more information.rates.
Edison International Parent and Other
Results of operations for Edison International Parent and Other include amounts from other Edison International subsidiaries that are not significant as a reportable segment, as well as intercompany eliminations.
Income from Continuing Operations
The following table summarizes the results of Edison International Parent and Other:
| | | | | Three months ended March 31, | | Three months ended March 31, |
| (in millions) | | 2016 | | 2015 | | 2017 | | 2016 |
| Edison Energy Group and subsidiaries | | $ | (6 | ) | | $ | 2 |
| |
Edison Energy Group and subsidiaries1 | | | $ | (6 | ) | | $ | (6 | ) |
| Edison Mission Group and subsidiaries | | — |
| | 3 |
| | (1 | ) | | — |
|
Corporate expenses and Other1 | | (11 | ) | | (11 | ) | |
Corporate expenses and other2 | | | 20 |
| | (9 | ) |
| Total Edison International Parent and Other | | $ | (17 | ) | | $ | (6 | ) | | $ | 13 |
| | $ | (15 | ) |
| |
1 | Includes interest expense (pre-tax) incomeof $8less than $1 million and $7$2 million for the three months ended March 31, 2017 and 2016, respectively, related to losses (net of distributions) allocated to tax equity investors under the HLBV accounting method. |
| |
2 | Includes interest expense (pre-tax) of $10 million and 2015,$8 million for the three months ended March 31, 2017 and 2016, respectively. |
The lossincome from continuing operations of Edison International Parent and Other increased $11was $13 million for the three months ended March 31, 20162017 compared to a loss of $15 million for the same period in 20152016. The increase in income for the first three months of 2017 was primarily due to:
Higher development and operating costs and lowerto higher income allocated under the HLBV accounting method at Edison Energy Group and subsidiaries for the three months ended March 31, 2016 compared with the same period in prior year. The results during the first quarter of 2016 also include the three businesses acquired by Edison Energy in December 2015. Revenue of Edison Energy Group for the three months ended March 31, 2016 and 2015, were
$6tax benefits related to stock option exercises ($35 million and $3 million, respectively. For further information, see the 2015 Form 10-K, "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies" and "Management Overview—Highlights of Operating Results."
A decrease in income from Edison Mission Group and subsidiaries of $3$2 million for the three months ended March 31, 2017 and 2016, primarily duerespectively).
Strategic Review of Edison Energy Group Competitive Businesses
Edison International is performing a strategic review of the competitive businesses pursued by subsidiaries of Edison Energy Group. Competitive businesses include energy services provided by Edison Energy and distributed solar solutions provided by SoCore Energy. The outcome of the strategic review may affect Edison International's ability to income related to affordable housing projectsfully recover its investments in the first quarterthese businesses. Edison International's investments in SoCore Energy and Edison Energy were $195 million and $103 million, respectively, as of 2015. In December 2015, EMG's subsidiary, Edison Capital completed the sale of its remaining affordable housing investments portfolio which represents the exit from this business activity.March 31, 2017.
LIQUIDITY AND CAPITAL RESOURCES
Southern California Edison Company
SCE's ability to operate its business, fund capital expenditures, and implement its business strategy is dependent upon its cash flow and access to the bank and capital markets. SCE's overall cash flows fluctuate based on, among other things, its ability to recover its costs in a timely manner from its customers through regulated rates, changes in commodity prices and volumes, collateral requirements, interest obligations and dividend payments to Edison International, and the outcome of tax and regulatory matters.
In the next 12 months, SCE expects to fund its 2016 obligations, capital expenditures, and dividends through operating cash flows, tax benefits, and capital market financings, of debt and preferred equity, as needed. SCE also has availability under its credit facilities to fund liquidity requirements.
Available Liquidity
At March 31, 2016,2017, SCE had approximately $2.56$2.66 billion available under its $2.75 billion multi-year revolving credit facility. In January 2017, SCE borrowed $300 million under a Term Loan Agreement and reissued $135 million of pollution control bonds. In March 2016,2017, SCE issued $300$700 million of preference stock.first and refunding mortgage bonds. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements" and "—Note 12. Preferred and Preference Stock of SCE" for further discussion).Agreements."
Debt Covenant
The debt covenant in SCE's credit facility limits its debt to total capitalization ratio to less than or equal to 0.65 to 1. At March 31, 2016,2017, SCE's debt to total capitalization ratio was 0.430.44 to 1.
At March 31, 2017, SCE was in compliance with all other financial covenants that affect access to capital.
Regulatory ProceedingsCapital Investment Plan
Cost of Capital
As discussed in the year-ended 2015 MD&A, SCEBelow are updates for large transmission and the other Joint Investor-Owned Utilities submitted a petition to the CPUC in connection with their request for a one-year extension of the due date forsubstation projects since the filing of the next cost2016 Form 10-K. SCE is currently evaluating the timing of capital applications. Aits major construction projects. For further information on these projects, see "Liquidity and Capital Resources—SCE—Capital Investment Plan—Major Transmission Projects" in the year-end 2016 MD&A.
Major Transmission Projects
West of Devers
In March 2017, the CPUC issued a decision denying ORA's September 2016 Application for Rehearing regarding the West of Devers Upgrade Project which sought additional project modifications and environmental mitigation measures. This action confirmed SCE's proposed project, which is on track to be placed in service in 2021.
Mesa Substation
In February 2017, the CPUC issued a final decision approving the Joint Investor-Owned Utilities' petition was approved on February 25, 2016. As extended, the Joint Investor-Owned Utilities must file their next costMesa Substation Project largely consistent with SCE's proposed project and rejected alternative project configurations proposed by CPUC staff. Timing of capital applications by April 20, 2017 instead of April 20, 2016. SCE's authorized rate of return and capital structure for CPUC-related activities will remain unchanged through December 31, 2017. See "Business—SCE—Overview of Ratemaking Process—CPUC" in the 2015 Form 10-K for details on SCE's cost of capital and authorized rates of return.
Energy Efficiency Incentive Mechanism
In March 2016, ORA and TURN filed a joint proposal requesting that the CPUC recalculate SCE's 2006 – 2008 incentive awardsapproval and order SCE to refund $39.9 million to its customers. SCE disputespreconstruction requirements for obtaining other permits and approvals have delayed the assertion that SCE should be at risk to repay previously awarded incentives. SCE cannot predict the outcomestart of this proceeding. See "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Energy Efficiency Incentive Mechanism" for more information.
Tax Repair Deductions and Memorandum Account
Previously, SCE recognized earnings and a regulatory asset for deferred income taxes related to 2012 – 2014 tax repair deductions.construction. As a result, ofSCE has revised the CPUC's rate base offset in the 2015 GRC decision, SCE wrote down this regulatory asset in full during 2015. The after-tax charge was reflected in "Income tax expense" on the consolidated statements of income. The amount of tax repair deductionsprojected in-service date to 2022.
Alberhill System
In April 2017, the CPUC used to establishissued a final environmental impact report for the rate base offset was based onAlberhill System. This report rejected different alternatives recommended by CPUC staff and intervenors, selecting SCE's forecastproposed project as the environmentally superior project. A final CPUC decision is anticipated by the end of 2012 – 2014 tax repair deductions from the Notice of Intent filed in the 2015 GRC. The amount of tax repair deductions included in the Notice of Intent was less than the actual tax repair deductions SCE reported on its 2012 through 2014 income tax returns. In April 2016, the CPUC granted SCE's request to reduce SCE's Base Revenue Requirement Balancing Account by $234 million during 2016 through 2020 subject to the outcome of audits that may be conducted by tax authorities. The refunds result in flowing incremental tax benefits for 2012 – 2014 to customers through 2020, beginning in the second quarter of 2016. SCE does not expect to record a gain or loss from this reduction. Regulatory assets recorded from flow through tax benefits are recovered through SCE's general rate case proceedings.
Capital Investment Plan – Major Transmission Projects2017.
Coolwater-Lugo
In February 2016, SCE filed an abandoned plant recovery request at2017, the FERC for the costs of the cancelled Coolwater-Lugo transmission project pursuant to the authority granted by FERC forapproved a settlement allowing SCE to recover 100% of all prudently-incurred costs if the project is cancelled for reasons beyond SCE's control. The project was cancelled by the CPUC in 2015 due to a reduction in need. SCE requested recovery of the $37.1 million inof costs thatincurred by SCE incurred forrelated to the project over a twelve-month period through the FERCcancelled Coolwater-Lugo transmission formula rate.
West of Devers
In April 2016, the CPUC issued a proposed decision to approve the project as recommended by SCE. An alternative project with a modified scope had been considered as part of required environmental impact reviews as discussed in the year-ended 2015 MD&A. The CPUC is expected to issue a final decision on the project in the second quarter of 2016.project.
Dividend Restrictions
The CPUC regulates SCE's capital structure which limits the dividends it may pay Edison International. SCE may make distributions to Edison International as long as the common equity component of SCE's capital structure remains at or above 48% on a 13-month weighted average basis. At March 31, 20162017, SCE's 13-month weighted-average common equity component of total capitalization was 50.2%50.4% and the maximum additional dividend that SCE could pay to Edison International under this limitation was approximately $516$603 million, resulting in a restriction on net assets of approximately $13.4$14.0 billion.
In the first quarter of 2016,2017, SCE declared and paid a dividend to Edison International of $170$191 million. Future dividend amounts and timing of distributions are dependent on a number of factors including the level of capital expenditures, operating cash flows and earnings.
Margin and Collateral Deposits
Certain derivative instruments, power procurement contracts and other contractual arrangements contain collateral requirements. Future collateral requirements may differ from the requirements at March 31, 20162017, due to the addition of incremental power and energy procurement contracts with collateral requirements, if any, and the impact of changes in wholesale power and natural gas prices on SCE's contractual obligations.
Some of the power procurement contracts contain provisions that require SCE to maintain an investment grade credit rating from the major credit rating agencies. If SCE's credit rating were to fall below investment grade, SCE may be required to pay the liability or post additional collateral.
The table below provides the amount of collateral posted by SCE to its counterparties as well as the potential collateral that would have been required as of March 31, 2016.2017.
|
| | | | |
| (in millions) | | |
Collateral posted as of March 31, 20161 | | $ | 131 |
|
| Incremental collateral requirements for power procurement contracts resulting from a potential downgrade of SCE's credit rating to below investment grade | | 26 |
|
Incremental collateral requirements for power procurement contracts resulting from adverse market price movement2 | | 14 |
|
| Posted and potential collateral requirements | | $ | 171 |
|
|
| | | | |
| (in millions) | | |
Collateral posted as of March 31, 20171 | | $ | 93 |
|
| Incremental collateral requirements for power contracts resulting from a potential downgrade of SCE's credit rating to below investment grade | | 22 |
|
Incremental collateral requirements for power contracts resulting from adverse market price movement2 | | 3 |
|
| Posted and potential collateral requirements | | $ | 118 |
|
| |
1 | Net collateral is provided to counterparties and other brokers consistedin the form of$11 million of cash which was offset against net derivative liabilities on the consolidated balance sheets, $25 million of cash reflected in "Other current assets" on the consolidated balance sheets and $95 million in letters of credit and surety bonds. |
| |
2 | Incremental collateral requirements were based on potential changes in SCE's forward positions as of March 31, 20162017 due to adverse market price movements over the remaining lives of the existing power procurement contracts using a 95% confidence level. |
Edison International Parent and Other
Edison International Parent and Other's liquidity and its ability to pay operating expenses and pay dividends to common shareholders are dependent on dividends from SCE, realization of tax benefits, and access to bank and capital markets.
At March 31, 2016, Edison International Parent had $988 million available under its $1.25 billion multi-year revolving credit facility. In March 2016, Edison International issued $400 million of senior notes. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
Edison International may also finance working capital requirements, payment of obligations, and capital investments, including capital contributions to subsidiaries to fund new businesses, with commercial paper or other borrowings, subject to availability in the bank and capital markets.
At March 31, 2017, Edison International Parent had $955 million available under its $1.25 billion multi-year revolving credit facility. In March 2017, Edison International issued $400 million of senior notes. For further details, see "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements."
The debt covenant in Edison International Parent's credit facility requires a consolidated debt to total capitalization ratio as defined in the credit agreement of less than or equal to 0.65 to 1. At March 31, 2016,2017, Edison International Parent's consolidated debt to total capitalization ratio was 0.470.48 to 1.
In August 2014,At March 31, 2017, Edison International entered into an amendment of the EME Settlement AgreementParent was in compliance with all other financial covenants that finalized the remaining matters relatedaffect access to the EME Settlement. Edison International is obligated to make the final payment of $214 million on September 30, 2016. Edison International has net operating loss and tax credit carryforwards retained by EME which are available to offset future consolidated taxable income or tax liabilities. In December 2015, the PATH Act of 2015 extended 50% bonus depreciation for qualifying property retroactive to January 1, 2015 and through 2017 and provided for 40% bonus depreciation in 2018 and 30% in 2019. As a result, realization of these tax benefits has been deferred (currently forecasted through 2022). The timing of realization of these tax benefits may be further delayed in the event of future extensions of bonus depreciation and the value of the net operating loss carryforwards could be permanently reduced in the event that tax reform decreases the current corporate tax rate.capital.
Historical Cash Flows
Southern California Edison Company
| | | | Three months ended March 31, | Three months ended March 31, |
| (in millions) | 2016 | | 2015 | 2017 | | 2016 |
| Net cash provided by operating activities | $ | 882 |
| | $ | 966 |
| $ | 931 |
| | $ | 884 |
|
| Net cash (used in) provided by financing activities | (55 | ) | | 320 |
| |
| Net cash provided by (used in) financing activities | | 56 |
| | (57 | ) |
| Net cash used in investing activities | (832 | ) | | (1,288 | ) | (926 | ) | | (832 | ) |
| Net decrease in cash and cash equivalents | $ | (5 | ) | | $ | (2 | ) | |
| Net increase (decrease) in cash and cash equivalents | | $ | 61 |
| | $ | (5 | ) |
Net Cash Provided by Operating Activities
The following table summarizes major categories of net cash provided by operating activities as provided in more detail in SCE's consolidated statements of cash flows for the three months ended March 31, 20162017 and 2015.2016.
| | | | Three months ended March 31, | | Change in cash flows | Three months ended March 31, | | Change in cash flows |
| (in millions) | 2016 | 2015 | | 2016/2015 | 2017 | 2016 | | 2017/2016 |
| Net income | $ | 317 |
| $ | 333 |
| | | $ | 380 |
| $ | 325 |
| | |
Non-cash items1 | 537 |
| 532 |
| | | 724 |
| 531 |
| | |
| Subtotal | $ | 854 |
| $ | 865 |
| | $ | (11 | ) | $ | 1,104 |
| $ | 856 |
| | $ | 248 |
|
Changes in cash flow resulting from working capital2 | (35 | ) | (99 | ) | | 64 |
| (155 | ) | (35 | ) | | (120 | ) |
| Derivative assets and liabilities, net | 5 |
| (10 | ) | | 15 |
| |
| Regulatory assets and liabilities, net | 119 |
| 193 |
| | (74 | ) | |
Other noncurrent assets and liabilities, net3 | (61 | ) | 17 |
| | (78 | ) | |
| Derivative assets and liabilities | | (12 | ) | 5 |
| | (17 | ) |
| Regulatory assets and liabilities | | 129 |
| 119 |
| | 10 |
|
Other noncurrent assets and liabilities3 | | (135 | ) | (61 | ) | | (74 | ) |
| Net cash provided by operating activities | $ | 882 |
| $ | 966 |
| | $ | (84 | ) | $ | 931 |
| $ | 884 |
| | $ | 47 |
|
| |
1 | Non-cash items include depreciation, decommissioning and amortization, allowance for equity during construction, impairment and other charges, deferred income taxes and investment tax credits, and other. |
| |
2 | Changes in working capital items include receivables, inventory, accounts payable, prepaid and accrued taxes, and other current assets and liabilities. |
3 Includes the nuclear decommissioning trusts.
Net cash provided by operating activities werewas impacted by the following:
Net income increased in 2017 by $55 million primarily due to higher authorized revenue in 2017 due to the escalation mechanism as set forth in the 2015 GRC decision, lower operation and maintenance expenses, and higher income tax benefits, partially offset by higher net financing costs.
Net cash used for working capital was $35$(155) million and $99$(35) million during the three months ended March 31, 20162017 and 2015,2016, respectively. The net cash outflow for each period was primarily related to the timingreductions of disbursements, includingpayables (including payments for payroll, payroll-related costs and income taxes. In addition, net cash for working capital during the first quarterpurchase power) of 2016 was benefited by the timing of receipts from customers. During the first three months of the 2016 and 2015, SCE had net tax payments of $11$230 million and $32 million, respectively. In addition, SCE had severance payments of $15 million and $23$215 million during the first quarters of 2017 and 2016, respectively, partially offset by reductions of receivables from customers ($130 million and 2015, respectively.$170 million in 2017 and 2016, respectively).
Net cash provided by regulatory assets and liabilities, including changes in over (under) collections of balancing accounts.accounts was $129 million and $119 million during the three months ended March 31, 2017 and 2016, respectively. SCE has a number of balancing accounts, which impact cash flows based on differences between timing of collection of amounts through rates and accrual expenditures. DuringCash flows were primarily impacted by the following:
2017
Higher cash due to $64 million of overcollections for the public purpose and energy efficiency programs. Overcollections for public purpose and energy efficiency programs increased due to lower spending for these programs.
Higher cash due to realization of $47 million in proceeds from the MHI arbitration. For further information on the MHI claims, see "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies—Contingencies—San Onofre Related Matters."
BRRBA overcollections decreased by $66 million during the first three months of 2016 and2017 primarily due to the refund of 2015 cash flows were impactedovercollections resulting from the implementation of the 2015 GRC decision, which was authorized to be refunded to customers over a two year period. The BRRBA tracks the differences between amounts authorized by the following principal balancing accounts:CPUC in the GRC proceedings and amounts billed to customers.
SCE had an increase in cash of approximately $84 million primarily due to lower spending for the new system generation program, which records the benefits and costs of power purchase agreements and SCE-owned peaker generation units associated with new generation resources.
2016
Higher cash due to an increase in overcollections of $134 million for the public purpose and energy efficiency programs due to lower spending for these programs during the first three months of 2016.
ERRA overcollections for fuel and purchased power decreased by $75 million during the first three months of 2016 primarily due to the implementation of the 2016 ERRA rate decrease in January 2016, partially offset by lower than forecasted power and gas prices experienced in 2016. ERRA undercollections for fuel and purchased power decreased $345
SCE had an increase in cash of approximately $60 million in the first three months of 2015 primarily due to lower power and gas prices experienced in 2015.
The base rate revenue balancing account ("BRRBA") tracks differences between amounts authorized by the CPUC in the GRC proceedings and amounts billed to customers. BRRBA overcollections decreased $85 million in the first three months of 2016 primarily due to the implementation of the 2015 GRC decision in January 2016 and lower electricity
sales than forecasted in rates from warmer weather experienced in 2016. BRRBA undercollections increased $72 million in the first three months of 2015 primarily due to reduced customer sales from warmer weather during the first quarter of 2015.
The public purpose and energy efficiency programs track the differences between amounts authorized by the CPUC and amounts incurred to fund programs established by the CPUC. Overcollections increased by $134 million during the first quarter of 2016 due to higher funding and lower spending for these programs. Overcollections decreased by $23 million during the first three months of 2015 due to increased spending for these programs.
The 2015 GRC decision established the TAMA. As a result of this memorandum account, together with a balancing account for pole loading expenditures, any differences between the authorized tax repair deductions and actual tax repair deductions will be adjusted through customer rates. Overcollections increased by $30 million during the first three months of 2016 due to higher tax repair deductions than forecasted in rates.
Timingtiming of greenhouse gas auction revenue and climate credit refunds to customers. Overcollections increased by $81 million compared to $36 million for the first three months of 2016 and 2015, respectively.
Cash flows (used in) provided byused in other noncurrent assets and liabilities were $(61)primarily related to net earnings from nuclear decommissioning trust investments ($27 million and $17$10 million in the first three months of2017 and 2016, respectively) and 2015, respectively. Major factors affecting cash flow related to noncurrent assets and liabilities were activities related to SCE's nuclear decommissioning trusts (principally related to the paymentpayments of decommissioning costs). Decommissioning costs of San Onofre were approximately($45 million and $41 million in 2017 and $32 million2016, respectively). See "Nuclear Decommissioning Activities" below for the three months ended March 31, 2016 and 2015, respectively (such costs were recorded as a reduction of SCE's asset retirement obligation).further discussion.
Net Cash Provided by (Used in) Provided by Financing Activities
The following table summarizes cash provided by (used in) provided by financing activities for the three months ended March 31, 20162017 and 2015.2016. Issuances of debt and preference stock are discussed in "Notes to Consolidated Financial Statements—Note 5. Debt and Credit Agreements—Long-Term Debt" and "—Note 12. Preferred and Preference Stock of SCE.Debt."
| | | | Three months ended March 31, | Three months ended March 31, |
| (in millions) | 2016 | | 2015 | 2017 | | 2016 |
| Issuances of first and refunding mortgage bonds, net | $ | — |
| | $ | 1,287 |
| |
| Issuances of first and refunding mortgage bonds, net of discount and issuance costs | | $ | 692 |
| | $ | — |
|
| Issuance of term loan | | 300 |
| | — |
|
| Remarketing of pollution control bonds, net of issuance costs | | 134 |
| | — |
|
| Long-term debt matured or repurchased | (40 | ) | | (419 | ) | (40 | ) | | (40 | ) |
| Issuances of preference stock, net | 294 |
| | — |
| |
| Issuances of preference stock, net of issuance costs | | — |
| | 294 |
|
| Redemptions of preference stock | (125 | ) | | — |
| — |
| | (125 | ) |
| Short-term debt financing, net | 52 |
| | (370 | ) | |
| Short-term debt (repayments), net of borrowings and discount | | (769 | ) | | 52 |
|
| Payments of common stock dividends to Edison International | (170 | ) | | (147 | ) | (191 | ) | | (170 | ) |
| Payments of preferred and preference stock dividends | (35 | ) | | (34 | ) | (36 | ) | | (35 | ) |
| Other | (31 | ) | | 3 |
| (34 | ) | | (33 | ) |
| Net cash (used in) provided by financing activities | $ | (55 | ) | | $ | 320 |
| |
| Net cash provided by (used in) financing activities | | $ | 56 |
| | $ | (57 | ) |
Net Cash Used in Investing Activities
Cash flows used in investing activities are primarily due to capital expenditures and funding of nuclear decommissioning trusts. Capital expenditures were $950 million and $1.3 billion for the three months ended March 31, 2016 and 2015, respectively, primarily related to transmission and distribution and generation investments. Net proceeds (purchases) of nuclear decommissioning trust investments were $106($929 million and $(36)$950 million for the three months ended March 31, 2017 and 2016, and 2015, respectively. Therespectively). In addition, in the first three months of 2016, SCE had a net proceeds from saleredemption of nuclear decommissioning trust investments was due to disbursements less net earnings during the period. The 2015 net purchase of nuclear decommissioning trust investments was due to net earnings during the period.$106 million. See "Nuclear Decommissioning Activities" below for further discussion.
Nuclear Decommissioning TrustsActivities
SCE's statement of cash flows includes nuclear decommissioning activities, of the Nuclear Decommissioning Trusts which are reflected in the following line items:
| | | | Three months ended March 31, | Three months ended March 31, |
| (in millions) | 2016 | | 2015 | 2017 | | 2016 |
Net cash (used in) provided by operating activities: Nuclear decommissioning trusts | $ | (106 | ) | | $ | 29 |
| |
Net cash used in operating activities: Net earnings from nuclear decommissioning trust investments | | $ | 27 |
| | $ | 10 |
|
| SCE's decommissioning costs | | (45 | ) | | (41 | ) |
Net cash flow from investing activities: Proceeds from sale of investments | 793 |
| | 1,026 |
| 1,718 |
| | 793 |
|
| Purchases of investments | (687 | ) | | (1,062 | ) | (1,719 | ) | | (687 | ) |
| Net cash impact | $ | — |
| | $ | (7 | ) | $ | (19 | ) | | $ | 75 |
|
Net cash (used in) provided byused in operating activities of the nuclear decommissioning trusts relate to interest and dividends less administrative expenses, taxes, and SCE's decommissioning costs. See "Notes to Consolidated Financial Statements—Note 9. Investments" for further information. SuchInvesting activities represent the source (use)purchase and sale of investments within the funds for investing activities.nuclear decommissioning trusts, including the reinvestment of earnings from nuclear decommissioning trust investments. The net cash impact represents the contributions made byreflects timing of decommissioning payments ($45 million and $41 million in 2017 and 2016, respectively) and reimbursements to SCE tofrom the nuclear decommissioning trusts.
In future periods, decommissioning costs of San Onofre will increase significantly. Such amounts will continue to be reflected as a decreasetrust ($26 million and $116 million in SCE2017 and 2016, respectively). The 2016 net cash provided by operating activitiesimpact included reimbursements for 2016 and will be funded from salesa portion of investments of the nuclear2015, 2014, and 2013 decommissioning trusts once approved by the CPUC. Decommissioning costs incurred prior to CPUC approval will be funded by SCE and are reflected as cash flow used by operating activities. See "Notes to Consolidated Financial Statements—Note 9. Investments" for further information.costs.
Edison International Parent and Other
The table below sets forth condensed historical cash flow from operations for Edison International Parent and Other.
| | | | Three months ended March 31, | Three months ended March 31, |
| (in millions) | 2016 | | 2015 | 2017 | | 2016 |
| Net cash used in operating activities | $ | (29 | ) | | $ | (2 | ) | $ | (52 | ) | | $ | (29 | ) |
| Net cash provided by (used in) financing activities | 12 |
| | (7 | ) | |
| Net cash provided by financing activities | | 56 |
| | 12 |
|
| Net cash used in investing activities | (2 | ) | | (6 | ) | (11 | ) | | (2 | ) |
| Net decrease in cash and cash equivalents | $ | (19 | ) | | $ | (15 | ) | $ | (7 | ) | | $ | (19 | ) |
Net Cash Used in Operating Activities
Net cash used in operating activities increased $27$23 million forduring the first three months of 20162017 compared to 20152016 due to higher interest payments related to long-term debt and the timing of payments and receipts relating to interest, operating costs and income taxes.costs.
Net Cash Provided by (Used in) Financing Activities
Net cash provided by (used in) financing activities werewas as follows:
|
| | | | | | | |
| | Three months ended March 31, |
| (in millions) | 2016 | | 2015 |
| Dividends paid to Edison International common shareholders | $ | (156 | ) | | $ | (136 | ) |
| Dividends received from SCE | 170 |
| | 147 |
|
| Payment for stock-based compensation | (38 | ) | | (94 | ) |
| Receipt from stock option exercises | 22 |
| | 54 |
|
| Long-term debt issuance, net | 397 |
| | — |
|
| Short-term debt financing, net | (384 | ) | | 15 |
|
| Other | 1 |
| | 7 |
|
| Net cash provided by (used in) financing activities | $ | 12 |
| | $ | (7 | ) |
|
| | | | | | | |
| | Three months ended March 31, |
| (in millions) | 2017 | | 2016 |
| Dividends paid to Edison International common shareholders | $ | (177 | ) | | $ | (156 | ) |
| Dividends received from SCE | 191 |
| | 170 |
|
| Payment for stock-based compensation, net of receipt from stock option exercises | (116 | ) | | (16 | ) |
| Long-term debt issuance, net of discount and issuance costs | 398 |
| | 397 |
|
| Short-term debt repayments, net of borrowings and discount | (244 | ) | | (384 | ) |
| Other | 4 |
| | 1 |
|
| Net cash provided by financing activities | $ | 56 |
| | $ | 12 |
|
Contingencies
SCE has contingencies related to San Onofre Related Matters, Energy Efficiency Incentive Mechanism,Long Beach Service Interruptions, Nuclear Insurance, Wildfire Insurance, and Spent Nuclear Fuel, which are discussed in "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies."
Environmental Remediation
As of March 31, 2016, SCE had identified 19 material sites for remediation and recorded an estimated minimum liability of $133 million. SCE expects to recover 90% of its remediation costs at certain sites. See "Notes to Consolidated Financial Statements—Note 11. Commitments and Contingencies" for further discussion.
MARKET RISK EXPOSURES
Edison International's and SCE's primary market risks are described in the 20152016 Form 10-K. For a further discussion of market risk exposures, including commodity price risk, credit risk, and interest rate risk, see "Notes to Consolidated Financial Statements—Note 4. Fair Value Measurements" and "—Note 6. Derivative Instruments."
Commodity Price Risk
The fair value of outstanding derivative instruments used to mitigate exposure to commodity price risk was a net liability of $1.2 billion at bothand $1.1 billion March 31, 20162017 and December 31, 2015.2016, respectively. For further discussion of fair value measurements and the fair value hierarchy, see "Notes to Consolidated Financial Statements—Note 4. Fair Value Measurements" and "— Note 6. Derivative Instruments."
Credit Risk
Credit risk exposure from counterparties for power and gas trading activities is measured as the sum of net accounts receivable (accounts receivable less accounts payable) and the current fair value of net derivative assets (derivative assets less derivative liabilities) reflected on the consolidated balance sheets. SCE enters into master agreements which typically provide for a right of setoff. Accordingly, SCE's credit risk exposure from counterparties is based on a net exposure under these arrangements. SCE manages the credit risk on the portfolio for both rated and non-rated counterparties based on credit ratings using published ratings of counterparties and other publicly disclosed information, such as financial statements, regulatory filings, and press releases, to guide it in the process of setting credit levels, risk limits, and contractual arrangements, including master netting agreements.
As of March 31, 2016,2017, the amount of balance sheet exposure as described above broken down by the credit ratings of SCE's counterparties, was as follows:
| | | | March 31, 2016 | March 31, 2017 |
| (in millions) | Exposure2 | | Collateral | | Net Exposure | Exposure2 | | Collateral | | Net Exposure |
S&P Credit Rating1 | | | | | | | | | | |
| A or higher | $ | 136 |
| | $ | — |
| | $ | 136 |
| $ | 64 |
| | $ | — |
| | $ | 64 |
|
| Not rated | 8 |
| | (12 | ) | | — |
| |
| Total | $ | 144 |
| | $ | (12 | ) | | $ | 136 |
| |
| |
1 | SCE assigns a credit rating based on the lower of a counterparty's S&P, Fitch or Moody's rating. For ease of reference, the above table uses the S&P classifications to summarize risk, but reflects the lower of the twothree credit ratings. |
| |
2 | Exposure excludes amounts related to contracts classified as normal purchases and sales and non-derivative contractual commitments that are not recorded on the consolidated balance sheets, except for any related net accounts receivable. |
CRITICAL ACCOUNTING ESTIMATES AND POLICIES
For a complete discussion on Edison International's and SCE's critical accounting policies, see "Critical Accounting Estimates and Policies" in the year-ended 20152016 MD&A.
NEW ACCOUNTING GUIDANCE
New accounting guidance is discussed in "Notes to Consolidated Financial Statements—Note 1. Summary of Significant Accounting Policies—New Accounting Guidance."
RISK FACTORS
The risk factors appearing in the 2015 Form 10-K under the headings set forth below are supplemented and updated as follows:
RISKS RELATING TO SOUTHERN CALIFORNIA EDISON COMPANY
Regulatory Risks
SCE's energy procurement activities are subject to regulatory and market risks that could materially affect its financial condition and liquidity.
SCE obtains energy, capacity, environmental credits and ancillary services needed to serve its customers from its own generating plants, and through contracts with energy producers and sellers. California law and CPUC decisions allow SCE to recover through the rates it is allowed to charge its customers reasonable procurement costs incurred in compliance with an approved procurement plan. Nonetheless, SCE's cash flows remain subject to volatility primarily resulting from changes in commodity prices. For instance, natural gas prices may increase due to the leak at the SoCalGas underground gas storage facility in Aliso Canyon, California. Additionally, significant and prolonged gas use restrictions may adversely impact the reliability of the electric grid if critical generation resources are limited in their operations. In April 2016, a joint action plan authored by staff of the CPUC, California Energy Commission, CAISO and Los Angeles Department of Water and Power concluded that the unavailability of the gas storage facility could result in electric reliability being at risk for outages in the summer of 2016 and possibly later in 2016 and in early 2017. For further information, see "Business-SCE-Purchased Power and Fuel Supply." SCE is also subject to the risks of unfavorable or untimely CPUC decisions about the compliance with SCE's procurement plan and the reasonableness of certain procurement-related costs.
SCE may not be able to hedge its risk for commodities on economic terms or fully recover the costs of hedges through the rates it is allowed to charge its customers, which could materially affect SCE's liquidity and results of operations, see "Market Risk Exposures" in the MD&A.
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Information responding to this section is included in the MD&A under the heading "Market Risk Exposures" and is incorporated herein by reference.
FINANCIAL STATEMENTS
| | | Consolidated Statements of Income | Edison International | | Edison International | |
| |
| |
| |
| Three months ended March 31, | Three months ended March 31, |
| (in millions, except per-share amounts, unaudited) | | 2016 |
| 2015 | 2017 | | 2016 |
| Total operating revenue | | $ | 2,440 |
|
| $ | 2,512 |
| $ | 2,463 |
| | $ | 2,440 |
|
| Purchased power and fuel | | 794 |
|
| 786 |
| 784 |
| | 794 |
|
| Operation and maintenance | | 629 |
|
| 636 |
| 596 |
| | 629 |
|
| Depreciation, decommissioning and amortization | | 477 |
|
| 463 |
| 499 |
| | 477 |
|
| Property and other taxes | | 92 |
| | 89 |
| 100 |
| | 92 |
|
| Impairment and other charges | | 5 |
| | — |
|
| Total operating expenses | | 1,992 |
|
| 1,974 |
| 1,984 |
| | 1,992 |
|
| Operating income | | 448 |
|
| 538 |
| 479 |
| | 448 |
|
| Interest and other income | | 31 |
|
| 39 |
| 33 |
| | 31 |
|
| Interest expense | | (140 | ) |
| (143 | ) | (152 | ) | | (140 | ) |
| Other expenses | | (6 | ) |
| (10 | ) | (8 | ) | | (6 | ) |
| Income from continuing operations before income taxes | | 333 |
|
| 424 |
| 352 |
| | 333 |
|
| Income tax expense | | 38 |
|
| 106 |
| |
| Income tax (benefit) expense | | (40 | ) | | 28 |
|
| Income from continuing operations | | 295 |
|
| 318 |
| 392 |
| | 305 |
|
| Income from discontinued operations, net of tax | | 1 |
| | — |
| — |
| | 1 |
|
| Net income | | 296 |
|
| 318 |
| 392 |
| | 306 |
|
| Preferred and preference stock dividend requirements of SCE | | 30 |
|
| 28 |
| 31 |
| | 30 |
|
| Other noncontrolling interests | | (5 | ) | | (9 | ) | (1 | ) | | (5 | ) |
| Net income attributable to Edison International common shareholders | | $ | 271 |
|
| $ | 299 |
| $ | 362 |
| | $ | 281 |
|
| Amounts attributable to Edison International common shareholders: | |
|
|
| | | |
| Income from continuing operations, net of tax | | $ | 270 |
|
| $ | 299 |
| $ | 362 |
| | $ | 280 |
|
| Income from discontinued operations, net of tax | | 1 |
|
| — |
| — |
| | 1 |
|
| Net income attributable to Edison International common shareholders | | $ | 271 |
|
| $ | 299 |
| $ | 362 |
| | $ | 281 |
|
| Basic earnings per common share attributable to Edison International common shareholders: | |
|
|
| | | |
| Weighted-average shares of common stock outstanding | | 326 |
|
| 326 |
| 326 |
| | 326 |
|
| Continuing operations | | $ | 0.83 |
|
| $ | 0.92 |
| $ | 1.11 |
| | $ | 0.86 |
|
| Total | | $ | 0.83 |
|
| $ | 0.92 |
| $ | 1.11 |
| | $ | 0.86 |
|
| Diluted earnings per common share attributable to Edison International common shareholders: | |
|
|
| | | |
| Weighted-average shares of common stock outstanding, including effect of dilutive securities | | 328 |
|
| 329 |
| 329 |
| | 329 |
|
| Continuing operations | | $ | 0.82 |
|
| $ | 0.91 |
| $ | 1.10 |
| | $ | 0.85 |
|
| Total | | $ | 0.82 |
|
| $ | 0.91 |
| $ | 1.10 |
| | $ | 0.85 |
|
| Dividends declared per common share | | $ | 0.4800 |
|
| $ | 0.4175 |
| $ | 0.5425 |
| | $ | 0.4800 |
|
The accompanying notes are an integral part of these consolidated financial statements.
14
|
| | | | | | | | |
| Consolidated Statements of Comprehensive Income | | Edison International | |
| | | |
| | | Three months ended March 31, |
| (in millions, unaudited) | | 2017 | | 2016 |
| Net income | | $ | 392 |
| | $ | 306 |
|
| Other comprehensive income, net of tax: | | | | |
| Pension and postretirement benefits other than pensions: | | | | |
| Amortization of net loss included in net income | | 2 |
| | 2 |
|
| Other | | 2 |
| | — |
|
| Other comprehensive income, net of tax | | 4 |
| | 2 |
|
| Comprehensive income | | 396 |
| | 308 |
|
| Less: Comprehensive income attributable to noncontrolling interests | | 30 |
| | 25 |
|
| Comprehensive income attributable to Edison International | | $ | 366 |
| | $ | 283 |
|
The accompanying notes are an integral part of these consolidated financial statements.
15
|
| | | | | | | |
| Consolidated Balance Sheets | Edison International | |
|
|
|
|
|
|
| (in millions, unaudited) | March 31,
2017 |
| December 31,
2016 |
| ASSETS | |
| |
| Cash and cash equivalents | $ | 150 |
|
| $ | 96 |
|
| Receivables, less allowances of $55 and $62 for uncollectible accounts at respective dates | 688 |
|
| 714 |
|
| Accrued unbilled revenue | 266 |
|
| 370 |
|
| Inventory | 237 |
|
| 239 |
|
| Derivative assets | 69 |
|
| 73 |
|
| Regulatory assets | 394 |
|
| 350 |
|
| Other current assets | 242 |
|
| 281 |
|
| Total current assets | 2,046 |
|
| 2,123 |
|
| Nuclear decommissioning trusts | 4,352 |
|
| 4,242 |
|
| Other investments | 89 |
|
| 83 |
|
| Total investments | 4,441 |
|
| 4,325 |
|
| Utility property, plant and equipment, less accumulated depreciation and amortization of $9,321 and $9,000 at respective dates | 36,951 |
|
| 36,806 |
|
| Nonutility property, plant and equipment, less accumulated depreciation of $102 and $99 at respective dates | 217 |
|
| 194 |
|
| Total property, plant and equipment | 37,168 |
|
| 37,000 |
|
| Regulatory assets | 7,674 |
|
| 7,455 |
|
| Other long-term assets | 411 |
|
| 416 |
|
| Total long-term assets | 8,085 |
|
| 7,871 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| | | | |
| | | | |
| Total assets | $ | 51,740 |
|
| $ | 51,319 |
|
The accompanying notes are an integral part of these consolidated financial statements.
16
|
| | | | | | | | |
| Consolidated Statements of Comprehensive Income | | Edison International | |
| | | |
| | | Three months ended March 31, |
| (in millions, unaudited) | | 2016 | | 2015 |
| Net income | | $ | 296 |
| | $ | 318 |
|
| Other comprehensive income (loss), net of tax: | | | | |
| Pension and postretirement benefits other than pensions: | | | | |
| Net gain (loss) arising during the period plus amortization included in net income | | 2 |
| | (1 | ) |
| Other comprehensive income (loss), net of tax | | 2 |
| | (1 | ) |
| Comprehensive income | | 298 |
| | 317 |
|
| Less: Comprehensive income attributable to noncontrolling interests | | 25 |
| | 19 |
|
| Comprehensive income attributable to Edison International | | $ | 273 |
| | $ | 298 |
|
|
| | | | | | | |
| Consolidated Balance Sheets | Edison International | |
| |
| |
| (in millions, except share amounts, unaudited) | March 31,
2017 |
| December 31,
2016 |
| LIABILITIES AND EQUITY | |
| |
| Short-term debt | $ | 295 |
|
| $ | 1,307 |
|
| Current portion of long-term debt | 981 |
|
| 981 |
|
| Accounts payable | 844 |
|
| 1,342 |
|
| Accrued taxes | 86 |
|
| 50 |
|
| Customer deposits | 272 |
|
| 269 |
|
| Derivative liabilities | 237 |
|
| 216 |
|
| Regulatory liabilities | 804 |
|
| 756 |
|
| Other current liabilities | 897 |
|
| 991 |
|
| Total current liabilities | 4,416 |
|
| 5,912 |
|
| Long-term debt | 11,662 |
|
| 10,175 |
|
| Deferred income taxes and credits | 8,523 |
|
| 8,327 |
|
| Derivative liabilities | 989 |
|
| 941 |
|
| Pensions and benefits | 1,358 |
|
| 1,354 |
|
| Asset retirement obligations | 2,585 |
|
| 2,590 |
|
| Regulatory liabilities | 5,910 |
|
| 5,726 |
|
| Other deferred credits and other long-term liabilities | 2,048 |
|
| 2,102 |
|
| Total deferred credits and other liabilities | 21,413 |
|
| 21,040 |
|
| Total liabilities | 37,491 |
|
| 37,127 |
|
| Commitments and contingencies (Note 11) |
|
|
|
|
|
| Redeemable noncontrolling interest | 7 |
| | 5 |
|
| Common stock, no par value (800,000,000 shares authorized; 325,811,206 shares issued and outstanding at respective dates) | 2,510 |
|
| 2,505 |
|
| Accumulated other comprehensive loss | (49 | ) |
| (53 | ) |
| Retained earnings | 9,590 |
|
| 9,544 |
|
| Total Edison International's common shareholders' equity | 12,051 |
|
| 11,996 |
|
Noncontrolling interests – preferred and preference stock of SCE | 2,191 |
|
| 2,191 |
|
| Total equity | 14,242 |
|
| 14,187 |
|
|
|
|
|
|
|
|
|
|
|
|
|
| Total liabilities and equity | $ | 51,740 |
|
| $ | 51,319 |
|
The accompanying notes are an integral part of these consolidated financial statements.
17
|
| | | | | | | |
| Consolidated Balance Sheets | Edison International | |
|
|
|
|
|
|
| (in millions, unaudited) | March 31,
2016 |
| December 31,
2015 |
| ASSETS | |
| |
| Cash and cash equivalents | $ | 137 |
|
| $ | 161 |
|
| Receivables, less allowances of $59 and $62 for uncollectible accounts at respective dates | 649 |
|
| 771 |
|
| Accrued unbilled revenue | 512 |
|
| 565 |
|
| Inventory | 268 |
|
| 267 |
|
| Derivative assets | 65 |
|
| 79 |
|
| Regulatory assets | 538 |
|
| 560 |
|
| Other current assets | 258 |
|
| 251 |
|
| Total current assets | 2,427 |
|
| 2,654 |
|
| Nuclear decommissioning trusts | 4,290 |
|
| 4,331 |
|
| Other investments | 208 |
|
| 203 |
|
| Total investments | 4,498 |
|
| 4,534 |
|
| Utility property, plant and equipment, less accumulated depreciation and amortization of $8,751 and $8,548 at respective dates | 35,323 |
|
| 34,945 |
|
| Nonutility property, plant and equipment, less accumulated depreciation of $88 and $85 at respective dates | 141 |
|
| 140 |
|
| Total property, plant and equipment | 35,464 |
|
| 35,085 |
|
| Derivative assets | 78 |
|
| 84 |
|
| Regulatory assets | 7,628 |
|
| 7,512 |
|
| Other long-term assets | 364 |
|
| 360 |
|
| Total long-term assets | 8,070 |
|
| 7,956 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| | | | |
| Total assets | $ | 50,459 |
|
| $ | 50,229 |
|
|
| | | | | | | |
| Consolidated Statements of Cash Flows | Edison International | |
|
|
| Three months ended March 31, |
| (in millions, unaudited) | 2017 |
| 2016 |
| Cash flows from operating activities: | |
| |
| Net income | $ | 392 |
|
| $ | 306 |
|
| Less: income from discontinued operations | — |
|
| 1 |
|
| Income from continuing operations | 392 |
|
| 305 |
|
| Adjustments to reconcile to net cash provided by operating activities: |
|
| |
| Depreciation, decommissioning and amortization | 520 |
|
| 499 |
|
| Allowance for equity during construction | (19 | ) |
| (22 | ) |
| Impairment and other charges | 5 |
|
| — |
|
| Deferred income taxes and investment tax credits | (13 | ) |
| 27 |
|
| Other | 5 |
|
| 5 |
|
Nuclear decommissioning trusts
| 1 |
| | (106 | ) |
| Changes in operating assets and liabilities: |
|
| |
| Receivables | 26 |
|
| 117 |
|
| Inventory | 2 |
|
| (1 | ) |
| Accounts payable | (226 | ) |
| (184 | ) |
| Prepaid and accrued taxes | 34 |
| | 66 |
|
| Other current assets and liabilities | 50 |
|
| (43 | ) |
| Derivative assets and liabilities | (12 | ) |
| 5 |
|
| Regulatory assets and liabilities | 129 |
|
| 119 |
|
| Other noncurrent assets and liabilities | (15 | ) |
| 68 |
|
| Net cash provided by operating activities | 879 |
|
| 855 |
|
| Cash flows from financing activities: | |
| |
| Long-term debt issued or remarketed, net of discount and issuance costs of $11 and $3 for respective periods | 1,524 |
|
| 397 |
|
| Long-term debt matured | (40 | ) |
| (40 | ) |
| Preference stock issued, net | — |
|
| 294 |
|
| Preference stock redeemed | — |
|
| (125 | ) |
| Short-term debt financing, net | (1,013 | ) |
| (332 | ) |
| Settlements of stock-based compensation, net | (139 | ) |
| (51 | ) |
| Dividends to noncontrolling interests | (37 | ) |
| (35 | ) |
| Dividends paid | (177 | ) |
| (156 | ) |
| Other | (6 | ) | | 3 |
|
| Net cash provided by (used in) financing activities | 112 |
|
| (45 | ) |
| Cash flows from investing activities: | |
| |
| Capital expenditures | (939 | ) |
| (951 | ) |
| Proceeds from sale of nuclear decommissioning trust investments | 1,718 |
|
| 793 |
|
| Purchases of nuclear decommissioning trust investments | (1,719 | ) |
| (687 | ) |
| Other | 3 |
|
| 11 |
|
| Net cash used in investing activities | (937 | ) |
| (834 | ) |
| Net increase (decrease) in cash and cash equivalents | 54 |
|
| (24 | ) |
| Cash and cash equivalents at beginning of period | 96 |
|
| 161 |
|
| Cash and cash equivalents at end of period | $ | 150 |
|
| $ | 137 |
|
The accompanying notes are an integral part of these consolidated financial statements.
18
|
| | | | | | | | |
| Consolidated Balance Sheets |
| Edison International | |
|
| |
| |
| (in millions, except share amounts, unaudited) |
| March 31,
2016 |
| December 31,
2015 |
| LIABILITIES AND EQUITY |
| |
| |
| Short-term debt |
| $ | 363 |
|
| $ | 695 |
|
| Current portion of long-term debt |
| 295 |
|
| 295 |
|
| Accounts payable |
| 938 |
|
| 1,310 |
|
| Accrued taxes |
| 139 |
|
| 72 |
|
| Customer deposits |
| 253 |
|
| 242 |
|
| Derivative liabilities |
| 232 |
|
| 218 |
|
| Regulatory liabilities |
| 1,157 |
|
| 1,128 |
|
| Other current liabilities |
| 856 |
|
| 967 |
|
| Total current liabilities |
| 4,233 |
|
| 4,927 |
|
| Long-term debt |
| 11,243 |
|
| 10,883 |
|
| Deferred income taxes and credits |
| 7,699 |
|
| 7,480 |
|
| Derivative liabilities |
| 1,136 |
|
| 1,100 |
|
| Pensions and benefits |
| 1,771 |
|
| 1,759 |
|
| Asset retirement obligations |
| 2,597 |
|
| 2,764 |
|
| Regulatory liabilities |
| 5,920 |
|
| 5,676 |
|
| Other deferred credits and other long-term liabilities |
| 2,225 |
|
| 2,246 |
|
| Total deferred credits and other liabilities |
| 21,348 |
|
| 21,025 |
|
| Total liabilities |
| 36,824 |
|
| 36,835 |
|
| Commitments and contingencies (Note 11) |
|
|
|
|
|
|
| Redeemable noncontrolling interest | | 4 |
| | 6 |
|
| Common stock, no par value (800,000,000 shares authorized; 325,811,206 shares issued and outstanding at respective dates) |
| 2,491 |
|
| 2,484 |
|
| Accumulated other comprehensive loss |
| (54 | ) |
| (56 | ) |
| Retained earnings |
| 9,002 |
|
| 8,940 |
|
| Total Edison International's common shareholders' equity |
| 11,439 |
|
| 11,368 |
|
Noncontrolling interests – preferred and preference stock of SCE |
| 2,192 |
|
| 2,020 |
|
| Total equity |
| 13,631 |
|
| 13,388 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Total liabilities and equity |
| $ | 50,459 |
|
| $ | 50,229 |
|
|
| | | | | | | | | | | | |
| Consolidated Statements of Income | | Southern California Edison Company
| |
| | | | | | | | | |
| | | | | | | Three months ended March 31, |
| (in millions, unaudited) | | | | | | 2017 | | 2016 |
| Operating revenue | | | | | | $ | 2,456 |
| | $ | 2,435 |
|
| Purchased power and fuel | | | | | | 784 |
| | 794 |
|
| Operation and maintenance | | | | | | 571 |
| | 603 |
|
| Depreciation, decommissioning and amortization | | | | | | 497 |
| | 475 |
|
| Property and other taxes | | | | | | 97 |
| | 91 |
|
| Total operating expenses | | | | | | 1,949 |
|
| 1,963 |
|
| Operating income | | | | | | 507 |
|
| 472 |
|
| Interest and other income | | | | | | 33 |
| | 31 |
|
| Interest expense | | | | | | (141 | ) | | (131 | ) |
| Other expenses | | | | | | (7 | ) | | (5 | ) |
| Income before income taxes | | | | | | 392 |
|
| 367 |
|
| Income tax expense | | | | | | 12 |
| | 42 |
|
| Net income | | | | | | 380 |
|
| 325 |
|
| Less: Preferred and preference stock dividend requirements | | | | | | 31 |
| | 30 |
|
| Net income available for common stock | | | | | | $ | 349 |
|
| $ | 295 |
|
|
| | | | | | | |
| Consolidated Statements of Comprehensive Income | | | |
| | | | |
| | Three months ended March 31, |
| (in millions, unaudited) | 2017 | | 2016 |
| Net income | $ | 380 |
| | $ | 325 |
|
| Other comprehensive income, net of tax: | | | |
| Pension and postretirement benefits other than pensions: | | | |
| Amortization of net loss included in net income | 1 |
| | 1 |
|
| Other | 1 |
| | — |
|
| Other comprehensive income, net of tax | 2 |
| | 1 |
|
| Comprehensive income | $ | 382 |
| | $ | 326 |
|
The accompanying notes are an integral part of these consolidated financial statements.
19
|
| | | | | | | |
| Consolidated Statements of Cash Flows | Edison International | |
|
|
| Three months ended March 31, |
| (in millions, unaudited) | 2016 |
| 2015 |
| Cash flows from operating activities: | |
| |
| Net income | $ | 296 |
|
| $ | 318 |
|
| Less: Income from discontinued operations | 1 |
|
| — |
|
| Income from continuing operations | 295 |
|
| 318 |
|
| Adjustments to reconcile to net cash provided by operating activities: |
|
| |
| Depreciation, decommissioning and amortization | 499 |
|
| 485 |
|
| Allowance for equity during construction | (22 | ) |
| (21 | ) |
| Deferred income taxes and investment tax credits | 35 |
|
| 72 |
|
| Other | 5 |
|
| 5 |
|
Nuclear decommissioning trusts
| (106 | ) | | 29 |
|
| Changes in operating assets and liabilities: |
|
| |
| Receivables | 117 |
|
| 31 |
|
| Inventory | (1 | ) |
| (10 | ) |
| Accounts payable | (184 | ) |
| 63 |
|
| Prepaid and accrued taxes | 66 |
| | 38 |
|
| Other current assets and liabilities | (43 | ) |
| (229 | ) |
| Derivative assets and liabilities, net | 5 |
|
| (10 | ) |
| Regulatory assets and liabilities, net | 119 |
|
| 193 |
|
| Other noncurrent assets and liabilities | 68 |
|
| — |
|
| Net cash provided by operating activities | 853 |
|
| 964 |
|
| Cash flows from financing activities: | |
| |
Long-term debt issued, net of discount and issuance costs of $3 and $13 for
respective periods | 397 |
|
| 1,287 |
|
| Long-term debt matured | (40 | ) |
| (419 | ) |
| Preference stock issued, net | 294 |
|
| — |
|
| Preference stock redeemed | (125 | ) |
| — |
|
| Short-term debt financing, net | (332 | ) |
| (355 | ) |
| Dividends to noncontrolling interests | (35 | ) |
| (34 | ) |
| Dividends paid | (156 | ) |
| (136 | ) |
| Other | (46 | ) | | (30 | ) |
| Net cash (used in) provided by financing activities | (43 | ) |
| 313 |
|
| Cash flows from investing activities: | |
| |
| Capital expenditures | (951 | ) |
| (1,268 | ) |
| Proceeds from sale of nuclear decommissioning trust investments | 793 |
|
| 1,026 |
|
| Purchases of nuclear decommissioning trust investments | (687 | ) |
| (1,062 | ) |
| Other | 11 |
|
| 10 |
|
| Net cash used in investing activities | (834 | ) |
| (1,294 | ) |
| Net decrease in cash and cash equivalents | (24 | ) |
| (17 | ) |
| Cash and cash equivalents at beginning of period | 161 |
|
| 132 |
|
| Cash and cash equivalents at end of period | $ | 137 |
|
| $ | 115 |
|
|
| |
| Consolidated Balance Sheets | Southern California Edison Company |
|
| | | | | | | |
| (in millions, unaudited) | March 31,
2017 | | December 31, 2016 |
| ASSETS | | | |
| Cash and cash equivalents | $ | 100 |
| | $ | 39 |
|
| Receivables, less allowances of $55 and $61 for uncollectible accounts at respective dates | 670 |
| | 699 |
|
| Accrued unbilled revenue | 265 |
| | 369 |
|
| Inventory | 235 |
| | 239 |
|
| Derivative assets | 69 |
| | 73 |
|
| Regulatory assets | 394 |
| | 350 |
|
| Other current assets | 307 |
| | 262 |
|
| Total current assets | 2,040 |
| | 2,031 |
|
| Nuclear decommissioning trusts | 4,352 |
| | 4,242 |
|
| Other investments | 61 |
| | 50 |
|
| Total investments | 4,413 |
| | 4,292 |
|
| Utility property, plant and equipment, less accumulated depreciation and amortization of $9,321 and $9,000 at respective dates | 36,951 |
| | 36,806 |
|
| Nonutility property, plant and equipment, less accumulated depreciation of $91 and $89 at respective dates | 75 |
| | 75 |
|
| Total property, plant and equipment | 37,026 |
| | 36,881 |
|
| Regulatory assets | 7,674 |
| | 7,455 |
|
| Other long-term assets | 231 |
| | 232 |
|
| Total long-term assets | 7,905 |
| | 7,687 |
|
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Total assets | $ | 51,384 |
| | $ | 50,891 |
|
The accompanying notes are an integral part of these consolidated financial statements.
20
|
| | | | | | | | | | | | |
| Consolidated Statements of Income | | Southern California Edison Company
| |
| | | | | | | |
| | | | | | | Three months ended March 31, |
| (in millions, unaudited) | | | | | | 2016 | | 2015 |
| Operating revenue | | | | | | $ | 2,435 |
| | $ | 2,508 |
|
| Purchased power and fuel | | | | | | 794 |
| | 786 |
|
| Operation and maintenance | | | | | | 603 |
| | 621 |
|
| Depreciation, decommissioning and amortization | | | | | | 475 |
| | 463 |
|
| Property and other taxes | | | | | | 91 |
| | 88 |
|
| Total operating expenses | | | | | | 1,963 |
| | 1,958 |
|
| Operating income | | | | | | 472 |
| | 550 |
|
| Interest and other income | | | | | | 31 |
| | 33 |
|
| Interest expense | | | | | | (131 | ) | | (136 | ) |
| Other expenses | | | | | | (5 | ) | | (7 | ) |
| Income before income taxes | | | | | | 367 |
| | 440 |
|
| Income tax expense | | | | | | 50 |
| | 107 |
|
| Net income | | | | | | 317 |
| | 333 |
|
| Less: Preferred and preference stock dividend requirements | | | | | | 30 |
| | 28 |
|
| Net income available for common stock | | | | | | $ | 287 |
| | $ | 305 |
|
|
| |
| Consolidated Balance Sheets | Southern California Edison Company |
|
| | | | | | | | |
| Consolidated Statements of Comprehensive Income | | | | |
| | | | | |
| | | Three months ended March 31, |
| (in millions, unaudited) | | 2016 | | 2015 |
| Net income | | $ | 317 |
| | $ | 333 |
|
| Other comprehensive income, net of tax: | | | | |
| Pension and postretirement benefits other than pensions: | | | | |
| Amortization of net loss included in net income | | 1 |
| | 1 |
|
| Other comprehensive income, net of tax | | 1 |
| | 1 |
|
| Comprehensive income | | $ | 318 |
| | $ | 334 |
|
|
| | | | | | | |
| (in millions, except share amounts, unaudited) | March 31,
2017 | | December 31, 2016 |
| LIABILITIES AND EQUITY | | | |
| Short-term debt | $ | — |
| | $ | 769 |
|
| Current portion of long-term debt | 579 |
| | 579 |
|
| Accounts payable | 847 |
| | 1,344 |
|
| Accrued taxes | 88 |
| | 45 |
|
| Customer deposits | 272 |
| | 269 |
|
| Derivative liabilities | 237 |
| | 216 |
|
| Regulatory liabilities | 804 |
| | 756 |
|
| Other current liabilities | 656 |
| | 729 |
|
| Total current liabilities | 3,483 |
| | 4,707 |
|
| Long-term debt | 10,843 |
| | 9,754 |
|
| Deferred income taxes and credits | 10,323 |
| | 9,886 |
|
| Derivative liabilities | 989 |
| | 941 |
|
| Pensions and benefits | 898 |
| | 896 |
|
| Asset retirement obligations | 2,580 |
| | 2,586 |
|
| Regulatory liabilities | 5,910 |
| | 5,726 |
|
| Other deferred credits and other long-term liabilities | 1,735 |
| | 1,912 |
|
| Total deferred credits and other liabilities | 22,435 |
| | 21,947 |
|
| Total liabilities | 36,761 |
| | 36,408 |
|
| Commitments and contingencies (Note 11) |
|
| |
|
|
| Common stock, no par value (560,000,000 shares authorized; 434,888,104 shares issued and outstanding at each date) | 2,168 |
| | 2,168 |
|
| Additional paid-in capital | 660 |
| | 657 |
|
| Accumulated other comprehensive loss | (18 | ) | | (20 | ) |
| Retained earnings | 9,568 |
| | 9,433 |
|
| Total common shareholder's equity | 12,378 |
| | 12,238 |
|
| Preferred and preference stock | 2,245 |
| | 2,245 |
|
| Total equity | 14,623 |
| | 14,483 |
|
| Total liabilities and equity | $ | 51,384 |
| | $ | 50,891 |
|
The accompanying notes are an integral part of these consolidated financial statements.
21
|
| |
Consolidated Balance Sheets | Southern California Edison Company |
|
| | | | | | | | |
| (in millions, unaudited) | | March 31,
2016 | | December 31, 2015 |
| ASSETS | | | | |
| Cash and cash equivalents | | $ | 21 |
| | $ | 26 |
|
| Receivables, less allowances of $59 and $62 for uncollectible accounts at respective dates | | 624 |
| | 724 |
|
| Accrued unbilled revenue | | 511 |
| | 564 |
|
| Inventory | | 251 |
| | 256 |
|
| Derivative assets | | 65 |
| | 79 |
|
| Regulatory assets | | 538 |
| | 560 |
|
| Other current assets | | 233 |
| | 234 |
|
| Total current assets | | 2,243 |
| | 2,443 |
|
| Nuclear decommissioning trusts | | 4,290 |
| | 4,331 |
|
| Other investments | | 173 |
| | 168 |
|
| Total investments | | 4,463 |
| | 4,499 |
|
| Utility property, plant and equipment, less accumulated depreciation and amortization of $8,751 and $8,548 at respective dates | | 35,323 |
| | 34,945 |
|
| Nonutility property, plant and equipment, less accumulated depreciation of $83 and $81 at respective dates | | 73 |
| | 73 |
|
| Total property, plant and equipment | | 35,396 |
| | 35,018 |
|
| Derivative assets | | 78 |
| | 84 |
|
| Regulatory assets | | 7,628 |
| | 7,512 |
|
| Other long-term assets | | 239 |
| | 239 |
|
| Total long-term assets | | 7,945 |
| | 7,835 |
|
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| | | | | |
| Total assets | | $ | 50,047 |
| | $ | 49,795 |
|
The accompanying notes are an integral part of these consolidated financial statements.
22
|
| |
Consolidated Balance Sheets | Southern California Edison Company |
|
| | | | | | | | |
| (in millions, except share amounts, unaudited) | | March 31,
2016 | | December 31, 2015 |
| LIABILITIES AND EQUITY | | | | |
| Short-term debt | | $ | 101 |
| | $ | 49 |
|
| Current portion of long-term debt | | 79 |
| | 79 |
|
| Accounts payable | | 935 |
| | 1,299 |
|
| Accrued taxes | | 105 |
| | 46 |
|
| Customer deposits | | 253 |
| | 242 |
|
| Derivative liabilities | | 232 |
| | 218 |
|
| Regulatory liabilities | | 1,157 |
| | 1,128 |
|
| Other current liabilities | | 662 |
| | 760 |
|
| Total current liabilities | | 3,524 |
| | 3,821 |
|
| Long-term debt | | 10,422 |
| | 10,460 |
|
| Deferred income taxes and credits | | 9,297 |
| | 9,073 |
|
| Derivative liabilities | | 1,134 |
| | 1,100 |
|
| Pensions and benefits | | 1,292 |
| | 1,284 |
|
| Asset retirement obligations | | 2,595 |
| | 2,762 |
|
| Regulatory liabilities | | 5,920 |
| | 5,676 |
|
| Other deferred credits and other long-term liabilities | | 1,934 |
| | 1,947 |
|
| Total deferred credits and other liabilities | | 22,172 |
| | 21,842 |
|
| Total liabilities | | 36,118 |
| | 36,123 |
|
| Commitments and contingencies (Note 11) | |
|
| |
|
|
| Common stock, no par value (560,000,000 shares authorized; 434,888,104 shares issued and outstanding at each date) | | 2,168 |
| | 2,168 |
|
| Additional paid-in capital | | 653 |
| | 652 |
|
| Accumulated other comprehensive loss | | (21 | ) | | (22 | ) |
| Retained earnings | | 8,884 |
| | 8,804 |
|
| Total common shareholder's equity | | 11,684 |
| | 11,602 |
|
| Preferred and preference stock | | 2,245 |
| | 2,070 |
|
| Total equity | | 13,929 |
| | 13,672 |
|
| Total liabilities and equity | | $ | 50,047 |
| | $ | 49,795 |
|
The accompanying notes are an integral part of these consolidated financial statements.
23
|
| |
| Consolidated Statements of Cash Flows | Southern California Edison Company |
| | | | Three months ended March 31, | Three months ended March 31, |
| (in millions, unaudited) | 2016 | | 2015 | 2017 | | 2016 |
| Cash flows from operating activities: | | | | | | |
| Net income | $ | 317 |
| | $ | 333 |
| $ | 380 |
| | $ | 325 |
|
| Adjustments to reconcile to net cash provided by operating activities: | | | | | | |
| Depreciation, decommissioning and amortization | 496 |
| | 483 |
| 517 |
| | 496 |
|
| Allowance for equity during construction | (22 | ) | | (21 | ) | (19 | ) | | (22 | ) |
| Deferred income taxes and investment tax credits | 60 |
| | 67 |
| 223 |
| | 54 |
|
| Other | 3 |
| | 3 |
| 3 |
| | 3 |
|
| Nuclear decommissioning trusts | (106 | ) | | 29 |
| 1 |
| | (106 | ) |
| Changes in operating assets and liabilities: | | | | | | |
| Receivables | 100 |
| | 18 |
| 28 |
| | 100 |
|
| Inventory | 5 |
| | (7 | ) | 5 |
| | 5 |
|
| Accounts payable | (175 | ) | | 52 |
| (226 | ) | | (175 | ) |
| Prepaid and accrued taxes | 60 |
| | 43 |
| (33 | ) | | 60 |
|
| Other current assets and liabilities | (25 | ) | | (205 | ) | 71 |
| | (25 | ) |
| Derivative assets and liabilities, net | 5 |
| | (10 | ) | |
| Regulatory assets and liabilities, net | 119 |
| | 193 |
| |
| Derivative assets and liabilities | | (12 | ) | | 5 |
|
| Regulatory assets and liabilities | | 129 |
| | 119 |
|
| Other noncurrent assets and liabilities | 45 |
| | (12 | ) | (136 | ) | | 45 |
|
| Net cash provided by operating activities | 882 |
| | 966 |
| 931 |
| | 884 |
|
| Cash flows from financing activities: | | | | | | |
| Long-term debt issued, net of discount and issuance costs of $13 for the three months ended March 31, 2015 | — |
| | 1,287 |
| |
| Long-term debt issued or remarketed, net of discount and issuance costs of $9 for the three months ended March 31, 2017 | | 1,126 |
| | — |
|
| Long-term debt matured | (40 | ) | | (419 | ) | (40 | ) | | (40 | ) |
| Preference stock issued, net | 294 |
| | — |
| — |
| | 294 |
|
| Preference stock redeemed | (125 | ) | | — |
| — |
| | (125 | ) |
| Short-term debt financing, net | 52 |
| | (370 | ) | (769 | ) | | 52 |
|
| Dividends paid | (205 | ) | | (181 | ) | (227 | ) | | (205 | ) |
| Other | (31 | ) | | 3 |
| (34 | ) | | (33 | ) |
| Net cash (used in) provided by financing activities | (55 | ) | | 320 |
| |
| Net cash provided by (used in) financing activities | | 56 |
| | (57 | ) |
| Cash flows from investing activities: | | | | | | |
| Capital expenditures | (950 | ) | | (1,266 | ) | (929 | ) | | (950 | ) |
| Proceeds from sale of nuclear decommissioning trust investments | 793 |
| | 1,026 |
| 1,718 |
| | 793 |
|
| Purchases of nuclear decommissioning trust investments | (687 | ) | | (1,062 | ) | (1,719 | ) | | (687 | ) |
| Other | 12 |
| | 14 |
| 4 |
| | 12 |
|
| Net cash used in investing activities | (832 | ) |
| (1,288 | ) | (926 | ) |
| (832 | ) |
| Net decrease in cash and cash equivalents | (5 | ) | | (2 | ) | |
| Net increase (decrease) in cash and cash equivalents | | 61 |
| | (5 | ) |
| Cash and cash equivalents, beginning of period | 26 |
| | 38 |
| 39 |
| | 26 |
|
| Cash and cash equivalents, end of period | $ | 21 |
| | $ | 36 |
| $ | 100 |
| | $ | 21 |
|
The accompanying notes are an integral part of these consolidated financial statements.
2422
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Note 1. Summary of Significant Accounting Policies
Organization and Basis of Presentation
Edison International is the parent holding company of Southern California Edison Company ("SCE"). SCE is an investor-owned public utility primarily engaged in the business of supplying and delivering electricity to an approximately 50,000 square mile area of southern California. Edison International is also the parent company of Edison Energy Group, Inc., a holding company that holds interests infor subsidiaries that are engaged in pursuing competitive businesses focused on providingbusiness opportunities across energy services toand distributed solar for commercial and industrial customers, including distributed resources, engaging in competitive transmission opportunities, and exploring distributed water treatment and recycling.customers. Such competitive business activities are currently not material to report as a separate business segment. These combined notes to the consolidated financial statements apply to both Edison International and SCE unless otherwise described. Edison International's consolidated financial statements include the accounts of Edison International, SCE, and other wholly owned and controlled subsidiaries. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to Edison International Parent and Other refer to Edison International Parent and its nonutilitycompetitive subsidiaries. SCE's consolidated financial statements include the accounts of SCE and its wholly owned and controlled subsidiaries. All intercompany transactions have been eliminated from the consolidated financial statements.
Edison International's and SCE's significant accounting policies were described in Note 1 of "Notes to Consolidated Financial Statements" included in Edison International's and SCE's combined Annual Report on Form 10-K for the 2015year-ended December 31, 2016 (the "2016 Form 10-K.10-K"). This quarterly report should be read in conjunction with the financial statements and notes included in the 20152016 Form 10-K.
In the opinion of management, all adjustments, consisting of recurring accruals, have been made that are necessary to fairly state the consolidated financial position, results of operations, and cash flows in accordance with accounting principles generally accepted in the United States of America("GAAP") for the periods covered by this quarterly report on Form 10-Q. The results of operations for the three-month period ended March 31, 20162017 are not necessarily indicative of the operating results for the full year.
The December 31, 20152016 financial statement data was derived from audited financial statements, but does not include all disclosures required by GAAP.
During the fourth quarter of 2016, Edison International and SCE early adopted an accounting principles generally acceptedstandard for share-based payments using the modified retrospective approach, effective January 1, 2016. Prior year financial statements have been updated to reflect the modified retrospective application of this accounting standard. For further information, see Note 1 and Note 18 of "Notes to Consolidated Financial Statements" included in the United States2016 Form 10-K and Note 2 and Note 7 of America. Certain prior year amounts have been reclassified for consistency with the current period presentation.this Form 10-Q.
Cash Equivalents
Cash equivalents includedincludes investments in money market funds. Generally, the carrying value of cash equivalents equals the fair value, as these investments have original maturities of three months or less. The cash equivalents were as follows:
| | | | | Edison International | | SCE | | Edison International | | SCE |
| (in millions) | | March 31,
2016 | | December 31, 2015 | | March 31,
2016 | | December 31, 2015 | | March 31,
2017 | | December 31, 2016 | | March 31,
2017 | | December 31, 2016 |
| Money market funds | | $ | 36 |
| | $ | 37 |
| | $ | 7 |
| | $ | 8 |
| | $ | 111 |
| | $ | 41 |
| | $ | 87 |
| | $ | 18 |
|
Cash is temporarily invested until required for check clearing. Checks issued, but not yet paid by the financial institution, are reclassified from cash to accounts payable at the end of each reporting period as follows:
|
| | | | | | | | | | | | | | | | |
| | | Edison International | | SCE |
| (in millions) | | March 31,
2016 | | December 31, 2015 | | March 31,
2016 | | December 31, 2015 |
| Book balances reclassified to accounts payable | | $ | 102 |
| | $ | 162 |
| | $ | 102 |
| | $ | 158 |
|
Inventory
Inventory is primarily composed of materials, supplies and spare parts, and stated at the lower of cost or market, cost being determined by the average cost method. |
| | | | | | | | | | | | | | | | |
| | | Edison International | | SCE |
| (in millions) | | March 31,
2017 | | December 31, 2016 | | March 31,
2017 | | December 31, 2016 |
| Book balances reclassified to accounts payable | | $ | 75 |
| | $ | 138 |
| | $ | 70 |
| | $ | 136 |
|
Revenue Recognition
Operating revenue is recognized when electricity is delivered and includes amounts for services rendered but unbilled at the
end of each reporting period. During the first quarter of 2015, SCE recognized revenue from CPUC activities largely based on 2014 authorized base revenue requirements included in customer rates. In the fourth quarter of 2015, SCE implemented its 2015 GRC decision which allowed SCE to recover its revenue requirement retroactive to January 1, 2015.
Earnings Per Share
Edison International computes earnings per common share ("EPS") using the two-class method, which is an earnings allocation formula that determines EPS for each class of common stock and participating security. Edison International's participating securities are stock-based compensation awards payable in common shares, including performance shares and restricted stock units, which earn dividend equivalents on an equal basis with common shares once the awards are vested. EPS attributable to Edison International common shareholders was computed as follows:
| | | | | Three months ended March 31, | | Three months ended March 31, |
| (in millions, except per-share amounts) | | 2016 | | 2015 | | 2017 | | 2016 |
| Basic earnings per share – continuing operations: | | | | | | | | |
| Income from continuing operations attributable to common shareholders | | $ | 270 |
| | $ | 299 |
| | $ | 362 |
| | $ | 280 |
|
| Participating securities dividends | | — |
| | — |
| | — |
| | — |
|
| Income from continuing operations available to common shareholders | | $ | 270 |
| | $ | 299 |
| | $ | 362 |
| | $ | 280 |
|
| Weighted average common shares outstanding | | 326 |
| | 326 |
| | 326 |
| | 326 |
|
| Basic earnings per share – continuing operations | | $ | 0.83 |
| | $ | 0.92 |
| | $ | 1.11 |
| | $ | 0.86 |
|
| Diluted earnings per share – continuing operations: | | | | | | | | |
| Income from continuing operations attributable to common shareholders | | | $ | 362 |
| | $ | 280 |
|
| Participating securities dividends | | | — |
| | — |
|
| Income from continuing operations available to common shareholders | | $ | 270 |
| | $ | 299 |
| | $ | 362 |
| | $ | 280 |
|
| Income impact of assumed conversions | | — |
| | — |
| | — |
| | — |
|
| Income from continuing operations available to common shareholders and assumed conversions | | $ | 270 |
| | $ | 299 |
| | $ | 362 |
| | $ | 280 |
|
| Weighted average common shares outstanding | | 326 |
| | 326 |
| | 326 |
| | 326 |
|
| Incremental shares from assumed conversions | | 2 |
| | 3 |
| | 3 |
| | 3 |
|
| Adjusted weighted average shares – diluted | | 328 |
| | 329 |
| | 329 |
| | 329 |
|
| Diluted earnings per share – continuing operations | | $ | 0.82 |
| | $ | 0.91 |
| | $ | 1.10 |
| | $ | 0.85 |
|
In addition to the participating securities discussed above, Edison International also may award stock options, which are payable in common shares and are included in the diluted earnings per share calculation. Stock option awards to purchase 2,023,7871,355,930 and 79,3942,023,787 shares of common stock for the three months ended March 31, 20162017 and 2015,2016, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the exercise price of the awards was greater than the average market price of the common shares during the respective periods and, therefore, the effect would have been antidilutive.
New Accounting Guidance
Accounting Guidance Adopted
On April 7, 2015, the FASB issued an accounting standards update that requires debt issuance costs to be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability, consistent with debt discounts. Previously, accounting guidance required these costs to be presented as a deferred charge asset. Edison International and SCE adopted this guidance in the first quarter of 2016. At March 31, 2016, the amount of debt issuance costs that are reflected as a deduction of "Long-term debt" was $76 million for SCE and $83 million for Edison International. At December 31, 2015 the amount of debt issuance costs that have been reclassified from "Other long-term assets" to a deduction of "Long-term debt" was $77 million for SCE and $81 million for Edison International.
On April 15, 2015, the FASB issued an accounting standards update on fees paid by a customer for software licenses. This new standard provides guidance about whether a cloud computing arrangement includes a software license which may be capitalized in certain circumstances. If a cloud computing arrangement does not include a software license, then the arrangement should be accounted for as a service contract. Edison International and SCE adopted this guidance prospectively, effective January 1, 2016. The adoption of this standard did not have a material impact on Edison International's and SCE's consolidated financial statements.
Accounting Guidance Not Yet Adopted
OnIn May 28, 2014, the FASBFinancial Accounting Standards Board ("FASB") issued an accounting standards update on revenue recognition including enhanced disclosures and further amended the standard in 2016.2016 and 2017. Under the new standard, revenue is recognized when (or as) a good or service is transferred to the customer and the customer obtains control of the good or service. On July 9, 2015, the FASB approved a one-year deferral, updating the effective date toThis standard will be adopted on January 1, 2018.Edison International and SCE are currently evaluating this new guidancehave completed the preliminary phases of their assessment of the impact on the consolidated financial statements and cannot determinedo not believe the impactadoption of this standard at this time.will have a material impact on the results of operations. As of March 31, 2017, approximately 98% of total operating revenue arises from SCE's tariff offerings that provide electricity to customers. For such arrangements, revenue from contracts with customers will be equivalent to the electricity supplied and billed in that period (including estimated billings). As such, there will not be a change in the timing or pattern of revenue recognition for such sales. Edison International and SCE anticipatesanticipate adopting the standard using the modified retrospective application which means that weEdison International and SCE would recognize the cumulative effect of initially applying the revenue standard as an adjustment to the opening balance of retained earnings in 2018.
OnIn January 5, 2016, the FASB issued an accounting standards update that amends the guidance on the classification and measurement of financial instruments. The amendments require equity investments (excluding those accounted for under the equity method or those that result in consolidation) to be measured at fair value, with changes in fair value recognized in net income. It also amends certain disclosure requirements associated with the fair value of financial instruments. In addition, the
new guidance requires financial assets and financial liabilities to be presented separately in the notes to the financial statements, grouped by measurement category and form of financial asset. Edison International and SCE will adopt this guidance effective January 1, 2018. The adoption of this standard is not expected to have a material impact on Edison International's and SCE's consolidated financial statements.
OnIn February 25, 2016, the FASB issued an accounting standards update related to lease accounting including enhanced disclosures. Under the new standard, a lease is defined as a contract, or part of a contract, that conveys the right to control the use of identified assets for a period of time in exchange for consideration. Lessees will classify leases with a term of more than one year as either operating or finance leases and will need to recognize leases on the balance sheet as a right-of-use asset and a related lease liability.liability, and classify the leases as either operating or finance. The liability will be equal to the present value of lease payments. The asset will be based on the liability, subject to adjustment, such as for initial direct costs. Operating leases will result in straight-line expense while finance leases will result in a front-loadedhigher initial expense pattern.pattern due to the interest component. SCE, as a regulated entity, is permitted to continue to have straight-line expense for finance leases, assuming the rate recovery is based upon current payments. Lessees can elect to exclude from the balance sheet short-term contracts one year or less. This guidance is effective January 1, 2019 but early2019. Early adoption is permitted.permitted, but Edison International and SCE do not expect to elect early adoption. The adoption of this standard is expected to increase right-of-use assets and lease liabilities in Edison International's and SCE's consolidated balance sheets. Edison International and SCE are currently evaluating this new guidance and cannot determine the impact of this standard at this time.will have on the results of operations and statements of cash flows.
On March 30, 2016,The FASB also issued accounting standards updates related to the impairment of financial instruments (effective January 1, 2020) and the presentation of certain cash receipts and payments in the statement of cash flows (effective January 1, 2018). Edison International and SCE are currently evaluating these updates to accounting standards.
In January 2017, the FASB issued an accounting standards update to simplify the accounting for share-based payments. Undergoodwill impairment. This accounting standards update changes the procedural steps in applying the goodwill impairment test. A goodwill impairment will now be the amount by which a reporting unit's carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. Edison International will apply this new guidance to the tax effectsgoodwill impairment test beginning in 2020.
In March 2017, the FASB issued an accounting standards update which amends the current requirements related to share based paymentsthe presentation of the components of net periodic benefit cost for an entity's defined benefit pension and other postretirement plans. The adoption of this standard is not expected to have a material impact on Edison International's and SCE's results of operations, but will be recorded throughresult in the separate presentation of service costs as an operating expense and non-service costs within other income statement. Currently, tax benefits in excess of compensation cost ("windfalls") are recorded in equity, and tax deficiencies ("shortfalls") are recorded in equity to the extent of previous windfalls, and then to the income statement. This guidance is effective January 1, 2017 but early adoption is permitted. The new standard also revised reporting on the statement of cash flows.expense. Edison International and SCE are currently evaluating the impact this standard will have on the consolidated balance sheets. The new guidance.standards update is effective on January 1, 2018. It is required to be applied on a retrospective basis for the presentation of the service cost component and the other components of net benefit cost and on a prospective basis for the capitalization of only the service cost component of net benefit cost.
Note 2. Consolidated Statements of Changes in Equity
The following table provides Edison International's changes in equity for the three months ended March 31, 2016:2017:
| | | | Equity Attributable to Common Shareholders | | Noncontrolling Interests | | | Equity Attributable to Common Shareholders | | Noncontrolling Interests | | |
| (in millions, except per-share amounts) | Common Stock | | Accumulated
Other
Comprehensive Loss | | Retained Earnings | | Subtotal | | Preferred and Preference Stock | | Total Equity | Common Stock | | Accumulated
Other
Comprehensive Loss | | Retained Earnings | | Subtotal | | Preferred and Preference Stock | | Total Equity |
| Balance at December 31, 2015 | $ | 2,484 |
| | $ | (56 | ) | | $ | 8,940 |
| | $ | 11,368 |
| | $ | 2,020 |
| | $ | 13,388 |
| |
| Balance at December 31, 2016 | | $ | 2,505 |
| | $ | (53 | ) | | $ | 9,544 |
| | $ | 11,996 |
| | $ | 2,191 |
| | $ | 14,187 |
|
| Net income | — |
| | — |
| | 271 |
| | 271 |
| | 30 |
| | 301 |
| — |
| | — |
| | 362 |
| | 362 |
| | 31 |
| | 393 |
|
| Other comprehensive income | — |
| | 2 |
| | — |
| | 2 |
| | — |
| | 2 |
| — |
| | 4 |
| | — |
| | 4 |
| | — |
| | 4 |
|
| Common stock dividends declared ($0.48 per share) | — |
| | — |
| | (156 | ) | | (156 | ) | | — |
| | (156 | ) | |
| Common stock dividends declared ($0.5425 per share) | | — |
| | — |
| | (177 | ) | | (177 | ) | | — |
| | (177 | ) |
| Dividends to noncontrolling interests | — |
| | — |
| | — |
| | — |
| | (30 | ) | | (30 | ) | — |
| | — |
| | — |
| | — |
| | (31 | ) | | (31 | ) |
| Stock-based compensation | 1 |
| | — |
| | (50 | ) | | (49 | ) | | — |
| | (49 | ) | — |
| | — |
| | (139 | ) | | (139 | ) | | — |
| | (139 | ) |
| Non-cash stock-based compensation | 6 |
| | — |
| | — |
| | 6 |
| | — |
| | 6 |
| 5 |
| | — |
| | — |
| | 5 |
| | — |
| | 5 |
|
| Issuance of preference stock | — |
| | — |
| | — |
| | — |
| | 294 |
| | 294 |
| |
| Redemption of preference stock | — |
| | — |
| | (3 | ) | | (3 | ) | | (122 | ) | | (125 | ) | |
| Balance at March 31, 2016 | $ | 2,491 |
| | $ | (54 | ) | | $ | 9,002 |
| | $ | 11,439 |
| | $ | 2,192 |
| | $ | 13,631 |
| |
| Balance at March 31, 2017 | | $ | 2,510 |
| | $ | (49 | ) | | $ | 9,590 |
| | $ | 12,051 |
| | $ | 2,191 |
| | $ | 14,242 |
|
The following table provides Edison International's changes in equity for the three months ended March 31, 20152016:
| | | | Equity Attributable to Common Shareholders | | Noncontrolling Interests | | | Equity Attributable to Common Shareholders | | Noncontrolling Interests | | |
| (in millions, except per-share amounts) | Common Stock | | Accumulated
Other
Comprehensive Loss | | Retained Earnings | | Subtotal | | Preferred and Preference Stock | | Total Equity | Common Stock | | Accumulated
Other
Comprehensive Loss | | Retained Earnings | | Subtotal | | Preferred and Preference Stock | | Total Equity |
| Balance at December 31, 2014 | $ | 2,445 |
| | $ | (58 | ) | | $ | 8,573 |
| | $ | 10,960 |
| | $ | 2,022 |
| | $ | 12,982 |
| |
| Balance at December 31, 2015 | | $ | 2,484 |
| | $ | (56 | ) | | $ | 8,940 |
| | $ | 11,368 |
| | $ | 2,020 |
| | $ | 13,388 |
|
| Net income | — |
| | — |
| | 299 |
| | 299 |
| | 28 |
| | 327 |
| — |
| | — |
| | 281 |
| 1 | 281 |
| | 30 |
| | 311 |
|
| Other comprehensive loss | — |
| | (1 | ) | | — |
| | (1 | ) | | — |
| | (1 | ) | |
| Common stock dividends declared ($0.4175 per share) | — |
| | — |
| | (136 | ) | | (136 | ) | | — |
| | (136 | ) | |
| Other comprehensive income | | — |
| | 2 |
| | — |
| | 2 |
| | — |
| | 2 |
|
| Common stock dividends declared ($0.4800 per share) | | — |
| | — |
| | (156 | ) | | (156 | ) | | — |
| | (156 | ) |
| Dividends to noncontrolling interests | — |
| | — |
| | — |
| | — |
| | (28 | ) | | (28 | ) | — |
| | — |
| | — |
| | — |
| | (30 | ) | | (30 | ) |
| Stock-based compensation | 9 |
| | — |
| | (61 | ) | | (52 | ) | | — |
| | (52 | ) | — |
| | — |
| | (8 | ) | 1 | (8 | ) | | — |
| | (8 | ) |
| Non-cash stock-based compensation | 6 |
| | — |
| | — |
| | 6 |
| | — |
| | 6 |
| 6 |
| | — |
| | — |
| | 6 |
| | — |
| | 6 |
|
| Balance at March 31, 2015 | $ | 2,460 |
| | $ | (59 | ) | | $ | 8,675 |
| | $ | 11,076 |
| | $ | 2,022 |
| | $ | 13,098 |
| |
| Issuance of preference stock | | — |
| | — |
| | — |
| | — |
| | 294 |
| | 294 |
|
| Redemption of preference stock | | — |
| | — |
| | (3 | ) | | (3 | ) | | (122 | ) | | (125 | ) |
| Balance at March 31, 2016 | | $ | 2,490 |
| | $ | (54 | ) | | $ | 9,054 |
| | $ | 11,490 |
| | $ | 2,192 |
| | $ | 13,682 |
|
| |
1 | Edison International adopted an accounting standard related to share-based payments during the fourth quarter of 2016, effective January 1, 2016. See Note 1 for further information. The table above reflects the adoption of this standard on January 1, 2016. Net income and stock-based compensation (as previously reported) were $271 million and $(50) million, respectively, for the three months ended March 31, 2016. |
The following table provides SCE's changes in equity for the three months ended March 31, 2016:2017:
| | | | Equity Attributable to Edison International | | | | | Equity Attributable to Edison International | | | | |
| (in millions) | Common
Stock | | Additional
Paid-in
Capital | | Accumulated
Other
Comprehensive Loss | | Retained
Earnings | | Preferred
and
Preference
Stock | | Total
Equity | Common
Stock | | Additional
Paid-in
Capital | | Accumulated
Other
Comprehensive Loss | | Retained
Earnings | | Preferred
and
Preference
Stock | | Total
Equity |
| Balance at December 31, 2015 | $ | 2,168 |
| | $ | 652 |
| | $ | (22 | ) | | $ | 8,804 |
| | $ | 2,070 |
| | $ | 13,672 |
| |
| Balance at December 31, 2016 | | $ | 2,168 |
| | $ | 657 |
| | $ | (20 | ) | | $ | 9,433 |
| | $ | 2,245 |
| | $ | 14,483 |
|
| Net income | — |
| | — |
| | — |
| | 317 |
| | — |
| | 317 |
| — |
| | — |
| | — |
| | 380 |
| | — |
| | 380 |
|
| Other comprehensive income | — |
| | — |
| | 1 |
| | — |
| | — |
| | 1 |
| — |
| | — |
| | 2 |
| | — |
| | — |
| | 2 |
|
| Dividends declared on common stock | — |
| | — |
| | — |
| | (170 | ) | | — |
| | (170 | ) | — |
| | — |
| | — |
| | (191 | ) | | — |
| | (191 | ) |
| Dividends declared on preferred and preference stock | — |
| | — |
| | — |
| | (30 | ) | | — |
| | (30 | ) | — |
| | — |
| | — |
| | (31 | ) | | — |
| | (31 | ) |
| Stock-based compensation | — |
| | 1 |
| | — |
| | (34 | ) | | — |
| | (33 | ) | — |
| | — |
| | — |
| | (23 | ) | | — |
| | (23 | ) |
| Non-cash stock-based compensation | — |
| | 3 |
| | — |
| | — |
| | — |
| | 3 |
| — |
| | 3 |
| | — |
| | — |
| | — |
| | 3 |
|
| Issuance of preference stock | — |
| | (6 | ) | | — |
| | — |
| | 300 |
| | 294 |
| |
| Redemption of preference stock | — |
| | 3 |
| | — |
| | (3 | ) | | (125 | ) | | (125 | ) | |
| Balance at March 31, 2016 | $ | 2,168 |
| | $ | 653 |
| | $ | (21 | ) | | $ | 8,884 |
| | $ | 2,245 |
| | $ | 13,929 |
| |
| Balance at March 31, 2017 | | $ | 2,168 |
| | $ | 660 |
| | $ | (18 | ) | | $ | 9,568 |
| | $ | 2,245 |
| | $ | 14,623 |
|
The following table provides SCE's changes in equity for the three months ended March 31, 20152016:
| | | | Equity Attributable to Edison International | | | | | Equity Attributable to Edison International | | | | |
| (in millions) | Common
Stock | | Additional
Paid-in
Capital | | Accumulated
Other
Comprehensive
Loss | | Retained
Earnings | | Preferred
and
Preference
Stock | | Total
Equity | Common
Stock | | Additional
Paid-in
Capital | | Accumulated
Other
Comprehensive
Loss | | Retained
Earnings | | Preferred
and
Preference
Stock | | Total
Equity |
| Balance at December 31, 2014 | $ | 2,168 |
| | $ | 618 |
| | $ | (28 | ) | | $ | 8,454 |
| | $ | 2,070 |
| | $ | 13,282 |
| |
| Balance at December 31, 2015 | | $ | 2,168 |
| | $ | 652 |
| | $ | (22 | ) | | $ | 8,804 |
| | $ | 2,070 |
| | $ | 13,672 |
|
| Net income | — |
| | — |
| | — |
| | 333 |
| | — |
| | 333 |
| — |
| | — |
| | — |
| | 325 |
| 1 | — |
| | 325 |
|
| Other comprehensive income | — |
| | — |
| | 1 |
| | — |
| | — |
| | 1 |
| — |
| | — |
| | 1 |
| | — |
| | — |
| | 1 |
|
| Dividends declared on common stock | — |
| | — |
| | — |
| | (147 | ) | | — |
| | (147 | ) | — |
| | — |
| | — |
| | (170 | ) | | — |
| | (170 | ) |
| Dividends declared on preferred and preference stock | — |
| | — |
| | — |
| | (28 | ) | | — |
| | (28 | ) | — |
| | — |
| | — |
| | (30 | ) | | — |
| | (30 | ) |
| Stock-based compensation | — |
| | 9 |
| | — |
| | (22 | ) | | — |
| | (13 | ) | — |
| | — |
| | — |
| | (28 | ) | 1 | — |
| | (28 | ) |
| Non-cash stock-based compensation | — |
| | 4 |
| | — |
| | — |
| | — |
| | 4 |
| — |
| | 3 |
| | — |
| | — |
| | — |
| | 3 |
|
| Balance at March 31, 2015 | $ | 2,168 |
| | $ | 631 |
| | $ | (27 | ) | | $ | 8,590 |
| | $ | 2,070 |
| | $ | 13,432 |
| |
| Issuance of preference stock | | — |
| | (6 | ) | | — |
| | — |
| | 300 |
| | 294 |
|
| Redemption of preference stock | | — |
| | 3 |
| | — |
| | (3 | ) | | (125 | ) | | (125 | ) |
| Balance at March 31, 2016 | | $ | 2,168 |
| | $ | 652 |
| | $ | (21 | ) | | $ | 8,898 |
| | $ | 2,245 |
| | $ | 13,942 |
|
| |
1 | SCE adopted an accounting standard related to share-based payments during the fourth quarter of 2016, effective January 1, 2016. See Note 1 for further information. The table above reflects the adoption of this standard on January 1, 2016. Net income and stock-based compensation (as previously reported) were $317 million and $(34) million, respectively, for the three months ended March 31, 2016. |
Note 3. Variable Interest Entities
A VIE is defined as a legal entity that meets one of two conditions: (1) the equity owners do not have sufficient equity at risk, or (2) the holders of the equity investment at risk, as a group, lack any of the following three characteristics: decision-making rights, the obligation to absorb losses, or the right to receive the expected residual returns of the entity. The primary beneficiary is identified as the variable interest holder that has both the power to direct the activities of the VIE that most significantly impact the entity's economic performance and the obligation to absorb losses or the right to receive benefits from the entity that could potentially be significant to the VIE. The primary beneficiary is required to consolidate the VIE. A subsidiary of Edison International is the primary beneficiary of an entityentities that ownsown rooftop solar projects. Commercial and operating activities are generally the factors that most significantly impact the economic performance of such VIEs. Commercial and operating activities include construction, operation and maintenance, fuel procurement, dispatch, and compliance with regulatory and contractual requirements.
Variable Interest in VIEs that are not Consolidated
Power Purchase ContractsAgreements
SCE has power purchase agreements ("PPAs") that are classified as variable interests in VIEs, including tolling agreements through which SCE provides the natural gas to fuel the plants and contracts with qualifying facilities ("QFs") that contain variable pricing provisions based on the price of natural gas. SCE has concluded that it is not the primary beneficiary of these VIEs since it does not control the commercial and operating activities of these entities. Since payments for capacity are the primary source of income, the most significant economic activity for these VIEs is the operation and maintenance of the power plants.
As of the balance sheet date, the carrying amount of assets and liabilities in SCE's consolidated balance sheet that relate to its involvement with VIEs result from amounts due under the PPAs or the fair value of those derivative contracts. Under these contracts, SCE recovers the costs incurred through demonstration of compliance with its CPUC-approvedCalifornia Public Utilities Commission ("CPUC")-approved long-term power procurement plans. SCE has no residual interest in the entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees, or other commitments associated with these contracts other than the purchase commitments described in Note 11 of the 20152016 Form 10-K. As a result, there is no significant potential exposure to loss to SCE from its variable interest in these VIEs. The aggregate contracted capacity dedicated to SCE from these VIE projects was 4,3834,928 MW and 4,1254,383 MW at March 31, 20162017 and 20152016, respectively, and the amounts that SCE paid to these projects were $127140 million and $103127 million for the three months ended March 31, 20162017 and 2015,2016, respectively. These amounts are recoverable in customer rates, subject to reasonableness review.
Unconsolidated Trusts of SCE
SCE Trust I, Trust II, Trust III, Trust IV, and Trust V were formed in 2012, 2013, 2014, 2015, and 2016, respectively, for the exclusive purpose of issuing the 5.625%, 5.10%, 5.75%, 5.375%, and 5.45% trust preference securities, respectively ("trust securities"). The trusts are VIEs. SCE has concluded that it is not the primary beneficiary of these VIEs as it does not have the obligation to absorb the expected losses or the right to receive the expected residual returns of the trusts. SCE Trust I, Trust II, Trust III, Trust IV, and Trust V issued to the public trust securities in the face amounts of $475 million, $400 million, $275 million, $325 million, and $300 million respectively, (cumulative, liquidation amounts of $25 per share), respectively, and $10,000 of common stock each to SCE. The trusts invested the proceeds of these trust securities in Series F, Series G, Series H, Series J, and Series K Preference Stock issued by SCE in the principal amounts of $475 million, $400 million, $275 million, $325 million, and $300 million (cumulative, $2,500 per share liquidation values), respectively, which have substantially the same payment terms as the respective trust securities.
The Series F, Series G, Series H, Series J, and Series K Preference Stock and the corresponding trust securities do not have a maturity date. Upon any redemption of any shares of the Series F, Series G, Series H, Series J, or Series K Preference Stock, a corresponding dollar amount of trust securities will be redeemed by the applicable trust (see Note 12 for further information).trust. The applicable trust will make distributions at the same rate and on the same dates on the applicable series of trust securities whenif and ifwhen the SCE board of directors declares and makes dividend payments on the related Preference Stock. The applicable trust will use any dividends it receives on the related Preference Stock to make its corresponding distributions on the applicable series of trust securities. If SCE does not make a dividend payment to any of these trusts, SCE would be prohibited from paying dividends on its common stock. SCE has fully and unconditionally guaranteed the payment of the trust securities and trust distributions, if and when SCE pays dividends on the related Preference Stock.
The Trust I, Trust II, Trust III, Trust IV, and Trust IVV balance sheets as of March 31, 20162017 and December 31, 20152016, consisted of investments of $475 million, $400 million, $275 million, $325 million, and $325$300 million in the Series F, Series G, Series H, Series J, and Series JK Preference Stock, respectively, $475 million, $400 million, $275 million, $325 million, and $325$300 million of trust securities, respectively, and $10,000 each of common stock. The Trust V balance sheet as of March 31, 2016 consisted of investments of $300 million in the Series K Preference Stock, $300 million of trust securities, and $10,000 of common stock.
The following table provides a summary of the trusts' income statements:
| | | | | Three months ended March 31, | | Three months ended March 31, |
| (in millions) | | Trust I | | Trust II | | Trust III | | Trust IV | | Trust V | | Trust I | | Trust II | | Trust III | | Trust IV | | Trust V |
| 2017 | | | | | | | | | | | |
| Dividend income | | | $ | 7 |
| | $ | 5 |
| | $ | 4 |
| | $ | 4 |
| | $ | 4 |
|
| Dividend distributions | | | 7 |
| | 5 |
| | 4 |
| | 4 |
| | 4 |
|
| 2016 | | | | | | | | | | | | | | | | | | | | |
| Dividend income | | $ | 7 |
| | $ | 5 |
| | $ | 4 |
| | $ | 4 |
| | $ | 1 |
| | $ | 7 |
|
| $ | 5 |
|
| $ | 4 |
| | $ | 4 |
| | $ | 1 |
|
| Dividend distributions | | 7 |
| | 5 |
| | 4 |
| | 4 |
| | 1 |
| | 7 |
|
| 5 |
|
| 4 |
| | 4 |
| | 1 |
|
| 2015 | | | | | | | | | | | |
| Dividend income | | $ | 7 |
|
| $ | 5 |
|
| $ | 4 |
| | * |
| | * |
| |
| Dividend distributions | | 7 |
|
| 5 |
|
| 4 |
| | * |
| | * |
| |
* Not applicable.
Note 4. Fair Value Measurements
Recurring Fair Value Measurements
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (referred to as an "exit price"). Fair value of an asset or liability considers assumptions that market participants would use in pricing the asset or liability, including assumptions about nonperformance risk. As of March 31, 20162017 and December 31, 20152016, nonperformance risk was not material for Edison International and SCE.
Assets and liabilities are categorized into a three-level fair value hierarchy based on valuation inputs used to determine fair value.
Level 1 – The fair value of Edison International's and SCE's Level 1 assets and liabilities is determined using unadjusted quoted prices in active markets that are available at the measurement date for identical assets and liabilities. This level includes exchange-traded equity securities, U.S. treasury securities, mutual funds, and money market funds.
Level 2 – Edison InternationalInternational's and SCE's Level 2 assets and liabilities include fixed income securities, primarily consisting of U.S. government and agency bonds, municipal bonds and corporate bonds, and over-the-counter derivatives. The fair value of fixed income securities is determined using a market approach by obtaining quoted prices for similar assets and liabilities in active markets and inputs that are observable, either directly or indirectly, for substantially the full term of the instrument.
The fair value of SCE's over-the-counter derivative contracts is determined using an income approach. SCE uses standard pricing models to determine the net present value of estimated future cash flows. Inputs to the pricing models include forward published or posted clearing prices from exchanges (New York Mercantile Exchange and Intercontinental Exchange) for similar instruments and discount rates. A primary price source that best represents trade activity for each market is used to develop observable forward market prices in determining the fair value of these positions. Broker quotes, prices from exchanges, or comparison to executed trades are used to validate and corroborate the primary price source. These price quotations reflect mid-market prices (average of bid and ask) and are obtained from sources believed to provide the most liquid market for the commodity.
Level 3 – The fair value of SCE's Level 3 assets and liabilities is determined using the income approach through various models and techniques that require significant unobservable inputs. This level includes over-the-counter options, tolling arrangements and derivative contracts that trade infrequently such as congestion revenue rights ("CRRs") and long-term power agreements.. Edison International Parent and Other does not have any Level 3 assets and liabilities.
Assumptions are made in order to value derivative contracts in which observable inputs are not available. Changes in fair value are based on changes to forward market prices, including extrapolation of short-term observable inputs into forecasted prices for illiquid forward periods. In circumstances where fair value cannot be verified with observable market transactions, it is possible that a different valuation model could produce a materially different estimate of fair value. Modeling methodologies, inputs, and techniques are reviewed and assessed as markets continue to develop and more pricing information becomes available and the fair value is adjusted when it is concluded that a change in inputs or techniques would result in a new valuation that better reflects the fair value of those derivative contracts. See Note 6 for a discussion of fair value of derivative instruments.
SCE
The following table sets forth assets and liabilities of SCE that were accounted for at fair value by level within the fair value hierarchy: |
| | | | | | | | | | | | | | | | | | | |
| | March 31, 2017 |
| (in millions) | Level 1 | | Level 2 | | Level 3 | | Netting and Collateral1 | | Total |
| Assets at fair value | | | | | | | | | |
| Derivative contracts | $ | — |
| | $ | 15 |
| | $ | 55 |
| | $ | — |
| | $ | 70 |
|
| Other | 103 |
| | — |
| | — |
| | — |
| | 103 |
|
| Nuclear decommissioning trusts: | | | | | | | | | |
Stocks2 | 1,537 |
| | — |
| | — |
| | — |
| | 1,537 |
|
Fixed Income3 | 1,153 |
| | 1,588 |
| | — |
| | — |
| | 2,741 |
|
| Short-term investments, primarily cash equivalents | 88 |
| | 84 |
| | — |
| | — |
| | 172 |
|
Subtotal of nuclear decommissioning trusts4 | 2,778 |
| | 1,672 |
| | — |
| | — |
| | 4,450 |
|
| Total assets | 2,881 |
| | 1,687 |
| | 55 |
| | — |
| | 4,623 |
|
| Liabilities at fair value | | | | | | | | | |
| Derivative contracts | — |
| | 5 |
| | 1,221 |
| | — |
| | 1,226 |
|
| Total liabilities | — |
| | 5 |
| | 1,221 |
| | — |
| | 1,226 |
|
| Net assets (liabilities) | $ | 2,881 |
| | $ | 1,682 |
| | $ | (1,166 | ) | | $ | — |
| | $ | 3,397 |
|
|
| | | | | | | | | | | | | | | | | | | |
| | December 31, 2016 |
| (in millions) | Level 1 | | Level 2 | | Level 3 | | Netting and Collateral1 | | Total |
| Assets at fair value | | | | | | | | | |
| Derivative contracts | $ | — |
| | $ | 6 |
| | $ | 68 |
| | $ | — |
| | $ | 74 |
|
| Other | 33 |
| | — |
| | — |
| | — |
| | 33 |
|
| Nuclear decommissioning trusts: | | | | | | | | | |
Stocks2 | 1,547 |
| | — |
| | — |
| | — |
| | 1,547 |
|
Fixed Income3 | 865 |
| | 1,751 |
| | — |
| | — |
| | 2,616 |
|
| Short-term investments, primarily cash equivalents | 36 |
| | 170 |
| | — |
| | — |
| | 206 |
|
Subtotal of nuclear decommissioning trusts4 | 2,448 |
| | 1,921 |
| | — |
| | — |
| | 4,369 |
|
| Total assets | 2,481 |
| | 1,927 |
| | 68 |
| | — |
| | 4,476 |
|
| Liabilities at fair value | | | | | | | | | |
| Derivative contracts | — |
| | — |
| | 1,157 |
| | — |
| | 1,157 |
|
| Total liabilities | — |
| | — |
| | 1,157 |
| | — |
| | 1,157 |
|
| Net assets (liabilities) | $ | 2,481 |
| | $ | 1,927 |
| | $ | (1,089 | ) | | $ | — |
| | $ | 3,319 |
|
|
| | | | | | | | | | | | | | | | | | | |
| | March 31, 2016 |
| (in millions) | Level 1 | | Level 2 | | Level 3 | | Netting and Collateral1 | | Total |
| Assets at fair value | | | | | | | | | |
| Derivative contracts | $ | — |
| | $ | — |
| | $ | 143 |
| | $ | — |
| | $ | 143 |
|
| Other | 28 |
| | — |
| | — |
| | — |
| | 28 |
|
| Nuclear decommissioning trusts: | | | | | | | | | |
Stocks2 | 1,464 |
| | — |
| | — |
| | — |
| | 1,464 |
|
Fixed Income3 | 907 |
| | 1,810 |
| | — |
| | — |
| | 2,717 |
|
| Short-term investments, primarily cash equivalents | 69 |
| | 48 |
| | — |
| | — |
| | 117 |
|
Subtotal of nuclear decommissioning trusts4 | 2,440 |
| | 1,858 |
| | — |
| | — |
| | 4,298 |
|
| Total assets | 2,468 |
| | 1,858 |
| | 143 |
| | — |
| | 4,469 |
|
| Liabilities at fair value | | | | | | | | | |
| Derivative contracts | — |
| | 21 |
| | 1,356 |
| | (11 | ) | | 1,366 |
|
| Total liabilities | — |
| | 21 |
| | 1,356 |
| | (11 | ) | | 1,366 |
|
| Net assets (liabilities) | $ | 2,468 |
| | $ | 1,837 |
| | $ | (1,213 | ) | | $ | 11 |
| | $ | 3,103 |
|
|
| | | | | | | | | | | | | | | | | | | |
| | December 31, 2015 |
| (in millions) | Level 1 | | Level 2 | | Level 3 | | Netting and Collateral1 | | Total |
| Assets at fair value | | | | | | | | | |
| Derivative contracts | $ | — |
| | $ | — |
| | $ | 163 |
| | $ | — |
| | $ | 163 |
|
| Other | 28 |
| | — |
| | — |
| | — |
| | 28 |
|
| Nuclear decommissioning trusts: | | | | | | | | | |
Stocks2 | 1,460 |
| | — |
| | — |
| | — |
| | 1,460 |
|
Fixed Income3 | 947 |
| | 1,776 |
| | — |
| | — |
| | 2,723 |
|
| Short-term investments, primarily cash equivalents | 91 |
| | 81 |
| | — |
| | — |
| | 172 |
|
Subtotal of nuclear decommissioning trusts4 | 2,498 |
| | 1,857 |
| | — |
| | — |
| | 4,355 |
|
| Total assets | 2,526 |
| | 1,857 |
| | 163 |
| | — |
| | 4,546 |
|
| Liabilities at fair value | | | | | | | | | |
| Derivative contracts | — |
| | 22 |
| | 1,311 |
| | (15 | ) | | 1,318 |
|
| Total liabilities | — |
| | 22 |
| | 1,311 |
| | (15 | ) | | 1,318 |
|
| Net assets (liabilities) | $ | 2,526 |
| | $ | 1,835 |
| | $ | (1,148 | ) | | $ | 15 |
| | $ | 3,228 |
|
| |
1 | Represents the netting of assets and liabilities under master netting agreements and cash collateral across the levels of the fair value hierarchy. Netting among positions classified within the same level is included in that level. |
| |
2 | Approximately 68% and 70% of SCE's equity investments were located in the United States at both March 31, 20162017 and December 31, 2015. 2016, respectively. |
| |
3 | Includes corporate bonds, which were diversified and included collateralized mortgage obligations and other asset backed securities of $101$83 million and $111$79 million at March 31, 20162017 and December 31, 2015,2016, respectively. |
| |
4 | Excludes net payables of $8$98 million and net payables of $24$127 million at March 31, 20162017 and December 31, 2015,2016, respectively, which consist of interest and dividend receivables as well as receivables and payables related to SCE's pending securities sales and purchases. |
Edison International Parent and Other
Edison International Parent and Other assets measured at fair value consisted of money market funds of $3024 million and $29$23 million at March 31, 20162017 and December 31, 20152016, respectively, classified as Level 1.
SCE Fair Value of Level 3
The following table sets forth a summary of changes in SCE's fair value of Level 3 net derivative assets and liabilities: | | | | | Three months ended March 31, | | Three months ended March 31, |
| (in millions) | | 2016 | | 2015 | | 2017 | | 2016 |
| Fair value of net liabilities at beginning of period | | $ | (1,148 | ) | | $ | (902 | ) | | $ | (1,089 | ) | | $ | (1,148 | ) |
| Total realized/unrealized gains (losses): | | | | | |
| Total realized/unrealized losses: | | | | | |
Included in regulatory assets and liabilities1 | | (65 | ) | | (74 | ) | | (77 | ) | | (65 | ) |
| Fair value of net liabilities at end of period | | $ | (1,213 | ) | | $ | (976 | ) | | $ | (1,166 | ) | | $ | (1,213 | ) |
| Change during the period in unrealized gains and losses related to assets and liabilities held at the end of the period | | $ | (84 | ) | | $ | (96 | ) | | $ | (102 | ) | | $ | (84 | ) |
| |
1 | Due to regulatory mechanisms, SCE's realized and unrealized gains and losses are recorded as regulatory assets and liabilities. |
Edison International and SCE recognize the fair value for transfers in and transfers out of each level at the end of each reporting period. There were no significantmaterial transfers between any levels during 20162017 and 20152016.
Valuation Techniques Used to Determine Fair Value
The process of determining fair value is the responsibility of SCE's risk management department, which reports to SCE's chief financial officer. This department obtains observable and unobservable inputs through broker quotes, exchanges, and internal valuation techniques that use both standard and proprietary models to determine fair value. Each reporting period, the risk and finance departments collaborate to determine the appropriate fair value methodologies and classifications for each derivative. Inputs are validated for reasonableness by comparison against prior prices, other broker quotes, and volatility fluctuation thresholds. Inputs used and valuations are reviewed period-over-period and compared with market conditions to determine reasonableness.
The following table sets forth SCE's valuation techniques and significant unobservable inputs used to determine fair value for significant Level 3 assets and liabilities: |
| | | | | | | | | | |
| | Fair Value (in millions) | | Significant | Range |
| | Assets | | Liabilities | Valuation Technique(s) | Unobservable Input | (Weighted Average) |
| Congestion revenue rights | | | | | |
| March 31, 2016 | $ | 136 |
| | $ | — |
| Market simulation model and auction prices | Load forecast | 6,289 MW - 24,349 MW |
| | | | | | Power prices1 | $0 - $110.44 |
| | | | | | Gas prices2 | $1.98 - $5.72 |
| December 31, 2015 | 152 |
| | — |
| Market simulation model and auction prices | Load forecast | 6,289 MW - 24,349 MW |
| | | | | | Power prices1 | $0 - $110.44 |
| | | | | | Gas prices2 | $1.98 - $5.72 |
| Tolling | | | | | | |
| March 31, 2016 | 7 |
| | 1,329 |
| Option model | Volatility of gas prices | 16% - 46% (30%) |
| | | | | | Volatility of power prices | 26% - 86% (40%) |
| | | | | | Power prices | $17.67 - $47.29 ($33.00) |
| December 31, 2015 | 10 |
| | 1,297 |
| Option model | Volatility of gas prices | 15% - 58% (20%) |
| | | | | | Volatility of power prices | 26% - 38% (30%) |
| | | | | | Power prices | $24.15 - $46.93 ($34.80) |
|
| | | | | | | | | | |
| | Fair Value (in millions) | | Significant | Range |
| | Assets | | Liabilities | Valuation Technique(s) | Unobservable Input | (Weighted Average) |
| Congestion revenue rights | | | | | |
| March 31, 2017 | $ | 55 |
| | $ | — |
| Market simulation model and auction prices | Load forecast | 3,708 MW - 22,840 MW |
| | | | | | Power prices1 | $3.65 - $99.58 |
| | | | | | Gas prices2 | $2.51 - $4.87 |
| December 31, 2016 | 67 |
| | — |
| Market simulation model and auction prices | Load forecast | 3,708 MW - 22,840 MW |
| | | | | | Power prices1 | $3.65 - $99.58 |
| | | | | | Gas prices2 | $2.51 - $4.87 |
| Tolling | | | | | | |
| March 31, 2017 | — |
| | 1,210 |
| Option model | Volatility of gas prices | 16% - 39% (25%) |
| | | | | | Volatility of power prices | 26% - 140% (36%) |
| | | | | | Power prices | $18.01 - $45.28 ($30.70) |
| December 31, 2016 | — |
| | 1,154 |
| Option model | Volatility of gas prices | 15% - 48% (20%) |
| | | | | | Volatility of power prices | 29% - 71% (40%) |
| | | | | | Power prices | $23.40 - $51.24 ($34.70) |
| |
1 | Prices are in dollars per megawatt-hour. |
| |
2 | Prices are in dollars per million British thermal units. |
Level 3 Fair Value Sensitivity
Congestion Revenue Rights
For CRRs, where SCE is the buyer, generally increases (decreases) in forecasted load in isolation would result in increases (decreases) to the fair value. In general, an increase (decrease) in electricity and gas prices at illiquid locations tends to result in increases (decreases) to fair value; however, changes in electricity and gas prices in opposite directions may have varying results on fair value.
Tolling Arrangements
The fair values of SCE's tolling arrangements contain intrinsic value and time value. Intrinsic value is the difference between the market price and strike price of the underlying commodity. Time value is made up of several components, including volatility, time to expiration, and interest rates. The option model for tolling arrangements reflects plant specific information such as operating and start-up costs.
For tolling arrangements where SCE is the buyer, increases in volatility of the underlying commodity prices would result in increases to fair value as it represents greater price movement risk. As power and gas prices increase, the fair value of tolling arrangements tends to increase. The valuation of tolling arrangements is also impacted by the correlation between gas and power prices. As the correlation increases, the fair value of tolling arrangements tends to decline.
Nuclear Decommissioning Trusts
SCE's nuclear decommissioning trust investments include equity securities, U.S. treasury securities, and other fixed income securities. Equity and treasury securities are classified as Level 1 as fair value is determined by observable market prices in active or highly liquid and transparent markets. The remaining fixed income securities are classified as Level 2. The fair value of these financial instruments is based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes, issuer spreads, bids, offers, and relevant credit information.
Fair Value of Debt Recorded at Carrying Value
The carrying value and fair value of Edison International's and SCE's long-term debt (including current portion of long-term debt) are as follows:
| | | | | March 31, 2016 | | December 31, 2015 | | March 31, 2017 | | December 31, 2016 |
| (in millions) | | Carrying Value | | Fair Value | | Carrying Value | | Fair Value | | Carrying Value1 | | Fair Value | | Carrying Value1 | | Fair Value |
| SCE | | $ | 10,501 |
| | $ | 12,045 |
| | $ | 10,616 |
| | $ | 11,592 |
| | $ | 11,422 |
| | $ | 12,665 |
| | $ | 10,333 |
| | $ | 11,539 |
|
| Edison International | | 11,538 |
| | 13,109 |
| | 11,259 |
| | 12,252 |
| | 12,643 |
| | 13,894 |
| | 11,156 |
| | 12,368 |
|
| |
1 | Carrying value is net of debt issuance costs. |
The fair value of Edison InternationalInternational's and SCE's short-term and long-term debt is classified as Level 2 and is based on evaluated prices that reflect significant observable market information such as reported trades, actual trade information of similar securities, benchmark yields, broker/dealer quotes of new issue prices, and relevant credit information.
The carrying value of Edison International's and SCE's trade receivables and payables, other investments, and short-term debt approximates fair value.
Note 5. Debt and Credit Agreements
Long-Term Debt
In January 2017, SCE borrowed $300 million under a Term Loan Agreement due July 2018, with a variable interest rate based on the London Interbank Offered Rate plus 65 basis points (1.53% at March 2016,31, 2017). The proceeds were used for general corporate purposes.
In January 2017, SCE reissued $135 million of 2.625% pollution-control bonds subject to mandatory remarketing in December 2023. The proceeds were used for general corporate purposes.
In March 2017, SCE issued $700 million of 4.00% first and refunding mortgage bonds due in 2047 and Edison International issued $400 million of 2.95%2.125% senior notes due in 2023.2020. The proceeds from these bonds were used to repay commercial paper borrowings and for general corporate purposes. In addition, the proceeds from SCE's bonds were used to fund SCE's capital program.
Credit Agreements and Short-Term Debt
SCE and Edison International Parent have multi-year revolving credit facilities of $2.75 billion and $1.25 billion, respectively, with both maturing in July 2020.2021. SCE's credit facility is generally used to support commercial paper borrowings and letters of credit issued for procurement-related collateral requirements, balancing account undercollections and for general corporate purposes, including working capital requirements to support operations and capital expenditures. Edison International Parent's credit facility is used to support commercial paper borrowings and for general corporate purposes.
At March 31, 20162017, SCE'sSCE had no outstanding commercial paper was $101 million at a weighted-average interest rate of 0.45%.paper. At March 31, 20162017, letters of credit issued under SCE's credit facility aggregated $94$91 million and are scheduled to expire in twelve months or less. At December 31, 20152016, the outstanding commercial paper, net of discount, was $49$769 million at a weighted-average interest rate of 0.51%0.9%.
At March 31, 20162017, Edison International Parent's outstanding commercial paper, net of discount, was $262$295 million at a weighted-average interest rate of 0.69%1.18%. At December 31, 20152016, the outstanding commercial paper, net of discount, was $646$538 million at a weighted-average interest rate of 0.78%0.97%.
Note 6. Derivative Instruments
Derivative financial instruments are used to manage exposure to commodity price risk. These risks are managed in part by entering into forward commodity transactions, including options, swaps, and futures. To mitigate credit risk from counterparties in the event of nonperformance, master netting agreements are used whenever possible and counterparties may be required to pledge collateral depending on the creditworthiness of each counterparty and the risk associated with the transaction.
Commodity Price Risk
Commodity price risk represents the potential impact that can be caused by a change in the market value of a particular commodity. SCE's electricity price exposure arises from energy purchased from and sold to wholesale markets as a result of differences between SCE's load requirements and the amount of energy delivered from its generating facilities and power purchase agreements.PPAs. SCE's natural gas price exposure arises from natural gas purchased for the Mountainview power plant and peaker plants, QFqualifying facility contracts where pricing is based on a monthly natural gas index, and power purchase agreementsPPAs in which SCE has agreed to provide the natural gas needed for generation, referred to as tolling arrangements.
Credit and Default Risk
Credit and default risk represent the potential impact that can be caused if a counterparty were to default on its contractual obligations and SCE would be exposed to spot markets for buying replacement power or selling excess power. In addition, SCE would be exposed to the risk of non-payment of accounts receivable, primarily related to the sales of excess power and realized gains on derivative instruments.
Certain power contracts contain master netting agreements or similar agreements, which generally allow counterparties subject to the agreement to setoff amounts when certain criteria are met, such as in the event of default. The objective of netting is to reduce credit exposure. Additionally, to reduce SCE's risk exposures counterparties may be required to pledge collateral depending on the creditworthiness of each counterparty and the risk associated with the transaction.
Certain power contracts contain a provision that requires SCE to maintain an investment grade rating from each of the major credit rating agencies, referred to as a credit-risk-related contingent feature. If SCE's credit rating were to fall below investment grade, SCE may be required to post additional collateral to cover derivative liabilities and the related outstanding payables. The net fair value of all derivative liabilities with these credit-risk-related contingent features was $50$19 million and $38$12 million as of March 31, 20162017 and December 31, 2015, respectively.2016, respectively, for which SCE has posted $12 million collateral at both March 31, 20162017 and no collateral at December 31, 20152016 to its counterparties at the respective dates for its derivative liabilities and related outstanding payables. If the credit-risk-related contingent features underlying these agreements were triggered on March 31, 2016,2017, SCE would be required to post $31$8 million of additional collateral of which $3$2 million is related to outstanding payables that are net of collateral already posted.
Fair Value of Derivative Instruments
SCE presents its derivative assets and liabilities on a net basis on its consolidated balance sheets when subject to master netting agreements or similar agreements. Derivative positions are offset against margin and cash collateral deposits. In addition, SCE has provided collateral in the form of letters of credit. Collateral requirements can vary depending upon the level of unsecured credit extended by counterparties, changes in market prices relative to contractual commitments, and other factors. See Note 4 for a discussion of fair value of derivative instruments. The following table summarizes the gross and net fair values of SCE's commodity derivative instruments:
| | | | | March 31, 2016 | | | | March 31, 2017 | | |
| | | Derivative Assets | | Derivative Liabilities | | Net
Liability | | Derivative Assets | | Derivative Liabilities | | Net
Liability |
| (in millions) | | Short-Term | | Long-Term | | Subtotal | | Short-Term | | Long-Term | | Subtotal | | | Short-Term | | Long-Term | | Subtotal | | Short-Term | | Long-Term | | Subtotal | |
| Commodity derivative contracts | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Gross amounts recognized | | $ | 66 |
| | $ | 78 |
| | $ | 144 |
| | $ | 244 |
| | $ | 1,134 |
| | $ | 1,378 |
| | $ | 1,234 |
| | $ | 70 |
| | $ | 1 |
| | $ | 71 |
| | $ | 238 |
| | $ | 989 |
| | $ | 1,227 |
| | $ | 1,156 |
|
| Gross amounts offset in the consolidated balance sheets | | (1 | ) | | — |
| | (1 | ) | | (1 | ) | | — |
| | (1 | ) | | — |
| | (1 | ) | | — |
| | (1 | ) | | (1 | ) | | — |
| | (1 | ) | | — |
|
Cash collateral posted1 | | — |
| | — |
| | — |
| | (11 | ) | | — |
| | (11 | ) | | (11 | ) | | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
|
| Net amounts presented in the consolidated balance sheets | | $ | 65 |
| | $ | 78 |
| | $ | 143 |
| | $ | 232 |
| | $ | 1,134 |
| | $ | 1,366 |
| | $ | 1,223 |
| | $ | 69 |
| | $ | 1 |
| | $ | 70 |
| | $ | 237 |
| | $ | 989 |
| | $ | 1,226 |
| | $ | 1,156 |
|
| | | | | December 31, 2015 | | | | December 31, 2016 | | |
| | | Derivative Assets | | Derivative Liabilities | | Net
Liability | | Derivative Assets | | Derivative Liabilities | | Net
Liability |
| (in millions) | | Short-Term | | Long-Term | | Subtotal | | Short-Term | | Long-Term | | Subtotal | | | Short-Term | | Long-Term | | Subtotal | | Short-Term | | Long-Term | | Subtotal | |
| Commodity derivative contracts | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Gross amounts recognized | | $ | 81 |
| | $ | 84 |
| | $ | 165 |
| | $ | 235 |
| | $ | 1,100 |
| | $ | 1,335 |
| | $ | 1,170 |
| | $ | 74 |
| | $ | 1 |
| | $ | 75 |
| | $ | 217 |
| | $ | 941 |
| | $ | 1,158 |
| | $ | 1,083 |
|
| Gross amounts offset in the consolidated balance sheets | | (2 | ) | | — |
| | (2 | ) | | (2 | ) | | — |
| | (2 | ) | | — |
| | (1 | ) | | — |
| | (1 | ) | | (1 | ) | | — |
| | (1 | ) | | — |
|
Cash collateral posted1 | | — |
| | — |
| | — |
| | (15 | ) | | — |
| | (15 | ) | | (15 | ) | | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
|
| Net amounts presented in the consolidated balance sheets | | $ | 79 |
| | $ | 84 |
| | $ | 163 |
| | $ | 218 |
| | $ | 1,100 |
| | $ | 1,318 |
| | $ | 1,155 |
| | $ | 73 |
| | $ | 1 |
| | $ | 74 |
| | $ | 216 |
| | $ | 941 |
| | $ | 1,157 |
| | $ | 1,083 |
|
| |
1 | In addition, at March 31, 2016 and 2017, there is no cash collateral posted that is not offset against derivative liabilities. At December 31, 2015,2016, SCE had posted $25received $2 million and $31 million, respectively, of collateral that is not offset against derivative liabilitiesassets and is reflected in "Other current assets"liabilities" on the consolidated balance sheets. |
Income Statement Impact of Derivative Instruments
SCE recognizes realized gains and losses on derivative instruments as purchased power expense and expects that such gains or losses will be part of the purchasepurchased power costs recovered from customers. As a result, realized gains and losses do not affect earnings, but may temporarily affect cash flows. Due to expected future recovery from customers, unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. The remaining effects of derivative activities and related regulatory offsets are recorded in cash flows from operating activities in the consolidated statements of cash flows.
The following table summarizes the components of SCE's economic hedging activity:
| | | | | Three months ended March 31, | | Three months ended March 31, |
| (in millions) | | 2016 | | 2015 | | 2017 | | 2016 |
| Realized losses | | $ | (27 | ) | | $ | (36 | ) | | $ | (2 | ) | | $ | (27 | ) |
| Unrealized losses | | (64 | ) | | (69 | ) | | (85 | ) | | (64 | ) |
Notional Volumes of Derivative Instruments
The following table summarizes the notional volumes of derivatives used for SCE hedging activities:
| | | | | Economic Hedges | | Economic Hedges |
| Commodity | | Unit of Measure | | March 31, 2016 | | December 31, 2015 | | Unit of Measure | | March 31, 2017 | | December 31, 2016 |
| Electricity options, swaps and forwards | | GWh | | 4,842 |
| | 6,221 | | GWh | | 1,812 |
| | 1,816 |
| Natural gas options, swaps and forwards | | Bcf | | 17 |
| | 32 | | Bcf | | 123 |
| | 36 |
| Congestion revenue rights | | GWh | | 96,182 |
| | 109,740 | | GWh | | 79,224 |
| | 93,319 |
| Tolling arrangements | | GWh | | 68,331 |
| | 70,663 | | GWh | | 58,153 |
| | 61,093 |
Note 7. Income Taxes
Effective Tax Rate
The table below provides a reconciliation of income tax expense computed at the federal statutory income tax rate to the income tax provision:
| | | | Edison International | | SCE | Edison International | | SCE |
| | Three months ended March 31, | Three months ended March 31, |
| (in millions) | 2016 | | 2015 | | 2016 | | 2015 | 2017 | | 2016 | | 2017 | | 2016 |
| Income from continuing operations before income taxes | $ | 333 |
| | $ | 424 |
| | $ | 367 |
| | $ | 440 |
| $ | 352 |
| | $ | 333 |
| | $ | 392 |
| | $ | 367 |
|
| Provision for income tax at federal statutory rate of 35% | 117 |
| | 148 |
| | 128 |
| | 154 |
| 124 |
| | 117 |
| | 137 |
| | 128 |
|
| Increase in income tax from: | | | | | | | | | | | | | | |
| State tax, net of federal benefit | 6 |
| | 11 |
| | 9 |
| | 14 |
| 10 |
| | 6 |
| | 13 |
| | 9 |
|
| Property-related | (79 | ) | | (60 | ) | | (79 | ) | | (60 | ) | (113 | ) | | (79 | ) | | (113 | ) | | (79 | ) |
| Change related to uncertain tax positions | (1 | ) | | 15 |
| | (1 | ) | | 10 |
| (12 | ) | | (1 | ) | | (11 | ) | | (1 | ) |
Shared-based compensation1 | | (43 | ) | | (10 | ) | | (8 | ) | | (8 | ) |
| Other | (5 | ) | | (8 | ) | | (7 | ) | | (11 | ) | (6 | ) | | (5 | ) | | (6 | ) | | (7 | ) |
| Total income tax expense from continuing operations | $ | 38 |
| | $ | 106 |
| | $ | 50 |
| | $ | 107 |
| |
| Total income tax (benefit) expense from continuing operations | | $ | (40 | ) | | $ | 28 |
| | $ | 12 |
| | $ | 42 |
|
| Effective tax rate | 11.4 | % | | 25.0 | % | | 13.6 | % | | 24.3 | % | (11.4 | )% | | 8.4 | % | | 3.1 | % | | 11.4 | % |
| |
1 | Includes state taxes for Edison International and SCE of $6 million and $1 million, respectively, for the three months ended March 31, 2017 and $3 million and $2 million, respectively, for the three months ended March 31, 2016. Refer to Note 1 for further information. |
The CPUC requires flow-through ratemaking treatment for the current tax benefit arising from certain property-related and other temporary differences which reverse over time. Flow-through items reduce current authorized revenue requirements in SCE's rate cases and result in a regulatory asset for recovery of deferred income taxes in future periods. The difference between the authorized amounts as determined in SCE's rate cases, adjusted for balancing and memorandum account activities, and the recorded flow-through items also result in increases or decreases in regulatory assets with a corresponding impact on the effective tax rate to the extent that recorded deferred amounts are expected to be recovered in future rates.
In March 2017, SCE received the final decision on claims against, and counterclaims of, Mitsubishi Heavy Industries, Inc. and related companies (together, "MHI") from the arbitration tribunal, the International Chamber of Commerce, discussed further in Note 11. San Onofre was permanently shut down on June 7, 2013 as a result of failure of replacement steam generators supplied by MHI. With the resolution of the insurance claim against Nuclear Electric Insurance Limited ("NEIL") in October 2015 and the conclusion of the arbitration proceeding against MHI, a tax abandonment loss of $698 million and $1.14 billion for federal and state income tax purposes, respectively, was claimed in the first quarter of 2017, resulting in a flow-through tax benefit of approximately $39 million impacting the effective tax rate. Due to the tax abandonment loss recognized this quarter, Edison International and SCE both expect to report a federal taxable loss in 2017. In addition, Edison International expects to report a California taxable loss in 2017.
Unrecognized Tax Benefits
In the first quarter of 2017, Edison International settled all open tax positions with the Internal Revenue Service ("IRS") for taxable years 2007 through 2012. The following table provides a reconciliation of unrecognized tax benefits for 2017 as a result of the audit settlement:
|
| | | | | | | |
| (in millions) | Edison International | | SCE |
| Balance at January 1, 2017 | $ | 471 |
| | $ | 371 |
|
| Tax positions taken during the current year: | | | |
| Increases | 10 |
| | 10 |
|
| Tax positions taken during a prior year: | | | |
| Increases | 2 |
| | 2 |
|
| Decreases | (10 | ) | | (10 | ) |
| Decreases for settlements during the period | (82 | ) | | (78 | ) |
| Balance at March 31, 2017 | $ | 391 |
| | $ | 295 |
|
Tax Disputes
Tax Years 2007 – 20092012
In the first quarter of 2017, Edison International received a Revenue Agent Report from the IRS in February 2013 which included a proposed adjustment to disallow deductions related to certain capitalized overhead costs. Edison International has tentatively reached an agreementsettled all open tax positions with the IRS regarding this matter, which if finalized, would result in a federal tax liability of approximately $64 million, including interestfor taxable years 2007 through March 31, 2016.
Tax Years 2010 – 2012
The IRS Revenue Agent Report was received in June 2015. As a result,2012. Edison International previously made cash deposits which are sufficient to settle all outstanding liabilities for this audit cycle. Total liabilities included tax reserves, previously settled issues, and SCE have re-measured their Federal and State uncertain tax positions and recorded $94 million and $100 million, respectively,an estimate of income tax benefits includingassociated interest and penalty during the second quarter of 2015. The Revenue Agent Report included a proposed adjustment to disallow deductions related to certain capitalized overhead expenses. Edison International has tentatively reached an agreement with IRS regarding this matter, which if finalized, would result in a federal tax liability of approximately
$9 million, including interest through March 31, 2016.
penalties.
Tax years that remain open for examination by the IRS and the California Franchise Tax Board are 20072013 – 2015 and 20032010 – 2015, respectively. Edison International has settled all open tax position with the IRS for taxable years prior to 2013. Tax years 2003 – 2009 are currently under protest with the California Franchise Tax Board.
Note 8. Compensation and Benefit Plans
Pension Plans
Edison International made contributions of $525 million during the three months ended March 31, 2016,2017, which includes contributions of $1$21 million by SCE. Edison International expects to make contributions of $115$111 million during the remainder of 2016,2017, which includes $94$64 million from SCE. Annual contributions made by SCE to most of SCE's pension plans are anticipated to be recovered through CPUC-approved regulatory mechanisms. Annual contributions to these plans are expected to be, at a minimum, equal to the related annual expense.
Pension expense components for continuing operations are:
| | | | Edison International | | SCE | Edison International | | SCE |
| | Three months ended March 31, | Three months ended March 31, |
| (in millions) | 2016 | | 2015 | | 2016 | | 2015 | 2017 | | 2016 | | 2017 | | 2016 |
| Service cost | $ | 39 |
| | $ | 35 |
| | $ | 38 |
| | $ | 35 |
| $ | 36 |
| | $ | 39 |
| | $ | 35 |
| | $ | 38 |
|
| Interest cost | 44 |
| | 41 |
| | 41 |
| | 38 |
| 41 |
| | 44 |
| | 37 |
| | 41 |
|
| Expected return on plan assets | (56 | ) | | (57 | ) | | (53 | ) | | (53 | ) | (53 | ) | | (56 | ) | | (50 | ) | | (53 | ) |
| Amortization of prior service cost | 1 |
| | 1 |
| | 1 |
| | 1 |
| 1 |
| | 1 |
| | 1 |
| | 1 |
|
Amortization of net loss1 | 9 |
| | 9 |
| | 8 |
| | 7 |
| 5 |
| | 9 |
| | 4 |
| | 8 |
|
| Expense under accounting standards | $ | 37 |
| | $ | 29 |
| | $ | 35 |
| | $ | 28 |
| $ | 30 |
| | $ | 37 |
| | $ | 27 |
| | $ | 35 |
|
| Regulatory adjustment | (9 | ) | | (1 | ) | | (9 | ) | | (1 | ) | (3 | ) | | (9 | ) | | (3 | ) | | (9 | ) |
| Total expense recognized | $ | 28 |
| | $ | 28 |
| | $ | 26 |
| | $ | 27 |
| $ | 27 |
| | $ | 28 |
| | $ | 24 |
| | $ | 26 |
|
| |
1 | Includes the amount of net loss reclassified from other comprehensive loss. The amount reclassified for Edison International and SCE was $3 million and $2 million, respectively, for the three months ended March 31, 2016,2017, and $3 million and $2 million, respectively, for the three months ended March 31, 2015.2016. |
Under GAAP, a settlement is recorded when lump-sum payments exceed estimated annual service and interest costs. Lump sum payments made in April 2017 to Edison International executives retiring in 2016 from the Executive Retirement Plan exceeded the estimated service and interest costs, resulting in a partial settlement of that plan. A settlement loss of approximately $7.7 million ($4.6 million after-tax) is expected to be recorded at Edison International in the second quarter of 2017.
Postretirement Benefits Other Than Pensions
Edison International made contributions of $75 million during the three months ended March 31, 20162017 and expects to make contributions of $2616 million during the remainder of 2016,2017, substantially all of which are expected to be made by SCE. Annual contributions related to SCE employees made to SCE plans are anticipated to be recovered through CPUC-approved regulatory mechanisms and are expected to be, at a minimum, equal to the total annual expense for these plans, pending the outcome of the 2015 GRC decision.plans. Benefits under these plans, with some exceptions, are generally unvested and subject to change. Under the terms of the Edison International Health and Welfare Plan ("PBOP Plan") each participating employer (Edison International or its participating subsidiaries) is responsible for the costs and expenses of all PBOP Plan benefits with respect to its employees and former employees. A participating employer may terminate the PBOP Plan benefits with respect to its employees and former employees, as may SCE (as PBOP Plan sponsor), and, accordingly, the participants' PBOP Plan benefits are not vested benefits.
PBOP expense components for continuing operations are:
|
| | | | | | | | | | | | | | | |
| | Edison International | | SCE |
| | Three months ended March 31, |
| (in millions) | 2016 | | 2015 | | 2016 | | 2015 |
| Service cost | $ | 10 |
| | $ | 12 |
| | $ | 10 |
| | $ | 12 |
|
| Interest cost | 26 |
| | 29 |
| | 26 |
| | 28 |
|
| Expected return on plan assets | (28 | ) | | (28 | ) | | (28 | ) | | (28 | ) |
| Amortization of prior service cost | (1 | ) | | (3 | ) | | (1 | ) | | (3 | ) |
| Amortization of net loss | — |
| | 6 |
| | — |
| | 6 |
|
| Total expense | $ | 7 |
| | $ | 16 |
| | $ | 7 |
| | $ | 15 |
|
Workforce Reductions
SCE continues to focus on productivity improvements to mitigate rate pressure from its capital program, optimize its cost structure and improve operational efficiency, which is expected to result in further workforce reductions through 2016. During the three months ended March 31, 2016, SCE increased the estimated impact for approved workforce reductions.
The following table provides a summary of changes in the accrued severance liability associated with these reductions:
|
| | | | |
| (in millions) | | |
| Balance at January 1, 2016 | | $ | 22 |
|
| Additions | | 5 |
|
| Payments | | (15 | ) |
| Balance at March 31, 2016 | | $ | 12 |
|
The liability presented in the table above is reflected in "Other current liabilities" on the consolidated balance sheets. The severance costs are included in "Operation and maintenance" on the consolidated income statements. |
| | | | | | | | | | | | | | | |
| | Edison International | | SCE |
| | Three months ended March 31, |
| (in millions) | 2017 | | 2016 | | 2017 | | 2016 |
| Service cost | $ | 9 |
| | $ | 10 |
| | $ | 9 |
| | $ | 10 |
|
| Interest cost | 24 |
| | 26 |
| | 24 |
| | 26 |
|
| Expected return on plan assets | (27 | ) | | (28 | ) | | (27 | ) | | (28 | ) |
| Amortization of prior service cost | (1 | ) | | (1 | ) | | (1 | ) | | (1 | ) |
| Total expense | $ | 5 |
| | $ | 7 |
| | $ | 5 |
| | $ | 7 |
|
Note 9. Investments
Nuclear Decommissioning Trusts
Future decommissioning costs related to SCE's nuclear assets are expected to be funded from independent decommissioning trusts.
The following table sets forth amortized cost and fair value of the trust investments (see Note 4 for a discussion of fair value of the trust investments):
| | | | Longest Maturity Dates | | Amortized Cost | | Fair Value | Longest Maturity Dates | | Amortized Cost | | Fair Value |
| (in millions) | | March 31,
2016 | | December 31,
2015 | | March 31,
2016 | | December 31, 2015 | | March 31,
2017 | | December 31,
2016 | | March 31,
2017 | | December 31, 2016 |
| Stocks | — | | $ | 311 |
| | $ | 304 |
| | $ | 1,464 |
| | $ | 1,460 |
| — | | $ | 291 |
| | $ | 319 |
| | $ | 1,537 |
| | $ | 1,547 |
|
| Municipal bonds | 2054 | | 736 |
| | 691 |
| | 894 |
| | 840 |
| 2054 | | 645 |
| | 659 |
| | 753 |
| | 766 |
|
| U.S. government and agency securities | 2046 | | 1,002 |
| | 1,070 |
| | 1,092 |
| | 1,128 |
| 2055 | | 1,308 |
| | 1,131 |
| | 1,380 |
| | 1,191 |
|
| Corporate bonds | 2057 | | 662 |
| | 708 |
| | 731 |
| | 755 |
| 2057 | | 552 |
| | 600 |
| | 608 |
| | 659 |
|
Short-term investments and receivables/payables1 | One-year | | 106 |
| | 144 |
| | 109 |
| | 148 |
| One-year | | 71 |
| | 75 |
| | 74 |
| | 79 |
|
| Total | | | $ | 2,817 |
| | $ | 2,917 |
| | $ | 4,290 |
| | $ | 4,331 |
| | | $ | 2,867 |
| | $ | 2,784 |
| | $ | 4,352 |
| | $ | 4,242 |
|
| |
1 | Short-term investments include $8$36 million and $81$114 million of repurchase agreements payable by financial institutions which earn interest, are fully secured by U.S. Treasury securities and mature by April 4, 20163, 2017 and January 5, 20164, 2017 as of March 31, 20162017 and December 31, 2015,2016, respectively. |
Trust fund earnings (based on specific identification) increase the trust fund balance and the AROasset retirement obligation ("ARO") regulatory liability. Unrealized holding gains, net of losses, were $1.5 billion and $1.4 billion at both March 31, 20162017 and December 31, 20152016, respectively..
The following table sets forth a summary of changes in the fair value of the trust:
| | | | | Three months ended March 31, | | Three months ended March 31, |
| (in millions) | | 2016 | | 2015 | | 2017 | | 2016 |
| Balance at beginning of period | | $ | 4,331 |
| | $ | 4,799 |
| | $ | 4,242 |
| | $ | 4,331 |
|
| Gross realized gains | | 17 |
| | 27 |
| | 99 |
| | 17 |
|
| Gross realized losses | | (3 | ) | | (2 | ) | | (16 | ) | | (3 | ) |
| Unrealized gains, net | | 59 |
| | 44 |
| |
| Unrealized gains, net of losses | | | 27 |
| | 59 |
|
| Other-than-temporary impairments | | (7 | ) | | (4 | ) | | (1 | ) | | (7 | ) |
| Interest and dividends | | 29 |
| | 28 |
| | 28 |
| | 29 |
|
| Contributions | | — |
| | 7 |
| |
| Income taxes | | (18 | ) | | — |
| | — |
| | (18 | ) |
| Decommissioning disbursements | | (116 | ) | | — |
| | (26 | ) | | (116 | ) |
| Administrative expenses and other | | (2 | ) | | (3 | ) | | (1 | ) | | (2 | ) |
| Balance at end of period | | $ | 4,290 |
| | $ | 4,896 |
| | $ | 4,352 |
| | $ | 4,290 |
|
Trust assets are used to pay income taxes as the Trust files separate income taxes returns from SCE.taxes. Deferred income taxestax liabilities related to net unrealized gains at March 31, 20162017 were $357$373 million. Accordingly, the fair value of Trusttrust assets available to pay future decommissioning costs, net of deferred income taxes, totaled $3.9$4.0 billion at March 31, 2016.2017. Due to regulatory mechanisms, changes in assets of the trusts from income or loss items have no impact on operating revenue or earnings.
Decommissioning disbursements are funded from sales of investments of the nuclear decommissioning trusts.
Note 10. Regulatory Assets and Liabilities
Regulatory Assets
SCE's regulatory assets included on the consolidated balance sheets are:
| | | (in millions) | March 31,
2016 | | December 31,
2015 | March 31,
2017 | | December 31,
2016 |
| Current: | | | | | | |
| Regulatory balancing accounts | $ | 329 |
| | $ | 382 |
| $ | 139 |
| | $ | 135 |
|
| Energy derivatives | 182 |
| | 159 |
| 186 |
| | 150 |
|
| Unamortized investments, net of accumulated amortization | | 37 |
| | 49 |
|
| Other | 27 |
| | 19 |
| 32 |
| | 16 |
|
| Total current | 538 |
| | 560 |
| 394 |
| | 350 |
|
| Long-term: | | | | | | |
| Deferred income taxes, net | 3,920 |
| | 3,757 |
| |
| Deferred income taxes, net of liabilities | | 4,689 |
| | 4,478 |
|
| Pensions and other postretirement benefits | 842 |
| | 849 |
| 711 |
| | 710 |
|
| Energy derivatives | 1,066 |
| | 1,027 |
| 996 |
| | 947 |
|
| Unamortized investments, net | 169 |
| | 182 |
| |
| Unamortized investments, net of accumulated amortization | | 79 |
| | 80 |
|
| San Onofre | 982 |
| | 1,043 |
| 815 |
| | 857 |
|
| Unamortized loss on reacquired debt | 197 |
| | 201 |
| 180 |
| | 184 |
|
| Regulatory balancing accounts | 39 |
| | 36 |
| 68 |
| | 66 |
|
| Environmental remediation | 131 |
| | 129 |
| 125 |
| | 126 |
|
| Other | 282 |
| | 288 |
| 11 |
| | 7 |
|
| Total long-term | 7,628 |
| | 7,512 |
| 7,674 |
| | 7,455 |
|
| Total regulatory assets | $ | 8,166 |
| | $ | 8,072 |
| $ | 8,068 |
| | $ | 7,805 |
|
Regulatory Liabilities
SCE's regulatory liabilities included on the consolidated balance sheets are:
| | | (in millions) | March 31,
2016 | | December 31,
2015 | March 31,
2017 | | December 31,
2016 |
| Current: | | | | | | |
| Regulatory balancing accounts | $ | 1,135 |
| | $ | 1,106 |
| $ | 740 |
| | $ | 736 |
|
San Onofre MHI arbitration award1 | | 47 |
| | — |
|
| Other | 22 |
| | 22 |
| 17 |
| | 20 |
|
| Total current | 1,157 |
| | 1,128 |
| 804 |
| | 756 |
|
| Long-term: | | | | | | |
| Costs of removal | 2,822 |
| | 2,781 |
| 2,838 |
| | 2,847 |
|
Recoveries in excess of ARO liabilities1 | 1,690 |
| | 1,502 |
| |
Recoveries in excess of ARO liabilities2 | | 1,735 |
| | 1,639 |
|
| Regulatory balancing accounts | 1,352 |
| | 1,314 |
| 1,278 |
| | 1,180 |
|
| Other | 56 |
| | 79 |
| 59 |
| | 60 |
|
| Total long-term | 5,920 |
| | 5,676 |
| 5,910 |
| | 5,726 |
|
| Total regulatory liabilities | $ | 7,077 |
| | $ | 6,804 |
| $ | 6,714 |
| | $ | 6,482 |
|
| |
1 | Represents SCE's net recovery from claims against MHI. See Note 11 for further discussion. |
| |
2 | Represents the cumulative differences between ARO expenses and amounts collected in rates primarily for the decommissioning of the SCE's nuclear generation facilities. Decommissioning costs recovered through rates are primarily placed in nuclear decommissioning trusts. This regulatory liability also represents the deferral of realized and unrealized gains and losses on the nuclear decommissioning trust investments. See Note 9.9 for further discussion. |
Net Regulatory Balancing Accounts
The following table summarizes the significant components of regulatory balancing accounts included in the above tables of regulatory assets and liabilities:
| | | (in millions) | March 31,
2016 | | December 31,
2015 | March 31,
2017 | | December 31,
2016 |
| Asset (liability) | | | | | | |
| Energy resource recovery account | $ | (364 | ) | | $ | (439 | ) | $ | 30 |
| | $ | (20 | ) |
| New system generation balancing account | (189 | ) | | (171 | ) | (97 | ) | | (6 | ) |
| Public purpose programs and energy efficiency programs | (817 | ) | | (683 | ) | (1,056 | ) | | (992 | ) |
| Tax accounting memorandum account and pole loading balancing account | (278 | ) | | (248 | ) | (136 | ) | | (142 | ) |
| Base rate recovery balancing account | (234 | ) | | (319 | ) | (360 | ) | | (426 | ) |
Department of Energy litigation memorandum account
| | (123 | ) | | (122 | ) |
| Greenhouse gas auction revenue | (156 | ) | | (75 | ) | (3 | ) | | 31 |
|
| FERC balancing accounts | 43 |
| | 74 |
| (93 | ) | | (69 | ) |
| Generator settlements | — |
| | (4 | ) | |
| Other | (124 | ) | | (137 | ) | 27 |
| | 31 |
|
| Liability | $ | (2,119 | ) | | $ | (2,002 | ) | $ | (1,811 | ) | | $ | (1,715 | ) |
Note 11. Commitments and Contingencies
Third-Party Power Purchase Agreements
During the first quarter of 2017, SCE had existing PPAs that met the critical contract provisions. The commitments for these contracts are estimated to be: $48 million in 2017, $116 million in 2018, $117 million in 2019, $119 million in 2020, $120 million in 2021, and $955 million for the remaining period thereafter. For further information, see Note 11 in the 2016 Form 10-K.
Indemnities
Edison International and SCE have various financial and performance guarantees and indemnity agreements, which are issued in the normal course of business.
Edison International and SCE have provided indemnifications through contracts entered into in the normal course of business. These are primarily indemnifications against adverse litigation outcomes in connection with underwriting agreements, and indemnities for specified environmental liabilities and income taxes with respect to assets sold. Edison International's and SCE's obligations under these agreements may or may not be limited in terms of time and/or amount, and in some instances Edison International and SCE may have recourse against third parties. Edison International and SCE have not recorded a liability related to these indemnities. The overall maximum amount of the obligations under these indemnifications cannot be reasonably estimated.
SCE has indemnified the City of Redlands, California in connection with Mountainview'sthe Mountainview power plant's California Energy Commission permit for cleanup or associated actions related to groundwater contaminated by perchlorate due to the disposal of filter cake at the City's solid waste landfill. The obligations under this agreement are not limited to a specific time period or subject to a maximum liability. SCE has not recorded a liability related to this indemnity.
Contingencies
In addition to the matters disclosed in these Notes, Edison International and SCE are involved in other legal, tax, and regulatory proceedings before various courts and governmental agencies regarding matters arising in the ordinary course of business. Edison International and SCE believe the outcome of these other proceedings will not, individually or in the aggregate, materially affect its financial position, results of operations or liquidity.and cash flows.
San Onofre Related Matters
Replacement steam generators were installed at San Onofre in 2010 and 2011. On January 31, 2012, a leak suddenly occurred in one of the heat transfer tubes in San Onofre's Unit 3 steam generators. The Unit was safely taken off-line and subsequent inspections revealed excessive tube wear. Unit 2 was off-line for a planned outage when areas of unexpected tube wear were also discovered. On June 6, 2013, SCE decided to permanently retire Units 2 and 3.
Settlement of San Onofre CPUC Proceedings
In November 2014, the CPUC approved the San Onofre OII Settlement Agreement thatby and among SCE, had entered into with TURN, ORA, The Utility Reform Network, the CPUC's Office of Ratepayer Advocates and San Diego Gas & Electric ("SDG&E,&E"), which was later joined by the Coalition of California Utility Employees and Friends of the Earth. The SanEarth, dated November 20, 2014 (the "San Onofre OII Settlement AgreementAgreement"), which resolved the CPUC's investigation regarding the Steam Generator Replacement Projectsteam generator replacement project at San Onofre and the related outages and subsequent shutdown of San Onofre. TheSubsequently, the San Onofre Order Instituting Investigation ("OII") proceeding record was reopened by a joint ruling of the Assigned Commissioner and the Assigned administrative law judge ("ALJ") to consider whether, in light of SCE not reporting certain ex parte communications on a timely basis, the San Onofre OII Settlement Agreement remained reasonable, consistent with the law, and in the public interest, which is the standard the CPUC applies in reviewing settlements submitted for approval. In comments filed with the CPUC in July 2016, SCE asserted that the San Onofre OII Settlement Agreement continues to meet this standard and therefore should not be disturbed. A number of the parties to the San Onofre OII, however, have requested that the CPUC either modify the San Onofre OII Settlement Agreement or vacate its previous approval of the settlement and reinstate the San Onofre OII for further proceedings.
In a December 2016 joint ruling, the Assigned Commissioner and the Assigned ALJ expressed concerns about the extent to which the failure to timely report ex parte communications had impacted the settlement negotiations and directed SCE and SDG&E to meet and confer with the other parties in the San Onofre OII to consider changing the terms of the San Onofre OII Settlement Agreement. The ruling set out a schedule requiring that at least two meet-and-confer sessions be held in the first quarter of 2017 and requiring the parties to submit a joint status report to the CPUC by April 28, 2017 if no modifications have been agreed to by some or all of the parties as a result of the meet-and-confer process. The parties held three meet-and-confer sessions. In March 2017, SCE and other parties reported to the CPUC that the parties participating in the meet-and-confer process have agreed to mediate the issues identified in the December 2016 joint ruling. In April 2017, SCE and other meet-and-confer parties filed a joint motion to extend the April 28, 2017 joint report deadline to August 15, 2017. SCE has recorded a regulatory asset of $815 million at March 31, 2017 to reflect the expected recoveries under the San Onofre OII Settlement Agreement. Management assesses at the end of each reporting period whether regulatory assets are probable of future recovery. SCE assessed the San Onofre regulatory asset at March 31, 2017 and continues to conclude that the asset is
probable, though not certain, of recovery based on SCE's knowledge of facts and judgment in applying the relevant regulatory principles to the issue. SCE does not affect proceedings related to recoveries from third parties describedbelieve that the conclusions in the MHI arbitration, discussed below, but does describe how shareholders and customers will share any recoveries.change the expectation on the probability of recovery of the San Onofre regulatory asset.
Challenges related to the Settlement of San Onofre CPUC Proceedings
A federal lawsuit challenging the CPUC's authority to permit rate recovery of San Onofre costs and an application to the CPUC for rehearing of its decision approving the San Onofre OII Settlement Agreement were filed in November and December 2014, respectively. In April 2015, the federal lawsuit was dismissed with prejudice and the plaintiffs in that case appealed the dismissal to the Ninth Circuit in May 2015. Both the appeal and the application for rehearing remain pending.
In April 2015, the Alliance for Nuclear Responsibility ("A4NR") filed a petition to modify the CPUC's decision approvinglight of the San Onofre OII Settlement Agreement based on SCE's alleged failuresmeet-and-confer sessions, the Ninth Circuit cancelled the hearing that had been scheduled for February 9, 2017 and ordered the parties to disclose communications between SCE and CPUC decision-makers pertaining to issues innotify the San Onofre OII. The petition seeks the reversalNinth Circuit of the decision approvingstatus of the San Onofre OII Settlement Agreementby May 1, 2017 and reopening of the OII proceeding. Subsequently, TURN and ORA filed responses supporting A4NR's petition to reopen the San Onofre OII proceeding. In August 2015, ORA filed its own petition to modify the CPUC's decision approving the San Onofre OII Settlement Agreement seeking to set aside the settlement and reopen the San Onofre OII proceeding. SCE and SDG&E responded to this petition in September 2015. Both petitions remain pending before the CPUC.periodically thereafter.
In July 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its then Chief Executive Officer and its then Chief Financial Officer andOfficer. The complaint was later amended to include SCE's former President as a defendant. The lawsuit alleges that the defendants violated the securities laws by failing to disclose that Edison International had ex parte
contacts with CPUC decision-makers regarding the San Onofre OII that were either unreported or more extensive than initially reported. The complaint purports to be filed on behalf of a class of persons who acquired Edison International common stock between March 21, 2014 and June 24, 2015. In September 2016, the federal court granted defendants’ motion to dismiss the complaint, with an opportunity for plaintiff to amend the complaint. Plaintiff filed an amended complaint and defendants again moved to dismiss the complaint in October 2016 and a decision is pending.
Subsequently and alsoAlso in July 2015, a federal shareholder derivative lawsuit was filed against members of the Edison International Board of Directors for breach of fiduciary duty and other claims. The federal derivative lawsuit is based on similar allegations to the federal class action securities lawsuit and seeks monetary damages, including punitive damages, and various corporate governance reforms. An additional federal shareholder derivative lawsuit making essentially the same allegations was filed in August 2015 and was subsequently consolidated with the July 2015 federal derivative lawsuit. In September 2016, the federal court granted defendants' motion to dismiss the consolidated complaint, with an opportunity for plaintiffs to amend the complaint. Plaintiffs did not file an amended complaint by the required date. Plaintiffs' deadline to appeal the federal court's order granting defendants' motion to dismiss lapsed in March 2017 and no appeal was filed.
In October 2015, a shareholder derivative lawsuit was filed in California state court against members of the Edison International Board of Directors for breach of fiduciary duty and other claims, making similar allegations to those in the federal derivative lawsuits discussed above. The California state court action is currently on hold in light of the pending federal suits discussed above.
In November 2015, a purported securities class action lawsuit was filed in federal court against Edison International, its then Chief Executive Officer and its Treasurer by an Edison International employee, alleging claims under the Employee Retirement Income Security Act ("ERISA").Act. The complaint purports to be filed on behalf of a class of Edison International employees who were participants in the Edison 401(k) Savings Plan and invested in the Edison International Stock Fund between March 27, 2014 and June 24, 2015. The complaint alleges that defendants breached their fiduciary duties because they knew or should have known that investment in the Edison International Stock Fund was imprudent because the price of Edison International common stock was artificially inflated due to Edison International's alleged failure to disclose certain ex parte communications with CPUC decision-makers related to the San Onofre OII. In July 2016, the federal court granted the defendants' motion to dismiss the lawsuit with an opportunity for the plaintiff to amend her complaint. Plaintiff filed an amended complaint in July 2016, that dismissed Edison International as a named defendant and the remaining defendants filed a motion to dismiss in August 2016. These defendants' motion was heard by the court in November 2016 and a decision is pending.
Edison International and SCE cannot predict the outcome of thesethe open proceedings.
MHI Claims
SCE is also pursuingpursued claims against Mitsubishi Heavy Industries, Ltd. and a related company ("MHI"),MHI, which designed and supplied the RSGs. MHI warranted the RSGs for an initial period of 20 years from acceptance and is contractually obligated to repair or replace defective items with dispatch and to pay specified damages for certain repairs. MHI's stated liability under the purchase agreement is limited to $138 million and excludes consequential damages, defined to include "the cost of replacement power;" however, limitations in the contract are subject to applicable exceptions both in the contract and under law. SCE has advised MHI that it believes one or more of such exceptions apply and that MHI's liability is not limited to $138 million. MHI has advised SCE that it disagrees.steam generators. In October 2013, SCE sent MHI a formal request for binding arbitration under the auspices of the International Chamber of Commerce in accordance with the purchase contract seeking damages for all losses. In the request for arbitration, SCE allegesalleged contract and tort claims and seekssought at least $4 billion in damages on behalf of itself and its customers and in its capacity as Operating Agent for San Onofre. MHI has denied any liability and has asserted counterclaims for $41 million, for which SCE has denied any liability. Each of the other San Onofre owners (SDG&E and Riverside) sued MHI, alleging claims arising from MHI's supplying the faulty steam generators. These litigation claims have been stayed pending the arbitration. The other co-owners (SDG&E and Riverside) have beenwere added as additional claimants in the arbitration. The arbitration is being conducted pursuant to a confidentiality order issued byIn March 2017, the arbitration panel. Hearings concluded
tribunal found MHI liable for breach of contract, but rejected claimants' other claims. The tribunal found that damages were subject to contractual limitations on April 29, 2016. Aliability. In addition, the tribunal ordered the claimants to pay MHI's legal costs but rejected MHI's counterclaims. The net recovery awarded to SCE was initially determined to be $52 million. An adjustment to the interest awarded to SCE subsequently reduced the net recovery to approximately $47 million. The decision may be issued by year-end 2016 but could be later.
SCE, on behalf of itself andis the other San Onofre co-owners, has submitted seven invoices to MHI totaling $149 million for steam generator repair costs incurred through April 30, 2013. MHI paid the first invoice of $45 million, while reserving its right to challenge it and subsequently rejected a portionfinal award of the first invoice andtribunal but can be challenged in court on limited grounds. SCE has determined that it will not paid further invoices, claiming further documentation is required, which SCE disputes. SCE recorded its shareappeal the decision. As a result of uncertainty associated with the allocation of the invoice paid (approximately $35 million) as a reduction of repair and inspection costs in 2012.
Underaward under the San Onofre OII Settlement Agreement, recoveries from MHI (including amounts paid by MHI underSCE recorded a regulatory liability for the first invoice), if any, will first be applied to reimburse costs incurred in pursuing such recoveries, including litigation costs. To the extent SCE's share of recoveries from MHI exceed such costs, they will be allocated 50% to customers and 50% to SCE.
The first $282 million of SCE's customers' portion of such recoveries from MHI will be distributed to customers via a credit to a sub-account of SCE's Base Revenue Requirement Balancing Account ("BRRBA"), reducing revenue requirements from customers. Amounts in excess of the first $282 million distributable to SCE customers will reduce SCE's regulatory asset represented by the unamortized balance of investment in San Onofre base plant, reducing the revenue requirement needed to amortize such investment. The amortization period, however, will be unaffected. Any additional amounts received after the regulatory asset is recovered will be applied to the BRRBA.
The San Onofre OII Settlement Agreement provides the utilities with the discretion to resolve the MHI dispute without CPUC approval, but the utilities are obligated to use their best efforts to inform the CPUC of any settlement or other resolution of these disputes to the extent this is possible without compromising any aspect of the resolution. SCE and SDG&E have also agreed to allow the CPUC to review the documentation of any final resolution of the MHI dispute and the litigation costs incurred in pursuing claims against MHI to ensure they are not exorbitant in relation to the recovery obtained. There is no assurance that there will be any recovery from MHI or, if there is a recovery, that it will equal or exceed the litigation costs incurred to pursue thenet recovery.
Energy Efficiency Incentive Mechanism
In September 2015, the CPUC granted TURN and ORA requests for rehearing of prior CPUC decisions related to $74.5 million of incentive awards that SCE received for savings achieved by its 2006 – 2008 energy efficiency programs. In March 2016, ORA and TURN filed a joint proposal requesting that the CPUC recalculate SCE's 2006 – 2008 incentive awards and order SCE to refund $39.9 million to its customers. SCE disputes the assertion that SCE should be at risk to repay previously awarded incentives. SCE cannot predict the outcome of these petitions.
Long Beach Service Interruptions
In July 2015, SCE's customers who are served via the network portion of SCE's electric system in Long Beach, California experienced service interruptions due to multiple underground vault fires and underground cable failures. No personal injuries have been reported in connection with these events. SCE instituted an internal investigation and commissioned an external investigation of these events and their causes, which revealed that the main cause of the interruptions was a lack of adequate management oversight of the downtown network system. The investigations also revealed deficiencies in maintaining the knowledge base on the configuration and operation of the system, and a lack of sophisticated controls needed to more efficiently and effectively prevent and respond to the cascading events that occurred. These events and their causes are also being investigated by the CPUC's SED. SCE is unable to estimate a possible loss or range of loss associated with any penalties that may be imposed by the CPUC related to this matter. Subject to applicable deductibles, SCE is generally insured against customer claims arising from these service interruptions.
Environmental Remediation
SCE records its environmental remediation liabilities when site assessments and/or remedial actions are probable and a range of reasonably likely cleanup costs can be estimated. SCE reviews its sites and measures the liability quarterly, by assessing a range of reasonably likely costs for each identified site using currently available information, including existing technology, presently enacted laws and regulations, experience gained at similar sites, and the probable level of involvement and financial condition of other potentially responsible parties. These estimates include costs for site investigations, remediation, operation and maintenance, monitoring, and site closure. Unless there is a single probable amount, SCE records the lower end of this reasonably likely range of costs (reflected in "Other long-term liabilities") at undiscounted amounts as timing of cash flows is uncertain.
At March 31, 2016,2017, SCE's recorded estimated minimum liability to remediate its 19 identified material sites (sites with a liability balance at March 31, 2017, in which the upper end of the range of the costs is at least $1$1 million) was $127 million,) was $133 including $75 million, including $80 million related to San Onofre. In addition to these sites, SCE also has 3917 immaterial sites with a liability balance as of March 31, 2017, for which the total minimum recorded liability was $3 million.$3 million. Of the $136$130 million total environmental remediation liability for SCE, $131$125 million has been recorded as a regulatory asset. SCE expects to recover $49$47 million through an incentive mechanism that allows SCE to recover 90% of its environmental remediation costs at certain sites (SCE may request to include additional sites) and $82$78 million through a mechanism that allows SCE to recover 100% of the costs incurred at certain sites through customer rates. SCE's identified sites include several sites for which there is a lack of currently available information, including the nature and magnitude of contamination, and the extent, if any, that SCE may be held responsible for contributing to any costs incurred for remediating these sites. Thus, no reasonable estimate of cleanup costs can be made for these sites.
The ultimate costs to clean up SCE's identified sites may vary from its recorded liability due to numerous uncertainties inherent in the estimation process, such as: the extent and nature of contamination; the scarcity of reliable data for identified sites; the varying costs of alternative cleanup methods; developments resulting from investigatory studies; the possibility of identifying additional sites; and the time periods over which site remediation is expected to occur. SCE believes that, due to these uncertainties, it is reasonably possible that cleanup costs at the identified material sites and immaterial sites could exceed its recorded liability by up to $165149 million and $78 million, respectively. The upper limit of this range of costs was estimated using assumptions least favorable to SCE among a range of reasonably possible outcomes.
SCE expects to clean up and mitigate its identified sites over a period of up to 30 years. Remediation costs for each of the next five years are expected to range from $75 million to $2318 million. Costs incurred were $1 million for both the three months ended March 31, 2017 and 2016 were $2 million and 2015.$1 million, respectively.
Based upon the CPUC's regulatory treatment of environmental remediation costs incurred at SCE, SCE believes that costs ultimately recorded will not materially affect its results of operations, financial position, or cash flows. There can be no assurance, however, that future developments, including additional information about existing sites or the identification of new sites, will not require material revisions to estimates.
Nuclear Insurance
SCE is a member of NEIL, a mutual insurance company owned by entities with nuclear facilities. NEIL provides insurance for nuclear property damage, including damages caused by acts of terrorism up to specified limits, and for accidental outages for active facilities. The amount of nuclear property damage insurance purchased for San Onofre and Palo Verde exceeds the minimum federal requirement of $1.06 billion.$1.06 billion. If NEIL losses at any nuclear facility covered by the arrangement were to exceed the accumulated funds for these insurance programs, SCE could be assessed retrospective premium adjustments of up to approximately $45$52 million per year.
Federal law limits public offsite liability claims for bodily injury and property damage from a nuclear incident to the amount of available financial protection, which is currently approximately $13.5$13.4 billion. Based on its ownership interests, SCE could
be required to pay a maximum of approximately $255$255 million per nuclear incident. However, it would have to pay no more than approximately $38$38 million per incident in any one year.
For more information on nuclear insurance coverage, see Note 11 in the 20152016 Form 10-K.
Wildfire Insurance
Severe wildfires in California have given rise to large damage claims against California utilities for fire-related losses alleged to be the result of the failure of electric and other utility equipment. Invoking a California Court of Appeal decision, plaintiffs pursuing these claims have relied on the doctrine of inverse condemnation, which can impose strict liability (including liability for a claimant's attorneys' fees) for property damage. Prolonged droughtDrought conditions in California have also increased the duration of the wildfire season and the risk of severe wildfire events. On June 1, 2015, Edison International renewed its liabilitySCE has approximately $1 billion of insurance coverage which included coverage for SCE's wildfire liabilities up to a $610 million limit (withfor the period ending on May 31, 2017. SCE has a self-insured retention of $10$10 million per wildfire occurrence). Various coverage limitations within the policies that make up this insurance coverage could result in additional self-insured costs in the event of multiple wildfire occurrences during the policy period (June 1, 2015 to May 31, 2016).occurrence. SCE also has additional coverage for certain wildfire liabilities of $390 million, which applies when total covered wildfire claims exceed $610 million, through June 14, 2016. SCEor its contractors may experience coverage reductions and/or increased insurance costs in future years. No assurance can be given that future losses will not exceed the limits of SCE's or its contractors' insurance coverage.
Spent Nuclear Fuel
Under federal law, the U.S. Department of Energy ("DOE") is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. The DOE has not met its contractual obligation to accept spent nuclear fuel. Extended delays by the DOE have led to the construction of costly alternatives and associated siting and environmental issues. Currently, both San Onofre and Palo Verde have interim storage for spent nuclear fuel on site sufficient for their current license period.
In June 2010, the United States Court of Federal Claims issued a decision granting SCE and the San Onofre co-owners damages of approximately $142 million (SCE share $112 million) to recover costs incurred through December 31, 2005 for the DOE's failure to meet its obligation to begin accepting spent nuclear fuel from San Onofre. SCE received payment from the federal government in the amount of the damage award. In April 2016, SCE, as operating agent, settled a lawsuit on behalf of the San Onofre owners against the DOE for $162 million, including reimbursement for legal costs (SCE share $124 million) to compensate for damages caused by the DOE's failure to meet its obligation to begin accepting spent nuclear fuel for the period from January 1, 2006 to December 31, 2013. The settlement also provides for a claim submission/audit process for expenses incurred from 2014 – 2016, where SCE will submit a claim for damages caused by the DOE failure to accept spent nuclear fuel each year, followed by a government audit and payment of the claim. This process will make additional legal action to recover damages incurred in 2014 – 2016 unnecessary. The first such claim covering damages for 2014 – 2015 was filed on September 30, 2016 for approximately $56 million. In February 2017, the DOE reviewed the 2014 – 2015 claim submission and reduced the original request to approximately $43 million primarily due to DOE allocation limits. SCE accepted the DOE's determination, and the government will pay the 2014 – 2015 claim under the terms of the settlement. SCE will make the claim submission for 2016 damages in the third quarter of 2017. All damages recovered by SCE are subject to CPUC review as to how these amounts would be distributed among customers, shareholders, or to offset fuel decommissioning or storage costs.
Note 12. Preferred and Preference Stock of SCE
During the first quarter of 2016, SCE issued $300 million of 5.45% Series K Preference Stock (120,004 shares; cumulative, $2,500 liquidation value) to SCE Trust V, a special purpose entity formed to issue trust securities as discussed in Note 3. The Series K Preference Stock may be redeemed at par, in whole, but not in part, at any time prior to March 15, 2026 if certain changes in tax or investment company laws occur. On or after March 15, 2026, SCE may redeem the Series K shares at par, in whole or in part and distributions will accrue and be payable at a floating rate. The shares are not subject to mandatory redemption. The proceeds were used to redeem $125 million of SCE's Series D Preference Stock and for general corporate purposes.
Note 13.12. Accumulated Other Comprehensive Loss
Edison International'sThe changes in accumulated other comprehensive loss, net of tax, consist of: | | | | Edison International | | SCE | Edison International | | SCE |
| | Three months ended March 31, | Three months ended March 31, |
| (in millions) | 2016 |
| | 2015 |
| | 2016 |
| | 2015 |
| 2017 | | 2016 | | 2017 | | 2016 |
| Beginning balance | $ | (56 | ) | | $ | (58 | ) | | $ | (22 | ) | | $ | (28 | ) | $ | (53 | ) | | $ | (56 | ) | | $ | (20 | ) | | $ | (22 | ) |
| Pension and PBOP – net loss: | | | | | | | | | | | | | | |
| Other comprehensive loss before reclassifications | — |
| | (3 | ) | | — |
| | — |
| |
Reclassified from accumulated other comprehensive loss1 | 2 |
| | 2 |
| | 1 |
| | 1 |
| 2 |
| | 2 |
| | 1 |
| | 1 |
|
| Other | | 2 |
| | — |
| | 1 |
| | — |
|
| Change | 2 |
| | (1 | ) | | 1 |
| | 1 |
| 4 |
| | 2 |
| | 2 |
| | 1 |
|
| Ending Balance | $ | (54 | ) | | $ | (59 | ) | | $ | (21 | ) | | $ | (27 | ) | $ | (49 | ) | | $ | (54 | ) | | $ | (18 | ) | | $ | (21 | ) |
| |
1 | These items are included in the computation of net periodic pension and PBOP Plan expense. See Note 8 for additional information. |
Note 14.13. Interest and Other Income and Other Expenses
Interest and other income and other expenses are as follows:
| | | | Three months ended March 31, | Three months ended March 31, |
| (in millions) | 2016 | | 2015 | 2017 | | 2016 |
| SCE interest and other income: | | | | | | |
| Equity allowance for funds used during construction | $ | 22 |
| | $ | 21 |
| $ | 19 |
| | $ | 22 |
|
| Increase in cash surrender value of life insurance policies and life insurance benefits | 7 |
| | 10 |
| 12 |
| | 7 |
|
| Interest income | — |
| | 1 |
| 1 |
| | — |
|
| Other | 2 |
| | 1 |
| 1 |
| | 2 |
|
| Total SCE interest and other income | 31 |
| | 33 |
| 33 |
| | 31 |
|
| Other income of Edison International Parent and Other | — |
| | 6 |
| |
| Total Edison International interest and other income | $ | 31 |
| | $ | 39 |
| $ | 33 |
| | $ | 31 |
|
| SCE other expenses: | | | | | | |
| Civic, political and related activities and donations | $ | (5 | ) | | $ | (5 | ) | $ | (4 | ) | | $ | (5 | ) |
| Other | — |
| | (2 | ) | (3 | ) | | — |
|
| Total SCE other expenses | (5 | ) | | (7 | ) | (7 | ) | | (5 | ) |
| Other expense of Edison International Parent and Other | (1 | ) | | (3 | ) | |
| Other expenses of Edison International Parent and Other | | (1 | ) | | (1 | ) |
| Total Edison International other expenses | $ | (6 | ) | | $ | (10 | ) | $ | (8 | ) | | $ | (6 | ) |
Note 15.14. Supplemental Cash Flows Information
Supplemental cash flows information for continuing operations is:
| | | | Edison International | | SCE | Edison International | | SCE |
| | Three months ended March 31, | Three months ended March 31, |
| (in millions) | 2016 | | 2015 | | 2016 | | 2015 | 2017 | | 2016 | | 2017 | | 2016 |
| Cash payments for interest and taxes: | | | | | | | | | | | | | | |
| Interest, net of amounts capitalized | $ | 158 |
| | $ | 152 |
| | $ | 149 |
| | $ | 144 |
| $ | 167 |
| | $ | 158 |
| | $ | 152 |
| | $ | 149 |
|
| Tax payments, net | 2 |
| | — |
| | 11 |
| | 32 |
| |
| Tax payments, net of refunds | | — |
| | 2 |
| | — |
| | 11 |
|
| Non-cash financing and investing activities: | | | | | | | | | | | | | | |
| Dividends declared but not paid: | | | | | | | | | | | | | | |
| Common stock | $ | 156 |
| | $ | 136 |
| | $ | — |
| | $ | 147 |
| $ | 177 |
| | $ | 156 |
| | $ | — |
| | $ | — |
|
| Preferred and preference stock | 1 |
| | 3 |
| | 1 |
| | 3 |
| 1 |
| | 1 |
| | 1 |
| | 1 |
|
SCE's accrued capital expenditures at March 31, 20162017 and 20152016 were $360$275 million and $407$360 million, respectively. Accrued capital expenditures will be included as an investing activity in the consolidated statements of cash flow in the period paid.
CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
The management of Edison International and SCE, under the supervision and with the participation of Edison International's and SCE's respective Chief Executive OfficerOfficers and Chief Financial Officer and SCE's President and Chief Financial Officer,Officers, have evaluated the effectiveness of Edison International's and SCE's disclosure controls and procedures (as that term is defined in
Rules 13a-15(e) or 15d-15(e) under the Securities Exchange Act of 1934, as amended), respectively, as of the end of the first quarter of 2016.2017. Based on that evaluation, Edison International's and SCE's respective Chief Executive OfficerOfficers and Chief Financial Officer and SCE's President and Chief Financial OfficerOfficers have each concluded that, as of the end of the period, Edison International's and SCE's disclosure controls and procedures, respectively, were effective.
Changes in Internal Control Over Financial Reporting
There were no changes in Edison International's or SCE's internal control over financial reporting, respectively, during the first quarter of 20162017 that have materially affected, or are reasonably likely to materially affect, Edison International's or SCE's internal control over financial reporting.
Jointly Owned Utility Plant
Edison International's and SCE's respective scope of evaluation of internal control over financial reporting includes their Jointly Owned SCEUtility Projects as discussed in Note 2. Property, Plant and Equipment in the 20152016 Form 10-K.
LEGAL PROCEEDINGS
The following proceeding was previously reported to comply with SEC regulations, which require disclosure of certain information about proceedings arising under federal, state or local environmental provisions if a company reasonably believes that such proceedings might result in monetary sanctions of $100,000 or more.
Shaver Lake Dam Project Administrative Civil Liability Complaint
In 2011, SCE installed a PVC plastic geomembrane liner on the Shaver Lake Dam to prevent water seepage. Before starting the project, SCE received the required regulatory permits and approvals. SCE and the California Department of Fish and Wildlife executed a Streambed Alteration Agreement in November 2011 that governed SCE's activities in Shaver Lake as required by state and federal law. SCE also obtained the required federal Clean Water Act Certification in November 2011 for the project's completion.
In February 2012, the California Department of Fish and Wildlife and the Central Valley Regional Water Quality control Board issued letters alleging that SCE had violated provisions of the Streambed Alteration Agreement and certain conditions of the federal Clean Water Act Certification, respectively. Both letters alleged that during the draining of Shaver Lake, SCE failed to prevent the discharge of sediment into an adjoining creek, causing the deaths of fish in the lake and creek. In
October 2014, SCE received a pre-issuance draft of an Administrative Civil Liability Complaint from the Central Valley Regional Water Quality Control Board alleging violations of certain permit conditions relating to the Shaver Lake Dam Project. The Regional Water Quality Control Board is seeking $25 million in civil penalties for the violations. SCE disputes the allegations but is working with the regulatory agencies to resolve the matter.None.
UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
Purchases of Equity Securities by Edison International and Affiliated Purchasers
The following table contains information about all purchases of Edison International Common Stock made by or on behalf of Edison International in the first quarter of 2016.2017. |
| | | | | | | | | | | | |
| Period | (a) Total Number of Shares (or Units) Purchased1 | | (b) Average Price Paid per Share (or Unit)1 | | (c) Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs | | (d) Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs |
| January 1, 2016 to January 31, 2016 | 391,478 |
| | | $ | 59.21 |
| | | — | | — |
| February 1, 2016 to February 29, 2016 | 961,019 |
| | | 66.88 |
| | | — | | — |
| March 1, 2016 to March 31, 2016 | 656,598 |
| | | 70.15 |
| | | — | | — |
| Total | 2,009,095 |
| | | $ | 66.45 |
| | | — | | — |
|
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| Period | (a) Total Number of Shares (or Units) Purchased1 | | (b) Average Price Paid per Share (or Unit)1 | | (c) Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs | | (d) Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs |
| January 1, 2017 to January 31, 2017 | 1,071,723 |
| | | $ | 72.35 |
| | | — | | — |
| February 1, 2017 to February 28, 2017 | 2,778,550 |
| | | 74.02 |
| | | — | | — |
| March 1, 2017 to March 31, 2017 | 447,903 |
| | | 79.65 |
| | | — | | — |
| Total | 4,298,176 |
| | | $ | 74.19 |
| | | — | | — |
| |
1 | The shares were purchased by agents acting on Edison International's behalf for delivery to plan participants to fulfill requirements in connection with Edison International's: (i) 401(k) Savings Plan; (ii) Dividend Reinvestment and Direct Stock Purchase Plan; and (iii) long-term incentive compensation plans. The shares were purchased in open-market transactions pursuant to plan terms or participant elections. The shares were never registered in Edison International's name and none of the shares purchased were retired as a result of the transactions. |
Purchases of Equity Securities by SCE and Affiliated Purchasers
The following table contains information about all purchases of SCE Series D Preference Stock made by or on behalf of SCE in the first quarter of 2016.
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| Period | (a) Total Number of Shares (or Units) Purchased1 | | (b) Average Price Paid per Share (or Unit)1 | | (c) Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs | | (d) Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs |
| January 1, 2016 to January 31, 2016 | | | | | | | — | | — |
| February 1, 2016 to February 29, 2016 | | | | | | | — | | — |
| March 1, 2016 to March 31, 2016 | 1,250,000 |
| | | $ | 100.54 |
| | | 1,250,000 | | — |
| Total | 1,250,000 |
| | | $ | 100.54 |
| | | 1,250,000 | | — |
| |
1
| On March 31, 2016, SCE repurchased 1,250,000 shares of the Series D Preference Shares, at $100.54 (liquidation value and accrued dividends) per share. The redemption of SCE's Series D Preference Stock was announced via an SCE press release on March 1, 2016. |
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| | |
Exhibit Number | | Description |
| | | |
3.1 | | Restated Articles of Incorporation of Southern California Edison Company, together with all Certificates of Determination of Preferences of all outstanding Preferred and Preference Stock |
| | |
| 10.1** | | Edison International 20082017 Executive Severance Plan, as amended and restated effective February 24, 2016Annual Incentive Program |
| | | |
| 10.2** | | Edison International 2008 Executive Disability Plan, as amended and restated effective January 1, 2016 |
| | |
10.3** | | Edison International 2016 Executive Annual Incentive Program |
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10.4** | | Edison International 20162017 Long-Term Incentives Terms and Conditions |
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| 31.1 | | Certifications of the Chief Executive Officer and Chief Financial Officer of Edison International pursuant to Section 302 of the Sarbanes-Oxley Act |
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| 31.2 | | Certifications of the Chief Executive Officer and Chief Financial Officer of Southern California Edison Company pursuant to Section 302 of the Sarbanes-Oxley Act |
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| 32.1 | | Certifications of the Chief Executive Officer and the Chief Financial Officer of Edison International required by Section 906 of the Sarbanes-Oxley Act |
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| 32.2 | | Certifications of the Chief Executive Officer and the Chief Financial Officer of Southern California Edison Company required by Section 906 of the Sarbanes-Oxley Act |
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| 101.1 | | Financial statements from the quarterly report on Form 10-Q of Edison International for the quarter ended March 31, 2016,2017, filed on May 2, 2016,1, 2017, formatted in XBRL: (i) the Consolidated Statements of Income; (ii) the Consolidated Statements of Comprehensive Income; (iii) the Consolidated Balance Sheets; (iv) the Consolidated Statements of Cash Flows; and (v) the Notes to Consolidated Financial Statements |
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| 101.2 | | Financial statements from the quarterly report on Form 10-Q of Southern California Edison Company for the quarter ended March 31, 2016,2017, filed on May 2, 2016,1, 2017, formatted in XBRL: (i) the Consolidated Statements of Income; (ii) the Consolidated Statements of Comprehensive Income; (iii) the Consolidated Balance Sheets; (iv) the Consolidated Statements of Cash Flows; and (v) the Notes to Consolidated Financial Statements |
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** | Indicates a management contract or compensatory plan or arrangement, as required by Item 15(a)(3). |
** Indicates a management contract or compensatory plan or arrangement, as required by Item 15(a)(3) of Form 10-K.
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized.
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| | EDISON INTERNATIONAL | | | SOUTHERN CALIFORNIA EDISON COMPANY |
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| By: | /s/ Aaron D. Moss | | By: | /s/ Connie J. Erickson |
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| | Aaron D. Moss Vice President and Controller (Duly Authorized Officer and Principal Accounting Officer) | | | Connie J. Erickson Vice President and Controller (Duly Authorized Officer and Principal Accounting Officer) |
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| Date: | May 2, 20161, 2017 | | Date: | May 2, 20161, 2017 |