UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549
FORM 10-K
x | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the fiscal year ended December 31, 2013 | |
o | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from ____________to ______________. | |
Commission File Number 1-6364
SOUTH JERSEY INDUSTRIES, INC.
(Exact name of registrant as specified in its charter)
New Jersey (State of incorporation) | 22-1901645 (IRS employer identification no.) |
1 South Jersey Plaza, Folsom, New Jersey 08037 | (609) 561-9000 |
(Address of principal executive offices, including zip code) | (Registrant's telephone number, including area code) |
Securities registered pursuant to Section 12(b) of the Act:
Common Stock - $1.25 par value per share (Title of each class) | New York Stock Exchange (Name of exchange on which registered) |
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act: Yes x No o
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Act: Yes o No x
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. Yes x 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). Yes x No o
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. x
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer x | Accelerated filer o |
Non-accelerated filer o (Do not check if a smaller reporting company) | Smaller reporting company o |
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No x
The aggregate market value of voting stock held by non-affiliates of the registrant as of June 30, 2013 was $1,827,264,253. As of February 15, 2014, there were 32,741,344 shares of the registrant's common stock outstanding.
Documents Incorporated by Reference:
In Part III of Form 10-K: Portions of the registrant's definitive proxy statement filed for the registrant's 2014 annual meeting of shareholders are incorporated by reference into Part III of this Form 10-K.
TABLE OF CONTENTS
Page No. | ||
PART I | ||
Item 1. | ||
Item 1A. | ||
Item 1B. | ||
Item 2. | ||
Item 3. | ||
Item 4. | ||
Item 4A. | ||
PART II | ||
Item 5. | ||
Item 6. | ||
Item 7. | ||
Item 7A. | ||
Item 8. | ||
Item 9. | ||
Item 9A. | ||
Item 9B. | ||
PART III | ||
Item 10. | ||
Item 11. | ||
Item 12. | ||
Item 13. | ||
Item 14. | ||
PART IV | ||
Item 15. | ||
South Jersey Industries, Inc.
Forward Looking Statements
Certain statements contained in this Annual Report on Form 10-K may qualify as “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than statements of historical fact included in this Report should be considered forward-looking statements made in good faith by South Jersey Industries (SJI or the Company) and are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. When used in this Report, or any other of the Company's documents or oral presentations, words such as “anticipate,” “believe,” “expect,” “estimate,” “forecast,” “goal,” “intend,” “objective,” “plan,” “project,” “seek,” “strategy” and similar expressions are intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed or implied in the statements. These risks and uncertainties include, but are not limited to the risks set forth under “Risk Factors” in Part I, Item 1A of this Annual Report on Form 10-K and elsewhere throughout this Report. These cautionary statements should not be construed by you to be exhaustive and they are made only as of the date of this Report. While the Company believes these forward-looking statements to be reasonable, there can be no assurance that they will approximate actual experience or that the expectations derived from them will be realized. Further, SJI undertakes no obligation to update or revise any of its forward-looking statements whether as a result of new information, future events or otherwise.
Available Information
The Company's Internet address is www.sjindustries.com. We make available free of charge on or through our website SJI's Annual Report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934 as soon as reasonably practicable after we electronically file such material with, or furnish it to, the Securities and Exchange Commission (SEC). The SEC maintains an Internet site that contains these reports at http://www.sec.gov. Also, copies of SJI's annual report will be made available, free of charge, upon written request. The content on any web site referred to in this filing is not incorporated by reference into this filing unless expressly noted otherwise.
Units of Measurement | ||
For Natural Gas: | ||
1 Bcf | = One billion cubic feet | |
1dt | = One decatherm | |
1 MMdts | = One million decatherms | |
dts/d | = Decatherms per day | |
MDWQ | = Maximum daily withdrawal quantity | |
For Electric: | ||
1 MMmwh | = One million megawatt hours | |
1 mwh | = One megawatt hour | |
1
South Jersey Industries, Inc.
Part I
PART I
Item 1. Business
Description of Business
The registrant, South Jersey Industries, Inc. (SJI), a New Jersey corporation, was formed in 1969 for the purpose of owning and holding all of the outstanding common stock of South Jersey Gas Company, a public utility, and acquiring and developing non-utility lines of business.
SJI currently provides a variety of energy-related products and services, primarily through the following subsidiaries:
• | South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey. |
• | South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial and industrial customers. |
• | Marina Energy LLC (Marina) develops and operates on-site energy-related projects. |
• | South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets on a wholesale basis in the mid-Atlantic, Appalachian and southern states. |
• | South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement. |
• | South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania. |
Additional Information on the nature of our business can be found in “Management's Discussion and Analysis of Financial Condition and Results of Operations,” under Item 7 of this Report.
Financial Information About Reportable Segments
Information regarding Reportable Segments is incorporated by reference to Note 8 of the consolidated financial statements included under Item 8 of this Report.
Sources and Availability of Raw Materials
South Jersey Gas Company
Transportation and Storage Agreements
SJG has direct connections to the interstate pipeline systems of both Transcontinental Gas Pipe Line Company, LLC (Transco) and Columbia Gas Transmission, LLC (Columbia). During 2013, SJG purchased and had delivered approximately 41.0 million decatherms (MMdts) of natural gas for distribution to both on-system and off-system customers and for injections into storage. Of this total, 23.8 MMdts were transported on the Transco pipeline system while 17.2 MMdts were transported on the Columbia pipeline system. Moreover, during 2013 third-party suppliers delivered 32.6 MMdts to SJG's system on behalf of end use customers behind our city gate stations. SJG also secures other long-term services from one additional pipeline upstream of the Transco and Columbia systems. This upstream pipeline is owned by Dominion Transmission, Inc. (Dominion). Services provided by Dominion are utilized to deliver gas into either the Transco or Columbia systems for ultimate delivery to SJG. Services provided by all of the above-mentioned pipelines are subject to the jurisdiction of the Federal Energy Regulatory Commission (FERC). Unless otherwise indicated, our intentions are to renew or extend these service agreements before they expire.
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Part I
Transco:
Transco is SJG's largest supplier of long-term gas transmission services which includes both year-round and seasonal firm transportation (FT) service arrangements. When combined, these FT services enable SJG to purchase gas from third parties and have delivered to its city gate stations by Transco a total of 297,958 dts per day (dts/d). Of this total, 133,917 dts/d is long-haul FT (where gas can be transported from the production areas of the Southwest to the market areas of the Northeast) while 164,041 dts/d is market area FT. The terms of SJG's year-round agreements extend for various periods through 2025. SJG's seasonal agreements are currently operating under their respective evergreen provisions.
Of the 297,958 dts/d of Transco services mentioned above, SJG has released a total of 39,800 dts/d of its long-haul FT and 49,041 dts/d of its market area FT service. These releases were made in association with SJG's Conservation Incentive Program (CIP) discussed further under Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations". In addition, SJG released 45,000 dts/d of its long-haul FT and 10,000 dts/d of market area FT as part of Asset Management Agreements (AMA). The AMA-related releases are discussed below under “Gas Supplies”.
SJG currently has six long-term gas storage service agreements with Transco that, when combined, are capable of storing approximately 5.0 MMdts. Through these agreements, SJG can inject gas into market and production area storages during periods of low demand and extract gas at a Maximum Daily Withdrawal Quantity (MDWQ) of up to 107,407 dts during periods of high demand. The longest term of these storage service agreements extends through March 31, 2023.
Dominion:
SJG subscribes to a firm storage service from Dominion, under its Rate Schedule GSS. This storage has a MDWQ of 10,000 dts during the period between November 16 and March 31 of each winter season, with an associated total storage capacity of 423,000 dts. Gas withdrawn from Dominion GSS storage is delivered through both the Dominion and Transco (Leidy Line) pipeline systems for delivery to SJG service territory. The primary term of this agreement extends through March 31, 2015. SJG has released this service under an AMA as discussed below under "Gas Supplies."
Columbia:
SJG subscribes to three firm transportation agreements with Columbia which provides for 54,022 dts/d of firm deliverability with 45,022 dts/d of this deliverability extending through October 31, 2019. The remaining 9,000 dts per day had a primary term of one year which extended from November 1, 2011 through October 31, 2012. The agreement is subject to pre-granted abandonment upon its termination, with SJG having the right of first refusal to extend the agreement. By way of an agreement dated July 19, 2013, this service was extended through October 31, 2014. SJG had previously released 14,714 dts/d of this amount to SJRG in conjunction with its CIP thereby reducing the combined availability of firm transportation on the Columbia system to 39,308 dts/d.
SJG also subscribes to a firm storage service with Columbia under its Rate Schedule FSS along with an associated firm transportation service under Rate Schedule SST, each of which extends through October 31, 2019. SJG has a total FSS MDWQ of 52,891 dts and a related 3,473,022 dts of storage capacity. SJG released to SJRG 19,029 dts of its FSS MDWQ along with 1,249,485 dts of its FSS storage capacity. Additionally, SJG released to SJRG 19,029 dts/d of its Columbia SST transportation service. Both releases made by SJG were in connection with its CIP and extend through September 30, 2014.
Gas Supplies
In 2013, SJG entered into an AMA with a gas marketer which extends through March 31, 2014. Under this agreement SJG released to the marketer its firm transportation rights equal to 30,000 dts/d of transportation capacity on Transco. The marketer manages this capacity and provides SJG with up to 30,000 dts/d of firm deliverability each day during the period November 1, 2013 through March 31, 2014. The marketer will seek to optimize the capacity released to it under this AMA and pay SJG a monthly Asset Management Fee in consideration for same.
Also during 2013, SJG entered into an AMA with a gas marketer which extends through October 31, 2014. Under this agreement SJG has released to the marketer its firm transportation rights equal to 15,000 dts/d of transportation capacity on Transco. The marketer manages this capacity and provides SJG with up to 15,000 dts/d of firm deliverability each day through October 31, 2014. The marketer will seek to optimize the capacity released to it under this AMA and pay SJG a one time Asset Management Fee in consideration for same.
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South Jersey Industries, Inc.
Part I
Also in 2013, SJG entered into an AMA with a gas marketer which extends through March 31, 2014. Under this agreement SJG released its GSS storage capacity and deliverability held on the Dominion pipeline system to the marketer equal to 423,000 dts of storage capacity and 10,000 dts/d of deliverability on both the Dominion and Transco Leidy Line systems. The marketer manages this capacity and provides SJG with right to call on up to 10,000 dts/d into Transco’s Leidy Line for the period from November 1, 2013 through March 31, 2014. The marketer will seek to optimize the storage capacity released to it under this AMA and pay SJG a one time Asset Management Fee in consideration for same.
In 2011, SJG entered into a long-term gas purchase agreement with a gas producer, the primary term of which extends through October 31, 2019. The maximum daily quantities (MDQ) available for purchase under this agreement initially starts at 6,250 dts/d and ratchets up to a MDQ of 25,000 dts/d. Gas purchased from this producer will be sourced in the Appalachian supply areas and delivered into the Columbia pipeline system for delivery to SJG.
As part of its gas purchasing strategy, SJG uses financial contracts to hedge against forward price risk. These contracts are recoverable through SJG’s Basic Gas Supply Service Clause (BGSS), subject to BPU approval.
Supplemental Gas Supplies
SJG is utilizing an option inherent in its Transco Liquefied Natural Gas (LNG) storage service, which permits the withdrawal of gas as liquid (and/or vapor), as a supply source to replenish its LNG inventory in McKee City during the 2013-2014 winter season.
SJG operates peaking facilities which can store and vaporize LNG for injection into its distribution system. SJG's LNG facility has a storage capacity equivalent to 434,300 dts of natural gas and has an installed capacity to vaporize up to 118,250 dts of LNG per day for injection into its distribution system.
Peak-Day Supply
SJG plans for a winter season peak-day demand on the basis of an average daily temperature of 2 degrees Fahrenheit (F). Gas demand on such a design day for the 2013-2014 winter season is estimated to be 486,110 dts (excluding industrial customers). SJG projects that it has adequate supplies and interstate pipeline entitlements to meet its design requirements. SJG experienced its highest peak-day demand for calendar year 2013 of 437,189 dts on January 22nd, while experiencing an average temperature of 17.3 degrees F that day.
Natural Gas Prices
SJG's average cost of natural gas purchased and delivered in 2013, 2012 and 2011, including demand charges, was $4.81 per dt, $4.73 per dt and $6.11 per dt, respectively.
South Jersey Energy Company
Transportation and Storage Agreements - Natural Gas
Access to gas suppliers and cost of gas are significant to the operations of SJE. No material part of the business of SJE is dependent upon a single customer or a few customers. SJE purchases delivered gas only, primarily from SJRG. Consequently, SJE maintains no transportation or storage agreements.
Electric Supply
Due to the liquidity in the market, SJE primarily purchases delivered electric in the day-ahead and real time markets through regional transmission organizations.
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South Jersey Industries, Inc.
Part I
South Jersey Resources Group
Transportation and Storage Agreements
National Fuel Gas Supply Corporation:
SJRG has multiple storage service agreements with National Fuel Gas Supply Corporation (National Fuel). Two contracts totaling 2,581,420 dts of capacity have evergreen rights that extend year to year. One additional contract covering 224,576 dts of storage capacity extends through March 31, 2018 while a final contract covering 150,040 dts of capacity expires March 31, 2023.
SJRG holds long-term firm transportation agreements with National Fuel associated with the above-mentioned agreements. Under these agreements, National Fuel will provide SJRG with a maximum daily injection transportation quantity of 16,947 dts/d with primary receipt points from Tennessee Gas Pipeline for delivery into storage, and 25,661 dts/d of maximum daily withdrawal transportation quantity with a primary receipt point of storage and a primary delivery point of Transcontinental Gas Pipeline.
Transcontinental Gas Pipeline:
SJRG has a storage agreement with Transco for storage service at Transco's WSS facility which expires in October 2017. Under this evergreen contract, up to 24,479 dts/d may be injected and up to 46,380 dts/d may be withdrawn. Total storage capacity on the agreement is 4,406,135 dts.
SJRG holds a firm transportation agreement with Transco which expires March 31, 2043. Under this agreement, Transco will provide SJRG with 10,000 dts/d of deliveries to New York and receipts at Leidy, PA.
Dominion Gas Transmission:
SJRG has a firm transportation agreement with Dominion which expires October 31, 2022. Under this agreement, Dominion will provide SJRG with 5,000 dts/d of deliveries to Leidy, Pennsylvania and receipts at Lebanon, Ohio.
SJRG also has a firm transportation agreement with Dominion related to SJRG's Transco SS-1 storage. Under this contract, Dominion will provide receipts at Leidy, Pennsylvania and deliveries to storage in the amount of 17,432 dts/d.
Columbia Gas Transmission:
SJRG holds a firm transportation agreement with Columbia. Under this evergreen agreement, Columbia provides receipts at Leach, Kentucky and deliveries of 14,714 dts/d to New Jersey. In addition, SJRG has 10,000 dts/d of Columbia capacity from New York to Maryland expiring October 31, 2018. These services with Columbia were released to SJRG by SJG as discussed above.
SJRG holds a storage agreement with Columbia for service under Columbia's FSS rate schedule. Under this evergreen agreement, Columbia will provide SJRG with storage capacity of 1,249,515 dts. Under this agreement, 19,029 dts/d may be withdrawn from storage and 9,996 dts/d may be injected.
SJRG holds firm transportation related to the above mentioned storage agreement which provides for receipts at storage and deliveries to New Jersey of 19,029 dts/d. Under this evergreen contract, these services with Columbia were released to SJRG by SJG.
Columbia Gulf Transmission:
SJRG holds a firm transportation agreement with Columbia Gulf which expires October 31, 2019. Under this evergreen agreement, Columbia Gulf provides receipts in Louisiana with deliveries at Leach, Kentucky in the amount of 15,000 dts/d.
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South Jersey Industries, Inc.
Part I
Tennessee Gas Transmission:
SJRG holds multiple firm transportation agreements with Tennessee Gas Pipeline that have various deliveries and receipts in Pennsylvania and Louisiana. The contract volumes range from 10,000 to 65,200 per contract and expire between October 31, 2014 and October 31, 2016.
Egan Storage:
SJRG holds a storage agreement with Egan Storage for service under Tetco’s FSS rate schedule. Under this agreement, which expires March 31, 2014, Tetco provides SJRG with storage capacity of 1,000,000 dts of which 60,000 dts/d may be withdrawn from storage and 40,000 dts/d may be injected.
Gas Supplies
SJRG has entered into several long-term natural gas supply agreements to purchase a minimum of 545,500 dts/d and up to 810,000 dts/d, depending upon production levels, for terms ranging from three to ten years at index based prices.
Patents and Franchises
South Jersey Gas Company
SJG holds nonexclusive franchises granted by municipalities in the seven-county area of southern New Jersey that it serves. No other natural gas public utility presently serves the territory covered by SJG's franchises. Otherwise, patents, trademarks, licenses, franchises and concessions are not material to the business of SJG.
Seasonal Aspects
South Jersey Gas Company
SJG experiences seasonal fluctuations in sales when selling natural gas for heating purposes. SJG meets this seasonal fluctuation in demand from its firm customers by buying and storing gas during the summer months, and by drawing from storage and purchasing supplemental supplies during the heating season. As a result of this seasonality, SJG's revenues and net income are significantly higher during the first and fourth quarters than during the second and third quarters of the year.
Non-Utility Companies
Among SJI's non-utility activities, wholesale and retail gas marketing have seasonal patterns similar to SJG's. Activities such as energy services and energy project development do not follow seasonal patterns. Other activities, such as retail electric marketing and appliance service, can have seasonal earnings patterns that are different from the utility. While growth in the earnings contributions from nonutility operations has improved SJI's second and third quarter net income levels, the first and fourth quarters remain the periods where most of SJI's revenue and net income is produced.
Working Capital Practices
Reference is made to “Liquidity and Capital Resources” included in Item 7, “Management's Discussion and Analysis of Financial Condition and Results of Operations,” of this Report.
Customers
No material part of the Company's business is dependent upon a single customer or a few customers, the loss of which would have a material adverse effect on SJI performance on a consolidated basis.
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South Jersey Industries, Inc.
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Backlog
Backlog is not material to an understanding of SJI's business or that of any of its subsidiaries.
Government Contracts
No material portion of the business of SJI or any of its subsidiaries is subject to renegotiation of profits or termination of contracts or subcontracts at the election of any government.
Competition
Information on competition for SJI and its subsidiaries can be found in Item 7, “Management's Discussion and Analysis of Financial Condition and Results of Operations,” of this Report.
Research
During the last three fiscal years, neither SJI nor any of its subsidiaries engaged in research activities to any material extent.
Environmental Matters
Information on environmental matters for SJI and its subsidiaries can be found in Note 15 of the consolidated financial statements included under Item 8 of this Report.
Employees
SJI and its subsidiaries had a total of approximately 700 employees as of December 31, 2013. Of that total, approximately 320 employees are unionized. The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76. SJG employees represented by the IBEW operate under a collective bargaining agreement that runs through February 28, 2017. SJESP employees represented by the IBEW operated under a collective bargaining agreement that was set to expire February 28, 2014, however a new collective bargaining agreement was agreed to which commences on March 1, 2014 and runs through February 28, 2017. The remaining unionized employees represented by the IAM operate under a collective bargaining agreement that expires in August 2014.
Financial Information About Foreign and Domestic Operations and Export Sales
SJI has no foreign operations and export sales have not been a significant part of SJI's business.
Item 1A. Risk Factors
SJI and its subsidiaries operate in an environment that involves risks, many of which are beyond our control. SJI has identified the following risk factors that could cause SJI's operating results and financial condition to be materially adversely affected. In addition, new risks may emerge at any time, and SJI cannot predict those risks or the extent to which they may affect SJI's businesses or financial performance.
• | SJI is a holding company and its assets consist primarily of investments in subsidiaries. Should SJI's subsidiaries be unable to pay dividends or make other payments to SJI for financial, regulatory, legal or other reasons, SJI's ability to pay dividends on its common stock could be limited. SJI's stock price could be adversely affected as a result. |
• | SJI's business activities are concentrated in southern New Jersey. Changes in the economies of southern New Jersey and surrounding regions could negatively impact the growth opportunities available to SJI and the financial condition of customers and prospects of SJI. |
• | Changes in the regulatory environment or unfavorable rate regulation at its utility may have an unfavorable impact on SJI's financial performance or condition. SJI's utility business is regulated by the New Jersey Board |
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South Jersey Industries, Inc.
Part I
of Public Utilities which has authority over many of the activities of the utility business including, but not limited to, the rates it charges to its customers, the amount and type of securities it can issue, the nature of investments it can make, the nature and quality of services it provides, safety standards and other matters. The extent to which the actions of regulatory commissions restrict or delay SJG's ability to earn a reasonable rate of return on invested capital and/or fully recover operating costs may adversely affect its results of operations, financial condition and cash flows.
• | SJI may not be able to respond effectively to competition, which may negatively impact SJI's financial performance or condition. Regulatory initiatives may provide or enhance opportunities for competitors that could reduce utility income obtained from existing or prospective customers. Also, competitors in all of SJI's business lines may be able to provide superior or less costly products or services based upon currently available or newly developed technologies. |
• | Warm weather, high commodity costs, or customer conservation initiatives could result in reduced demand for some of SJI's energy products and services. While SJI's utility currently has a conservation incentive program clause that protects its revenues and gross margin against usage per customer that is lower than a set level, the clause is currently approved as a pilot program through September 2014. Should this clause expire without replacement or extension, lower customer energy utilization levels would likely reduce SJI's net income. |
• | High natural gas prices could cause more of SJI's receivables to be uncollectible. Higher levels of uncollectibles from either residential or commercial customers would negatively impact SJI's income and could result in higher working capital requirements. |
• | SJI's net income could decrease if it is required to incur additional costs to comply with new governmental safety, health or environmental legislation. SJI is subject to extensive and changing federal and state laws and regulations that impact many aspects of its business; including the storage, transportation and distribution of natural gas, as well as the remediation of environmental contamination at former manufactured gas plant facilities. |
• | Climate change legislation could impact SJI's financial performance and condition. Climate change is receiving ever increasing attention from scientists and legislators alike. The debate is ongoing as to the extent to which our climate is changing, the potential causes of this change and its future impacts. Some attribute global warming to increased levels of greenhouse gases, which has led to significant legislative and regulatory efforts to limit greenhouse gas emissions. The outcome of federal and state actions to address global climate change could result in a variety of regulatory programs including additional charges to fund energy efficiency activities or other regulatory actions. These actions could affect the demand for natural gas and electricity, result in increased costs to our business and impact the prices we charge our customers. Because natural gas is a fossil fuel with low carbon content, it is possible that future carbon constraints could create additional demands for natural gas, both for production of electricity and direct use in homes and businesses. Any adoption by federal or state governments mandating a substantial reduction in greenhouse gas emissions could have far-reaching and significant impacts on the energy industry. We cannot predict the potential impact of such laws or regulations on our future consolidated financial condition, results of operations or cash flows. |
• | SJI's wholesale commodity marketing and retail electric businesses are exposed to the risk that counterparties that owe money or energy to SJI will not be able to meet their obligations for operational or financial reasons. SJI could be forced to buy or sell commodity at a loss as a result of such failure. Such a failure, if large enough, could also impact SJI's liquidity. |
• | Increasing interest rates will negatively impact the net income of SJI. Several of SJI's subsidiaries are capital intensive, resulting in the incurrence of significant amounts of debt financing. Almost all of the long-term debt of SJI and its subsidiaries is issued at fixed rates or has utilized interest rate swaps to mitigate changes in variable rates. However, new issues of long-term debt and all variable rate short-term borrowings are exposed to the impact of rising interest rates. |
• | SJI has guaranteed certain obligations of unconsolidated affiliates and is exposed to the risk that these affiliates will not be able to meet performance and financial commitments. SJI's unconsolidated affiliates develop and operate on-site energy related projects. SJI has guaranteed certain obligations of these affiliates in connection with the development and operation of the facilities. In the event that these projects do not meet specified levels of operating performance or are unable to meet certain financial obligations as they become due, SJI could be required to make payments related to these obligations. |
• | The inability to obtain capital, particularly short-term capital from commercial banks, could negatively impact the daily operations and financial performance of SJI. SJI uses short-term borrowings under committed and uncommitted credit facilities provided by commercial banks to supplement cash provided by operations, to support working capital needs, and to finance capital expenditures, as incurred. SJG relies upon short-term borrowings issued under a commercial paper program supported by a committed bank credit facility to support working capital needs, and to finance capital expenditures, as incurred. If the customary sources of short-term capital were no longer available due to market conditions, SJI and its subsidiaries may not be able to meet its working capital and capital expenditure requirements and borrowing costs could increase. |
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South Jersey Industries, Inc.
Part I
• | A downgrade in either SJI's or SJG's credit ratings could negatively affect our ability to access adequate and cost effective capital. Our ability to obtain adequate and cost effective capital depends largely on our credit ratings, which are greatly influenced by financial condition and results of operations. If the rating agencies downgrade either SJI's or SJG's credit ratings, particularly below investment grade, our borrowing costs would increase. In addition, we would likely be required to pay higher interest rates in future financings and potential funding sources would likely decrease. To the extent that a decline in SJG's credit rating has a negative effect on SJI, SJI could be required to provide additional support to certain counterparties. |
• | Hedging activities of the company designed to protect against commodity price or interest rate risk may cause fluctuations in reported financial results and SJI's stock price could be adversely affected as a result. Although SJI enters into various contracts to hedge the value of energy assets, liabilities, firm commitments or forecasted transactions, the timing of the recognition of gains or losses on these economic hedges in accordance with accounting principles generally accepted in the United States of America does not always match up with the gains or losses on the items being hedged. The difference in accounting can result in volatility in reported results, even though the expected profit margin is essentially unchanged from the dates the transactions were consummated. |
• | The inability to obtain natural gas or electricity from suppliers would negatively impact the financial performance of SJI. Several of SJI's subsidiaries have businesses based upon the ability to deliver natural gas or electricity to customers. Disruption in the production or transportation to SJI from its suppliers could prevent SJI from completing sales to its customers. |
• | Transporting and storing natural gas involves numerous risks that may result in accidents and other operating risks and costs. SJI's gas distribution activities involve a variety of inherent hazards and operating risks, such as leaks, accidents, mechanical problems, natural disasters or terrorist activities which could cause substantial financial losses. In addition, these risks could result in loss of human life, significant damage to property, environmental pollution and impairment of operations, which in turn could lead to substantial losses. In accordance with customary industry practice, SJI maintains insurance against some, but not all, of these risks and losses. The occurrence of any of these events not fully covered by insurance could adversely affect SJI's financial position, results of operations and cash flows. |
• | Adverse results in legal proceedings could be detrimental to the financial condition of SJI. The outcomes of legal proceedings can be unpredictable and can result in adverse judgments. |
• | Renewable energy projects at Marina receive significant benefit from tax and regulatory incentives. A significant portion of the expected return on investment of these renewable energy projects is dependent upon federal investment tax credits (ITCs) and the future market for renewable energy credits (RECs). The benefits from ITCs are typically available when the project is placed in service while the benefits from RECs are produced during the entire life of the project. As a result, earnings from existing projects would be adversely affected without a liquid REC market. In addition, the return on investment from new projects may not be as attractive if ITCs are not available and/or a liquid REC market ceases to exist. Therefore, these projects are exposed to the risk that currently favorable tax and regulatory incentives expire or are adversely modified. |
• | Constraints in available pipeline capacity, particularly in the Marcellus Shale producing region, may negatively impact SJI's financial performance. Increasing natural gas production and/or pipeline transportation disruptions in the Marcellus region, where SJI has natural gas receipt requirements, may cause temporary take-away constraints resulting in higher transportation costs and the sale of shale gas at a loss. |
• | New legislation could have an impact on our ability to hedge risks associated with our business. The Dodd-Frank Act regulates derivative transactions, which include certain instruments used in our risk management activities. This legislation and any new regulations could increase the operational and transactional cost of derivatives contracts and affect the number and/or creditworthiness of available counterparties. |
• | Failures in the security of our computer systems through cyberattacks, hackers or other sources, could have a material adverse impact on our business and results of operations. SJI uses computer systems and services that involve the storage of confidential information on our employees, customers and vendors. In addition, certain computer systems monitor and control our generation and distribution processes. Experienced hackers may be able to develop and deploy viruses that exploit the security of our computer systems and thus obtain confidential information and/or disrupt significant business processes. Unauthorized access to confidential information or disruptions to significant business processes could damage our reputation and negatively impact our results of operations and financial condition. |
Item 1B. Unresolved Staff Comments
None.
9
Item 2. Properties
The principal property of SJI consists of SJG's gas transmission and distribution systems that include mains, service connections and meters. The transmission facilities carry the gas from the connections with Transco and Columbia to SJG's distribution systems for delivery to customers. As of December 31, 2013, there were approximately 122.7 miles of mains in the transmission systems and 6,247 miles of mains in the distribution systems.
SJG owns approximately 154 acres of land in Folsom, New Jersey which is the site of SJI's corporate headquarters. Approximately 140 acres of this property is deed restricted. SJG also has office and service buildings at six other locations in the territory. There is a liquefied natural gas storage and vaporization facility at one of these locations.
As of December 31, 2013, SJG's utility plant had a gross book value of $1.8 billion and a net book value, after accumulated depreciation, of $1.4 billion. In 2013, $161.5 million was spent on additions to utility plant and there were retirements of property having an aggregate gross book cost of $17.1 million.
Virtually all of SJG's transmission pipeline, distribution mains and service connections are under streets or highways or on the property of others. The transmission and distribution systems are maintained under franchises or permits or rights-of-way, many of which are perpetual. SJG's properties (other than property specifically excluded) are subject to a lien of mortgage under which its first mortgage bonds are outstanding. We believe these properties are well maintained and in good operating condition.
Nonutility property and equipment with a net book value of $434.3 million consists primarily of Marina's energy projects, in particular the thermal energy plant in Atlantic City, N.J.
Energy and Minerals Inc. (EMI) owns 235 acres of land in Vineland, New Jersey.
South Jersey Fuel, Inc., an inactive subsidiary, owns land in Deptford Township and owns real estate in Upper Township, New Jersey.
R&T Castellini, Inc., an inactive subsidiary, owns land and buildings in Vineland, New Jersey.
Item 3. Legal Proceedings
The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.0 million and$3.1 million related to all claims in the aggregate as of December 31, 2013 and 2012, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows.
Item 4. Mine Safety Disclosures
Not Applicable
South Jersey Industries, Inc.
Part I
Item 4A. Executive Officers of the Registrant
Set forth below are the names, ages and positions of our executive officers along with their business experience during the past five years. All executive officers of SJI are elected annually and serve at the discretion of the Board of Directors. All information is as of the date of the filing of this Report.
Name, age and position with the Company | Period Served | |
Edward J. Graham, Age 56 | ||
Chairman | April 2005 - Present | |
Chief Executive Officer | February 2004 - Present | |
President | January 2003 - January 2014 | |
Michael J. Renna, Age 46 | ||
Director | January 2014 - Present | |
President | January 2014 - Present | |
Chief Operating Officer | January 2014 - Present | |
Senior Vice President | January 2013 - January 2014 | |
Vice President | January 2004 - December 2012 | |
David A. Kindlick, Age 59 | ||
Executive Vice President | November 2013 - Present | |
Chief Financial Officer | January 2002 - November 2013 | |
Senior Vice President | January 2013 - November 2013 | |
Vice President | June 1997 - December 2012 | |
Jeffrey E. DuBois, Age 55 | ||
Senior Vice President | January 2013 - Present | |
Vice President | January 2004 - December 2012 | |
Stephen H. Clark, Age 55 | ||
Chief Financial Officer | November 2013 - Present | |
Vice President | January 2013 - November 2013 | |
Treasurer | January 2004 - Present | |
Kevin D. Patrick, Age 53 | ||
Vice President | June 2007 - Present | |
Gina M. Merritt-Epps, Age 46 | ||
General Counsel and Corporate Secretary | May 2009 - Present | |
Assistant General Counsel and Assistant Secretary | December 2007 - April 2009 | |
Kathleen A. McEndy, Age 60 | ||
Vice President | March 2013 - Present | |
Principal, The McEndy Group, LLC | January 2009 - March 2013 | |
Kenneth A. Lynch, Age 48 | ||
Chief Accounting Officer | January 2013 - Present | |
Assistant Vice President | July 2006 - December 2012 | |
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South Jersey Industries, Inc.
Part II
PART II
Item 5. Market for the Registrant's Common Equity,
Related Stockholder Matters and Issuer Purchases of Equity Securities
Market Price of Common Stock and Related Information
Quarter Ended | Market Price Per Share | Dividends | Quarter Ended | Market Price Per Share | Dividends | ||||||||||||||||
Declared | Declared | ||||||||||||||||||||
2013 | High | Low | Per Share | 2012 | High | Low | Per Share | ||||||||||||||
March 31 | $ | 56.21 | $ | 50.52 | $ | 0.4430 | March 31 | $ | 57.99 | $ | 49.55 | $ | 0.4025 | ||||||||
June 30 | $ | 61.78 | $ | 54.11 | $ | 0.4430 | June 30 | $ | 51.90 | $ | 46.52 | $ | 0.4025 | ||||||||
September 30 | $ | 62.28 | $ | 55.97 | $ | 0.4430 | September 30 | $ | 53.98 | $ | 50.50 | $ | 0.4025 | ||||||||
December 31 | $ | 61.18 | $ | 54.30 | $ | 0.4720 | December 31 | $ | 53.47 | $ | 45.81 | $ | 0.4425 | ||||||||
These quotations are based on the list of composite transactions of the New York Stock Exchange. Our stock is traded on the New York Stock Exchange under the symbol SJI. We have declared and expect to continue to declare regular quarterly cash dividends. As of December 31, 2013, the latest available date, our records indicate there were 6,924 shareholders of record.
Stock Performance Graph
The performance graph below illustrates a five year comparison of cumulative total returns based on an initial investment of $100 in South Jersey Industries, Inc. common stock, as compared with the S&P 500 Stock Index and the S&P Utility Index for the period 2008 through 2013.
This performance chart assumes:
• | $100 invested on December 31, 2008 in South Jersey Industries, Inc. common stock, in the S&P 500 Stock Index and in the S&P Utility Index; and |
• | All dividends are reinvested. |
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South Jersey Industries, Inc.
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Dec-08 | Dec-09 | Dec-10 | Dec-11 | Dec-12 | Dec-13 | |||||||||||||
S&P 500 | $ | 100 | $ | 126 | $ | 146 | $ | 149 | $ | 172 | $ | 228 | ||||||
S&P Utilities | $ | 100 | $ | 112 | $ | 118 | $ | 142 | $ | 143 | $ | 162 | ||||||
SJI | $ | 100 | $ | 99 | $ | 141 | $ | 156 | $ | 143 | $ | 164 | ||||||
Information required by this item is also found in Note 6 of the consolidated financial statements included under Item 8 of this Report.
SJI has a stated goal of increasing its dividend by at least 6% to 7% annually.
In 2013, non-employee members of SJI's Board of Directors received an aggregate of 12,285 shares of restricted stock, valued at that time at $635,626, as part of their compensation for serving on the Board.
Issuer Purchases of Equity Securities - There were no purchases by SJI of its own common stock during the year ended December 31, 2013.
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South Jersey Industries, Inc.
Part II
Item 6. Selected Financial Data
2013 HIGHLIGHTS
Five-Year Summary of Selected Financial Data
(In Thousands Where Applicable)
South Jersey Industries, Inc. and Subsidiaries
Year Ended December 31,
2013 | 2012 | 2011 | 2010 | 2009 | |||||||||||
Operating Results: | |||||||||||||||
Operating Revenues | $ | 731,421 | $ | 706,280 | $ | 828,560 | $ | 925,067 | $ | 845,444 | |||||
Operating Income | $ | 69,636 | $ | 109,898 | $ | 121,607 | $ | 116,492 | $ | 111,110 | |||||
Income from Continuing Operations | $ | 82,389 | $ | 92,776 | $ | 89,859 | $ | 67,285 | $ | 58,532 | |||||
Discontinued Operations - Net (1) | (796 | ) | (1,168 | ) | (568 | ) | (633 | ) | (427 | ) | |||||
Net Income | $ | 81,593 | $ | 91,608 | $ | 89,291 | $ | 66,652 | $ | 58,105 | |||||
Total Assets | $ | 2,924,855 | $ | 2,631,440 | $ | 2,247,510 | $ | 2,076,615 | $ | 1,782,008 | |||||
Capitalization: | |||||||||||||||
Equity | $ | 827,000 | $ | 736,214 | $ | 624,114 | $ | 570,097 | $ | 544,564 | |||||
Long-Term Debt | 680,400 | 601,400 | 424,213 | 340,000 | 312,793 | ||||||||||
Total Capitalization | $ | 1,507,400 | $ | 1,337,614 | $ | 1,048,327 | $ | 910,097 | $ | 857,357 | |||||
Ratio of Operating Income to Fixed Charges (2) | 3.0 | x | 5.1x | 5.4x | 5.3x | 5.9x | |||||||||
Diluted Earnings Per Common Share (Based on Average Diluted Shares Outstanding): | |||||||||||||||
Continuing Operations | $ | 2.57 | $ | 3.01 | $ | 2.99 | $ | 2.25 | $ | 1.96 | |||||
Discontinued Operations - Net (1) | (0.02 | ) | (0.04 | ) | (0.02 | ) | (0.03 | ) | (0.02 | ) | |||||
Diluted Earnings Per Common Share | $ | 2.55 | $ | 2.97 | $ | 2.97 | $ | 2.22 | $ | 1.94 | |||||
Return on Average Equity (3) | 10.5 | % | 13.6 | % | 15.0 | % | 12.1 | % | 11.0 | % | |||||
Share Data: | |||||||||||||||
Number of Shareholders of Record | 6.9 | 7.1 | 7.1 | 7.1 | 7.3 | ||||||||||
Average Common Shares | 31,989 | 30,744 | 30,000 | 29,861 | 29,785 | ||||||||||
Common Shares Outstanding at Year End | 32,715 | 31,653 | 30,212 | 29,873 | 29,796 | ||||||||||
Dividend Reinvestment Plan: | |||||||||||||||
Number of Shareholders | 5.2 | 4.8 | 4.4 | 4.9 | 5.1 | ||||||||||
Number of Participating Shares | 2,059 | 2,462 | 2,193 | 2,682 | 2,072 | ||||||||||
Book Value at Year End | $ | 25.28 | $ | 23.26 | $ | 20.66 | $ | 19.08 | $ | 18.28 | |||||
Dividends Declared per Common Share | $ | 1.80 | $ | 1.65 | $ | 1.50 | $ | 1.36 | $ | 1.22 | |||||
Market Price at Year End | $ | 55.96 | $ | 50.33 | $ | 56.81 | $ | 52.82 | $ | 38.18 | |||||
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Dividend Payout: | |||||||||||||||
From Continuing Operations | 69.9 | % | 54.7 | % | 50.1 | % | 60.1 | % | 62.2 | % | |||||
From Total Net Income | 70.6 | % | 55.4 | % | 50.4 | % | 60.7 | % | 62.7 | % | |||||
Market-to-Book Ratio | 2.2 | x | 2.2x | 2.7x | 2.8x | 2.1x | |||||||||
Price Earnings Ratio (3) | 21.8 | x | 16.7x | 19.0x | 23.4x | 19.5x | |||||||||
Consolidated Economic Earnings (4) | |||||||||||||||
Income from Continuing Operations | $ | 82,389 | $ | 92,776 | $ | 89,859 | $ | 67,285 | $ | 58,532 | |||||
Minus/Plus: | |||||||||||||||
Unrealized Mark-to-Market Losses/(Gains) on Derivatives and Realized (Gains)/Losses on Inventory Injection Hedges | 14,054 | (865 | ) | (2,876 | ) | 13,698 | 12,723 | ||||||||
Net (Gain)/Loss from Affiliated Companies, Not Part of Ongoing Operations (5) | 751 | — | — | — | — | ||||||||||
Unrealized Loss on Property, Plant and Equipment | — | 1,402 | — | — | — | ||||||||||
Other (6) | (100 | ) | — | — | — | — | |||||||||
Economic Earnings | $ | 97,094 | $ | 93,313 | $ | 86,983 | $ | 80,983 | $ | 71,255 | |||||
Earnings per Share from Continuing Operations | $ | 2.57 | $ | 3.01 | $ | 2.99 | $ | 2.25 | $ | 1.96 | |||||
Minus/Plus: | |||||||||||||||
Unrealized Mark-to-Market Losses/(Gains) on Derivatives and Realized (Gains)/Losses on Inventory Injection Hedges | 0.44 | (0.03 | ) | (0.10 | ) | 0.45 | 0.42 | ||||||||
Net (Gain)/Loss from Affiliated Companies, Not Part of Ongoing Operations (5) | 0.02 | — | — | — | — | ||||||||||
Unrealized Loss on Property, Plant and Equipment | — | 0.05 | — | — | — | ||||||||||
Economic Earnings per Share | $ | 3.03 | $ | 3.03 | $ | 2.89 | $ | 2.70 | $ | 2.38 | |||||
(1) | Represents discontinued business segments: sand mining and distribution operations sold in 1996 and fuel oil operations with related environmental liabilities in 1986 (See Note 3 to Consolidated Financial Statements). |
(2) | Calculated as Operating Income divided by Interest Charges. |
(3) | Calculated based on Income from Continuing Operations. |
(4) | This section includes the non-generally accepted accounting principles (“non-GAAP”) financial measures of Economic Earnings and Economic Earnings per share. See Management's Discussion and Analysis of Financial Condition and Results of Operations in Item 7 of this Report for a discussion regarding the use of non-GAAP financial measures. |
(5) | Resulting from the termination of the contract at LVE Energy Partners, LLC to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada. |
(6) | Represents additional depreciation expense within Economic Earnings on a solar generating facility. During 2012 an impairment charge was recorded within Income from Continuing Operations on a solar generating facility which reduced its depreciable basis and recurring depreciation expense. This impairment charge was excluded from Economic Earnings and therefore the related reduction in depreciation expense is being added back. |
15
South Jersey Industries, Inc.
Part II
Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations
OVERVIEW - South Jersey Industries, Inc. (SJI or the Company) is an energy services holding company that provides a variety of products and services through the following wholly owned subsidiaries:
South Jersey Gas Company (SJG)
SJG, a New Jersey corporation, is an operating public utility company engaged in the purchase, transmission and sale of natural gas for residential, commercial and industrial use. SJG also sells natural gas and pipeline transportation capacity (off-system sales) on a wholesale basis to various customers on the interstate pipeline system and transports natural gas purchased directly from producers or suppliers to their customers. SJG contributed approximately 76.3% of SJI's net income on a consolidated basis in 2013.
SJG's service territory covers approximately 2,500 square miles in the southern part of New Jersey. It includes 112 municipalities throughout Atlantic, Cape May, Cumberland and Salem Counties and portions of Burlington, Camden and Gloucester Counties, with an estimated permanent population of 1.2 million. SJG benefits from its proximity to Philadelphia, PA and Wilmington, DE on the western side of its service territory and Atlantic City, NJ and the popular shore communities on the eastern side. Continuing expansion of SJG's infrastructure throughout its seven-county region has fueled annual customer growth and creates opportunities for future extension into areas not yet served by natural gas. In the past, economic growth in Atlantic City and the surrounding region has been primarily driven by new and proposed gaming and non-gaming investments that emphasize destination style attractions. Combining with the gaming industry catalyst is the ongoing transition of southern New Jersey's oceanfront communities from seasonal resorts to year round economies. Building expansions in the medical, hospitality and education sectors throughout the service territory have contributed to SJG's growth. In 2013, SJG serves approximately 69% of households within its territory with natural gas. SJG also serves southern New Jersey's diversified industrial base that includes processors of petroleum and agricultural products; chemical, glass and consumer goods manufacturers; and high technology industrial parks.
As of December 31, 2013, SJG served 362,256 residential, commercial and industrial customers in southern New Jersey, compared with 357,306 customers at December 31, 2012. No material part of SJG's business is dependent upon a single customer or a few customers. Gas sales, transportation and capacity release for 2013 amounted to 111.7 MMdts (million dekatherms), of which 60.5 MMdts were firm sales and transportation, 1.5MMdts were interruptible sales and transportation and 49.7 MMdts were off-system sales and capacity release. The breakdown of firm sales and transportation includes 42.0% residential, 20.1% commercial, 22.1% industrial, and 15.8% cogeneration and electric generation. As of December 31, 2013, SJG served 337,936 residential customers, 23,873 commercial customers and 447 industrial customers. This includes 2013 net additions of 4,589 residential customers and 367 commercial customers.
SJG makes wholesale gas sales to gas marketers for resale and ultimate delivery to end users. These “off-system” sales are made possible through the issuance of the Federal Energy Regulatory Commission (FERC) Orders No. 547 and 636. Order No. 547 issued a blanket certificate of public convenience and necessity authorizing all parties, which are not interstate pipelines, to make FERC jurisdictional gas sales for resale at negotiated rates, while Order No. 636 allowed SJG to deliver gas at delivery points on the interstate pipeline system other than its own city gate stations and release excess pipeline capacity to third parties. During 2013, off-system sales amounted to 9.7 MMdts and capacity release amounted to 40.1 MMdts.
Supplies of natural gas available to SJG that are in excess of the quantity required by those customers who use gas as their sole source of fuel (firm customers) make possible the sale and transportation of gas on an interruptible basis to commercial and industrial customers whose equipment is capable of using natural gas or other fuels, such as fuel oil and propane. The term “interruptible” is used in the sense that deliveries of natural gas may be terminated by SJG at any time if this action is necessary to meet the needs of higher priority customers as described in SJG's tariffs. In 2013, usage by interruptible customers, excluding off-system customers, amounted to 1.5 MMdts, approximately 1.3% of the total throughput.
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South Jersey Industries, Inc.
Part II
South Jersey Energy Solutions, LLC
SJI established South Jersey Energy Solutions, LLC, (SJES) as a direct subsidiary for the purpose of serving as a holding company for all of SJI's non-utility businesses. The following businesses are wholly owned subsidiaries of SJES:
South Jersey Energy Company (SJE)
SJE provides services for the acquisition and transportation of natural gas and electricity for retail end users and markets total energy management services. As of December 31, 2013, SJE marketed natural gas and electricity to approximately 6,700 commercial and industrial customers. SJE is no longer active in the residential markets. Most customers served by SJE are located within New Jersey, northwestern Pennsylvania and New England. In 2013, SJE contributed approximately 1.0% of SJI's net income on a consolidated basis.
Marina Energy LLC (Marina)
Marina develops and operates energy-related projects. Marina's largest wholly owned operating project provides cooling, heating and emergency power to the Borgata Hotel Casino & Spa in Atlantic City, NJ. Marina also owns numerous solar generation projects, many of which came on line in 2012 and 2013. In March 2013, substantially all of the assets of Marina's joint venture, LVE Energy Partners, LLC (LVE), an entity in which Marina had a 50% equity interest, were sold, and as of December 31, 2013 LVE was dissolved (see Note 15 to the consolidated financial statements).
Marina's other projects include a 50% equity interest in Energenic-US, LLC (Energenic). Energenic develops, owns and operates on-site energy projects such as thermal facilities, combined heat and power facilities, landfill gas-fired electric production facilities and solar projects. In 2013, Marina contributed approximately 47.7% of SJI's net income on a consolidated basis.
South Jersey Resources Group, LLC (SJRG)
SJRG markets natural gas storage, commodity and transportation assets on a wholesale basis. Customers include energy marketers, electric and gas utilities, power plants and natural gas producers. SJRG's marketing activities occur mainly in the mid-Atlantic, Appalachian and southern regions of the country.
SJRG also conducts price risk management activities by entering into a variety of physical and financial transactions including forward contracts, swap agreements, option contracts and futures contracts. In 2013, SJRG transacted 642.5 Bcf of natural gas. In 2013, SJRG incurred a loss which was approximately (27.4%) of SJI's net income on a consolidated basis.
South Jersey Energy Service Plus, LLC (SJESP)
SJESP services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. SJESP serves southern New Jersey where it is one of the largest local HVAC service company's with nearly 30 experienced, NATE certified technicians. SJESP receives a commission on all new and renewed service contracts and is paid a fee to service those warranty contracts. In 2013, SJESP contributed approximately 2.3% of SJI's net income on a consolidated basis.
South Jersey Exploration, LLC (SJEX)
SJEX owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania. SJEX was a wholly owned subsidiary of SJRG until November 2011, when it became a wholly owned subsidiary of SJES. SJEX remains part of SJI's wholesale energy operations. In 2013, SJEX contributed approximately 1.0% of SJI's net income on a consolidated basis.
Other
SJI Services, LLC (SJIS) provides services such as information technology, human resources, corporate communications, materials purchasing and fleet management to SJI and its other subsidiaries. As of January 1, 2014, the functions of SJIS have been moved to SJI.
Energy & Minerals, Inc. (EMI) principally manages liabilities associated with its discontinued operations of nonutility subsidiaries.
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South Jersey Industries, Inc.
Part II
Primary Factors Affecting SJI's Business
SJI's stated long-term goals are to: 1) Grow Economic Earnings per share by an average of at least 6% to 7% per year; 2) Increase the dividend on common stock by at least 6% to 7% annually; and 3) Maintain a low-to-moderate risk platform. Management established those goals in conjunction with SJI's Board of Directors based upon a number of different internal and external factors that characterize and influence SJI's current and expected future activities.
The following is a summary of the primary factors we expect to have the greatest impact on SJI's performance and ability to achieve long-term goals going forward:
Business Model - In developing SJI's current business model, our focus has been on our core utility and natural extensions of that business. That focus enables us to concentrate on business activities that match our core competencies. Going forward we expect to pursue business opportunities that fit this model.
Customer Growth - Southern New Jersey, our primary area of operations, has not been immune to the issues impacting the new housing market nationally. However, net customers for SJG still grew 1.4% for 2013 as SJG increased its focus on customer conversions. In 2013, the 5,165 consumers converting their homes and businesses from other heating fuels, such as electric, propane or oil represented over 69.0% of the total new customer acquisitions for the year. In comparison, conversions over the past five years averaged 4,142 annually. Customers in our service territory typically base their decisions to convert on comparisons of fuel costs, environmental considerations and efficiencies. As such, SJG began a comprehensive partnership with the State's Office of Clean Energy to educate consumers on energy efficiency and to promote the rebates and incentives available to natural gas users.
Regulatory Environment - SJG is primarily regulated by the New Jersey Board of Public Utilities (BPU). The BPU sets the rates that SJG charges its rate-regulated customers for services provided and establishes the terms of service under which SJG operates. SJG expects the BPU to continue to set rates and establish terms of service that will enable SJG to obtain a fair and reasonable return on capital invested. The BPU approved a Conservation Incentive Program (CIP) effective October 1, 2006, discussed in greater detail under "Results of Operations", that protects SJG's net income from reductions in gas used by residential, commercial and small industrial customers. In addition, in February 2013, the BPU issued a Board Order approving the Accelerated Infrastructure Replacement Program (AIRP), a $141.2 million program to replace cast iron and unprotected bare steel mains and services over a four-year period, with annual investments of approximately $35.3 million. SJG earns a return on AIRP investments until they are included in rate base in future base rate proceedings.
Weather Conditions and Customer Usage Patterns - Usage patterns can be affected by a number of factors, such as wind, precipitation, temperature extremes and customer conservation. SJG's earnings are largely protected from fluctuations in temperatures by the CIP. The CIP has a stabilizing effect on utility earnings as SJG adjusts revenues when actual usage per customer experienced during an annual period varies from an established baseline usage per customer. Our nonutility retail marketing business is directly affected by weather conditions, as it does not have regulatory mechanisms that address weather volatility. The impact of different weather conditions on the earnings of our nonutility businesses is dependent on a range of different factors. Consequently, weather may impact the earnings of SJI's various subsidiaries in different, or even opposite, ways. Further, the profitability of individual subsidiaries may vary from year-to-year despite experiencing substantially similar weather conditions.
Changes in Natural Gas and Electricity Prices - The utility's gas costs are passed on directly to customers without any profit margin added by SJG. The price the utility charges its periodic customers is set annually, with a regulatory mechanism in place to make limited adjustments to that price during the course of a year. In the event that gas cost increases would justify customer price increases greater than those permitted under the regulatory mechanism, SJG can petition the BPU for an incremental rate increase. High prices can make it more difficult for SJG's customers to pay their bills and may result in elevated levels of bad-debt expense. Among our nonutility activities, the one most likely to be impacted by changes in natural gas prices is our wholesale gas marketing business. Wholesale gas marketing typically benefits from volatility in gas prices during different points in time. The actual price of the commodity does not typically have an impact on the performance of this business line. Our ability to add and retain customers at our retail marketing business is affected by the relationship between the price that the utility charges customers for gas or electric and the cost available in the market at specific points in time. However, retail marketing accounts for a very small portion of SJI's overall activities.
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South Jersey Industries, Inc.
Part II
Energy Project Development - Marina Energy, LLC, SJI's energy project development business, focuses on designing, building, owning and/or operating energy production facilities on, or adjacent to, customer sites. That business is currently involved with several projects that are either operating, or are under development. Based upon our experience to date, market issues that impact the reliability and price of electricity supplied by utilities, and discussions that we are having regarding additional projects, we expect to continue to expand this business. However, the price of natural gas, as well as the availability of various tax incentives and rebates, has a direct effect on the economics of these projects. While Marina's largest project opportunities have been in the casino gaming industry, prospects for future growth exist within urban district energy systems, medical and educational campuses.
Changes in Interest Rates - SJI has operated in a relatively low interest rate environment over the past several years. Rising interest rates would raise the expense associated with existing variable-rate debt and all issuances of new debt. We have sought to mitigate the impact of a potential rising rate environment by directly issuing fixed-rate debt, or by entering into derivative transactions to hedge against rising interest rates.
Labor and Benefit Costs - Labor and benefit costs have a significant impact on SJI's profitability. Benefit costs, especially those related to pension and health care, have risen in recent years. We sought to manage these costs by revising health care plans offered to existing employees, capping postretirement health care benefits, and changing health care and pension packages offered to new hires. We expect savings from these changes to gradually increase as new hires replace retiring employees. Our workforce totaled approximately 700 employees at the end of 2013, of which approximately 320 are unionized.
Balance Sheet Strength - Our goal is to maintain a strong balance sheet with an average annual equity-to-capitalization ratio of 50%. Our average equity-to-capitalization ratio was 45% as calculated for the four quarters of 2013 as compared with 44% in 2012. A strong balance sheet permits us to maintain the financial flexibility necessary to take advantage of growth opportunities and to address volatile economic and commodity markets while maintaining a low-to-moderate risk platform.
CRITICAL ACCOUNTING POLICIES - ESTIMATES AND ASSUMPTIONS - As described in the notes to our consolidated financial statements, management must make estimates and assumptions that affect the amounts reported in the consolidated financial statements and related disclosures. Actual results could differ from those estimates. Five types of transactions presented in our consolidated financial statements require a significant amount of judgment and estimation. These relate to regulatory accounting, derivatives, environmental remediation costs, pension and other postretirement benefit costs, and revenue recognition.
Regulatory Accounting - SJI's largest subsidiary, SJG, maintains its accounts according to the Uniform System of Accounts as prescribed by the BPU. As a result of the ratemaking process, SJG is required to follow Financial Accounting Standards Board (FASB) ASC Topic 980 - “Regulated Operations.” SJG is required under Topic 980 to recognize the impact of regulatory decisions on its financial statements. SJG is required under its Basic Gas Supply Service (BGSS) clause to forecast its natural gas costs and customer consumption in setting its rates. Subject to BPU approval, SJG is able to recover or return the difference between gas cost recoveries and the actual costs of gas through a BGSS charge to customers. SJG records any over/under recoveries as a regulatory asset or liability on the consolidated balance sheets and reflects them in the BGSS charge to customers in subsequent years. SJG also enters into derivatives that are used to hedge natural gas purchases. The offset to the resulting derivative assets or liabilities is also recorded as a regulatory asset or liability on the consolidated balance sheets. See additional detailed discussions on Rates and Regulatory Actions in Note 10 to the consolidated financial statements.
Derivatives - SJI recognizes assets or liabilities for contracts that qualify as derivatives that are entered into by its subsidiaries when contracts are executed. We record contracts at their fair value in accordance with FASB ASC Topic 815 - “Derivatives and Hedging.” We record changes in the fair value of the effective portion of derivatives qualifying as cash flow hedges, net of tax, in Accumulated Other Comprehensive Loss and recognize such changes in the income statement when the hedged item affects earnings. Changes in the fair value of derivatives not designated as hedges are recorded in earnings in the current period. Currently we do not have any energy-related derivative instruments designated as cash flow hedges. Beginning in July 2012, hedge accounting was discontinued for the remaining interest rate derivatives. As a result, unrealized gains and losses on these derivatives, that were previously recorded in Accumulated Other Comprehensive Loss on the consolidated balance sheets, are being reclassified into earnings over the remaining life of the originally hedged items. These derivatives will mature in 2026.
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Certain derivatives that result in the physical delivery of the commodity may meet the criteria to be accounted for as normal purchases and normal sales, if so designated, in which case the contract is not marked-to-market, but rather is accounted for when the commodity is delivered. Due to the application of regulatory accounting principles generally accepted in the United States of America (GAAP), derivatives related to SJG's gas purchases that are marked-to-market are recorded through the BGSS. SJG periodically enters into financial derivatives to hedge against forward price risk. These derivatives are recorded at fair value with an offset to regulatory assets and liabilities through SJG's BGSS, subject to BPU approval (See Notes 10 and 11 to the consolidated financial statements).
We adjust the fair value of the contracts each reporting period for changes in the market. As discussed in Notes 16 and 17 of the consolidated financial statements, energy-related derivative instruments are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy established by FASB ASC Topic 820 - “Fair Value Measurements and Disclosures.” Certain non-exchange-based contracts are valued using indicative non-binding price quotations available through brokers or from over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. Management reviews and corroborates the price quotations with at least one additional source to ensure the prices are observable market information, which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration. Derivative instruments that are used to limit our exposure to changes in interest rates on variable-rate, long-term debt are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment, as a result, these instruments are categorized in Level 2 in the fair value hierarchy. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 in the fair value hierarchy as the model inputs generally are not observable. Counterparty credit risk and the credit risk of SJI, are incorporated and considered in the valuation of all derivative instruments as appropriate. The effect of counterparty credit risk and the credit risk of SJI on the derivative valuations is not significant.
Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forwards, which calculates fair values based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the fair values and changes in these values from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the fair values or the market pricing information is evaluated further and adjusted, if necessary.
Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electrical load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
Environmental Remediation Costs -We estimate a range of future costs based on projected investigation and work plans using existing technologies. In preparing consolidated financial statements, SJI records liabilities for future costs using the lower end of the range because a single reliable estimation point is not feasible due to the amount of uncertainty involved in the nature of projected remediation efforts and the long period over which remediation efforts will continue. We update estimates each year to take into account past efforts, changes in work plans, remediation technologies, government regulations and site specific requirements (See Note 15 to the consolidated financial statements).
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Pension and Other Postretirement Benefit Costs - The costs of providing pension and other postretirement employee benefits are impacted by actual plan experience as well as assumptions of future experience. Employee demographics, plan contributions, investment performance, and assumptions concerning mortality, return on plan assets, discount rates and health care cost trends all have a significant impact on determining our projected benefit obligations. We evaluate these assumptions annually and adjust them accordingly. These adjustments could result in significant changes to the net periodic benefit costs of providing such benefits and the related liabilities recognized by SJI.
The combination of slowing equity markets and lower discount rates in 2011, which were used in determining plan costs in 2012, increased the cost of providing such plans in 2012. SJI took measures to manage this increase by making a $25.0 million pension plan contribution in January 2012; as such, the resulting financial impact on the company was not significant. Discount rates continued to decline in 2012 and are the primary cost driver used in determining plan costs in 2013. However, improvements in the equity markets during 2012 and a $12.7 million pension plan contribution in January 2013, significantly offset the negative impact of declining discount rates. As such, the resulting financial impact on the Company was not significant in 2013. During 2013, discount rates increased and equity markets continued to outperform management's expectations. As a result, the Company currently expects a $4.1 million decrease in the cost of providing such benefits in 2014.
Additional information regarding investment returns and assumptions can be found in Pension and Other Postretirement Benefits in Note 12 to the consolidated financial statements.
Revenue Recognition - Gas and electricity revenues are recognized in the period the commodity is delivered to customers. SJG, SJRG and SJE bill customers monthly. A majority of SJG and SJE customers have their meters read on a cycle basis throughout the month. For SJG and SJE retail customers that are not billed at the end of each month, we record an estimate to recognize unbilled revenues for gas/electricity delivered from the date of the last meter reading to the end of the month. SJG's and SJE's unbilled revenue for natural gas is estimated each month based on monthly deliveries into the system; unaccounted for natural gas based on historical results; customer-specific use factors, when available; actual temperatures during the period; and applicable customer rates. SJE's unbilled revenue for retail electricity is based on customer-specific use factors and applicable customer rates. We bill SJG customers at rates approved by the BPU. SJE and SJRG customers are billed at rates negotiated between the parties.
We recognize revenues related to SJESP's appliance service contracts on a monthly basis as work is completed or commissions are earned. Revenues related to services provided on a time and materials basis are recognized on a monthly basis as the services are provided.
Marina recognizes revenue on a monthly basis as services are provided and for on-site energy production that is delivered to its customers.
The BPU allows SJG to recover gas costs in rates through the BGSS price structure. SJG defers over/under recoveries of gas costs and includes them in subsequent adjustments to the BGSS rate. These adjustments result in over/under recoveries of gas costs being included in rates during future periods. As a result of these deferrals, utility revenue recognition does not directly translate to profitability. While SJG realizes profits on gas sales during the month of providing the utility service, significant shifts in revenue recognition may result from the various recovery clauses approved by the BPU. This revenue recognition process does not shift earnings between periods, as these clauses only provide for cost recovery on a dollar-for-dollar basis (See Notes 10 and 11 to the consolidated financial statements).
In January 2010, the BPU approved an extension of the CIP through September 2013, with an automatic one year extension through September 2014 if a request for an extension was filed by March 2013. A petition was filed in March 2013 to extend the Conservation Incentive Program (CIP). The CIP may be extended for a one year period in the absence of a Board order taking any affirmative action to the contrary. Each CIP year begins October 1 and ends September 30 of the subsequent year. On a monthly basis during the CIP year, SJG records adjustments to earnings based on weather and customer usage factors, as incurred. Subsequent to each year, SJG makes filings with the BPU to review and approve amounts recorded under the CIP. BPU approved cash inflows or outflows generally will not begin until the next CIP year and have no impact on earnings at that time.
NEW ACCOUNTING PRONOUNCEMENTS - See detailed discussions concerning New Accounting Pronouncements and their impact on SJI in Note 1 to the consolidated financial statements.
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RATES AND REGULATION - As a public utility, SJG is subject to regulation by the BPU. Additionally, the Natural Gas Policy Act, which was enacted in November 1978, contains provisions for Federal regulation of certain aspects of SJG's business. SJG is affected by Federal regulation with respect to transportation and pricing policies applicable to pipeline capacity from Transcontinental Gas Pipeline Corporation (SJG's major supplier), Columbia Gas Transmission Corporation and Dominion Transmission, Inc., since such services are provided under rates and terms established under the jurisdiction of the FERC. SJG's retail sales are made under rate schedules within a tariff filed with, and subject to the jurisdiction of, the BPU. These rate schedules provide primarily for either block rates or demand/commodity rate structures. SJG's primary rate mechanisms include base rates, the Basic Gas Supply Service Clause (BGSS) Capital Investment Recovery Tracker (CIRT), Energy Efficiency Tracker (EET) and the Conservation Incentive Program (CIP).
In September 2010, the BPU granted SJG a base rate increase of $42.1 million, which was predicated in part upon an 8.21% rate of return on rate base that included a 10.3% return on common equity. The $42.1 million includes $16.6 million of revenue previously recovered through the CIP and $6.8 million of revenues previously recovered through the CIRT, resulting in incremental revenue of $18.7 million. SJG was permitted to recover regulatory assets contained in its petition and is allowed to defer certain federally mandated pipeline integrity management program costs for recovery in its next base rate case. In addition, annual depreciation expense will be reduced by $1.2 million as a result of the amortization of excess cost of removal recoveries. The BPU also authorized a Phase II of the base rate proceeding to address the recovery of investment in CIRT not rolled into rate base in this case.
In November 2013, SJG filed a base rate case with the BPU to increase their base rates to obtain a certain level of return on their capital investments. SJG expects the base rate case to be concluded during 2014.
In April 2009, the BPU approved the CIRT, an accelerated infrastructure investment program and an associated rate tracker, which allowed SJG to accelerate $103.0 million of capital spending into 2009 and 2010. The BPU authorized Phase II of its rate case proceeding to address the recovery of investments in CIRT not rolled into rate base in its September 2010 rate case settlement. The CIRT allows SJG to earn a return of, and return on, investment as the capital is spent. In March 2011, the BPU approved an extension of the Capital Investment Recovery Tracker II (CIRT II) allowing SJG to accelerate $60.3 million of capital spending into 2011 and 2012. In May 2012, the BPU approved a modification and extension of CIRT II and CIRT III allowing SJG to accelerate an incremental $35.0 million of capital spending through December 2012. Under CIRT II and CIRT III, SJG capitalizes a return on investments until they are recovered in rate base as utility plant in service. A proceeding took place in 2013 to roll into base rates the remaining $22.5 million of CIRT I project costs that were not included in the 2010 proceeding, as well as CIRT II and III investments totaling $95.0 million that were made subsequent to the 2010 base rate case. These costs were rolled into rate base and reflected in base rates effective October 2013.
The CIP is a BPU approved pilot program that is designed to eliminate the link between SJG profits and the quantity of natural gas SJG sells, and to foster conservation efforts. With the CIP, SJG's profits are tied to the number of customers served and how efficiently SJG serves them, thus allowing SJG to focus on encouraging conservation and energy efficiency among its customers without negatively impacting net income. The CIP tracking mechanism adjusts earnings based on weather, and also adjusts SJG's earnings when actual usage per customer experienced during an annual period varies from an established baseline usage per customer. In January 2010, the BPU approved an extension of the CIP through September 2013, with an automatic one year extension through September 2014 if a request for an extension was filed by March 2013. A petition was filed in March 2013 to extend the CIP program.
Utility earnings are recognized during current periods based upon the application of the CIP. The cash impact of variations in customer usage will result in cash being collected from, or returned to, customers during the subsequent CIP year, which runs from October 1 to September 30.
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The effects of the CIP on SJG's net income for the last three years and the associated weather comparisons were as follows ($'s in millions):
2013 | 2012 | 2011 | |||||||
Net Income Benefit: | |||||||||
CIP - Weather Related | $ | (0.3 | ) | $ | 9.4 | $ | 5.6 | ||
CIP - Usage Related | 3.4 | 5.8 | 2.2 | ||||||
Total Net Income Benefit | $ | 3.1 | $ | 15.2 | $ | 7.8 | |||
Weather Compared to 20-Year Average | 0.6% colder | 17.7% warmer | 10.0% warmer | ||||||
Weather Compared to Prior Year | 20.6% colder | 8.6% warmer | 7.8% warmer | ||||||
As part of the CIP, SJG is required to implement additional conservation programs, including customized customer communication and outreach efforts, targeted upgrade furnace efficiency packages, financing offers, and an outreach program to speak to local and state institutional constituents. SJG is also required to reduce gas supply and storage assets and their associated fees. Note that changes in fees associated with supply and storage assets have no effect on SJG's net income as these costs are passed through directly to customers on a dollar-for-dollar basis.
Earnings accrued and payments received under the CIP are limited to a level that will not cause SJG's return on equity to exceed 10.3% (excluding earnings from off-system gas sales and certain other tariff clauses) and the annualized savings attained from reducing gas supply and storage assets.
See additional detailed discussions on Rates and Regulatory Actions in Note 10 to the consolidated financial statements.
ENVIRONMENTAL REMEDIATION - See detailed discussion concerning Environmental Remediation in Note 15 to the consolidated financial statements.
COMPETITION - SJG's franchises are non-exclusive. Currently, no other utility provides retail gas distribution services within SJG's territory. SJG does not expect any other utilities to do so in the foreseeable future because of the extensive investment required for utility plant and related costs. SJG competes with oil, propane and electricity suppliers for residential, commercial and industrial users, with alternative fuel source providers (wind, solar and fuel cells) based upon price, convenience and environmental factors, and with other marketers/brokers in the selling of wholesale natural gas services. The market for natural gas commodity sales is subject to competition due to deregulation. SJG's competitive position was enhanced while maintaining margins by using an unbundled tariff. This tariff allows full cost-of-service recovery when transporting gas for SJG's customers. Under this tariff, SJG profits from transporting, rather than selling, the commodity. SJG's residential, commercial and industrial customers can choose their supplier, while SJG recovers the cost of service through transportation service (See Customer Choice Legislation below).
SJRG competes in the wholesale natural gas market against a wide array of competitors on a cost competitive, term of service, and reliability basis. SJRG has been a reliable energy provider in this arena for 18 years.
Marina competes with other companies that develop and operate on-site energy production. Marina also faces competition from customers' preferences for alternative technologies for energy production, as well as those customers that address their energy needs internally.
SJE competes with utilities and other third-party marketers to sell the unregulated natural gas and electricity commodity to customers. Marketers compete largely on price, which is driven by the commodity market. While the utilities are typically indifferent as to where customers get their gas or electricity, the price they set for the commodity they sell creates competition for SJE. Based on its market share, SJE is one of the largest marketers of natural gas in southern New Jersey as of December 31, 2013. In addition, similar to SJG, SJE faces competition from other energy products.
SJESP competes primarily with smaller, local contractors in southern New Jersey that service residential and commercial HVAC systems and provide major appliance repair and plumbing services. These contractors typically only serve their local communities and do not serve the entire southern part of New Jersey.
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CUSTOMER CHOICE LEGISLATION - All residential natural gas customers in New Jersey can choose their natural gas commodity supplier under the terms of the “Electric Discount and Energy Competition Act of 1999." This bill created the framework and necessary time schedules for the restructuring of the state's electric and natural gas utilities. The Act established unbundling, where redesigned utility rate structures allow natural gas and electric consumers to choose their energy supplier. It also established time frames for instituting competitive services for customer account functions and for determining whether basic gas supply services should become competitive. Customers purchasing natural gas from a provider other than the local utility (the “marketer”) are charged for the gas costs by the marketer and charged for the transportation costs by the utility. The total number of customers in SJG's service territory purchasing natural gas from a marketer averaged 46,872, 39,398, and 37,829 during 2013, 2012 and 2011, respectively.
RESULTS OF OPERATIONS:
SJI operates in several different reportable operating segments. Gas Utility Operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers. Wholesale Energy Operations include the activities of SJRG and SJEX. SJE is involved in both retail gas and retail electric activities. Retail Gas and Other Operations include natural gas acquisition and transportation service business lines. Retail Electric Operations consist of electricity acquisition and transportation to commercial and industrial customers. On-Site Energy Production consists of Marina's thermal energy facility and other energy-related projects. Appliance Service Operations includes SJESP's servicing of appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. The Retail Energy Operations caption includes Retail Gas and Other, Retail Electric, On-Site Energy Production and Appliance Service Operations.
Net Income attributable to SJI for 2013 decreased $10.0 million, or 10.9%, to $81.6 million compared to 2012 primarily as a result of the following:
• | The income contribution from SJRG decreased $21.0 million to a net loss of $22.3 million due primarily to an approximately $12.1 million decrease due to lower daily trading margins as described in Gross Margin - Nonutility below, along with an approximately $8.9 million change in unrealized gains and losses on derivatives used by SJRG to mitigate natural gas commodity price risk, as discussed under Operating Revenues - Nonutility below. |
• | The income contribution from SJE decreased $6.7 million to $0.7 million due primarily to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on electric as discussed under Operating Revenues – Nonutility below. |
• | The income contribution from Marina increased $11.3 million to $38.9 million due primarily to the impact of the investment tax credits available on renewable energy facilities as compared to the prior year. |
• | The income contribution from SJG increased $4.0 million to $62.2 million due primarily to increases in the accelerated infrastructure programs and customer growth over the prior year. |
Net Income attributable to SJI for 2012 increased $2.3 million, or 2.6%, to $91.6 million compared to 2011 primarily as a result of the following:
• | The income contribution from Marina increased $6.0 million to $27.6 million due primarily to the impact of the investment tax credits available on renewable energy facilities as compared to the prior year. |
• | The income contribution from SJE increased $5.5 million to $7.4 million due primarily to the change in unrealized gains and losses on forward financial contracts used to mitigate electric price risk as discussed in Operating Revenues - Nonutility below, partially offset by the expiration of a significant electric sales contract with a group of school boards. |
• | The income contribution from SJG increased $5.4 million to $58.2 million due primarily to an increase in CIRT-related earnings along with an increase in residential customers. |
• | The income contribution from SJRG decreased $11.3 million to a net loss of $1.3 million due primarily to the change in unrealized gains and losses on derivatives used by SJRG to mitigate natural gas commodity price risk, as discussed below. |
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• | The income contribution from SJESP decreased $2.3 million to a net loss of less than $0.1 million due primarily to proceeds received in 2011 from a provider of homeowner assistance services in accordance with an agreement with the Company that gives them the exclusive right to renew the home appliance repair contracts at SJESP. |
A significant portion of the volatility in operating results is due to the impact of the accounting methods associated with SJI's derivative activities. The Company uses derivatives to limit its exposure to market risk on transactions to buy, sell, transport and store natural gas and to buy and sell retail electricity. The Company also uses derivatives to limit its exposure to increasing interest rates on variable-rate debt.
The types of transactions that cause the most significant volatility in operating results are as follows:
• | SJRG purchases and holds natural gas in storage to earn a profit margin from its ultimate sale in the future. SJRG uses derivatives to mitigate commodity price risk in order to substantially lock-in the profit margin that will ultimately be realized. However, gas stored in inventory is accounted for at the lower of average cost or market; the derivatives used to reduce the risk associated with a change in the value of the inventory are accounted for at fair value, with changes in fair value recorded in operating results in the period of change. As a result, earnings are subject to volatility as the market price of derivatives change, even when the underlying hedged value of the inventory is unchanged. Additionally, volatility in earnings is created when realized gains and losses on derivatives used to mitigate commodity price risk on expected future purchases of gas injected into storage are recognized in earnings when the derivatives settle, but the cost of the related gas in storage is not recognized in earnings until the period of withdrawal. This volatility can be significant from period to period. Over time, gains or losses on the sale of gas in storage will be offset by losses or gains on the derivatives, resulting in the realization of the profit margin expected when the transactions were initiated. |
• | SJE uses forward contracts to mitigate commodity price risk on fixed price electric contracts with customers. In accordance with GAAP, the forward contracts are recorded at fair value, with changes in fair value recorded in earnings in the period of change. Several related customer contracts are not considered derivatives and therefore are not recorded in earnings until the electricity is delivered. As a result, earnings are subject to volatility as the market price of the forward contracts change, even when the underlying hedged value of the customer contract is unchanged. Over time, gains or losses on the sale of the fixed price electric under contract will be offset by losses or gains on the forward contracts, resulting in the realization of the profit margin expected when the transactions were initiated. |
As a result, management also uses the non-generally accepted accounting principles (“non-GAAP”) financial measures of Economic Earnings and Economic Earnings per share when evaluating the results of operations for its nonutility operations. These non-GAAP financial measures should not be considered as an alternative to GAAP measures, such as net income, operating income, earnings per share from continuing operations or any other GAAP measure of liquidity or financial performance.
We define Economic Earnings as: Income from continuing operations, (1) less the change in unrealized gains and plus the change in unrealized losses, as applicable and in each case after tax, on all derivative transactions, and (2) less realized gains and plus realized losses, as applicable and in each case after tax, on all commodity derivative transactions attributed to expected purchases of gas in storage to match the recognition of these gains and losses with the recognition of the related cost of the gas in storage in the period of withdrawal, and (3) less the impact of transactions or contractual arrangements where the true economic impact will be realized in a future period. With respect to the third part of the definition of Economic Earnings, for the twelve months ended December 31, 2013:
• | Economic Earnings excludes a $0.8 million loss (net of tax), respectively, from affiliated companies, not part of ongoing operations. This adjustment is the result of the termination of the contract at LVE Energy Partners, LLC (see Note 15 to the consolidated financial statements) and is being excluded because all of the assets of LVE have been sold and LVE is no longer considered part of the ongoing operations of the Company. |
• | Economic Earnings includes additional depreciation expense on a solar generating facility. During 2012 an impairment charge was recorded within Income from Continuing Operations on a solar generating facility which reduced its depreciable basis and recurring depreciation expense. This impairment charge was excluded from Economic Earnings and therefore the related reduction in depreciation expense is being added back. |
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With respect to the third part of the definition of Economic Earnings, for the twelve months ended December 31, 2012:
• | Economic Earnings excludes a $1.4 million impairment charge due to a reduction in the expected cash flows to be received from a solar generating facility, net of tax, determined using a statutory tax rate of 41% (see Note 1 to the consolidated financial statements). |
Economic Earnings is a significant performance metric used by our management to indicate the amount and timing of income from continuing operations that we expect to earn after taking into account the impact of derivative instruments on the related transactions and transactions or contractual arrangements where the true economic impact will be realized in a future period. Specifically, we believe that this financial measure indicates to investors the profitability of the entire derivative related transaction and not just the portion that is subject to mark-to-market valuation under GAAP. Considering only the change in market value on the derivative side of the transaction can produce a false sense as to the ultimate profitability of the total transaction as no change in value is reflected for the non-derivative portion of the transaction.
Economic Earnings for 2013 increased $3.8 million, or 4.1%, to $97.1 million compared to 2012 primarily as a result of the following:
• | The income contribution from Marina increased $10.2 million to $38.3 million due primarily to the impact of the investment tax credits available on renewable energy facilities as compared to the prior year. |
• | The income contribution from SJG increased $4.0 million to $62.2 million due primarily to increases in the accelerated infrastructure programs and customer growth over the prior year. |
• | The income contribution from SJRG decreased $12.1 million to a net loss of $7.5 million due primarily to lower daily trading margins as described in Gross Margin - Nonutility below. |
Economic Earnings for 2012 increased $6.3 million, or 7.3%, to $93.3 million compared to 2011 primarily as a result of the following:
• | The income contribution from Marina increased $6.1 million to $28.1 million due primarily to the impact of the investment tax credits available on renewable energy facilities as compared to the prior year. |
• | The income contribution from SJG increased $5.4 million to $58.2 million due primarily to an increase in CIRT-related earnings along with an increase in residential customers. |
• | The income contribution from SJESP decreased $2.3 million to a net loss of less than $0.1 million due primarily to proceeds received in 2011 from a provider of homeowner assistance services in accordance with an agreement with the Company that gives them the exclusive right to renew the home appliance repair contracts at SJESP. |
• | The income contribution from SJE decreased $2.2 million to $1.6 million due primarily to the expiration of a significant electric sales contract with a group of school boards. |
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The following table presents a reconciliation of our income from continuing operations and earnings per share from continuing operations to Economic Earnings and Economic Earnings per share (in thousands except per share data):
2013 | 2012 | 2011 | |||||||
Income from Continuing Operations | $ | 82,389 | $ | 92,776 | $ | 89,859 | |||
Minus/Plus: | |||||||||
Unrealized Mark-to-Market Losses/(Gains) on Derivatives | 14,058 | (854 | ) | (2,815 | ) | ||||
Realized (Gains)/Losses on Inventory Injection Hedges | (4 | ) | (11 | ) | (61 | ) | |||
Net (Gain) Loss from Affiliated Companies, Not Part of Ongoing Operations (A) | 751 | — | — | ||||||
Unrealized Loss on Property, Plant and Equipment | — | 1,402 | — | ||||||
Other (B) | (100 | ) | — | — | |||||
Economic Earnings | $ | 97,094 | $ | 93,313 | $ | 86,983 | |||
Earnings per Share from Continuing Operations | $ | 2.57 | $ | 3.01 | $ | 2.99 | |||
Minus/Plus: | |||||||||
Unrealized Mark-to-Market Losses/(Gains) on Derivatives | 0.44 | (0.03 | ) | (0.10 | ) | ||||
Net (Gain) Loss from Affiliated Companies, Not Part of Ongoing Operations (A) | 0.02 | — | — | ||||||
Unrealized Loss on Property, Plant and Equipment | — | 0.05 | — | ||||||
Economic Earnings per Share | $ | 3.03 | $ | 3.03 | $ | 2.89 | |||
The effect of derivative instruments not designated as hedging instruments under GAAP in the consolidated statements of income (see Note 16 to the consolidated financial statements) is as follows (gains (losses) in thousands):
2013 | 2012 | 2011 | |||||||||
(Losses) gains on energy related commodity contracts | $ | (25,823 | ) | $ | (193 | ) | $ | 5,377 | |||
Gains (losses) on interest rate contracts | 2,760 | 660 | (149 | ) | |||||||
Total before income taxes | (23,063 | ) | 467 | 5,228 | |||||||
Income taxes (C) | 9,455 | (191 | ) | (2,143 | ) | ||||||
Total after income taxes | (13,608 | ) | 276 | 3,085 | |||||||
Unrealized mark-to-market (losses) gains on derivatives held by affiliated companies, net of tax (C) | (450 | ) | 578 | (270 | ) | ||||||
Total unrealized mark-to-market (losses) gains on derivatives | (14,058 | ) | 854 | 2,815 | |||||||
Realized gains on inventory injection hedges, net of tax (C) | 4 | 11 | 61 | ||||||||
Net Loss from Affiliated Companies, Not Part of Ongoing Operations (A) | (751 | ) | — | — | |||||||
Unrealized Loss on Property, Plant and Equipment | — | (1,402 | ) | — | |||||||
Other (B) | 100 | — | — | ||||||||
Total reconciling items between income from continuing operations and economic earnings | $ | (14,705 | ) | $ | (537 | ) | $ | 2,876 | |||
(A) Resulting from the termination of the contract at LVE Energy Partners, LLC to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada.
(B) Represents additional depreciation expense within Economic Earnings on a solar generating facility. During 2012 an impairment charge was recorded within Income from Continuing Operations on a solar generating facility which reduced its depreciable basis and recurring depreciation expense. This impairment charge was excluded from Economic Earnings and therefore the related reduction in depreciation expense is being added back.
(C) Determined using a combined statutory tax rate of 41%.
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Throughput-Utility - The following table summarizes the composition of select gas utility data for the three years ended December 31 (in thousands, except for customer and degree day data):
December 31, 2013 | December 31, 2012 | December 31, 2011 | ||||||||||||||||||
Utility Throughput - dth: | ||||||||||||||||||||
Firm Sales - | ||||||||||||||||||||
Residential | 22,070 | 20 | % | 18,586 | 14 | % | 20,332 | 16 | % | |||||||||||
Commercial | 5,408 | 5 | % | 4,733 | 4 | % | 5,426 | 4 | % | |||||||||||
Industrial | 292 | — | 258 | 1 | % | 319 | — | |||||||||||||
Cogeneration and electric generation | 1,562 | 1 | % | 1,598 | 1 | % | 1,618 | 2 | % | |||||||||||
Firm Transportation - | ||||||||||||||||||||
Residential | 3,319 | 3 | % | 2,335 | 2 | % | 2,382 | 2 | % | |||||||||||
Commercial | 6,780 | 6 | % | 5,587 | 4 | % | 5,715 | 4 | % | |||||||||||
Industrial | 13,051 | 12 | % | 12,892 | 10 | % | 13,024 | 10 | % | |||||||||||
Cogeneration and electric generation | 7,977 | 7 | % | 9,816 | 8 | % | 6,110 | 5 | % | |||||||||||
Total Firm Throughput | 60,459 | 54 | % | 55,805 | 44 | % | 54,926 | 43 | % | |||||||||||
Interruptible Sales | 14 | — | 2 | — | 13 | — | ||||||||||||||
Interruptible Transportation | 1,452 | 1 | % | 1,361 | 1 | % | 1,769 | 2 | % | |||||||||||
Off-System | 9,685 | 9 | % | 8,318 | 6 | % | 8,009 | 6 | % | |||||||||||
Capacity Release | 40,088 | 36 | % | 63,998 | 49 | % | 63,413 | 49 | % | |||||||||||
Total Throughput - Utility | 111,698 | 100 | % | 129,484 | 100 | % | 128,130 | 100 | % | |||||||||||
Utility Operating Revenues: | ||||||||||||||||||||
Firm Sales- | ||||||||||||||||||||
Residential | $ | 246,227 | 56 | % | $ | 248,547 | 59 | % | $ | 232,457 | 56 | % | ||||||||
Commercial | 57,126 | 13 | % | 53,726 | 13 | % | 58,122 | 14 | % | |||||||||||
Industrial | 3,485 | 1 | % | 2,872 | — | 3,991 | 2 | % | ||||||||||||
Cogeneration and electric generation | 8,144 | 2 | % | 6,562 | 2 | % | 9,469 | 2 | % | |||||||||||
Firm Transportation - | ||||||||||||||||||||
Residential | 21,392 | 5 | % | 16,388 | 4 | % | 15,161 | 4 | % | |||||||||||
Commercial | 28,165 | 6 | % | 24,217 | 6 | % | 22,500 | 5 | % | |||||||||||
Industrial | 23,551 | 5 | % | 21,637 | 5 | % | 18,827 | 5 | % | |||||||||||
Cogeneration and electric generation | 6,982 | 2 | % | 7,555 | 2 | % | 3,742 | 1 | % | |||||||||||
Total Firm Revenues | 395,072 | 90 | % | 381,504 | 91 | % | 364,269 | 89 | % | |||||||||||
Interruptible Sales | 342 | — | 52 | — | 230 | — | ||||||||||||||
Interruptible Transportation | 1,827 | — | 1,546 | — | 1,727 | — | ||||||||||||||
Off-System | 41,488 | 9 | % | 30,249 | 7 | % | 37,413 | 9 | % | |||||||||||
Capacity Release | 6,384 | 1 | % | 7,322 | 2 | % | 7,534 | 2 | % | |||||||||||
Other | 1,367 | — | 1,201 | — | 1,276 | — | ||||||||||||||
446,480 | 100 | % | 421,874 | 100 | % | 412,449 | 100 | % | ||||||||||||
Less: | ||||||||||||||||||||
Intercompany Sales | 1,560 | 1,056 | 6,707 | |||||||||||||||||
Total Utility Operating Revenue | 444,920 | 420,818 | 405,742 | |||||||||||||||||
Less: | ||||||||||||||||||||
Cost of sales | 198,521 | 187,655 | 181,158 | |||||||||||||||||
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Conservation recoveries * | 15,909 | 9,019 | 7,159 | |||||||||||||||||
Remediation Adjustment Clause recoveries * | 8,137 | 7,823 | 6,579 | |||||||||||||||||
Energy Efficiency Tracker (EET) recoveries* | 4,509 | 3,350 | 2,499 | |||||||||||||||||
Revenue taxes | 5,247 | 5,974 | 8,022 | |||||||||||||||||
Utility Margin | $ | 212,597 | $ | 206,997 | $ | 200,325 | ||||||||||||||
Margin: | ||||||||||||||||||||
Residential | $ | 138,136 | 65 | % | $ | 118,015 | 57 | % | $ | 124,882 | 62 | % | ||||||||
Commercial and industrial | 57,495 | 27 | % | 51,048 | 25 | % | 52,356 | 26 | % | |||||||||||
Cogeneration and electric generation | 5,022 | 2 | % | 5,062 | 2 | % | 3,235 | 2 | % | |||||||||||
Interruptible | 114 | — | 83 | — | 136 | — | ||||||||||||||
Off-system & capacity release | 2,070 | 1 | % | 2,044 | 1 | % | 1,829 | 1 | % | |||||||||||
Other revenues | 1,752 | 1 | % | 1,602 | 1 | % | 1,576 | 1 | % | |||||||||||
Margin before incentive mechanisms | 204,589 | 96 | % | 177,854 | 86 | % | 184,014 | 92 | % | |||||||||||
CIRT mechanism | 2,204 | 1 | % | 3,031 | 2 | % | 2,655 | 1 | % | |||||||||||
CIP mechanism | 5,310 | 3 | % | 25,672 | 12 | % | 13,270 | 7 | % | |||||||||||
EET mechanism | 494 | — | 440 | — | 386 | — | ||||||||||||||
Utility Margin | $ | 212,597 | 100 | % | $ | 206,997 | 100 | % | $ | 200,325 | 100 | % | ||||||||
Number of Customers at Year End: | ||||||||||||||||||||
Residential | 337,936 | 93 | % | 333,347 | 93 | % | 327,678 | 93 | % | |||||||||||
Commercial | 23,873 | 7 | % | 23,506 | 7 | % | 23,169 | 7 | % | |||||||||||
Industrial | 447 | — | 453 | — | 457 | — | ||||||||||||||
Total Customers | 362,256 | 100 | % | 357,306 | 100 | % | 351,304 | 100 | % | |||||||||||
Annual Degree Days: | 4,658 | 3,862 | 4,226 | |||||||||||||||||
* Represents expenses for which there is a corresponding credit in operating revenues. Therefore, such recoveries have no impact on our financial results.
Throughput - Utility - Total gas throughput decreased 17.8 MMdts, or 13.7%, from 2012 to 2013 primarily due to lower throughput in the Capacity Release market which decreased 23.9 MMdts. SJG was releasing capacity in smaller segments ("segmenting") in 2012 and 2011 based on the demand in the market at that time. While segmenting has little impact on revenue and margin generated from such activity, it does increase throughput significantly. Due to colder weather experienced in the region in 2013, SJG also experienced increased demand from its firm customers, thereby creating fewer opportunities for Capacity Release during the winter months. Firm throughput increased 4.7 MMdts, or 8.3%, in 2013. This is most apparent in the heat sensitive residential and commercial markets whose throughput increased as a result of weather that was 20.6% colder in 2013, as compared with 2012. Also contributing to higher throughput was the addition of 4,950 customers over the last 12 months, representing 1.4% customer growth.
Total gas throughput increased 1.4 MMdts, or 1.1%, from 2011 to 2012. This increase is due to higher electric generation transportation throughput, which increased 3.7 MMdts, or 60.7%, as a result of the excessive heat during the summer months of 2012. As the third quarter of 2012 was one of the warmest on record in the region, higher electric consumption for air conditioning drove the demand for greater natural gas consumption by the region's electric producers. Partially offsetting this increase in throughput was lower consumption by residential and commercial customers. Residential and commercial firm sales decreased 1.7 MMdts and 0.7 MMdts, respectively, as a result of weather that was 8.6% warmer in 2012, compared with 2011.
.
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Operating Revenues - Utility 2013 vs. 2012 - Revenues increased $24.1 million, or 5.7%, during 2013 compared with 2012 after eliminating intercompany transactions. Total firm revenue increased $13.6 million, or 3.6%, in 2013 as a result of 20.6% colder weather and 4,950 additional customers compared with 2012, as previously discussed under "Throughput-Utility." While these factors increased firm sales volumes significantly, associated revenue did not increase proportionately as a result of lower gas costs being passed through to those customers. In October 2012, SJG reduced its periodic BGSS rate by 18% and also gave a refund of $9.4 million to its periodic BGSS customers in January 2013. While changes in gas costs and BGSS recoveries/refunds fluctuate from period to period, SJG does not profit from the sale of the commodity. Therefore, corresponding fluctuations in Operating Revenue or Cost of Sales have no impact on Company profitability, as further discussed below under the caption "Margin-Utility".
Higher OSS volume and unit prices resulted in an $11.2 million, or 37.2%, increase in revenues from 2012 to 2013. Colder weather led to greater demand and advantageous pricing spreads in the latter part of 2013, allowing SJG to increase revenue from such sales. However, the impact of changes in OSS activity does not have a material impact on earnings, as SJG is required to share 85% of the profits of such activity with its ratepayers. Earnings from OSS can be seen in the Margin table above.
Operating Revenues - Utility 2012 vs. 2011 - Revenues increased $15.1 million, or 3.7%, during 2012 compared with 2011 after eliminating intercompany transactions. Firm sales revenue increased $17.2 million, or 4.7%, during 2012 versus 2011, primarily as a result of two customer refunds in 2011, which reduced prior year revenue by $39.8 million (See Note 10 to the consolidated financial statements). There were no such refunds during 2012. In 2012, firm sales revenue was significantly impacted by weather that was 8.6% warmer than 2011 and lower natural gas costs. As a result, the change in revenue caused by the 2011 refunds was substantially offset by the impact of warm weather and lower gas costs on revenues during 2012. The average cost of natural gas purchased during 2012 was $4.56 per dt, representing an 23.2% decrease relative to the average cost of $5.94 per dt during 2011.
As previously stated under "Throughput-Utility," record warm weather during the summer season resulted in increased sales to area electric producers. This resulted in a $3.8 million increase in cogeneration and electric generation transportation revenue over 2011.
Off-System Sales (OSS) revenue decreased $7.2 million, or 19.1%, despite throughput that was relatively consistent from 2011 to 2012. The decrease was primarily due to lower natural gas prices in 2012. As can be seen in the table above, this reduction in revenue had no adverse impact on SJG's margin in 2012.
Operating Revenues - Nonutility 2013 vs. 2012 - Combined revenues for SJI's nonutility businesses, net of intercompany transactions, increased $1.0 million, or 0.4%, in 2013, compared with 2012.
SJE's revenues from retail gas operations, net of intercompany transactions, increased by $27.5 million, or 34.4%, in 2013, compared with 2012. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts of $(0.7) million due to price volatility, revenues increased $28.2 million, or 35.6%. This increase was due to a 30.9% increase in the average monthly NYMEX settle price, along with a 21.8% increase in sales volumes compared with 2012, which was due to the impact of acquiring a retail gas marketing book in the third quarter of 2012. As of December 31, 2013 and 2012, SJE was serving 3,041 and 2,174 retail gas customers, respectively. Sales volumes totaled 24,960,661 and 20,475,114 dekatherms for the year ended December 31, 2013 and 2012, respectively.
SJE's revenues from retail electric operations, net of intercompany transactions, decreased $14.6 million, or 10.5%, in 2013, compared with 2012. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts due to price volatility of $9.8 million, revenues decreased $4.8 million, or 3.7%.
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A summary of SJE's retail electric revenue is as follows (in millions):
2013 | 2012 | Change | |||||||
SJE Retail Electric Revenue | $ | 123.7 | $ | 138.3 | $ | (14.6 | ) | ||
Add: Unrealized Losses (Subtract: Unrealized Gains) | 0.7 | (9.1 | ) | 9.8 | |||||
SJE Retail Electric Revenue, Excluding Unrealized Losses (Gains) | $ | 124.4 | $ | 129.2 | $ | (4.8 | ) | ||
This decrease was mainly due to a 15.1% decrease in volumes that resulted from a significant school board contract that expired in the second quarter of 2012. SJE uses forward financial contracts to mitigate commodity price risk on fixed price electric contracts. In accordance with GAAP, the forward financial contracts are recorded at fair value, with changes in fair value recorded in earnings in the period of change. Some of the related customer contracts are not considered derivatives and therefore are not recorded in earnings until electricity is delivered. As a result, earnings are subject to volatility as the market price for the forward financial contracts change, even when the underlying hedged value of the contract is unchanged. Over time, gains or losses on the sale of the fixed price electricity under contract will be offset by losses or gains on the forward financial contracts, resulting in the realization of the profit margin expected when the transactions were initiated. SJE serves both fixed and market-priced customers.
SJRG's revenues from wholesale energy operations, net of intercompany transactions, decreased $16.5 million in 2013 compared with 2012. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts due to price volatility of $15.1 million, SJRG's revenues decreased $1.4 million. A summary of SJRG's revenue is as follows (in millions):
2013 | 2012 | Change | |||||||
SJRG Revenue | $ | 0.7 | $ | 17.2 | $ | (16.5 | ) | ||
Add: Unrealized Losses (Subtract: Unrealized Gains) | 25.1 | 10.0 | 15.1 | ||||||
SJRG Revenue, Excluding Unrealized Losses (Gains) and Realized Losses (Gains) on Inventory Injection Hedges | $ | 25.8 | $ | 27.2 | $ | (1.4 | ) | ||
This decrease in revenues is mainly due to compressed margins on energy trading activities in 2013 compared with 2012. As discussed in Note 16 to the consolidated financial statements, revenues and expenses related to the energy trading activities of SJRG are presented on a net basis in Operating Revenues - Nonutility.
Revenues from on-site energy production at Marina, net of intercompany transactions, increased $5.0 million, or 13.7%, in 2013 compared with 2012, primarily as a result of several new renewable energy projects that began operations in 2012 and 2013. Revenues also increased due to higher hot water production and electricity sales at the thermal facility due to colder temperatures during 2013 as compared with the prior year.
Revenues from appliance service operations at SJESP did not change significantly in 2013 compared with 2012.
Operating Revenues - Nonutility 2012 vs. 2011 - Combined revenues for SJI's nonutility businesses, net of intercompany transactions, decreased $137.4 million, or 32.5%, in 2012, compared with 2011.
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SJE's revenues from retail gas operations, net of intercompany transactions, decreased by $19.9 million, or 19.9%, in 2012, compared with 2011. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts of $(0.8) million due to price volatility, revenues decreased $20.7 million, or 20.7%. This decrease was due to a 31.0% decrease in the average monthly NYMEX settle price, along with the impact of SJE exiting the residential market in October of 2011 and significantly warmer weather experienced during 2012. SJE's residential contracts were at higher fixed prices reflective of market conditions from three years ago when the expired program was established. The majority of SJE's other natural gas customer contracts are market-priced. These decreases are partially offset by a 9.4% increase in overall volumes due to the purchase of a retail gas marketing book in central Pennsylvania that added over 350 commercial and small industrial customers in the third quarter of 2012.
As of December 31, SJE was serving the following number of retail gas customers:
2012 | 2011 | |||||
Commercial & Large Volume | 2,174 | 1,662 | ||||
Sales volumes for the comparative period were as follows (in dekatherms):
2012 | 2011 | |||||
Residential | — | 407,808 | ||||
Commercial & Large Volume | 20,475,114 | 18,252,903 | ||||
SJE's revenues from retail electric operations, net of intercompany transactions, decreased $61.1 million, or 30.6%, in 2012, compared with 2011. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts due to price volatility of $(12.2) million, revenues decreased $73.3 million or 36.2%. A summary of SJE's retail electric revenue is as follows (in millions):
2012 | 2011 | Change | |||||||
SJE Retail Electric Revenue | $ | 138.3 | $ | 199.4 | $ | (61.1 | ) | ||
Add: Unrealized Losses (Subtract: Unrealized Gains) | (9.1 | ) | 3.1 | (12.2 | ) | ||||
SJE Retail Electric Revenue, Excluding Unrealized Losses (Gains) | $ | 129.2 | $ | 202.5 | $ | (73.3 | ) | ||
This decrease was mainly due to a 19.6% decrease in average monthly sales price which was driven by lower-priced fixed price contracts and lower Locational Marginal Price (LMP) per megawatt hour in 2012 compared with 2011. Volumes also decreased 21.9% for the comparative period mainly due to a significant school board contract that expired in the second quarter of 2012. SJE uses forward financial contracts to mitigate commodity price risk on fixed price electric contracts. In accordance with GAAP, the forward financial contracts are recorded at fair value, with changes in fair value recorded in earnings in the period of change. Some of the related customer contracts are not considered derivatives and therefore are not recorded in earnings until electricity is delivered. As a result, earnings are subject to volatility as the market price for the forward financial contracts change, even when the underlying hedged value of the contract is unchanged. Over time, gains or losses on the sale of the fixed price electricity under contract will be offset by losses or gains on the forward financial contracts, resulting in the realization of the profit margin expected when the transactions were initiated. SJE serves both fixed and market-priced customers.
SJRG's revenues from wholesale energy operations, net of intercompany transactions, decreased $50.8 million, or 75.2%, in 2012, compared with 2011. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $18.6 million and adjusting for the net change in realized gains and losses on all hedges attributed to inventory injection transactions of $0.1 million to align them with the related cost of inventory in the period of withdrawal, SJRG's revenues decreased $32.1 million.
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A summary of SJRG's revenue is as follows (in millions):
2012 | 2011 | Change | |||||||
SJRG Revenue | $ | 17.2 | $ | 68.0 | $ | (50.8 | ) | ||
Add: Unrealized Losses (Subtract: Unrealized Gains) | 10.0 | (8.6 | ) | 18.6 | |||||
Add: Realized Losses (Subtract: Realized Gains) on Inventory Injection Hedges | — | (0.1 | ) | 0.1 | |||||
SJRG Revenue, Excluding Unrealized Losses (Gains) and Realized Losses (Gains) on Inventory Injection Hedges | $ | 27.2 | $ | 59.3 | $ | (32.1 | ) | ||
This decrease in revenues is mainly due to a 71.6% decrease in sales of storage volumes, which are shown gross in the statement of operations, along with a 31.0% decrease in the average monthly NYMEX settle price. As discussed in Note 16 to the consolidated financial statements, revenues and expenses related to the energy trading activities of SJRG are presented on a net basis in Operating Revenues - Nonutility.
Revenues from on-site energy production at Marina, net of intercompany transactions, decreased $1.6 million, or 4.2%, in 2012 compared with 2011, due mainly to lower sales rates for chilled and hot water production at the thermal facility which were driven by lower underlying commodity rates and an asset sale that resulted in the termination of a large customer contract in August 2011. These decreases were partially offset by revenues from several new renewable energy projects that began operations in 2011 and 2012.
Revenues from appliance service operations at SJESP decreased $3.4 million, or 20.0%, in 2012, compared with 2011, due mainly to a decrease in customer warranty contract sales. SJESP sold the rights to renew the home appliance repair contracts to a provider of homeowner assistance services under an exclusive agreement that took effect in the third quarter of 2011. Under the terms of this agreement, SJESP received a fee for the sale of these rights (See Other Income and Expense). SJESP also receives a commission for all new and renewed service contracts and is paid a fee to service those warranty contracts.
Margin - Utility - SJG's margin is defined as natural gas revenues less natural gas costs; volumetric and revenue based energy taxes; and regulatory rider expenses. We believe that margin provides a more meaningful basis for evaluating utility operations than revenues since natural gas costs, energy taxes and regulatory rider expenses are passed through to customers, and therefore, have no effect on margin. Natural gas costs are charged to operating expenses on the basis of therm sales at the prices approved by the New Jersey Board of Public Utilities through the BGSS tariff.
Total margin in 2013 increased $5.6 million, or 2.7%, from 2012 primarily due to customer additions. SJG added 4,950 customers during 2013 representing growth of 1.4% over the prior year.
The CIP protected $5.3 million of pre-tax margin in 2013 that would have been lost due to lower customer usage, compared to $25.7 million in 2012. Of these amounts, $(0.5) million and $15.8 million were related to weather variations and $5.8 million and $9.9 million were related to other customer usage variations in 2013 and 2012, respectively.
Total margin in 2012 increased $6.7 million, or 3.3%, from 2011 primarily due to customer additions and increased margins from cogeneration and electric generation due to the warmer temperatures noted above. SJG added 6,002 customers during 2012 representing growth of 1.7% over the prior year and a corresponding increase in margin.
The CIP protected $25.7 million of pre-tax margin in 2012 that would have been lost due to lower customer usage, compared to $13.3 million in 2011. Of these amounts, $15.8 million and $9.6 million were related to weather variations and $9.9 million and $3.7 million were related to other customer usage variations in 2012 and 2011, respectively.
Gross Margin - Nonutility - Gross margin for the nonutility businesses is defined as revenue less all costs that are directly related to the production, selling and delivery of the company's products and services. These costs primarily include natural gas and electric commodity costs as well as certain payroll and related benefits. On the statements of consolidated income, revenue is reflected in Operating Revenues - Nonutility and the costs are reflected in Cost of Sales - Nonutility. As discussed in Note 16 to the consolidated financial statements, revenues and expenses related to the energy trading activities of SJRG are presented on a net basis in Operating Revenues - Nonutility.
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For 2013, combined gross margins for the nonutility businesses, net of intercompany transactions, decreased $39.3 million to $16.0 million compared with 2012. This decrease is primarily due to the following:
• | Gross Margin from SJE's retail gas and other operations increased $1.3 million in 2013 compared with 2012. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts due to price volatility of $(0.7) million as discussed above, gross margin increased $2.0 million in 2013, compared with 2012. This increase was primarily due to the impact of acquiring a retail gas marketing book in the third quarter of 2012. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts as discussed above, gross margin as a percentage of Operating Revenues did not change significantly in 2013 compared with 2012. |
• | Gross margin from SJE's retail electric operations decreased $12.0 million in 2013, compared with 2012. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts due to price volatility of $9.8 million as discussed above, gross margin decreased $2.2 million in 2013 compared with 2012 mainly due to a significant school board contract that expired in the second quarter of 2012 (See Operating Revenues - Nonutility). Excluding the impact of the unrealized gains/losses discussed above, gross margin as a percentage of Operating Revenues did not change significantly in 2013 compared with 2012. |
• | Gross margin from the wholesale energy operations of SJRG decreased $36.0 million in 2013 compared with 2012. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts of $15.1 million as discussed above, gross margin for SJRG decreased $20.9 million. The decrease in gross margin was mainly due to lower daily trading margins in 2013 as compared with 2012. |
Overall, SJRG's contribution to margin from storage and transportation assets has decreased due to market conditions. However, SJRG expects to continue to add incremental margin from marketing and related opportunities in the Marcellus region, capitalizing on its established presence in the area. Future margins could fluctuate significantly due to the volatile nature of wholesale gas prices. As of December 31, 2013, SJRG had 9.6 Bcf of storage and 562,401 dts/day of transportation under contract.
• | Gross Margin from on-site energy production at Marina increased $5.4 million in 2013 compared with 2012. Gross margin as a percentage of Operating Revenues increased 3.9 percentage points in 2013 compared with 2012. This was due mainly to the impact of several new, higher margin renewable energy projects added over the last twelve months. |
• | Gross margin from the appliance service operations at SJESP increased $2.1 million in 2013 compared with 2012. Gross margin as a percentage of Operating Revenues increased 14.9 percentage points in 2013 compared with 2012. These increases are mainly due to the significant decline in personnel costs that resulted from an initiative to right-size our workforce. |
For 2012, combined gross margins for the nonutility businesses, net of intercompany transactions, decreased $3.7 million to $55.3 million compared with 2011. This decrease is primarily due to the following:
• | Gross margin from the wholesale energy operations of SJRG decreased $17.0 million in 2012 compared with 2011. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $18.6 million and adjusting for the net change in realized gains and losses on all hedges attributed to inventory injection transactions of $0.1 million as discussed above, gross margin for SJRG increased $1.7 million. This increase is due mainly to strong margins from acquired capacity and optimization in 2012 compared to losses on transportation contracts in 2011 that occurred due to temporary take-away constraints. These increases are partially offset by the treatment of the costs attributable to injections of gas into storage, which are included in the carrying value of gas in storage when injections are made. SJRG has not injected significant amounts of gas into storage during 2012, and as a result, these costs have been expensed as incurred. |
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As of December 31, 2012, SJRG had 9.3 Bcf of storage and 530,701 dts/day of transportation under contract.
• | Gross margin from the appliance service operations at SJESP decreased $0.8 million in 2012 compared with 2011 mainly due to lower customer warranty contract sales (See Operating Revenues - Nonutility). Gross margin as a percentage of Operating Revenues increased 2.1 percentage points in 2012 compared with 2011 mainly due to the significant decline in personnel costs that resulted from an initiative to right-size our workforce. |
• | Gross margin from SJE's retail electric operations increased $11.7 million in 2012, compared with 2011. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts due to price volatility of $(12.2) million as discussed above, gross margin decreased $0.5 million in 2012 compared with 2011 mainly due to a significant school board contract that expired in the second quarter of 2012 (See Operating Revenues - Nonutility). Excluding the impact of the unrealized gains/losses discussed above, gross margin as a percentage of Operating Revenues increased 1.9 percentage points in 2012 compared with 2011 mainly due to lower capacity, transmission and network service costs and the addition of numerous higher-margin customers over the past twelve months, which was partially offset by the expiration of the school board contract. |
• | Gross margin from on-site energy production at Marina increased $2.7 million in 2012 compared with 2011. Gross margin as a percentage of Operating Revenues increased 12.1 percentage points. This was due mainly to the impact of several solar projects coming on line in 2012, which was partially offset by an asset sale that resulted in the termination of a customer contract in 2011. Solar projects typically produce higher margins as compared to the margins produced by the terminated contract. |
• | Gross margin from SJE's retail gas and other operations remained relatively unchanged in 2012, compared with 2011. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts due to price volatility of $(0.8) million as discussed above, gross margin decreased $0.8 million in 2012, compared with 2011. Excluding the impact of the net change in unrealized gains/losses recorded on forward financial contracts as discussed above, gross margin as a percentage of Operating Revenues remained relatively unchanged in 2012, compared with 2011. The decrease in margin is mainly due to the warmer weather experienced in the first and fourth quarters of 2012, partially offset by the impact of acquiring a retail gas marketing book in the third quarter of 2012 that contained higher-margin customers (See Operating Revenues - Nonutility). |
Operations Expense - A summary of net changes in operations expense follows (in thousands):
2013 vs. 2012 | 2012 vs. 2011 | |||||
Gas Utility Operations | $ | 7,380 | $ | 10,276 | ||
Nonutility: | ||||||
Wholesale Energy Operations | (560 | ) | 1,454 | |||
Retail Gas and Other Operations | (137 | ) | 1,512 | |||
Retail Electric Operations | 799 | 718 | ||||
On-Site Energy Production | 100 | 1,779 | ||||
Appliance Service Operations | (1,108 | ) | (2,138 | ) | ||
Total Nonutility | (906 | ) | 3,325 | |||
Intercompany Eliminations and Other | 88 | (859 | ) | |||
Total Operations Expense | $ | 6,562 | $ | 12,742 | ||
Utility Operations expense increased $7.4 million during 2013, compared with 2012. This is primarily the result of increases in spending under the New Jersey Clean Energy Program and Energy Efficiency Programs. Such costs are recovered on a dollar-for-dollar basis; therefore, SJG experienced an offsetting increase in revenues during 2013.
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South Jersey Industries, Inc.
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Utility Operations expense increased $10.3 million during 2012, compared with 2011. This is the result of increases in expense associated with uncollectible customer accounts receivable, along with moderate increases in corporate support, governance, compliance and employee compensation costs. Also contributing was increased spending under the New Jersey Clean Energy Program and Energy Efficiency Programs. Such costs are recovered on a dollar-for-dollar basis; therefore, SJG experienced an offsetting increase in revenues during the period.
Nonutility Operations expense decreased $0.9 million during 2013 compared with 2012 due primarily to a $2.4 million impairment charge taken in 2012 as discussed below, along with a decline in personnel costs at SJESP that resulted from an initiative to right-size our workforce. Partially offsetting this decrease is additional governance and compliance costs to support continued growth.
Nonutility Operations expense increased $3.3 million in 2012 compared with 2011 due mainly to additional personnel at the retail gas and other operations segment, partially offset by a decrease in personnel at the appliance service operations segment, along with additional governance and compliance costs to support continued growth. Also contributing to the increase is a $2.4 million impairment charge due to a reduction in the expected cash flows to be received from a solar generating facility within the on-site energy production segment.
Other Operating Expenses - A summary of changes in other consolidated operating expenses (in thousands):
2013 vs. 2012 | 2012 vs. 2011 | |||||
Maintenance | $ | (479 | ) | $ | 493 | |
Depreciation | $ | 8,301 | $ | 5,587 | ||
Energy and Other Taxes | $ | (170 | ) | $ | (2,203 | ) |
Maintenance - Maintenance expense decreased $0.5 million during 2013 compared with 2012 as cost amortizations previously approved in SJG's September 2010 rate case settlement ceased. Such amortizations totaled $1.0 million in 2012; however, as of late 2012 these costs were fully amortized. This reduction in expense was partially offset by an increase in Remediation Adjustment Clause (RAC) expense amortization. Maintenance expense increased $0.5 million during 2012 compared with 2011 primarily due to an increase in RAC expense amortization.
Depreciation Expense - Depreciation increased $8.3 million and $5.6 million during 2013 and 2012, respectively, compared to the prior year due mainly to the increased investment in property, plant and equipment by SJG and Marina.
Energy and Other Taxes - The change in Energy and Other Taxes in 2013 compared with 2012 was not significant. Energy and Other Taxes decreased $2.2 million in 2012 compared with 2011 primarily due to a decrease in SJG's primary energy tax, the Transitional Energy Facilities Assessment, effective January 1, 2012. As this tax is passed through to customers, this decrease in expense had no impact on the financial results of the Company.
Other Income and Expense - The change in other income and expense in 2013 compared with 2012 was not significant due primarily to a decrease in interest income on notes receivable from affiliates, which was offset by a $1.1 million charge during the first quarter of 2012 at SJEX related to a reduction in expected cash flows to be received from certain shallow well investments in the Marcellus region. Other income and expense decreased $4.5 million in 2012 compared with 2011 primarily due to proceeds received during 2011 from a provider of homeowner assistance services, in accordance with an agreement with the Company, that gives them the exclusive right to renew the home appliance repair contracts at SJESP. The Company also incurred a $1.1 million charge during the first quarter of 2012 at SJEX related to a reduction in expected cash flows to be received from certain shallow well investments in the Marcellus region.
Interest Charges - The change in interest charges in 2013 compared with 2012 was not significant due primarily to an increase in interest costs resulting from the issuance of long-term debt in 2012 as discussed below, which was offset by a gain on interest rate contracts not designated as hedging instruments (see Note 16 of the consolidated financial statements). Interest charges decreased $5.1 million in 2012 compared with 2011 due primarily to the positive impact of retiring $35.0 million of SJG's higher priced long-term debt during 2012 and higher capitalization of interest cost on construction at SJG. These decreases are partially offset by the issuance of $115.0 million aggregate principal amount of Senior Notes at the end of the second quarter 2012, along with long-term debt issued by SJG as discussed in Note 14 to the consolidated financial statements.
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South Jersey Industries, Inc.
Part II
Income Taxes - Income taxes changed from an $11.5 million expense for the year ended December 31, 2012 to a $19.0 million benefit for the year ended December 31, 2013. These changes were primarily due to lower income before income taxes, along with a lower effective tax rate due to the increase in the investment tax credits available on renewable energy facilities at Marina in 2013 compared with 2012. Investment tax credits from renewable energy facilities at Marina of $37.7 million and $26.0 million were recognized for the years ended December 31, 2013 and 2012, respectively. Income tax expense decreased $11.0 million in 2012 compared with 2011 primarily due to lower taxable income and a lower effective tax rate during 2012 as compared with 2011. The change in the effective tax rate is primarily due to the increase in the investment tax credits available on renewable energy facilities at Marina in 2012 as compared to 2011.
Equity in Earnings of Affiliated Companies - Equity in earnings of affiliated companies decreased $0.7 million for 2013 compared to 2012, primarily due to losses incurred at LVE during 2013 along with less production from landfill gas fired electric production facilities compared to the prior year. Equity in earnings of affiliated companies increased $3.0 million for 2012 as compared to 2011, primarily due to new projects coming on line in 2012 and the improved operating performance of our renewable energy project fleet at affiliated companies.
Discontinued Operations - The losses are primarily comprised of environmental remediation and product liability litigation associated with previously disposed of businesses.
LIQUIDITY AND CAPITAL RESOURCES:
Liquidity needs are driven by factors that include natural gas commodity prices; the impact of weather on customer bills; lags in fully collecting gas costs from customers under the BGSS charge and other regulatory clauses; working capital needs of our energy trading and marketing activities; the timing of construction and remediation expenditures and related permanent financings; the timing of equity contributions to unconsolidated affiliates; mandated tax payment dates; both discretionary and required repayments of long-term debt; and the amounts and timing of dividend payments.
Cash Flows from Operating Activities - Liquidity needs are first met with net cash provided by operating activities. Net cash provided by operating activities totaled $159.5 million, $117.8 million and $191.4 million in 2013, 2012 and 2011, respectively. Net cash provided by operating activities varies from year-to-year primarily due to the impact of weather on customer demand and related gas purchases, customer usage factors related to conservation efforts and the price of the natural gas commodity, inventory utilization and gas cost recoveries. Net cash flow from operating activities increased in 2013 as compared to 2012. Factors contributing to the increase included changes in working capital requirements, a lower pension contribution and lower cash tax payments due to the utilization of investment tax credits. Working capital requirements were positively impacted by $26.0 million higher collections under regulatory clauses during 2013 that were under-recovered due to warmer-than-normal weather in 2012. Lower pension contributions also improved cash flows for 2013 by approximately $12.3 million as discussed in Note 12 to the consolidated financial statements. The Company strives to keep its pension plans fully funded. When factors such as lesser than expected asset performance and/or declining discount rates negatively impact the funding status of the plans, the Company increases its contributions to supplant that funding shortfall. While discount rates continued to decline, greater than expected asset performance during 2012 added significantly to improving the Company's funding status, which resulted in a decrease in the pension contribution during 2013. The Company contributed $12.7 million and $25.0 million to its pension plans in January 2013 and 2012, respectively.
Net cash flow from operating activities declined in 2012 as compared to 2011. Factors contributing to the decline included changes in working capital requirements, a pension contribution and income tax refunds. Working capital requirements were higher at the end of 2012 than the prior year due to colder weather experienced at the end of 2012 and customer growth. An $18.7 million bill credit provided at the end of 2011 also reduced cash collections in 2012. Conversely, 2011 cash from operations benefited from storage gas sold at the end of 2010, the receivable for which was collected in 2011. Net cash provided by operating activities was also impacted by a $25.0 million pension contribution that occurred in January 2012. There were no pension contributions made by the Company in 2011. Finally, income tax refunds related to investment tax credits and bonus depreciation were higher in 2011 than 2012.
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South Jersey Industries, Inc.
Part II
Cash Flows from Investing Activities - SJI has a continuing need for cash resources and capital, primarily to invest in new and replacement facilities and equipment. Net cash outflows for capital expenditures, which are primarily construction projects, for 2013, 2012 and 2011 amounted to $316.6 million, $253.8 million and $193.1 million, respectively. We estimate the net cash outflows for construction projects for 2014, 2015 and 2016 to be approximately $309.9 million, $319.1 million and $273.0 million, respectively. The high level of capital expenditures is due to a combination of the accelerated infrastructure investment programs, a major pipeline project to support an electric generation facility, and a new customer information system, all at SJG. For capital expenditures, including those under SJG’s CIRT and AIRP, the Company expects to use short-term borrowings under lines of credit from commercial banks and the commercial paper program to finance capital expenditures as incurred. From time to time, the Company may refinance the short-term debt incurred to support capital expenditures with long-term debt. Also contributing to the high level of capital expenditures are anticipated solar projects at Marina.
In support of its risk management activities, the Company is required to maintain margin accounts with selected counterparties as collateral for its forward contracts, swap agreements, options contracts and futures contracts. These margin accounts are included in Restricted Investments or Margin Account Liability, depending upon the value of the related contracts (the change in the Margin Account Liability is reflected in cash flows from Operating Activities) on the consolidated balance sheets. The required amount of restricted investments changes on a daily basis due to fluctuations in the market value of the related outstanding contracts and is difficult to predict. Margin posted by the Company increased by $25.2 million during 2013, decreased by $0.8 million during 2012 and increased by $10.3 million during 2011.
During 2013, 2012 and 2011, the Company made investments in, and provided net advances to, unconsolidated affiliates of $9.6 million, $94.0 million and $14.6 million, respectively. These amounts do not include the cash proceeds from LVE and the repayment of the advances to Energenic as discussed below. The purpose of these investments and advances was to cover certain project related costs of affiliates.
In March 2013, substantially all of the assets of Marina's joint venture, LVE Energy Partners, LLC (LVE), an entity in which Marina had a 50% equity interest, were sold. As a result of the transaction, Marina received cash proceeds of $57.9 million. See Note 15 to the consolidated financial statements.
In April 2012, Energenic acquired The Energy Network, LLC, a holding company for the Hartford Steam Company, TEN Companies and CNE Power I, LLC. In conjunction with this acquisition, Marina provided $35.4 million of advances to Energenic, which were repaid by Energenic during the second quarter of 2013 when permanent financing was obtained.
Cash Flows from Financing Activities - Short-term borrowings from the commercial paper program and lines of credit from commercial banks are used to supplement cash flows from operations, to support working capital needs and to finance capital expenditures as incurred. From time to time, short-term debt incurred to finance capital expenditures may be refinanced with long-term debt.
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South Jersey Industries, Inc.
Part II
Credit facilities and available liquidity as of December 31, 2013 were as follows (in thousands):
Company | Total Facility | Usage | Available Liquidity | Expiration Date | ||||||||||
SJG: | ||||||||||||||
Commercial Paper Program/Revolving Credit Facility | $ | 200,000 | $ | 65,500 | $ | 134,500 | May 2018 | |||||||
Uncommitted Bank Lines | 10,000 | — | 10,000 | August 2014 | ||||||||||
Total SJG | 210,000 | 65,500 | 144,500 | |||||||||||
SJI: | ||||||||||||||
Revolving Credit Facility | 400,000 | 315,200 | 84,800 | February 2018 (A) | ||||||||||
Total SJI | 400,000 | 315,200 | 84,800 | |||||||||||
Total | $ | 610,000 | $ | 380,700 | $ | 229,300 | ||||||||
(A) Includes letters of credit outstanding in the amount of $26.8 million.
The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary the SJI facilities can also be used to support SJG's liquidity needs. All committed facilities contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements), measured on a quarterly basis. SJI and SJG were in compliance with these covenants as of December 31, 2013. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.04%, 1.10% and 1.12% at December 31, 2013, 2012 and 2011, respectively. In September, 2013, SJG extended its $200.0 million syndicated credit facility to May 2018. Based upon the existing credit facilities and a regular dialogue with our banks, we believe there will continue to be sufficient credit available to meet our business' future liquidity needs.
SJG renewed its $10.0 million line of credit during the third quarter of 2013.
In October 2013, SJI entered into an unsecured $50.0 million term loan, which matures in October 2015. This agreement replaces existing short-term facilities that were set to expire in November 2013 (see Note 13 to the consolidated financial statements). This term loan is included in long-term debt on the consolidated balance sheets.
SJG manages a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million. The notes have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes. SJG uses the commercial paper program in tandem with the $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.
SJI supplements its operating cash flow, commercial paper program and credit lines with both debt and equity capital. Over the years, SJG has used long-term debt, primarily in the form of First Mortgage Bonds and Medium Term Notes (MTN's), secured by the same pool of utility assets, to finance its long-term borrowing needs. These needs are primarily capital expenditures for property, plant and equipment.
During the third quarter of 2013, SJG redeemed at par $10.5 million of 4.46% MTN's issued in July 2003 and $14.5 million of 5.027% MTN's issued in September 2003.
In November 2013, SJG issued $50.0 million of 4.01% MTN's due November 2030, and issued $30.0 million of 4.23% MTN's in January 2014 due January 2030.
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South Jersey Industries, Inc.
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In October 2013, SJG filed a petition with the BPU to issue up to $200.0 million of long-term debt securities in various forms including MTN's and unsecured debt, with maturities of more than 12 months, over the next three years. This petition was approved in January 2014.
In February 2012, SJG called its $35.0 million, 7.70% MTN's due April 2027 at par plus a 2.0% premium. The early redemption occurred concurrently with the issuance in April 2012 of $35.0 million, 3.74% Series D MTN's due April 2032 as discussed in Note 14 to the consolidated financial statements.
In June 2012 (as discussed in Note 14 to the consolidated financial statements), the Company issued $115.0 million aggregate principal amount of MTNs, consisting of the following: (a) $64.0 million aggregate principal amount of 2.39% Senior Notes due June 2015; (b) $16.0 million aggregate principal amount of 2.71% Senior Notes due June 2017; and (c) $35.0 million aggregate principal amount of 3.46% Senior Notes due June 2022.
In September 2012 (as discussed in Note 14 to the consolidated financial statements), SJG issued $50.0 million of 3.0% aggregate principal amount of MTN's due September 20, 2024. The notes purchase agreement also provided for the issuance of $35.0 million aggregate principal amount of its MTNs that were issued in November 2012.
No other long-term debt was issued during the years ended December 31, 2013 or 2012.
SJI raises equity capital through its Dividend Reinvestment Plan (DRP). Participants in SJI's DRP receive newly issued shares. Prior to April 2013, shares of common stock offered by the DRP were issued at a 2% discount directly by SJI from its authorized but unissued shares of common stock. In April 2013, SJI discontinued the 2% discount on shares issued through the DRP in an effort to manage the amount of equity raised through the plan; however the discount was reinstated during the third quarter of 2013. Through the DRP, SJI raised $54.0 million and $70.2 million of equity capital by issuing 1.0 million and 1.4 million shares in 2013 and 2012, respectively.
SJI's capital structure was as follows:
As of December 31, | |||||
2013 | 2012 | ||||
Equity | 43.9 | % | 43.3 | % | |
Long-Term Debt | 37.3 | % | 36.8 | % | |
Short-Term Debt | 18.8 | % | 19.9 | % | |
Total | 100.0 | % | 100.0 | % | |
The change in the SJI capital structure from 2012 to 2013 is primarily related to the issuance of long-term debt at SJI and SJG as discussed in Note 14 to the consolidated financial statements.
For 2013, 2012 and 2011, SJI paid quarterly dividends to its common shareholders. SJI has paid dividends on its common stock for 62 consecutive years and has increased that dividend each year for the last fourteen years. The Company currently looks to grow that dividend by at least 6% to 7% per year and has a targeted payout ratio of between 50% and 60% of Economic Earnings. In setting the dividend rate, the Board of Directors of SJI considers future earnings expectations, payout ratio, and dividend yield relative to those at peer companies, as well as returns available on other income-oriented investments. However, there can be no assurance that the Company will be able to continue to increase the dividend, meet the targeted payout ratio or pay a dividend at all in the future.
COMMITMENTS AND CONTINGENCIES:
SJI has a continuing need for cash resources and capital, primarily to invest in new and replacement facilities and equipment, and for environmental remediation costs. Cash outflows for capital expenditures for 2013, 2012 and 2011 amounted to $316.6 million, $253.8 million and $193.1 million, respectively. Management estimates net cash outflows for construction projects for 2014, 2015 and 2016 to be approximately $309.9 million, $319.1 million and $273.0 million, respectively. Costs for remediation projects, net of insurance reimbursements, for 2013, 2012 and 2011 amounted to net cash outflows of $0.4 million, $0.2 million and $13.6 million, respectively. Total cash outflows for remediation projects are expected to be approximately $13.9 million, $25.9 million and $21.1 million for 2014, 2015 and 2016, respectively. As discussed in Notes 10 and 15 to the consolidated financial statements, certain environmental costs are subject to recovery from insurance carriers and ratepayers.
40
STANDBY LETTERS OF CREDIT — As of December 31, 2013, SJI provided $26.8 million of standby letters of credit through SJI’s revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.
CONTRACTUAL OBLIGATIONS - SJG and SJRG have certain commitments for both pipeline capacity and gas supply for which they pay fees regardless of usage. Those commitments as of December 31, 2013, average $52.3 million annually and total $362.6 million over the contracts' lives. Approximately 46.6% of the financial commitments under these contracts expire during the next five years. These contracts are included in the Company's contractual obligations below. We expect to renew each of these contracts under renewal provisions as provided in each contract. SJG recovers all prudently incurred fees through rates via the BGSS clause.
In addition, in the normal course of business, SJG and SJRG have entered into long-term contracts for natural gas supplies. SJRG has committed to purchase a minimum of 545,500 dts/d and up to 810,000 dts/d of natural gas, from various suppliers, for terms ranging from three to ten years at index-based prices and has also committed to shorter term index deals of approximately 625,000 dts/d. SJG has committed to purchase a minimum of 6,250 dts/d and up to 25,000 dts/d of natural gas, from one supplier, for a term of eight years at index-based prices. The obligations for these purchases have not been included in the Company's contractual obligations discussed below because the actual volumes and prices are not fixed.
The following table summarizes our contractual cash obligations and their applicable payment due dates as of December 31, 2013 (in thousands):
Up to | Years | Years | More than | ||||||||||||
Contractual Cash Obligations | Total | 1 Year | 2 & 3 | 4 & 5 | 5 Years | ||||||||||
Long-Term Debt | $ | 701,400 | $ | 21,000 | $ | 152,818 | $ | 70,818 | $ | 456,764 | |||||
Interest on Long-Term Debt | 313,258 | 26,736 | 48,781 | 44,108 | 193,633 | ||||||||||
Construction Obligations | 32,149 | 32,149 | — | — | — | ||||||||||
Operating Leases | 2,654 | 879 | 1,083 | 692 | — | ||||||||||
Commodity Supply Purchase Obligations | 524,128 | 177,360 | 172,786 | 56,118 | 117,864 | ||||||||||
New Jersey Clean Energy Program | 8,673 | 8,673 | — | — | — | ||||||||||
Other Purchase Obligations | 359 | 359 | — | — | — | ||||||||||
Total Contractual Cash Obligations | $ | 1,582,621 | $ | 267,156 | $ | 375,468 | $ | 171,736 | $ | 768,261 | |||||
Interest on long-term debt in the table above includes the related interest obligations through maturity as well as the impact of all interest rate swap agreements. Expected environmental remediation costs, asset retirement obligations and the liability for unrecognized tax benefits are not included in the table above as the total obligation cannot be calculated due to the subjective nature of these costs and timing of anticipated payments. SJI made contributions to its employee pension plans totaling $12.7 million in January 2013 and $25.0 million in January 2012. However, future pension contributions beyond 2013 cannot be determined at this time. SJG's regulatory obligation to contribute $3.6 million annually to its postretirement benefit plans’ trusts, as discussed in Note 12 to the consolidated financial statements, is also not included as its duration is indefinite.
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South Jersey Industries, Inc.
Part II
Off-Balance Sheet Arrangements - An off-balance sheet arrangement is any contractual arrangement involving an unconsolidated entity under which the company has either made guarantees or has certain other interests or obligations.
The Company has recorded a liability of $0.7 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the consolidated balance sheets as of December 31, 2013 for the fair value of the following guarantees:
In April 2007, SJI guaranteed certain obligations of LVE Energy Partners, LLC (LVE) an unconsolidated joint venture in which Marina had a 50% equity interest. LVE entered into a 25-year contract with a resort developer to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada. LVE began construction of the facility in 2007 and expected to provide full energy service in 2010 when the resort was originally scheduled to be completed. LVE suspended construction of the district energy system and central energy center in January 2009 after the resort developer’s announcement that it was delaying the completion of construction of the resort.
In March 2013, the resort developer purchased substantially all of the assets of LVE. As a result, the guarantees provided by SJI of certain performance obligations of LVE under the operating agreements between LVE and the resort developer were canceled.
During the twelve months ended December 31, 2013, the Company received $57.9 million of repayments of advances to LVE and a $7.9 million note receivable from a third party. As of December 31, 2013, LVE was dissolved and the Company incurred a $0.8 million charge to write-off the remaining interest. During 2013, SJI provided support to LVE of approximately $3.2 million to cover interest and other project related costs.
SJI has guaranteed certain obligations of WC Landfill Energy, LLC (WCLE) and BC Landfill Energy, LLC (BCLE), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. WCLE and BCLE have entered into agreements through 2018 and 2027, respectively, with the respective county governments to lease and operate facilities that will produce electricity from landfill methane gas. Although unlikely, the maximum amount that SJI could be obligated for, in the event that WCLE and BCLE do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due, is approximately $4.2 million each year. SJI and its partner in these joint ventures have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees. SJI holds variable interests in WCLE and BCLE but is not the primary beneficiary.
In December 2013, SJI entered into an agreement to guarantee certain obligations of WCLE, SC Landfill Energy, LLC, SX Landfill Energy, LLC, FC Landfill Energy, LLC, and AC Landfill Energy, LLC (collectively, the "Landfills"), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. The landfills have entered into long-term debt agreements which run through 2020. Although unlikely, SJI could be liable through the guarantee for 50% of the outstanding debt along with any interest related to the debt in the event the landfills do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due. As of December 31, 2013, 50% of the currently outstanding debt is $9.7 million. As a result, the Company has recorded a liability of $0.5 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the consolidated balance sheets as of December 31, 2013.
In February 2011, ACR Energy Partners, LLC (ACR), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 20-year contract with a developer to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012 and as a result, ACR is providing full energy services to the complex. Marina and its joint venture partner have agreed to provide a $5.0 million letter of credit to support certain operating performance obligations of ACR under the operating agreements between ACR and the developer. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI to or on behalf of ACR.
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South Jersey Industries, Inc.
Part II
In May 2012, UMM Energy Partners, LLC (UMM), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 30-year contract with a public university to build, own and operate a combined heating, cooling and power system for its main campus in New Jersey. The system commenced commercial operations in September 2013. SJI has guaranteed certain obligations of UMM under the operating and lease agreements between UMM and the university, for the terms of the agreements, commencing with the first year of operations. SJI has guaranteed up to $2.2 million for the first year. This amount is adjusted each year based upon the Consumer Price Index. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.
As of December 31, 2013, SJI had issued $6.8 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.
PENDING LITIGATION - The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.0 million and $3.1 million related to all claims in the aggregate as of December 31, 2013 and 2012, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows.
MARKET RISKS:
Commodity Market Risks - Certain regulated and nonregulated SJI subsidiaries are involved in buying, selling, transporting and storing natural gas and buying and selling retail electricity for their own accounts as well as managing these activities for other third parties. These subsidiaries are subject to market risk due to price fluctuations. To hedge against this risk, we enter into a variety of physical and financial transactions including forward contracts, swaps, futures and options agreements. To manage these transactions, SJI has a well-defined risk management policy approved by our Board of Directors that includes volumetric and monetary limits. Management reviews reports detailing activity daily. Generally, the derivative activities described above are entered into for risk management purposes.
As part of its gas purchasing strategy, SJG uses financial contracts to hedge against forward price risk. These contracts are recoverable through SJG's BGSS, subject to BPU approval.
SJE transacts commodities on a physical basis and typically does not enter into financial derivative positions directly. SJRG manages risk in the natural gas markets for SJE as well as for its own portfolio by entering into the types of transactions noted above. It is management's policy, to the extent practical, within predetermined risk management policy guidelines, to have limited unmatched positions on a deal or portfolio basis while conducting these activities. As a result of holding open positions to a minimal level, the economic impact of changes in value of a particular transaction is substantially offset by an opposite change in the related hedge transaction.
SJI has entered into certain contracts to buy, sell, and transport natural gas and to buy and sell retail electricity. SJI recorded the net unrealized pre-tax (loss) gain on these contracts of $(25.8) million, $(0.2) million and $5.4 million in earnings during the years 2013, 2012 and 2011, respectively, which are included with realized gains and losses in Operating Revenues - Nonutility.
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South Jersey Industries, Inc.
Part II
The fair value and maturity of these energy-trading contracts determined under the mark-to-market method as of December 31, 2013 is as follows (in thousands):
Assets | ||||||||||||
Source of Fair Value | Maturity < 1 Year | Maturity 1 - 3 Years | Maturity Beyond 3 Years | Total | ||||||||
Prices actively quoted | $ | 3,417 | $ | 968 | $ | — | $ | 4,385 | ||||
Prices provided by other external sources | 18,673 | 8,052 | 457 | 27,182 | ||||||||
Prices based on internal models or other valuation methods | 34,237 | 13,663 | 3,311 | 51,211 | ||||||||
Total | $ | 56,327 | $ | 22,683 | $ | 3,768 | $ | 82,778 | ||||
Liabilities | ||||||||||||
Source of Fair Value | Maturity < 1 Year | Maturity 1 - 3 Years | Maturity Beyond 3 Years | Total | ||||||||
Prices actively quoted | $ | 3,571 | $ | 665 | $ | — | $ | 4,236 | ||||
Prices provided by other external sources | 36,736 | 15,824 | 212 | 52,772 | ||||||||
Prices based on internal models or other valuation methods | 37,686 | 4,804 | 626 | 43,116 | ||||||||
Total | $ | 77,993 | $ | 21,293 | $ | 838 | $ | 100,124 | ||||
NYMEX (New York Mercantile Exchange) is the primary national commodities exchange on which natural gas is traded. Basis represents the differential to the NYMEX natural gas futures contract for delivering gas to a specific location. Fixed Price Gas Daily represents the price of a NYMEX natural gas futures contract adjusted for the difference in price for delivering the gas at another location. Contracted volumes of our NYMEX contracts included in the table above are 0.5 million dekatherms (dts) with a weighted average settlement price of $4.09 per dt. Contracted volumes of our basis contracts included in the table above are 33.4 million dts with a weighted average settlement price of$(0.04) per dt. Contracted volumes of our Fixed Price Gas Daily contracts included in the table above are 1.8 million dts with a weighted average settlement price of $4.05 per dt. Contracted volumes of our discounted index related purchase and sales contracts included in the table above are 55.2 million dts with a weighted average settlement price of $(0.04) per dt. Contracted volumes of electric included in the table above are less than 0.1 million mwh with a weighted average settlement price of $48.74 per mwh.
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A reconciliation of SJI's estimated net fair value of energy-related derivatives follows (in thousands):
Net Derivatives - Energy Related Assets, January 1, 2013 | $ | 7,308 | |
Contracts Settled During 2013, Net | (414 | ) | |
Other Changes in Fair Value from Continuing and New Contracts, Net | (24,240 | ) | |
Net Derivatives - Energy Related Liabilities, December 31, 2013 | $ | (17,346 | ) |
Interest Rate Risk - Our exposure to interest-rate risk relates primarily to short-term, variable-rate borrowings. Short-term, variable-rate debt outstanding at December 31, 2013 was $353.9 million and averaged $325.6 million during 2013. A hypothetical 100 basis point (1%) increase in interest rates on our average variable-rate debt outstanding would result in a $1.9 million increase in our annual interest expense, net of tax. The 100 basis point increase was chosen for illustrative purposes, as it provides a simple basis for calculating the impact of interest rate changes under a variety of interest rate scenarios. Over the past five years, the change in basis points (b.p.) of our average monthly interest rates from the beginning to end of each year was as follows: 2013 - 16 b.p. decrease; 2012 - 9 b.p. decrease; 2011 - 33 b.p. increase; 2010 - 13 b.p. decrease; and 2009 - 29 b.p. decrease. For December 2013, our average interest rate on short-term, variable-rate debt was 1.21%.
We issue long-term debt either at fixed rates or use interest rate derivatives to limit our exposure to changes in interest rates on variable-rate, long-term debt. As of December 31, 2013, the interest costs on all but $77.1 million of our long-term debt was either at a fixed-rate or hedged via an interest rate derivative. Consequently, interest expense on existing long-term debt is not significantly impacted by changes in market interest rates.
As of December 31, 2013, SJI's active interest rate swaps were as follows:
Notional Amount | Fixed Interest Rate | Start Date | Maturity | Type of Debt | Obligor | |||||||
$ | 3,900,000 | 4.795% | 12/1/2004 | 12/1/2014 | Taxable | Marina | ||||||
$ | 8,000,000 | 4.775% | 11/12/2004 | 11/12/2014 | Taxable | Marina | ||||||
$ | 14,500,000 | 3.905% | 3/17/2006 | 1/15/2026 | Tax-exempt | Marina | ||||||
$ | 500,000 | 3.905% | 3/17/2006 | 1/15/2026 | Tax-exempt | Marina | ||||||
$ | 330,000 | 3.905% | 3/17/2006 | 1/15/2026 | Tax-exempt | Marina | ||||||
$ | 7,100,000 | 4.895% | 2/1/2006 | 2/1/2016 | Taxable | Marina | ||||||
$ | 12,500,000 | 3.430% | 12/1/2006 | 2/1/2036 | Tax-exempt | SJG | ||||||
$ | 12,500,000 | 3.430% | 12/1/2006 | 2/1/2036 | Tax-exempt | SJG | ||||||
Credit Risk - As of December 31, 2013, approximately $28.1 million, or 33.9%, of the current and noncurrent Derivatives – Energy Related Assets are with two counterparties. One of these counterparties has contracts with a large number of diverse customers which minimizes the concentration of this risk. A portion of these contracts may be assigned to SJI in the event of a default by the counterparty.
As of December 31, 2013, SJRG had $140.2 million of Accounts Receivable under sales contracts. Of that total, 87.1% were with regulated utilities or companies rated investment-grade or guaranteed by an investment-grade-rated parent or were with companies where we have a collateral arrangement or insurance coverage. The remainder of the Accounts Receivable were within approved credit limits.
Item 7A. Quantitative and Qualitative Disclosures about Market Risks
Information required by this item can be found in the section entitled “Market Risks” on page 43 of this Report.
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Item 8. Financial Statements and Supplementary Data
Statements of Consolidated Income
(In Thousands Except for Per Share Data)
South Jersey Industries, Inc. and Subsidiaries | |||||||||||
Year Ended December 31, | |||||||||||
2013 | 2012 | 2011 | |||||||||
Operating Revenues: | |||||||||||
Utility | $ | 444,920 | $ | 420,818 | $ | 405,742 | |||||
Nonutility | 286,501 | 285,462 | 422,818 | ||||||||
Total Operating Revenues | 731,421 | 706,280 | 828,560 | ||||||||
Operating Expenses: | |||||||||||
Cost of Sales - (Excluding depreciation) | |||||||||||
- Utility | 198,521 | 187,655 | 181,158 | ||||||||
- Nonutility | 270,470 | 230,147 | 363,834 | ||||||||
Operations | 120,205 | 113,643 | 100,901 | ||||||||
Maintenance | 13,136 | 13,615 | 13,122 | ||||||||
Depreciation | 49,637 | 41,336 | 35,749 | ||||||||
Energy and Other Taxes | 9,816 | 9,986 | 12,189 | ||||||||
Total Operating Expenses | 661,785 | 596,382 | 706,953 | ||||||||
Operating Income | 69,636 | 109,898 | 121,607 | ||||||||
Other Income and Expense | 10,979 | 11,104 | 15,642 | ||||||||
Interest Charges | (18,825 | ) | (18,986 | ) | (24,078 | ) | |||||
Income Before Income Taxes | 61,790 | 102,016 | 113,171 | ||||||||
Income Taxes | 19,014 | (11,479 | ) | (22,502 | ) | ||||||
Equity in Earnings (Loss) of Affiliated Companies | 1,585 | 2,239 | (810 | ) | |||||||
Income from Continuing Operations | 82,389 | 92,776 | 89,859 | ||||||||
Loss from Discontinued Operations - (Net of tax benefit) | (796 | ) | (1,168 | ) | (568 | ) | |||||
Net Income | $ | 81,593 | $ | 91,608 | $ | 89,291 | |||||
Basic Earnings per Common Share: | |||||||||||
Continuing Operations | $ | 2.58 | $ | 3.02 | $ | 3.00 | |||||
Discontinued Operations | (0.03 | ) | (0.04 | ) | (0.02 | ) | |||||
Basic Earnings per Common Share | $ | 2.55 | $ | 2.98 | $ | 2.98 | |||||
Average Shares of Common Stock Outstanding - Basic | 31,989 | 30,744 | 30,000 | ||||||||
Diluted Earnings per Common Share: | |||||||||||
Continuing Operations | $ | 2.57 | $ | 3.01 | $ | 2.99 | |||||
Discontinued Operations | (0.02 | ) | (0.04 | ) | (0.02 | ) | |||||
Diluted Earnings per Common Share | $ | 2.55 | $ | 2.97 | $ | 2.97 | |||||
Average Shares of Common Stock Outstanding - Diluted | 32,046 | 30,824 | 30,086 | ||||||||
The accompanying notes are an integral part of the consolidated financial statements.
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Statements of Consolidated Comprehensive Income
(In Thousands)
South Jersey Industries, Inc. and Subsidiaries | |||||||||||
Year Ended December 31, | |||||||||||
2013 | 2012 | 2011 | |||||||||
Net Income | $ | 81,593 | $ | 91,608 | $ | 89,291 | |||||
Other Comprehensive Income (Loss), Net of Tax:* | |||||||||||
Postretirement Liability Adjustment | 4,934 | (1,842 | ) | (5,667 | ) | ||||||
Unrealized Gain (Loss) on Available-for-Sale Securities | 103 | 500 | (360 | ) | |||||||
Unrealized Gain (Loss) on Derivatives - Other | 265 | (92 | ) | (788 | ) | ||||||
Other Comprehensive Income (Loss) of Affiliated Companies | 5,043 | (1,233 | ) | 189 | |||||||
Other Comprehensive Income (Loss) - Net of Tax* | 10,345 | (2,667 | ) | (6,626 | ) | ||||||
Comprehensive Income | 91,938 | 88,941 | 82,665 | ||||||||
* Determined using a combined statutory tax rate of 41%.
The accompanying notes are an integral part of the consolidated financial statements.
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Statements of Consolidated Cash Flows
(In Thousands)
South Jersey Industries, Inc. and Subsidiaries | |||||||||||
Year Ended December 31, | |||||||||||
2013 | 2012 | 2011 | |||||||||
Cash Flows from Operating Activities: | |||||||||||
Net Income | $ | 81,593 | $ | 91,608 | $ | 89,291 | |||||
Loss from Discontinued Operations | 796 | 1,168 | 568 | ||||||||
Income from Continuing Operations | 82,389 | 92,776 | 89,859 | ||||||||
Adjustments to Reconcile Income from Continuing Operations to Net Cash Provided by Operating Activities: | |||||||||||
Depreciation and Amortization | 64,890 | 55,089 | 47,759 | ||||||||
Net Unrealized Loss (Gain) on Derivatives - Energy Related | 25,823 | 193 | (5,377 | ) | |||||||
Unrealized (Gain) Loss on Derivatives - Other | (2,760 | ) | (660 | ) | 149 | ||||||
Unrealized Loss on Property, Plant and Equipment | — | 3,506 | — | ||||||||
Provision for Losses on Accounts Receivable | 4,245 | 4,932 | 2,272 | ||||||||
CIP Receivable | 21,160 | (18,106 | ) | (1,289 | ) | ||||||
Deferred Gas Costs - Net of Recoveries | 5,473 | 25,050 | (37,343 | ) | |||||||
Deferred SBC Costs - Net of Recoveries | 2,393 | (4,183 | ) | (4,402 | ) | ||||||
Stock-Based Compensation Expense | 3,001 | 2,992 | 2,511 | ||||||||
Deferred and Noncurrent Income Taxes - Net | (21,549 | ) | 20,306 | 23,303 | |||||||
Environmental Remediation Costs - Net | (367 | ) | (186 | ) | (13,608 | ) | |||||
Gas Plant Cost of Removal | (6,092 | ) | (2,133 | ) | (1,590 | ) | |||||
Pension Contribution | (12,700 | ) | (25,000 | ) | — | ||||||
Changes in: | |||||||||||
Accounts Receivable | (67,825 | ) | (59,701 | ) | 90,407 | ||||||
Inventories | (2,449 | ) | 13,481 | 1,905 | |||||||
Prepaid and Accrued Taxes - Net | 17,703 | (4,635 | ) | 5,398 | |||||||
Accounts Payable and Other Accrued Liabilities | 49,444 | 18,829 | (6,131 | ) | |||||||
Derivatives - Energy Related | 1,500 | 306 | 740 | ||||||||
Other Assets and Liabilities | (3,769 | ) | (4,211 | ) | (2,245 | ) | |||||
Cash Flows from Discontinued Operations | (975 | ) | (819 | ) | (961 | ) | |||||
Net Cash Provided by Operating Activities | 159,535 | 117,826 | 191,357 | ||||||||
Cash Flows from Investing Activities: | |||||||||||
Capital Expenditures | (316,644 | ) | (253,845 | ) | (193,119 | ) | |||||
Proceeds from Sale of Property, Plant and Equipment | — | 29 | 3,500 | ||||||||
Net (Purchase of) Proceeds from Sale of Restricted Investments in Margin Accounts | (25,164 | ) | 755 | (10,269 | ) | ||||||
Investment in Long-Term Receivables | (7,182 | ) | (6,243 | ) | (4,926 | ) | |||||
Proceeds from Long-Term Receivables | 5,764 | 8,182 | 6,312 | ||||||||
Purchase of Company Owned Life Insurance | (5,149 | ) | (4,547 | ) | (4,628 | ) | |||||
Investment in Affiliate | (2,973 | ) | (39,431 | ) | (23,043 | ) | |||||
Return of Investment in Affiliate | — | — | 2,339 | ||||||||
Advances on Notes Receivable - Affiliate | (19,349 | ) | (67,943 | ) | (41,612 | ) | |||||
Repayment of Notes Receivable - Affiliate | 124,946 | 13,402 | 47,694 | ||||||||
Other | (41 | ) | (6,276 | ) | (6,423 | ) | |||||
Net Cash Used in Investing Activities | (245,792 | ) | (355,917 | ) | (224,175 | ) | |||||
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Cash Flows from Financing Activities: | |||||||||||
Net Borrowings from Short-Term Credit Facilities | 65,000 | 17,500 | 70,714 | ||||||||
Proceeds from Issuance of Long-Term Debt | 50,000 | 235,000 | — | ||||||||
Payments for Issuance of Long-Term Debt | (411 | ) | (1,788 | ) | (43 | ) | |||||
Principal Repayments of Long-Term Debt | (25,000 | ) | (35,000 | ) | (25,000 | ) | |||||
Premium for Early Retirement of Debt | — | (700 | ) | — | |||||||
Dividends on Common Stock | (57,679 | ) | (50,942 | ) | (44,975 | ) | |||||
Proceeds from Sale of Common Stock | 54,028 | 70,241 | 13,436 | ||||||||
Proceeds from Finance Obligation | — | — | 23,482 | ||||||||
Other | (501 | ) | 880 | 379 | |||||||
Net Cash Provided by Financing Activities | 85,437 | 235,191 | 37,993 | ||||||||
Net (Decrease) Increase in Cash and Cash Equivalents | (820 | ) | (2,900 | ) | 5,175 | ||||||
Cash and Cash Equivalents at Beginning of Year | 4,638 | 7,538 | 2,363 | ||||||||
Cash and Cash Equivalents at End of Year | $ | 3,818 | $ | 4,638 | $ | 7,538 | |||||
Supplemental Disclosures of Cash Flow Information | |||||||||||
Cash paid during the year for: | |||||||||||
Interest (Net of Amounts Capitalized) | $ | 18,584 | $ | 18,442 | $ | 25,303 | |||||
Income Taxes (Net of Refunds) | $ | (12,387 | ) | $ | 218 | $ | (9,861 | ) | |||
Supplemental Disclosures of Non-Cash Investing Activities | |||||||||||
Capital Expenditures acquired on account but unpaid as of year-end | $ | 44,874 | $ | 34,086 | $ | 20,457 | |||||
Reclass from Notes Receivable Affiliate to Investment in Affiliates | $ | — | $ | 2,952 | $ | 5,351 | |||||
Notes Receivable from Affiliate Exchanged for Notes Receivable from a Third Party | $ | 7,882 | $ | — | $ | — | |||||
Notes Receivable Affiliate Exchanged for Accounts Receivable | $ | — | $ | — | $ | 1,783 | |||||
The accompanying notes are an integral part of the consolidated financial statements.
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Consolidated Balance Sheets
(In Thousands)
South Jersey Industries, Inc. and Subsidiaries | |||||||
December 31, | |||||||
2013 | 2012 | ||||||
Assets | |||||||
Property, Plant and Equipment: | |||||||
Utility Plant, at original cost | $ | 1,816,804 | $ | 1,658,790 | |||
Accumulated Depreciation | (392,029 | ) | (373,199 | ) | |||
Nonutility Property and Equipment, at cost | 486,332 | 328,638 | |||||
Accumulated Depreciation | (52,009 | ) | (36,208 | ) | |||
Property, Plant and Equipment - Net | 1,859,098 | 1,578,021 | |||||
Investments: | |||||||
Available-for-Sale Securities | 8,716 | 7,538 | |||||
Restricted | 43,115 | 17,903 | |||||
Investment in Affiliates | 78,273 | 75,825 | |||||
Total Investments | 130,104 | 101,266 | |||||
Current Assets: | |||||||
Cash and Cash Equivalents | 3,818 | 4,638 | |||||
Accounts Receivable | 253,566 | 195,293 | |||||
Unbilled Revenues | 47,594 | 40,938 | |||||
Provision for Uncollectibles | (5,854 | ) | (5,924 | ) | |||
Notes Receivable - Affiliate | 8,908 | 39,495 | |||||
Natural Gas in Storage, average cost | 57,786 | 55,517 | |||||
Materials and Supplies, average cost | 2,798 | 2,618 | |||||
Deferred Income Taxes - Net | 30,609 | — | |||||
Prepaid Taxes | 9,431 | 26,187 | |||||
Derivatives - Energy Related Assets | 56,327 | 24,242 | |||||
Other Prepayments and Current Assets | 17,915 | 11,833 | |||||
Total Current Assets | 482,898 | 394,837 | |||||
Regulatory and Other Noncurrent Assets: | |||||||
Regulatory Assets | 296,081 | 352,656 | |||||
Derivatives - Energy Related Assets | 26,451 | 12,297 | |||||
Unamortized Debt Issuance Costs | 7,803 | 8,226 | |||||
Notes Receivable - Affiliate | 39,907 | 117,188 | |||||
Contract Receivables | 14,595 | 13,985 | |||||
Notes Receivable | 7,882 | — | |||||
Other | 60,036 | 52,964 | |||||
Total Regulatory and Other Noncurrent Assets | 452,755 | 557,316 | |||||
Total Assets | $ | 2,924,855 | $ | 2,631,440 | |||
The accompanying notes are an integral part of the consolidated financial statements.
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2013 | 2012 | ||||||
Capitalization and Liabilities | |||||||
Equity: | |||||||
Common Stock: Par Value $1.25 per share; Authorized 60,000,000 shares; Outstanding Shares: 32,715,042 (2013) and 31,653,262 (2012) | |||||||
Balance at Beginning of Year | $ | 39,567 | $ | 37,765 | |||
Common Stock Issued or Granted Under Stock Plans | 1,327 | 1,802 | |||||
Balance at End of Year | 40,894 | 39,567 | |||||
Premium on Common Stock | 401,011 | 345,807 | |||||
Treasury Stock (at par) | (186 | ) | (182 | ) | |||
Accumulated Other Comprehensive Loss | (20,760 | ) | (31,105 | ) | |||
Retained Earnings | 406,041 | 382,127 | |||||
Total Equity | 827,000 | 736,214 | |||||
Long-Term Debt | 680,400 | 601,400 | |||||
Total Capitalization | 1,507,400 | 1,337,614 | |||||
Current Liabilities: | |||||||
Notes Payable | 353,900 | 338,900 | |||||
Current Portion of Long-Term Debt | 21,000 | 25,000 | |||||
Accounts Payable | 259,757 | 193,331 | |||||
Customer Deposits and Credit Balances | 15,546 | 17,757 | |||||
Environmental Remediation Costs | 16,695 | 21,026 | |||||
Taxes Accrued | 3,234 | 2,156 | |||||
Derivatives - Energy Related Liabilities | 77,993 | 23,828 | |||||
Deferred Income Taxes - Net | — | 10,812 | |||||
Interest Accrued | 6,363 | 6,635 | |||||
Pension Benefits | 1,275 | 1,272 | |||||
Other Current Liabilities | 9,210 | 11,127 | |||||
Total Current Liabilities | 764,973 | 651,844 | |||||
Deferred Credits and Other Noncurrent Liabilities: | |||||||
Deferred Income Taxes - Net | 319,368 | 289,489 | |||||
Investment Tax Credits | 360 | 618 | |||||
Pension and Other Postretirement Benefits | 57,370 | 105,168 | |||||
Environmental Remediation Costs | 106,734 | 91,072 | |||||
Asset Retirement Obligations | 41,687 | 39,385 | |||||
Derivatives - Energy Related Liabilities | 22,131 | 5,403 | |||||
Derivatives - Other | 6,676 | 13,462 | |||||
Regulatory Liabilities | 60,949 | 56,517 | |||||
Finance Obligation | 20,656 | 21,646 | |||||
Other | 16,551 | 19,222 | |||||
Total Deferred Credits and Other Noncurrent Liabilities | 652,482 | 641,982 | |||||
Commitments and Contingencies (Note 15) | |||||||
Total Capitalization and Liabilities | $ | 2,924,855 | $ | 2,631,440 | |||
The accompanying notes are an integral part of the consolidated financial statements.
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Consolidated Statements of Changes in Equity and Comprehensive Income
(In Thousands)
South Jersey Industries, Inc. and Subsidiaries | ||||||||||||||||||||||||
Years Ended December 31, 2011, 2012 & 2013 | ||||||||||||||||||||||||
Common Stock | Premium on Common Stock | Treasury Stock | Accumulated Other Comprehensive Loss | Retained Earnings | Total | |||||||||||||||||||
Balance at January 1, 2011 | $ | 37,341 | $ | 257,274 | $ | (179 | ) | $ | (21,812 | ) | $ | 297,473 | $ | 570,097 | ||||||||||
Net Income | 89,291 | 89,291 | ||||||||||||||||||||||
Other Comprehensive Loss, Net of Tax (a) | (6,626 | ) | (6,626 | ) | ||||||||||||||||||||
Common Stock Issued or Granted Under Stock Plans | 424 | 16,029 | (14 | ) | (112 | ) | 16,327 | |||||||||||||||||
Cash Dividends Declared - Common Stock | (44,975 | ) | (44,975 | ) | ||||||||||||||||||||
Balance at December 31, 2011 | 37,765 | 273,303 | (193 | ) | (28,438 | ) | 341,677 | 624,114 | ||||||||||||||||
Net Income | 91,608 | 91,608 | ||||||||||||||||||||||
Other Comprehensive Loss, Net of Tax (a) | (2,667 | ) | (2,667 | ) | ||||||||||||||||||||
Common Stock Issued or Granted Under Stock Plans | 1,802 | 72,504 | 11 | (216 | ) | 74,101 | ||||||||||||||||||
Cash Dividends Declared - Common Stock | (50,942 | ) | (50,942 | ) | ||||||||||||||||||||
Balance at December 31, 2012 | 39,567 | 345,807 | (182 | ) | (31,105 | ) | 382,127 | 736,214 | ||||||||||||||||
Net Income | 81,593 | 81,593 | ||||||||||||||||||||||
Other Comprehensive Income, Net of Tax (a) | 10,345 | 10,345 | ||||||||||||||||||||||
Common Stock Issued or Granted Under Stock Plans | 1,327 | 55,204 | (4 | ) | 56,527 | |||||||||||||||||||
Cash Dividends Declared - Common Stock | (57,679 | ) | (57,679 | ) | ||||||||||||||||||||
Balance at December 31, 2013 | $ | 40,894 | $ | 401,011 | $ | (186 | ) | $ | (20,760 | ) | $ | 406,041 | $ | 827,000 | ||||||||||
(a) Determined using a combined statutory tax rate of 41% .
The accompanying notes are an integral part of the consolidated financial statements.
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Disclosure of Changes In Accumulated Other Comprehensive Loss Balances (a)
(In Thousands)
Postretirement Liability Adjustment | Unrealized Gain (Loss) on Derivatives-Other | Unrealized Gain (Loss) on Available- for-Sale Securities | Other Comprehensive Income (Loss) of Affiliated Companies | Accumulated Other Comprehensive Loss | ||||||||||||||||
Balance at January 1, 2011 | $ | (15,928 | ) | $ | (2,082 | ) | $ | 154 | $ | (3,956 | ) | $ | (21,812 | ) | ||||||
Changes During Year | (5,667 | ) | (788 | ) | (360 | ) | 189 | (6,626 | ) | |||||||||||
Balance at December 31, 2011 | (21,595 | ) | (2,870 | ) | (206 | ) | (3,767 | ) | (28,438 | ) | ||||||||||
Changes During Year | (1,842 | ) | (92 | ) | 500 | (1,233 | ) | (2,667 | ) | |||||||||||
Balance at December 31, 2012 | (23,437 | ) | (2,962 | ) | 294 | (5,000 | ) | (31,105 | ) | |||||||||||
Changes During Year | 4,934 | 265 | 103 | 5,043 | 10,345 | |||||||||||||||
Balance at December 31, 2013 | $ | (18,503 | ) | $ | (2,697 | ) | $ | 397 | $ | 43 | $ | (20,760 | ) | |||||||
(a) Determined using a combined statutory tax rate of 41% .
The accompanying notes are an integral part of the consolidated financial statements.
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Notes to Consolidated Financial Statements
1. | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES: |
GENERAL - South Jersey Industries, Inc. (SJI or the Company) currently provides a variety of energy related products and services primarily through the following subsidiaries:
▪ | South Jersey Gas Company (SJG) is a regulated natural gas utility. SJG distributes natural gas in the seven southernmost counties of New Jersey. |
▪ | South Jersey Energy Company (SJE) acquires and markets natural gas and electricity to retail end users and provides total energy management services to commercial and industrial customers. |
▪ | Marina Energy, LLC (Marina) develops and operates on-site energy-related projects. |
▪ | South Jersey Resources Group, LLC (SJRG) markets natural gas storage, commodity and transportation assets on a wholesale basis in the mid-Atlantic, Appalachian and southern states. |
▪ | South Jersey Energy Service Plus, LLC (SJESP) services residential and small commercial HVAC systems, installs small commercial HVAC systems, provides plumbing services and services appliances under warranty via a subcontractor arrangement. |
▪ | South Jersey Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania. |
BASIS OF PRESENTATION - The consolidated financial statements include the accounts of SJI, its wholly owned subsidiaries and subsidiaries in which SJI has a controlling interest. SJI eliminates all significant intercompany accounts and transactions. In management's opinion, the consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI's financial position and operating results at the dates and for the periods presented.
Certain reclassifications have been made to the prior periods regulatory assets disclosure to conform to the current period presentation. The deferred pipeline integrity cost previously included in "Other Regulatory Assets" was reclassified to the line item "Pipeline Integrity Cost" in the regulatory asset table disclosed in Note 11.
Certain reclassifications have been made to the prior period segment disclosures to conform to the current period presentation. In all periods presented, net receivables between the Discontinued Operations segment and the Corporate and Services segment have been reclassified in the Identifiable Assets Segment disclosure in Note 8.
EQUITY INVESTMENTS - Marketable equity securities that are purchased as long-term investments are classified as Available-for-Sale Securities and carried at their fair value on the consolidated balance sheets. Any unrealized gains or losses are included in Accumulated Other Comprehensive Loss. SJI, through wholly owned subsidiaries, holds significant variable interests in several companies but is not the primary beneficiary. Consequently, these investments are accounted for under the equity method. In the event that losses and/or distributions from these equity method investments exceed the carrying value, and the Company is obligated to provide additional financial support, the excess will be recorded as either a current or non-current liability on the consolidated balance sheets. We include the operations of these affiliated companies on a pre-tax basis in the statements of consolidated income under Equity in Earnings (Loss) of Affiliated Companies (See Note 3). An impairment loss is recorded when there is clear evidence that a decline in value is other than temporary. No impairment losses were recorded on Investments during 2013, 2012 or 2011.
ESTIMATES AND ASSUMPTIONS - We prepare our consolidated financial statements to conform with accounting principles generally accepted in the United States of America (GAAP). Management makes estimates and assumptions that affect the amounts reported in the consolidated financial statements and related disclosures. Therefore, actual results could differ from those estimates. Significant estimates include amounts related to regulatory accounting, energy derivatives, environmental remediation costs, pension and other postretirement benefit costs, and revenue recognition.
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REGULATION - SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU). See Note 10 for a detailed discussion of SJG's rate structure and regulatory actions. SJG maintains its accounts according to the BPU's prescribed Uniform System of Accounts. SJG follows the accounting for regulated enterprises prescribed by FASB ASC Topic 980 -”Regulated Operations.” In general, Topic 980 allows for the deferral of certain costs (regulatory assets) and creation of certain obligations (regulatory liabilities) when it is probable that such items will be recovered from or refunded to customers in future periods. See Note 11 for a detailed discussion of regulatory assets and liabilities.
OPERATING REVENUES - Gas and electric revenues are recognized in the period the commodity is delivered to customers. For SJG and SJE retail customers that are not billed at the end of the month, we record an estimate to recognize unbilled revenues for gas and electricity delivered from the date of the last meter reading to the end of the month. SJRG's gas revenues are recognized in the period the commodity is delivered. Realized and unrealized gains and losses on energy related derivative instruments are also recognized in operating revenues for SJRG. See further discussion under Derivative Instruments. We recognize revenues related to SJESP appliance service contracts on a monthly basis as work is completed or commissions are earned. Revenue related to services provided on a time and materials basis is recognized on a monthly basis as the services are provided. Marina recognizes revenue on a monthly basis as services are provided, as lease income is earned, and for on-site energy production that is delivered to its customers.
REVENUE AND THROUGHPUT-BASED TAXES — SJG collects certain revenue-based energy taxes from its customers. Such taxes include New Jersey State Sales Tax and Public Utilities Assessment (PUA). SJG also collects a throughput-based energy tax from customers in the form of a Transitional Energy Facility Assessment (TEFA). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. TEFA and PUA are included in both utility revenue and cost of sales and totaled $5.2 million, $6.0 million, and $8.0 million in 2013, 2012 and 2011, respectively. TEFA is subject to a planned phase-out which decreased the assessment in increments of 25.0% in 2012 and 2013, and is eliminated after December 31, 2013.
ACCOUNTS RECEIVABLE AND PROVISION FOR UNCOLLECTIBLE ACCOUNTS - Accounts receivable are carried at the amount owed by customers. A provision for uncollectible accounts is established based on our collection experience and an assessment of the collectibility of specific accounts.
PROPERTY, PLANT AND EQUIPMENT - For regulatory purposes, utility plant is stated at original cost, which may be different than SJG's cost if the assets were acquired from another regulated entity. Nonutility plant is stated at cost. The cost of adding, replacing and renewing property is charged to the appropriate plant account.
ASSET RETIREMENT OBLIGATIONS - The amounts included under Asset Retirement Obligations (ARO) are primarily related to the legal obligations the Company has to cut and cap gas distribution pipelines when taking those pipelines out of service in future years. These liabilities are generally recognized upon the acquisition or construction of the asset. The related asset retirement cost is capitalized concurrently by increasing the carrying amount of the related asset by the same amount as the liability. Changes in the liability are recorded for the passage of time (accretion) or for revisions to cash flows originally estimated to settle the ARO.
ARO activity was as follows (in thousands):
2013 | 2012 | |||||
AROs as of January 1, | 39,385 | 29,430 | ||||
Accretion | 1,530 | 1,872 | ||||
Additions | 743 | 1,438 | ||||
Settlements | (1,630 | ) | (1,603 | ) | ||
Revisions in Estimated Cash Flows (A) | 1,659 | 8,248 | ||||
ARO's as of December 31, | 41,687 | 39,385 | ||||
(A) The revision in estimated cash flows in 2013 reflects an increase in the inflation rate used to determine the ARO settlement amount. In 2012, the revision in estimated cash flows reflected increases in the contractual cost as well as changes in the discount rates used to determine the ARO. A corresponding increase was made to Regulatory Assets, thus having no impact on earnings.
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DEPRECIATION - We depreciate utility plant on a straight-line basis over the estimated remaining lives of the various property classes. These estimates are periodically reviewed and adjusted as required after BPU approval. The composite annual rate for all depreciable utility property was approximately 2.3% in 2013, 2.4% in 2012, and 2.3% in 2011. The actual composite rate may differ from the approved rate as the asset mix changes over time. Except for retirements outside of the normal course of business, accumulated depreciation is charged with the cost of depreciable utility property retired, less salvage. Nonutility property depreciation is computed on a straight-line basis over the estimated useful lives of the property, ranging up to 50 years. Gain or loss on the disposition of nonutility property is recognized in operating income.
CAPITALIZED INTEREST - SJG capitalizes interest on construction at the rate of return on the rate base utilized by the BPU to set rates in its last base rate proceeding (see Note 10). Marina capitalizes interest on construction projects in progress based on the actual cost of borrowed funds. SJG's amounts are included in Utility Plant and Marina's amounts are included in Nonutility Property and Equipment on the consolidated balance sheets. Interest Charges are presented net of capitalized interest on the consolidated statements of income. The amount of interest capitalized by SJI for the years ended December 31, 2013, 2012 and 2011 was $8.7 million, $6.5 million and $1.2 million, respectively.
IMPAIRMENT OF LONG-LIVED ASSETS - We review the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. During the year ended December 31, 2012, the Company recorded an impairment charge of $2.4 million within Operating Expenses on the consolidated statement of income due to a reduction in the expected cash flows to be received from a solar generating facility within the on-site energy production segment. The Company also recorded a $1.1 million impairment charge during the year ended December 31, 2012 related to certain shallow wells in the Marcellus region as discussed under “Gas Exploration and Development”. For the years ended December 31, 2013 and 2011, no significant impairments were identified.
DERIVATIVE INSTRUMENTS - SJI accounts for derivative instruments in accordance with FASB ASC Topic 815 - “Derivatives and Hedging.” We record all derivatives, whether designated in hedging relationships or not, on the consolidated balance sheets at fair value unless the derivative contracts qualify for the normal purchase and sale exemption. In general, if the derivative is designated as a fair value hedge, we recognize the changes in the fair value of the derivative and of the hedged item attributable to the hedged risk in earnings. We currently have no fair value hedges. If the derivative is designated as a cash flow hedge, we record the effective portion of the hedge in Accumulated Other Comprehensive Loss and recognize it in the income statement when the hedged item affects earnings. We recognize ineffective portions of the cash flow hedges immediately in earnings. We currently have no cash flow hedges. We formally document all relationships between hedging instruments and hedged items, as well as our risk management objectives, strategies for undertaking various hedge transactions and our methods for assessing and testing correlation and hedge ineffectiveness. All hedging instruments are linked to the hedged asset, liability, firm commitment or forecasted transaction. Due to the application of regulatory accounting principles under FASB ASC Topic 980, gains and losses on derivatives related to SJG's gas purchases are recorded through the Basic Gas Supply Service (BGSS) clause.
Initially and on an ongoing basis, we assess whether derivatives designated as hedges are highly effective in offsetting changes in cash flows or fair values of the hedged items. We discontinue hedge accounting prospectively if we decide to discontinue the hedging relationship; determine that the anticipated transaction is no longer likely to occur; or determine that a derivative is no longer highly effective as a hedge. In the event that hedge accounting is discontinued, we will continue to carry the derivative on the balance sheet at its current fair value and recognize subsequent changes in fair value in current period earnings. Unrealized gains and losses on the discontinued hedges that were previously included in Accumulated Other Comprehensive Loss will be reclassified into earnings when the forecasted transaction occurs, or when it is probable that it will not occur. In July 2012, hedge accounting was discontinued for all remaining derivatives that were designated as hedging instruments.
GAS EXPLORATION AND DEVELOPMENT - The Company capitalizes all costs associated with gas property acquisition, exploration and development activities under the full cost method of accounting. Capitalized costs include costs related to unproved properties, which are not amortized until proved reserves are found or it is determined that the unproved properties are impaired. All costs related to unproved properties are reviewed quarterly to determine if impairment has occurred. During the year ended December 31, 2012, the Company recorded $1.1 million of impairment charges within Other Income and Expense on the consolidated statement of income due to a reduction in the expected cash flows to be received from certain shallow wells in the Marcellus region. No impairment charges were recorded during the years ended December 31, 2013 and 2011. As of December 31, 2013 and 2012, $8.9 million and $9.0 million, respectively, related to interests in proved and unproved properties in Pennsylvania, net of amortization, are included with Nonutility Property and Equipment and Other Noncurrent Assets on the consolidated balance sheets.
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TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of December 31, 2013 and 2012, SJI held 148,890 and 145,414 shares of treasury stock, respectively. These shares are related to deferred compensation arrangements where the amounts earned are held in the stock of SJI.
INCOME TAXES - Deferred income taxes are provided for all significant temporary differences between the book and taxable bases of assets and liabilities in accordance with FASB ASC Topic 740 - “Income Taxes” (See Note 4). A valuation allowance is established when it is determined that it is more likely than not that a deferred tax asset will not be realized. Investment tax credits related to renewable energy facilities of the non-regulated entities are recognized on the flow through method.
CASH AND CASH EQUIVALENTS - For purposes of reporting cash flows, highly liquid investments with original maturities of three months or less are considered cash equivalents.
NEW ACCOUNTING PRONOUNCEMENTS - Other than as described below, no new accounting pronouncement issued or effective during 2013, 2012 or 2011 had, or is expected to have, a material impact on the consolidated financial statements.
In January 2012, the FASB issued ASU 2011-11, Enhanced Disclosure Requirements Concerning Offsetting of Financial Assets and Financial Liabilities. This ASU amends ASC 210-20 to add disclosure requirements in respect of the offsetting of financial assets and financial liabilities. In February 2013, the FASB issued ASU 2013-01 Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, which amends and clarifies the scope of the balance sheet offsetting disclosures required through ASU 2011-11. The new guidance is effective for fiscal years beginning on or after January 1, 2013. The adoption of this guidance modified the disclosures around derivative instruments, but did not have an impact on the Company's financial statement results.
In February 2013, the FASB issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This ASU expands the disclosure requirements in ASC 220 and requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective lines in net income. The ASU requires an entity to present information about significant items reclassified out of accumulated other comprehensive income by component either on the face of the statement where net income is presented, or as a separate disclosure in the notes to the financial statements. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. The adoption of this guidance modified the disclosures around accumulated other comprehensive income, but did not have an impact on the Company's financial statement results.
In July 2013, the FASB issued ASU 2013-11, Balance Sheet Presentation of an Unrecognized Income Tax Benefit for a Net Operating Loss or Tax Credit Carryforward. This ASU provides that a liability related to an unrecognized tax benefit should be offset against a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such settlement is required or expected in the event the uncertain tax position is disallowed. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. Management does not anticipate that the adoption of this guidance will have an impact on the Company's financial statement results.
2. | STOCK-BASED COMPENSATION PLAN: |
Under the Amended and Restated 1997 Stock-Based Compensation Plan, no more than 2,000,000 shares in the aggregate may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. The plan will terminate on January 26, 2015, unless terminated earlier by the Board of Directors. No options were granted or outstanding during the years ended December 31, 2013, 2012 and 2011. No stock appreciation rights have been issued under the plan. During the years ended December 31, 2013, 2012 and 2011, SJI granted 56,464, 40,955 and 40,711 restricted shares to Officers and other key employees, respectively. These restricted shares vest over a three-year period and are subject to SJI achieving certain market and earnings based performance targets as compared to a peer group average, which can cause the actual amount of shares that ultimately vest to range from between 0% to 150% of the original share units granted.
Grants containing market-based performance targets have been issued in each of the last three years and use SJI's total shareholder return (TSR) relative to a peer group to measure performance. As TSR-based grants are contingent upon market and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant on a straight-line basis over the requisite three-year service period of each award. In addition, SJI identifies specific forfeitures of share-based awards and compensation expense is adjusted accordingly over the requisite service period. Compensation expense is not adjusted based on the actual achievement of performance goals. The fair value of TSR-based restricted stock awards on the date of grant is estimated using a Monte Carlo simulation model.
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Beginning with 2012, grants containing earnings-based targets have also been issued. These new grants are based on SJI's earnings per share (EPS) growth rate relative to a peer group to measure performance. As EPS-based grants are contingent upon performance and service conditions, SJI is required to measure and recognize stock-based compensation expense based on the fair value at the date of grant over the requisite three-year period of each award. The fair value is measured as the market price at the date of grant. The initial accruals of compensation expense are based on the estimated number of shares expected to vest, assuming the requisite service is rendered and probable outcome of the performance condition is achieved. That estimate is revised if subsequent information indicates that the actual number of shares is likely to differ from previous estimates. Compensation expense is ultimately adjusted based on the actual achievement of service and performance goals.
SJI granted 12,285, 9,904 and 12,220 restricted shares to Directors in 2013, 2012 and 2011, respectively. Shares issued to Directors in 2011 vest over a three-year service period and contain no performance conditions. Shares issued to Directors in 2013 and 2012 vest over twelve months and contain no performance conditions. As a result, 100% of the shares granted generally vest.
The following table summarizes the nonvested restricted stock awards outstanding at December 31, 2013 and the assumptions used to estimate the fair value of the awards:
Grant Date | Shares Outstanding | Fair Value Per Share | Expected Volatility | Risk-Free Interest Rate | ||||||||||
Officers & Key Employees - | Jan. 2012 - TSR | 19,810 | $ | 51.23 | 22.5 | % | 0.43 | % | ||||||
Jan. 2012 - EPS | 19,810 | $ | 56.93 | N/A | N/A | |||||||||
Jan. 2013 - TSR | 27,286 | $ | 44.38 | 21.1 | % | 0.40 | % | |||||||
Jan. 2013 - EPS | 27,286 | $ | 51.18 | N/A | N/A | |||||||||
Directors - | Jan. 2011 | 7,332 | $ | 52.94 | — | — | ||||||||
Jan. 2013 | 12,285 | $ | 51.74 | — | — | |||||||||
Expected volatility is based on the actual volatility of SJI’s share price over the preceding three-year period as of the valuation date. The risk-free interest rate is based on the zero-coupon U.S. Treasury Bond, with a term equal to the three-year term of the Officers’ and other key employees’ restricted shares. As notional dividend equivalents are credited to the holders, which are reinvested during the three-year service period, no reduction to the fair value of the award is required. As the Directors’ restricted stock awards contain no performance conditions and dividends are paid or credited to the holder during the requisite service period, the fair value of these awards are equal to the market value of the shares on the date of grant.
The following table summarizes the total stock-based compensation cost for the years ended December 31 (in thousands):
2013 | 2012 | 2011 | |||||||||
Officers & Key Employees | $ | 2,236 | $ | 2,096 | $ | 1,852 | |||||
Directors | 765 | 896 | 658 | ||||||||
Total Cost | 3,001 | 2,992 | 2,510 | ||||||||
Capitalized | (237 | ) | (231 | ) | (218 | ) | |||||
Net Expense | $ | 2,764 | $ | 2,761 | $ | 2,292 | |||||
As of December 31, 2013, there was $2.5 million of total unrecognized compensation cost related to nonvested share-based compensation awards granted under the restricted stock plans. That cost is expected to be recognized over a weighted average period of 1.7 years.
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The following table summarizes information regarding restricted stock award activity during 2013, excluding accrued dividend equivalents:
Officers & Other Key Employees | Directors | Weighted Average Fair Value | |||||||
Nonvested Shares Outstanding, January 1, 2013 | 81,005 | 27,688 | $ | 51.29 | |||||
Granted | 56,464 | 12,285 | $ | 48.49 | |||||
Vested* | (39,720 | ) | (20,356 | ) | $ | 49.20 | |||
Cancelled/Forfeited | (3,557 | ) | — | $ | 50.28 | ||||
Nonvested Shares Outstanding, December 31, 2013 | 94,192 | 19,617 | $ | 50.73 | |||||
*Performance targets during the three-year vesting period were not attained for the January 2011 grant. As a result, no shares will be awarded in 2014.
During the years ended December 31, 2013, 2012 and 2011, SJI awarded 66,077 shares to its Officers and other key employees at a market value of $3.3 million, 33,322 shares at a market value of $1.9 million, and 69,271 shares at a market value of $3.7 million, respectively. Also, during the years ended December 31, 2013, 2012 and 2011, SJI awarded 12,285, 9,904 and 12,220 shares to its Directors at a market value of $0.6 million for each year. The Company has a policy of issuing new shares to satisfy its obligations under these plans; therefore, there are no cash payment requirements resulting from the normal operation of this plan. However, a change in control could result in such shares becoming nonforfeitable or immediately payable in cash. At the discretion of the Officers, Directors and other key employees, the receipt of vested shares can be deferred until future periods. These deferred shares are included in Treasury Stock on the consolidated balance sheets.
3. | DISCONTINUED OPERATIONS AND AFFILATIONS: |
DISCONTINUED OPERATIONS - Discontinued Operations consist of the environmental remediation activities related to the properties of South Jersey Fuel, Inc. (SJF) and the product liability litigation and environmental remediation activities related to the prior business of The Morie Company, Inc. (Morie). SJF is a subsidiary of Energy & Minerals, Inc. (EMI), an SJI subsidiary, which previously operated a fuel oil business. Morie is the former sand mining and processing subsidiary of EMI. EMI sold the common stock of Morie in 1996.
SJI conducts tests annually to estimate the environmental remediation costs for these properties.
Summarized operating results of the discontinued operations for the years ended December 31, were (in thousands, except per share amounts):
2013 | 2012 | 2011 | |||||||||
Loss before Income Taxes: | |||||||||||
Sand Mining | $ | (406 | ) | $ | (1,396 | ) | $ | (169 | ) | ||
Fuel Oil | (816 | ) | (401 | ) | (701 | ) | |||||
Income Tax Benefits | 426 | 629 | 302 | ||||||||
Loss from Discontinued Operations — Net | $ | (796 | ) | $ | (1,168 | ) | $ | (568 | ) | ||
Earnings Per Common Share from | |||||||||||
Discontinued Operations — Net: | |||||||||||
Basic | $ | (0.03 | ) | $ | (0.04 | ) | $ | (0.02 | ) | ||
Diluted | $ | (0.02 | ) | $ | (0.04 | ) | $ | (0.02 | ) | ||
AFFILIATIONS — The following affiliated entities are accounted for under the equity method:
Energenic – US, LLC (Energenic) - Marina and a joint venture partner formed Energenic, in which Marina has a 50% equity interest Energenic develops and operates on-site, self-contained, energy-related projects.
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In April 2012, Energenic acquired The Energy Network, LLC, a holding company for the Hartford Steam Company, TEN Companies and CNE Power I, LLC. In conjunction with this acquisition, Marina provided $35.4 million of advances to Energenic, which were repaid by Energenic during the second quarter of 2013 when permanent financing was obtained.
Potato Creek, LLC (Potato Creek) - SJI and a joint venture partner formed Potato Creek, in which SJI has a 30% equity interest. Potato Creek owns and manages the oil, gas and mineral rights of certain real estate in Pennsylvania.
LVE Energy Partners, LLC (LVE) - In March 2013, substantially all of the assets of Marina's joint venture, LVE, an entity in which Marina has a 50% equity interest, were sold. As a result of the transaction, Marina received cash proceeds of $57.9 million. LVE was dissolved prior to December 31, 2013. See Note 15.
During 2013, 2012 and 2011, the Company made investments in, and provided net advances to, unconsolidated affiliates of $9.6 million, $94.0 million and $14.6 million, respectively. These amounts do not include the cash proceeds from LVE and the repayment of the advances to Energenic as discussed above. The purpose of these investments and advances was to cover certain project-related costs of affiliates. As of December 31, 2013 and 2012, the outstanding balance on these Notes Receivable – Affiliate was $48.8 million and $156.7 million, respectively. These notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025.
SJI holds significant variable interests in these entities but is not the primary beneficiary. Consequently, these entities are accounted for under the equity method because SJI does not have both a) the power to direct the activities of the entity that most significantly impact the entity’s economic performance and b) the obligation to absorb losses of the entity that could potentially be significant to the entity or the right to receive benefits from the entity that could potentially be significant to the entity. As of December 31, 2013, the Company had a net asset of approximately $78.3 million included in Investment in Affiliates and Other Noncurrent Liabilities on the consolidated balance sheets related to equity method investees, in addition to Notes Receivable – Affiliate as discussed above. SJI’s maximum exposure to loss from these entities as of December 31, 2013 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $127.1 million and the guarantees discussed in Note 15.
The following tables present summarized financial information of the total balances for all Affiliates (of which, on average, SJI has only a 50% equity interest) accounted for under the equity method (in thousands):
2013 | 2012 | |||||||
Current assets | $ | 57,725 | $ | 57,711 | ||||
Noncurrent assets | $ | 494,933 | $ | 759,996 | ||||
Current liabilities | $ | 60,355 | $ | 211,628 | ||||
Noncurrent liabilities | $ | 341,548 | $ | 460,560 | ||||
2013 | 2012 | 2011 | ||||||||||
Revenues | $ | 178,026 | $ | 148,009 | $ | 95,647 | ||||||
Cost of sales | $ | 91,228 | $ | 71,141 | $ | 64,181 | ||||||
Income from continuing operations | $ | 6,229 | $ | 5,795 | $ | 1,522 | ||||||
Net Income | $ | 6,229 | $ | 5,795 | $ | 1,522 | ||||||
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4. | INCOME TAXES: |
SJI files a consolidated federal income tax return. State income tax returns are filed on a separate company basis in states where SJI has operations and/or a requirement to file. Total income taxes applicable to operations differ from the tax that would have resulted by applying the statutory Federal income tax rate to pre-tax income for the following reasons (in thousands):
2013 | 2012 | 2011 | ||||||||||
Tax at Statutory Rate | $ | 22,181 | $ | 36,490 | $ | 39,326 | ||||||
Increase (Decrease) Resulting from: | ||||||||||||
State Income Taxes | 971 | 5,857 | 6,763 | |||||||||
ESOP | (1,176 | ) | (1,141 | ) | (1,063 | ) | ||||||
Amortization of Investment Tax Credits - Utility | (258 | ) | (287 | ) | (302 | ) | ||||||
Amortization of Flowthrough Depreciation | — | — | 526 | |||||||||
AFUDC | (916 | ) | (1,048 | ) | (729 | ) | ||||||
Investment and Other Tax Credits | (38,179 | ) | (26,574 | ) | (21,927 | ) | ||||||
Other - Net | (1,637 | ) | (1,818 | ) | (92 | ) | ||||||
Income Taxes: | ||||||||||||
Continuing Operations | (19,014 | ) | 11,479 | 22,502 | ||||||||
Discontinued Operations | (426 | ) | (629 | ) | (302 | ) | ||||||
Net Income Taxes | $ | (19,440 | ) | $ | 10,850 | $ | 22,200 | |||||
The provision for Income Taxes is comprised of the following (in thousands): | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Current: | ||||||||||||
Federal | $ | (273 | ) | $ | (8,761 | ) | $ | (844 | ) | |||
State | 3,066 | 221 | 345 | |||||||||
Total Current | 2,793 | (8,540 | ) | (499 | ) | |||||||
Deferred: | ||||||||||||
Federal | (19,978 | ) | 11,515 | 13,244 | ||||||||
State | (1,571 | ) | 8,791 | 10,059 | ||||||||
Total Deferred | (21,549 | ) | 20,306 | 23,303 | ||||||||
Investment Tax Credit - Utility | (258 | ) | (287 | ) | (302 | ) | ||||||
Income Taxes: | ||||||||||||
Continuing Operations | (19,014 | ) | 11,479 | 22,502 | ||||||||
Discontinued Operations | (426 | ) | (629 | ) | (302 | ) | ||||||
Net Income Taxes | $ | (19,440 | ) | $ | 10,850 | $ | 22,200 | |||||
Investment Tax Credits attributable to SJG are deferred and amortized at the annual rate of 3.0%, which approximates the life of related assets.
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The net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting and income tax purposes resulted in the following net deferred tax liabilities (assets) at December 31 (in thousands):
2013 | 2012 | |||||||
Current: | ||||||||
Net Operating Loss Carryforward | $ | (26,800 | ) | $ | (2,586 | ) | ||
Derivatives / Unrealized Gain | (8,608 | ) | 257 | |||||
Conservation Incentive Program | 4,631 | 13,942 | ||||||
Budget Billing - Customer Accounts | 1,152 | 1,033 | ||||||
Provision for Uncollectibles | (1,994 | ) | (1,883 | ) | ||||
Other | 1,010 | 49 | ||||||
Current Deferred Tax (Asset) Liability - Net | $ | (30,609 | ) | $ | 10,812 | |||
Noncurrent: | ||||||||
Book versus Tax Basis of Property | $ | 476,039 | $ | 395,322 | ||||
Deferred Gas Costs - Net | 1,330 | 3,325 | ||||||
Environmental | 13,017 | 16,006 | ||||||
Deferred Regulatory Costs | 13,665 | 15,374 | ||||||
Deferred State Tax | (17,949 | ) | (17,924 | ) | ||||
Investment Tax Credit Basis Gross-Up | (185 | ) | (318 | ) | ||||
Deferred Pension & Other Post Retirement Benefits | 24,218 | 39,174 | ||||||
Pension & Other Post Retirement Benefits | (17,777 | ) | (33,739 | ) | ||||
Deferred Revenues | (9,593 | ) | (9,367 | ) | ||||
Derivatives / Unrealized Gain | 2,149 | (82 | ) | |||||
Net Operating Loss Carryforward | (90,818 | ) | (79,217 | ) | ||||
Investment and Other Tax Credits | (117,726 | ) | (71,547 | ) | ||||
Equity In Loss Of Affiliated Companies | 37,764 | 30,707 | ||||||
Other | 5,234 | 1,775 | ||||||
Noncurrent Deferred Tax Liability - Net | $ | 319,368 | $ | 289,489 | ||||
As of December 31, 2013, SJI has federal net operating loss carryforwards of $317.7 million and state net operating loss carryforwards of $105.4 million. Of these totals, $163.9 million and $45.9 million of the federal and state net operating loss carryforwards, respectively, will expire in 2031, $43.7 million and $19.4 million of the federal and state net operating loss carryforwards, respectively, will expire in 2032 and $110.1 million and $40.1 million of the federal and state net operating loss carryforwards, respectively, will expire in 2033. SJI also has investment tax credit carryforwards of $116.5 million, of which $11.6 million will expire in 2030, $26.6 million will expire in 2031,$32.1 million will expire in 2032 and $46.2 million will expire in 2033. SJI has $1.2 million of federal alternative minimum tax credits which have no expiration date. A valuation allowance is recorded when it is more likely than not that any of SJI's deferred tax assets will not be realized. SJI believes that it will generate sufficient future taxable income to realize the income tax benefits related to SJI's net deferred tax assets.
The total unrecognized tax benefits as of December 31, 2013, 2012, and 2011 were $0.5 million, $0.5 million, and $0.7 million, respectively, which excludes $0.6 million, $0.6 million, and $0.7 million of accrued interest and penalties, respectively.
A reconciliation of the beginning and ending amount of unrecognized tax benefits for the years ended December 31, is as follows (in thousands):
2013 | 2012 | 2011 | ||||||||||
Balance at January 1, | $ | 503 | $ | 736 | $ | 793 | ||||||
Increase as a result of tax positions taken in prior years | 44 | 108 | 119 | |||||||||
Decrease due to a lapse in the statute of limitations | — | (341 | ) | (90 | ) | |||||||
Settlements | — | — | (86 | ) | ||||||||
Balance at December 31, | $ | 547 | $ | 503 | $ | 736 | ||||||
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The amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate is not significant. The Company's policy is to record interest and penalties related to unrecognized tax benefits as interest expense and other expense, respectively. These amounts were not significant in 2013, 2012 or 2011. There have been no significant changes to the unrecognized tax benefits during 2013, 2012 or 2011 and the Company does not anticipate any significant changes in the total unrecognized tax benefits within the next 12 months.
The unrecognized tax benefits are primarily related to an uncertainty of state income tax issues relating to the Company's nexus in certain states. Federal and state income tax returns from 2009 forward are open and subject to examination.
5. | PREFERRED STOCK: |
REDEEMABLE CUMULATIVE PREFERRED STOCK - SJI has 2,500,000 authorized shares of Preference Stock, no par value, which has not been issued.
6. | COMMON STOCK: |
The following shares were issued and outstanding at December 31:
2013 | 2012 | 2011 | ||||||
Beginning of Year | 31,653,262 | 30,212,453 | 29,872,825 | |||||
New Issues During Year: | ||||||||
Dividend Reinvestment Plan | 983,417 | 1,397,583 | 259,359 | |||||
Stock-Based Compensation Plan | 78,363 | 43,226 | 80,269 | |||||
End of Year | 32,715,042 | 31,653,262 | 30,212,453 | |||||
The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value at December 31, 2013, 2012, and 2011 of approximately $55.2 million, $72.5 million, and $16.0 million, respectively, was recorded in Premium on Common Stock.
EARNINGS PER COMMON SHARE (EPS) — Basic EPS is based on the weighted-average number of common shares outstanding. The incremental shares required for inclusion in the denominator for the diluted EPS calculation were 57,760, 79,475, and 86,031 shares for the years ended December 31, 2013, 2012 and 2011, respectively. These shares relate to SJI’s restricted stock as discussed in Note 2.
DIVIDENDS PER SHARE - Dividends per share were $1.80, $1.65 and $1.50 for the years ended December 31, 2013, 2012 and 2011, respectively.
DIVIDEND REINVESTMENT PLAN (DRP) —The Company offers a DRP which allows participating shareholders to purchase shares of SJI common stock by automatic reinvestment of dividends or optional purchases. Shares of common stock offered by the DRP have been issued directly by SJI from its authorized but unissued shares of common stock. The Company raised $54.0 million and $70.2 million of equity capital through the DRP during the years ended December 31, 2013 and 2012, respectively.
7. | FINANCIAL INSTRUMENTS: |
RESTRICTED INVESTMENTS — In accordance with the terms of certain Marina and SJG loan agreements, unused proceeds are required to be escrowed pending approval of construction expenditures. As of both December 31, 2013 and 2012, the escrowed proceeds, including interest earned, totaled $1.3 million.
The Company maintains margin accounts with selected counterparties to support its risk management activities. The balances required to be held in these margin accounts increase as the net value of the outstanding energy related contracts with the respective counterparties decrease. As of December 31, 2013 and 2012, the balances in these accounts totaled $41.8 million and $16.6 million, respectively. The carrying amounts of the Restricted Investments approximate their fair values at December 31, 2013 and 2012, which would be included in Level 1 of the fair value hierarchy (See Note 17 - Fair Value of Financial Assets and Financial Liabilities).
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LONG-TERM RECEIVABLES — SJG provides financing to customers for the purpose of attracting conversions to natural gas heating systems from competing fuel sources. The terms of these loans call for customers to make monthly payments over a period of up to five years with no interest. The carrying amounts of such loans were $15.0 million and $13.6 million as of December 31, 2013 and 2012, respectively. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Contract Receivables on the consolidated balance sheets. The carrying amounts noted above are net of unamortized discounts resulting from imputed interest in the amount of $1.3 million as of both December 31, 2013 and 2012. The annual amortization to interest is not material to the Company’s consolidated financial statements. The carrying amounts of these receivables approximate their fair value at December 31, 2013 and 2012, which would be included in Level 2 of the fair value hierarchy (See Note 17 - Fair Value of Financial Assets and Financial Liabilities).
CREDIT RISK - As of December 31, 2013, approximately $28.1 million or 33.9% of current and noncurrent Derivatives–Energy Related Assets are with two counterparties. One of these counterparties has contracts with a large number of diverse customers which minimizes the concentration of this risk. A portion of these contracts may be assigned to SJI in the event of default by the counterparty.
FINANCE OBLIGATION - During 2010, ACB Energy Partners LLC (ACB), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, completed construction of a combined heat and power generating facility to serve, under an energy services agreement, a thermal plant owned by Marina. Construction period financing was provided by Marina. As substantially all of the costs of constructing the facility were funded by the financing provided by Marina, Marina was considered the owner of the facility for accounting purposes during the construction period. When an entity is considered the accounting owner during the construction period, a sale of the asset effectively occurs when construction of the asset is completed. However, due to its continuing involvement in the facility through its equity interest in Energenic, Marina continues to be considered the owner of the facility for accounting purposes under ASC Topic 360 Property, Plant and Equipment. As a result, the transaction is being accounted for as a financing arrangement under ASC Topic 840 Leases and therefore the Company has included costs to construct the facility within Nonutility Property, Plant and Equipment on the consolidated balance sheets of $23.7 million and $23.6 million as of December 31, 2013 and 2012, respectively. In addition, the Company included repayments from ACB to Marina on the construction loan within the Finance Obligation on the consolidated balance sheets. Marina does not have a fixed payment obligation to ACB; as a result, the Finance Obligation is classified as a noncurrent liability on the consolidated balance sheets. The costs to construct the facility and the repayments of the construction loan are amortized over the term of the energy services agreement. The impact on the consolidated statements of income is not significant. As a result, the Company recorded $20.7 million and $21.6 million, net of amortization, within Finance Obligation on the consolidated balance sheets at December 31, 2013 and 2012, respectively.
FINANCIAL INSTRUMENTS NOT CARRIED AT FAIR VALUE - The fair value of a financial instrument is the market price to sell an asset or transfer a liability at the measurement date. The carrying amounts of SJI's financial instruments approximate their fair values at December 31, 2013 and 2012, except as noted below.
• | For Long-Term Debt, in estimating the fair value, we use the present value of remaining cash flows at the balance sheet date. We based the estimates on interest rates available to SJI at the end of each period for debt with similar terms and maturities (Level 2 in the fair value hierarchy, see Note 17 - Fair Value of Financial Assets and Financial Liabilities). The estimated fair values of SJI's long-term debt, including current maturities, as of December 31, 2013 and 2012, were $713.2 million and $682.3 million, respectively. The carrying amounts of SJI's long-term debt, including current maturities, as of December 31, 2013 and 2012, was $701.4 million and $626.4 million, respectively. |
OTHER FINANCIAL INSTRUMENTS – The carrying amounts of SJI’s other financial instruments approximate their fair values at December 31, 2013 and 2012.
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8. | SEGMENTS OF BUSINESS: |
SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the chief operating decision maker. Gas Utility Operations (SJG) consists primarily of natural gas distribution to residential, commercial and industrial customers. Wholesale Energy Operations include SJRG’s and SJEX's activities. SJE is involved in both retail gas and retail electric activities. Retail Gas and Other Operations include natural gas acquisition and transportation service business lines. Retail Electric Operations consist of electricity acquisition and transportation to commercial and industrial customers. On-Site Energy Production consists of Marina’s thermal energy facility and other energy-related projects. Appliance Service Operations includes SJESP’s servicing of appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. The Retail Energy Operations caption includes Retail Gas and Other, Retail Electric, On-Site Energy Production and Appliance Service Operations. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. Intersegment sales and transfers are treated as if the sales or transfers were to third parties at current market prices.
Information about SJI’s operations in different reportable operating segments is presented below (in thousands):
2013 | 2012 | 2011 | |||||||||
Operating Revenues: | |||||||||||
Gas Utility Operations | $ | 446,480 | $ | 421,874 | $ | 412,449 | |||||
Wholesale Energy Operations | 831 | 17,429 | 68,370 | ||||||||
Retail Energy Operations: | |||||||||||
Retail Gas and Other Operations | 107,748 | 80,486 | 100,977 | ||||||||
Retail Electric Operations | 128,932 | 144,197 | 206,422 | ||||||||
On-Site Energy Production | 43,551 | 38,308 | 39,919 | ||||||||
Appliance Service Operations | 13,723 | 13,646 | 17,056 | ||||||||
Subtotal Retail Energy Operations | 293,954 | 276,637 | 364,374 | ||||||||
Corporate & Services | 31,286 | 29,318 | 25,325 | ||||||||
Subtotal | 772,551 | 745,258 | 870,518 | ||||||||
Intersegment Sales | (41,130 | ) | (38,978 | ) | (41,958 | ) | |||||
Total Operating Revenues | $ | 731,421 | $ | 706,280 | $ | 828,560 | |||||
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2013 | 2012 | 2011 | |||||||||
Operating Income: | |||||||||||
Gas Utility Operations | $ | 105,822 | $ | 101,762 | $ | 102,663 | |||||
Wholesale Energy Operations | (37,720 | ) | (2,142 | ) | 16,225 | ||||||
Retail Energy Operations: | |||||||||||
Retail Gas and Other Operations | 278 | (1,204 | ) | 478 | |||||||
Retail Electric Operations | (98 | ) | 12,683 | 1,755 | |||||||
On-Site Energy Production | (2,011 | ) | (1,696 | ) | 2,254 | ||||||
Appliance Service Operations | 2,995 | (225 | ) | (1,539 | ) | ||||||
Subtotal Retail Energy Operations | 1,164 | 9,558 | 2,948 | ||||||||
Corporate and Services | 370 | 720 | (229 | ) | |||||||
Total Operating Income | $ | 69,636 | $ | 109,898 | $ | 121,607 | |||||
Depreciation and Amortization: | |||||||||||
Gas Utility Operations | $ | 48,261 | $ | 44,171 | $ | 41,959 | |||||
Wholesale Energy Operations | 206 | 229 | 253 | ||||||||
Retail Energy Operations: | |||||||||||
Retail Gas and Other Operations | 93 | 78 | 33 | ||||||||
On-Site Energy Production | 15,192 | 9,604 | 4,527 | ||||||||
Appliance Service Operations | 261 | 308 | 322 | ||||||||
Subtotal Retail Energy Operations | 15,546 | 9,990 | 4,882 | ||||||||
Corporate and Services | 877 | 699 | 665 | ||||||||
Total Depreciation and Amortization | $ | 64,890 | $ | 55,089 | $ | 47,759 | |||||
Interest Charges: | |||||||||||
Gas Utility Operations | $ | 12,550 | $ | 12,427 | $ | 18,922 | |||||
Wholesale Energy Operations | 417 | 229 | 54 | ||||||||
Retail Energy Operations: | |||||||||||
Retail Gas and Other Operations | 280 | 139 | 186 | ||||||||
On-Site Energy Production | 4,480 | 4,936 | 5,436 | ||||||||
Subtotal Retail Energy Operations | 4,760 | 5,075 | 5,622 | ||||||||
Corporate and Services | 6,004 | 4,219 | 2,648 | ||||||||
Subtotal | 23,731 | 21,950 | 27,246 | ||||||||
Intersegment Borrowings | (4,906 | ) | (2,964 | ) | (3,168 | ) | |||||
Total Interest Charges | $ | 18,825 | $ | 18,986 | $ | 24,078 | |||||
Income Taxes: | |||||||||||
Gas Utility Operations | $ | 34,833 | $ | 33,711 | $ | 34,281 | |||||
Wholesale Energy Operations | (15,070 | ) | (907 | ) | 7,517 | ||||||
Retail Energy Operations: | |||||||||||
Retail Gas and Other Operations | 434 | (144 | ) | 511 | |||||||
Retail Electric Operations | (40 | ) | 5,181 | 717 | |||||||
On-Site Energy Production | (40,755 | ) | (26,811 | ) | (22,258 | ) | |||||
Appliance Service Operations | 1,237 | (75 | ) | 1,480 | |||||||
Subtotal Retail Energy Operations | (39,124 | ) | (21,849 | ) | (19,550 | ) | |||||
Corporate and Services | 347 | 524 | 254 | ||||||||
Total Income Taxes | $ | (19,014 | ) | $ | 11,479 | $ | 22,502 | ||||
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2013 | 2012 | 2011 | |||||||||
Property Additions: | |||||||||||
Gas Utility Operations | $ | 173,099 | $ | 156,990 | $ | 141,918 | |||||
Wholesale Energy Operations | 50 | 23 | 83 | ||||||||
Retail Energy Operations: | |||||||||||
Retail Gas and Other Operations | 702 | 177 | 22 | ||||||||
On-Site Energy Production | 151,592 | 107,993 | 57,093 | ||||||||
Appliance Service Operations | — | 34 | 254 | ||||||||
Subtotal Retail Energy Operations | 152,294 | 108,204 | 57,369 | ||||||||
Corporate and Services | 3,061 | 4,308 | 605 | ||||||||
Total Property Additions | $ | 328,504 | $ | 269,525 | $ | 199,975 | |||||
2013 | 2012 | ||||||
Identifiable Assets (See Note 1): | |||||||
Gas Utility Operations | $ | 1,909,126 | $ | 1,786,459 | |||
Wholesale Energy Operations | 331,182 | 204,358 | |||||
Retail Energy Operations: | |||||||
Retail Gas and Other Operations | 50,384 | 39,481 | |||||
Retail Electric Operations | 25,496 | 21,919 | |||||
On-Site Energy Production | 576,315 | 543,416 | |||||
Appliance Service Operations | 1,812 | 3,244 | |||||
Subtotal Retail Energy Operations | 654,007 | 608,060 | |||||
Discontinued Operations | 1,068 | 2,290 | |||||
Corporate and Services | 406,245 | 334,798 | |||||
Intersegment Assets | (376,773 | ) | (304,525 | ) | |||
Total Identifiable Assets | $ | 2,924,855 | $ | 2,631,440 | |||
9. LEASES:
The Company is considered to be the lessor of certain thermal energy generating property and equipment under an operating lease which expires in May 2027. As of December 31, 2013 and 2012 the carrying costs of this property and equipment under operating lease was $81.8 million and $72.3 million, respectively, (net of accumulated depreciation of $22.7 million and $20.0 million, respectively) and is included in Nonutility Property and Equipment in the consolidated balance sheets.
Minimum future rentals to be received on non-cancelable leases of thermal energy generating property and equipment as of December 31, 2013 for each of the next five years and in the aggregate are (in thousands):
Year ended December 31, | |||
2014 | $ | 5,396 | |
2015 | 5,396 | ||
2016 | 5,396 | ||
2017 | 5,396 | ||
2018 | 5,396 | ||
Thereafter | 45,418 | ||
Total minimum future rentals | $ | 72,398 | |
Minimum future rentals do not include additional amounts to be received based on actual use of the leased property.
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10. | RATES AND REGULATORY ACTIONS: |
BASE RATES - SJG is subject to the rules and regulations of the BPU. In September 2010, the BPU granted SJG a base rate increase of $42.1 million, which was predicated, in part, upon an 8.21% rate of return on rate base that included a 10.3% return on common equity. The $42.1 million includes $16.6 million of revenue previously recovered through the Conservation Incentive Program (CIP) and $6.8 million of revenues previously recovered through the Capital Investment Recovery Tracker (CIRT), resulting in incremental revenue of $18.7 million. SJG was permitted to recover regulatory assets contained in its petition and defer certain federally mandated pipeline integrity management program costs for recovery in its next base rate case. In addition, annual depreciation expense will be reduced by $1.2 million as a result of the amortization of excess cost of removal recoveries. The BPU also authorized a Phase II of the base rate proceeding to review the costs of CIRT projects not rolled into rate base in the September 2010 settlement. A proceeding took place in 2013 to roll into base rates the remaining $22.5 million of CIRT I project costs that were not included in the 2010 rate increase, as well as CIRT II and III investments totaling $95.0 million that were made subsequent to the 2010 base rate case. These costs were rolled into rate base and reflected in base rates effective October 2013.
In November 2013, SJG filed a base rate case with the BPU to increase its base rates to obtain a certain level of return on its capital investments. SJG expects the base rate case to be concluded during 2014. Other than the CIRT items discussed above, SJG has not sought a base rate increase from the BPU since the implementation of its base rate case approved in September 2010.
RATE MECHANISMS - SJG's tariff, a schedule detailing the terms, conditions and rate information applicable to the various types of natural gas service, as approved by the BPU, has several primary rate mechanisms as discussed in detail below:
Basic Gas Supply Service (BGSS) Clause - The BGSS price structure was approved by the BPU in January 2003, and allows SJG to recover all prudently incurred gas costs. BGSS charges to customers can be either monthly or periodic (annual). Monthly BGSS charges are applicable to large use customers and are referred to as monthly because the rate changes on a monthly basis pursuant to a BPU-approved formula based on commodity market prices. Periodic BGSS charges are applicable to lower usage customers, which include all of SJG's residential customers, and are evaluated at least annually by the BPU. However, to some extent, more frequent rate changes to the periodic BGSS are allowed. SJG collects gas costs from customers on a forecasted basis and defers periodic over/under recoveries to the following BGSS year, which runs from October 1 though September 30. If SJG is in a net cumulative undercollected position, gas costs deferrals are reflected on the balance sheet as a regulatory asset. If SJG is in a net cumulative overcollected position, amounts due back to customers are reflected on the balance sheet as a regulatory liability. SJG pays interest on net overcollected BGSS balances at the rate of return on rate base utilized by the BPU to set rates in the last base rate proceeding.
Regulatory actions regarding the BGSS were as follows:
.
• | March 2011 - SJG credited the accounts of its periodic BGSS customers with refunds totaling $21.1 million due to gas costs that were lower than projected during the winter season. |
• | June 2011 - SJG filed its annual BGSS filing with the BPU requesting a $10.6 million, or 2.9%, reduction in gas cost recoveries commencing on October 1, 2011. |
• | September 2011 - The BPU issued an Order finalizing the 2010-2011 provisional BGSS rate and approved, on a provisional basis, SJG's request for a $10.6 million or 2.9% reduction in gas cost recoveries. |
• | December 2011 - SJG credited the accounts of its periodic BGSS customers with refunds totaling $18.7 million due to gas costs that were lower than projections. |
• | May 2012 - The BPU issued an Order finalizing the 2011-2012 provisional BGSS rates. |
• | June 2012 - SJG filed its annual BGSS filing with the BPU requesting a $27.0 million, or 8.8%, reduction in gas cost recoveries commencing on October 1, 2012. |
• | September 2012 - The BPU issued an Order approving, on a provisional basis, SJG's request for a 27.0 million, or 8.8%, reduction in gas cost recoveries. |
• | January 2013 - SJG credited the accounts of its periodic BGSS customers with refunds totaling $9.4 million due to gas costs that were lower than projections. |
• | May 2013 - SJG filed its annual BGSS filing with the BPU requesting a $0.6 million reduction in gas cost recoveries. |
• | September 2013 - The BPU issued an Order approving, on a provisional basis, SJG’s request for a $0.6 million reduction in gas cost recoveries. |
• | January 2014 - SJG credited the accounts of its periodic BGSS customer with refunds totaling $11.2 million due to gas costs that were lower than projected. |
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Conservation Incentive Program (CIP) - The primary purpose of the CIP is to promote conservation efforts, without negatively impacting financial stability, and to base SJG's profit margin on the number of customers rather than the amount of natural gas distributed to customers. In October 2006, the BPU approved SJG's CIP as a three-year pilot program. In January 2010, the BPU approved an extension of this program through September 2013, with an automatic one year extension through September 2014 if a request for an extension was filed by March 2013. A petition was filed in March 2013 to extend the CIP program. Each CIP year begins October 1 and ends September 30 of the subsequent year. On a monthly basis during the CIP year, SJG records adjustments to earnings based on weather and customer usage factors, as incurred. Subsequent to each year, SJG makes filings with the BPU to review and approve amounts recorded under the CIP. BPU approved cash inflows or outflows generally will not begin until the next CIP year.
Regulatory actions regarding the CIP were as follows:
• | June 2011 - SJG made its annual CIP filing with the BPU requesting recovery of $2.5 million, which includes a $2.7 million credit to customers for the current 2011-2012 CIP year and prior year carryovers of $5.2 million. The CIP credit of $2.7 million includes $1.3 million non-weather related credits and $1.4 million weather related credits. |
• | September 2011 - The BPU issued an Order finalizing the 2010-2011 provisional CIP rates and also approved, on a provisional basis, the 2011-2012 CIP rates filed in June 2011, effective October 1, 2011. |
• | May 2012 - The BPU issued an Order finalizing the 2011-2012 provisional CIP rates. |
• | June 2012 - SJG made its annual CIP filing with the BPU requesting recovery of $28.0 million, which includes a $8.4 million non-weather related recovery and a $19.6 million weather related recovery. |
• | September 2012 - The BPU issued an Order approving, on a provisional basis, the 2012-2013 CIP rates filed in June 2012, effective October 1, 2012. |
• | March 2013 - SJG filed a joint petition with another utility requesting modification to, and the continuation of, the CIP program effective October 1, 2013. |
• | May 2013 - SJG made its annual CIP filing with the BPU requesting a reduction in revenue of $17.8 million, which includes a $2.3 million reduction in non-weather related recovery and a $15.5 million reduction in weather related recovery. |
• | September 2013 - The BPU issued an Order approving, on a provisional basis, the 2013-2014 CIP rates filed in May 2013, effective October 1, 2013. |
Capital Investment Recovery Tracker (CIRT) - In January 2009, SJG made a filing with the BPU requesting approval for an accelerated infrastructure investment program. The purpose of the CIRT was to accelerate $103.0 million of capital expenditures from five years to two years. The petition requested that the Company be allowed to earn a return of, and a return on, its investment. Under the CIRT, 2009 spending was projected to be $70.5 million and 2010 spending was projected to be $32.5 million. In September 2010, the BPU authorized $81.3 million of CIRT-related expenditures to be rolled into rate base and also authorized that the remaining balance of CIRT-related expenditures continue to be recovered. These remaining expenditures were reviewed and rolled into rate base during Phase II of the base rate case. On a monthly basis during the CIRT year, SJG recorded adjustments to earnings based on actual CIRT program expenditures, as incurred. Annually, SJG made filings with the BPU for review and approval of expenditures recorded under the CIRT.
Regulatory actions regarding the CIRT were as follows:
• | March 2011 - The BPU approved a CIRT II program allowing SJG to accelerate an additional $60.3 million of capital spending into 2011 and 2012. Under CIRT II, SJG continues to earn a return on investment as the capital is spent, as it did under the original CIRT. The return of investment begins when the investments are rolled into rate base. As such, SJG is permitted to earn a return on CIRT II investments until the roll in is approved and recovery commences. |
• | June 2011 - SJG filed a petition with the BPU requesting the recovery of a portion of CIRT II investments via a roll-in to rate base, and requested to increase the base rates by 0.5%. |
• | October 2011 - SJG filed a petition with the BPU requesting to modify and extend the CIRT II program. The petition requested an additional incremental investment of $40.0 million in 2012 and $50.0 million in 2013. |
• | May 2012 - The BPU approved a modification and extension of the CIRT II program (CIRT III), allowing SJG to accelerate an incremental $35.0 million of capital spending through December 2012. |
• | October 2012 - SJG filed a petition requesting a $13.2 million increase in annual revenues by rolling $110.6 million of CIRT I, II and III investments into base rates. |
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• | September 2013 - The BPU approved the base rate roll in of the CIRT I, II and III program investments effective October 2013, resulting in a $15.5 million increase in annual revenue. This approval also concluded Phase II of the 2010 base rate case. |
All CIRT program investments have been rolled into rate base and the CIRT program is now concluded.
Accelerated Infrastructure Replacement Program (AIRP) - In July 2012, SJG filed a petition to implement a five-year, $250.0 million Accelerated Infrastructure Replacement Program (AIRP) to replace the annual CIRT programs. In February 2013, the BPU issued a Board Order approving a $141.2 million program to replace cast iron and unprotected bare steel mains and services over a four year period, with annual investments of approximately $35.3 million. Pursuant to the Board Order, AIRP investments are to be reviewed and included in rate base in future base rate proceedings.
Storm Hardening and Reliability Program (SHARP) - In September 2013, SJG filed with the BPU an asset hardening program pursuant to which SJG will invest approximately $280.0 million over seven years to replace low pressure distribution mains and services with high pressure mains and services in coastal areas that are susceptible to flooding during major storm events. This petition is currently pending.
Energy Efficiency Tracker (EET) - In January 2009, SJG filed a petition with the BPU requesting approval of an Energy Efficiency Program (EEP I) for residential, commercial and industrial customers. The BPU approved this petition in July 2009. Under this program, SJG is permitted to invest $17.0 million over two years in energy efficiency measures to be installed in customer homes and businesses. SJG also recovers incremental operating and maintenance expenses and earn a return of, and return on, program investments.
Regulatory actions regarding the EET were as follows:
• | November 2010 - SJG filed a petition with the BPU requesting a one year extension of the program and a reallocation of investment dollars between the EET programs to fund the more popular programs. In January 2011, SJG’s request to reallocate investment dollars between the programs and a one year extension was approved by the BPU. |
• | June 2011 - SJG filed its annual 2011-2012 petition requesting approval of a $4.7 million increase in EET recovery. This petition was approved in September 2012 with rates effective October1, 2012. |
• | October 2011 - SJG filed a petition requesting a modification of the EET with regards to the Combined Heat and Power (CHP) program. The BPU approved this petition in February 2012. |
• | May 2012 - SJG filed a petition requesting the approval of a new Energy Efficiency Program (“EEP II”) and to continue the existing EET to recover all costs associated with the EEP II through a $3.1 million increase in annual revenues. These programs provide customers with increased incentives to reduce their natural gas consumption. In June 2013, the BPU approved the EEP II program in the form of an extension of the existing EEP program, permitting SJG to invest $24.0 million in energy efficiency programs through June 2015. The BPU also approved in June 2013 an extension of the EET with a $2.1 million revenue increase effective July 2013. |
• | June 2012 - SJG filed a petition requesting a continuation of the original Energy Efficiency Program (“EEP I”) to bridge the gap between the expiration of the EEP I program on April 30, 2012, and the implementation of the proposed new EEP II program. This petition was approved by the BPU in August 2012. Also in June 2012, SJG filed its 2012 - 2013 annual EET rate adjustment petition requesting a $5.8 million increase in annual revenues to recover the costs associated with its EEP I program. This petition is still pending. |
• | May 2013 - SJG filed its annual petition requesting an increase of $2.2 million for current EET programs. This petition is still pending. |
Societal Benefits Clause (SBC) - The SBC allows SJG to recover costs related to several BPU-mandated programs. Within the SBC are a Remediation Adjustment Clause (RAC), a New Jersey Clean Energy Program (NJCEP), a Universal Service Fund (USF) program and a Consumer Education Program (CEP).
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Regulatory actions regarding the SBC, with the exception of USF which requires separate regulatory filings, were as follows:
• | July 2011 - SJG made its annual 2011-2012 SBC filing requesting a $31.2 million increase in SBC recoveries. The BPU approved this filing in July 2013. |
• | September 2011 - The BPU finalized rates for the 2008-2009 and 2009-2010 SBC petitions. |
• | July 2012 - SJG made its annual 2012-2013 SBC filing requesting an $11.8 million increase in SBC recoveries. The BPU approved this filing in July 2013. |
• | September 2012 - The BPU finalized rates for the 2010-2011 SBC petition effective October 1, 2012. |
• | July 2013- SJG made its annual 2013-2014 SBC filing requesting a $6.4 million decrease in SBC revenues. This petition is still pending. |
Remediation Adjustment Clause (RAC) - The RAC recovers environmental remediation costs of 12 former gas manufacturing plants (See Note 15). The BPU allows SJG to recover such costs over seven-year amortization periods. The net between the amounts actually spent and amounts recovered from customers is recorded as a regulatory asset, Environmental Remediation Cost Expended - Net. Note that RAC activity affects revenue and cash flows but does not directly affect earnings because of the cost recovery over seven-year amortization periods. As of December 31, 2013 and 2012, SJG reflected the unamortized remediation costs of $29.9 million and $37.9 million, respectively, on the consolidated balance sheets under Regulatory Assets (See Note 11). Since implementing the RAC in 1992, SJG has recovered $92.6 million through rates.
New Jersey Clean Energy Program (NJCEP) - This mechanism recovers costs associated with SJG's energy efficiency and renewable energy programs. In August 2008, the BPU approved the statewide funding of the NJCEP of $1.2 billion for the years 2009 through 2012. Of this amount, SJG was responsible for expensing approximately $41.5 million over the four-year period. In November 2012, the BPU approved a six-month extension of the program through June 2013. Under this extension, SJG is responsible for $7.5 million of funding. NJCEP adjustments affect revenue and cash flows but do not directly affect earnings as related costs are deferred and recovered through rates on an on-going basis.
Universal Service Fund (USF) - The USF is a statewide program through which funds for the USF and Lifeline Credit and Tenants Assistance Programs are collected from customers of all New Jersey electric and gas utilities. USF adjustments affect cash flows but do not directly affect revenue or earnings as related costs are deferred and recovered through rates on an on-going basis.
Separate regulatory actions regarding the USF were as follows:
• | June 2011 - SJG made its annual USF filing, along with the state's other electric and gas utilities, proposing to decrease annual statewide gas revenues by $9.3 million. This proposal was designed to decrease SJG's annual USF revenue by $0.8 million. |
• | October 2011 - The BPU approved the statewide budget of $57.4 million for all of the State's gas utilities. SJG's portion of the total is approximately $5.4 million, which decreased rates effective November 1, 2011, resulting in a $0.5 million decrease to SJG's annual USF recoveries. |
• | June 2012 - SJG made its annual USF filing, along with the state's other electric and gas utilities, proposing to decrease annual statewide gas revenues by $0.5 million. This proposal was designed to decrease SJG's annual USF revenue by $0.1 million. |
• | September 2012 - The BPU approved the statewide budget of $78.0 million for all of the State's gas utilities. SJG's portion of the total is approximately $8.2 million, which decreased rates effective October 1, 2012, resulting in a $0.1 million decrease to SJG's annual USF recoveries. |
• | June 2013 - SJG made its annual USF filing, along with the state’s other electric and gas utilities, proposing to decrease the statewide gas revenues by $29.4 million. This proposal was designed to decrease SJG's annual USF revenue by $3.7 million. |
• | September 2013 - The BPU approved the statewide USF budget of $54.4 million for all the State’s gas utilities. SJG's portion of the total is approximately $5.8 million, which decreased rates effective October 1, 2013, resulting in a $3.4 million decrease to SJG's USF recoveries. |
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Other Regulatory Matters -
Unbundling - In 2000, the BPU approved full unbundling of SJG's system. This allows all natural gas consumers to select their natural gas commodity supplier. As of December 31, 2013, 47,074 of SJG's customers were purchasing their gas commodity from someone other than SJG. Customers choosing to purchase natural gas from providers other than the utility are charged for the cost of gas by the marketer. The resulting decrease in utility revenues is offset by a corresponding decrease in gas costs. While customer choice can reduce utility revenues, it does not negatively affect SJG's net income or financial condition. The BPU continues to allow for full recovery of prudently incurred natural gas costs through the BGSS. Unbundling did not change the fact that SJG still recovers cost of service, including certain deferred costs, through base rates.
Pipeline Integrity - In October 2005, SJG filed a petition with the BPU to implement a Pipeline Integrity Management Tracker (Tracker). The purpose of this Tracker was to recover incremental costs to be incurred by SJG as a result of new federal regulations, which are aimed at enhancing public safety and reliability. The regulations require that utilities use a comprehensive analysis to assess, evaluate, repair and validate the integrity of certain transmission lines in the event of a leak or failure. As part of SJG's September 2010 base rate increase, SJG was permitted to recover previously deferred pipeline integrity costs incurred through September 2010. In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in the next base rate proceeding, subject to review by the BPU. Accordingly, SJG withdrew its petition for the Pipeline Integrity Management Tracker. As of December 31, 2013 and 2012, deferred pipeline integrity costs totaled $2.8 million and $1.6 million, respectively, and are included in other regulatory assets.
Superstorm Sandy - In June 2013, SJG filed a petition requesting deferral of incremental operating and maintenance expenses incurred due to Superstorm Sandy. These costs totaled $0.7 million and are expected to be recovered in SJG’s next base rate case. This petition is currently pending.
Filings and petitions described above are still pending unless otherwise indicated.
11. | REGULATORY ASSETS & REGULATORY LIABILITIES: |
The discussion under Note 10, Rates and Regulatory Actions, is integral to the following explanations of specific regulatory assets and liabilities.
Regulatory Assets consisted of the following items (in thousands):
December 31, 2013 | December 31, 2012 | ||||||
Environmental Remediation Costs: | |||||||
Expended - Net | $ | 29,945 | $ | 37,892 | |||
Liability for Future Expenditures | 119,492 | 107,410 | |||||
Deferred Asset Retirement Obligation Costs | 31,142 | 30,199 | |||||
Deferred Pension and Other Postretirement Benefit Costs | 59,284 | 95,897 | |||||
Conservation Incentive Program Receivable | 10,526 | 31,686 | |||||
Societal Benefit Costs Receivable | 10,408 | 12,801 | |||||
Premium for Early Retirement of Debt | 955 | 1,075 | |||||
Deferred Interest Rate Contracts | 3,735 | 7,761 | |||||
Energy Efficiency Tracker | 10,420 | 12,306 | |||||
Pipeline Supplier Service Charges | 7,106 | 8,771 | |||||
Pipeline Integrity Cost | 2,902 | 1,584 | |||||
Other Regulatory Assets | 10,166 | 5,274 | |||||
Total Regulatory Assets | $ | 296,081 | $ | 352,656 | |||
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Except where noted below, all regulatory assets are or will be recovered through utility rate charges, as detailed in the following discussion. SJG is currently permitted to recover interest on Environmental Remediation Costs, Societal Benefit Costs Receivable, Energy Efficiency Tracker and Pipeline Integrity Costs, while the other assets are being recovered without a return on investment.
Environmental Remediation Costs - SJG has two regulatory assets associated with environmental costs related to the cleanup of 12 sites where SJG or their predecessors previously operated gas manufacturing plants. The first asset, Environmental Remediation Cost: Expended - Net, represents what was actually spent to clean up the sites, less recoveries through the RAC and insurance carriers. These costs meet the deferral requirements of GAAP as the BPU allows SJG to recover such expenditures through the RAC. The other asset, Environmental Remediation Cost: Liability for Future Expenditures, relates to estimated future expenditures required to complete the remediation of these sites. SJG recorded this estimated amount as a regulatory asset with the corresponding current and noncurrent liabilities reflected on the consolidated balance sheets under the captions Current Liabilities and Deferred Credits and Other Noncurrent Liabilities. The BPU allows SJG to recover the deferred costs over seven-year periods after they are spent.
Deferred Asset Retirement Obligation (ARO) Costs - This regulatory asset resulted from the recording of ARO and additional utility plant, primarily related to a legal obligation SJG has for certain safety requirements upon the retirement of its gas distribution and transmission system. SJG recovers asset retirement costs through rates charged to customers. All related accumulated accretion and depreciation amounts for these ARO represent timing differences in the recognition of retirement costs that SJG is currently recovering in rates and, as such, SJG is deferring such differences as regulatory assets.
Deferred Pension and Other Postretirement Benefit Costs - The BPU authorized SJG to recover costs related to postretirement benefits under the accrual method of accounting consistent with GAAP. SJG deferred amounts accrued prior to that authorization and amortized them as allowed by the BPU over 15 years through 2012. Upon the adoption of FASB ASC Topic 715 “Compensation - Retirement Benefits” in 2006, SJG's regulatory asset was increased by $37.1 million representing the recognition of the underfunded positions of SJG's pension and other postretirement benefit plans. Subsequent adjustments to this balance occur annually to reflect changes in the funded positions of these benefit plans caused by changes in actual plan experience as well as assumptions of future experience (See Note 12).
Conservation Incentive Program Receivable - The impact of the CIP is recorded as an adjustment to earnings as incurred, while cash recovery under the CIP generally occurs during the subsequent CIP year (see Note 10).
Societal Benefit Costs Receivable - This regulatory asset primarily represents cumulative costs less recoveries under the USF program.
Premium for Early Retirement of Debt - At December 31, 2013, this regulatory asset represents unamortized debt issuance costs related to long-term debt refinancings. Unamortized debt issuance costs are being amortized over the term of the new debt issue pursuant to regulatory approval by the BPU.
Deferred Interest Rate Contracts - These amounts represent the market value of interest rate derivatives as discussed further in Note 16.
Energy Efficiency Tracker - This regulatory asset represents cumulative investments less recoveries under the Energy Efficiency Program.
Pipeline Supplier Service Charges - This regulatory asset represents costs necessary to maintain adequate supply and system pressures, which are being recovered on a monthly basis through the BGSS over the term of the underlying supplier contracts (See Note 10).
Pipeline Integrity Cost - As part of SJG's September 2010 base rate increase, SJG was permitted to recover previously deferred pipeline integrity costs incurred through September 2010. In addition, SJG is authorized to defer future program costs, including related carrying costs, for recovery in SJG's next base rate proceeding, subject to review by the BPU (see Note 3).
Other Regulatory Assets - Some of the assets included in Other Regulatory Assets are currently being recovered from ratepayers as approved by the BPU. Management believes the remaining deferred costs are probable of recovery from ratepayers through future utility rates.
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Regulatory Liabilities consisted of the following items (in thousands):
December 31, 2013 | December 31, 2012 | ||||||
Excess Plant Removal Costs | $ | 40,029 | $ | 45,593 | |||
Deferred Revenues - Net | 19,067 | 10,924 | |||||
Other Regulatory Liabilities | 1,853 | — | |||||
Total Regulatory Liabilities | $ | 60,949 | $ | 56,517 | |||
Excess Plant Removal Costs - Represents amounts accrued in excess of actual utility plant removal costs incurred to date. As part of SJG's September 2010 base rate increase, SJG is required to amortize approximately $1.2 million of this balance to depreciation expense each year.
Deferred Revenues - Net - Over/under collections of gas costs are monitored through SJG’s BGSS mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability (See Note 10). Derivative contracts used to hedge SJG's natural gas purchases are also included in the BGSS, subject to BPU approval. The increase from a $10.9 million regulatory liability at December 31, 2012 to a $19.1 million regulatory liability at December 31, 2013 was due to gas costs recovered from customers exceeding the actual cost of the commodity incurred during 2013.
Other Regulatory Liabilities - All other regulatory liabilities are subject to being returned to ratepayers in future rate proceedings.
12. | PENSION AND OTHER POSTRETIREMENT BENEFITS: |
SJI has several defined benefit pension plans and other postretirement benefit plans. The pension plans provide annuity payments to the majority of full-time, regular employees upon retirement. Participation in the Company's qualified defined benefit pension plans was closed to new employees beginning in 2003; however, employees who are not eligible for these pension plans are eligible to receive an enhanced version of SJI's defined contribution plan. Certain SJI officers also participate in a non-funded supplemental executive retirement plan (SERP), a non-qualified defined benefit pension plan. The other postretirement benefit plans provide health care and life insurance benefits to some retirees.
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Net periodic benefit cost related to the employee and officer pension and other postretirement benefit plans consisted of the following components (in thousands):
Pension Benefits | |||||||||||
2013 | 2012 | 2011 | |||||||||
Service Cost | $ | 5,421 | $ | 4,533 | $ | 3,918 | |||||
Interest Cost | 9,439 | 9,622 | 9,524 | ||||||||
Expected Return on Plan Assets | (11,914 | ) | (10,341 | ) | (9,367 | ) | |||||
Amortizations: | |||||||||||
Prior Service Cost | 251 | 251 | 267 | ||||||||
Actuarial Loss | 9,006 | 7,629 | 5,440 | ||||||||
Net Periodic Benefit Cost | 12,203 | 11,694 | 9,782 | ||||||||
ERIP Costs | — | — | 102 | ||||||||
Capitalized Benefit Costs | (5,002 | ) | (4,684 | ) | (3,661 | ) | |||||
Total Net Periodic Benefit Expense | $ | 7,201 | $ | 7,010 | $ | 6,223 | |||||
Other Postretirement Benefits | |||||||||||
2013 | 2012 | 2011 | |||||||||
Service Cost | $ | 1,139 | $ | 1,037 | $ | 996 | |||||
Interest Cost | 2,730 | 3,001 | 3,201 | ||||||||
Expected Return on Plan Assets | (2,378 | ) | (2,105 | ) | (2,248 | ) | |||||
Amortizations: | |||||||||||
Prior Service Credits | (283 | ) | (283 | ) | (355 | ) | |||||
Actuarial Loss | 1,738 | 1,725 | 1,654 | ||||||||
Net Periodic Benefit Cost | 2,946 | 3,375 | 3,248 | ||||||||
Capitalized Benefit Costs | (1,172 | ) | (1,340 | ) | (1,222 | ) | |||||
Total Net Periodic Benefit Expense | $ | 1,774 | $ | 2,035 | $ | 2,026 | |||||
Capitalized benefit costs reflected in the table above relate to SJG’s construction program.
The ERIP costs reflected in the table above relate to an early retirement plan offered during 2011 to one of our business segments.
Companies with publicly traded equity securities that sponsor a postretirement benefit plan are required to fully recognize, as an asset or liability, the overfunded or underfunded status of its benefit plans and recognize changes in the funded status in the year in which the changes occur. Changes in funded status are generally reported in Other Comprehensive Loss; however, since SJG recovers all prudently incurred pension and postretirement benefit costs from its ratepayers, a significant portion of the charges resulting from the recording of additional liabilities under this statement are reported as regulatory assets (See Note 11).
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Details of the activity within the Regulatory Asset and Accumulated Other Comprehensive Loss associated with Pension and Other Postretirement Benefits are as follows (in thousands):
Regulatory Assets | Accumulated Other Comprehensive Loss (pre-tax) | ||||||||||||||
Pension Benefits | Other Postretirement Benefits | Pension Benefits | Other Postretirement Benefits | ||||||||||||
Balance at January 1, 2012 | $ | 61,811 | $ | 26,435 | $ | 31,766 | $ | 4,745 | |||||||
Amounts Arising during the Period: | |||||||||||||||
Net Actuarial Loss (Gain) | 11,599 | 2,089 | 6,811 | (446 | ) | ||||||||||
Amounts Amortized to Net Periodic Costs: | |||||||||||||||
Net Actuarial Loss | (4,490 | ) | (1,535 | ) | (3,103 | ) | (187 | ) | |||||||
Prior Service (Cost) Credit | (207 | ) | 195 | (43 | ) | 83 | |||||||||
Balance at December 31, 2012 | 68,713 | 27,184 | 35,431 | 4,195 | |||||||||||
Amounts Arising during the Period: | |||||||||||||||
Net Actuarial Gain | (20,554 | ) | (9,171 | ) | (4,173 | ) | (390 | ) | |||||||
Amounts Amortized to Net Periodic Costs: | |||||||||||||||
Net Actuarial Loss | (5,319 | ) | (1,555 | ) | (3,642 | ) | (177 | ) | |||||||
Prior Service (Cost) Credit | (208 | ) | 194 | (42 | ) | 82 | |||||||||
Balance at December 31, 2013 | $ | 42,632 | $ | 16,652 | $ | 27,574 | $ | 3,710 | |||||||
The estimated costs that will be amortized from Regulatory Assets into net periodic benefit costs in 2014 are as follows (in thousands):
Pension Benefits | Other Postretirement Benefits | ||||||
Prior Service Costs | $ | 158 | $ | 133 | |||
Net Actuarial Loss | $ | 2,856 | $ | 790 | |||
The estimated costs that will be amortized from Accumulated Other Comprehensive Loss into net periodic benefit costs in 2014 are as follows (in thousands):
Pension Benefits | Other Postretirement Benefits | ||||||
Prior Service Costs | $ | 17 | $ | 18 | |||
Net Actuarial Loss | $ | 2,848 | $ | 182 | |||
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A reconciliation of the plans' benefit obligations, fair value of plan assets, funded status and amounts recognized in SJI's consolidated balance sheets follows (in thousands):
Pension Benefits | Other Postretirement Benefits | ||||||||||||||
2013 | 2012 | 2013 | 2012 | ||||||||||||
Change in Benefit Obligations: | |||||||||||||||
Benefit Obligation at Beginning of Year | $ | 224,389 | $ | 194,990 | $ | 68,779 | $ | 64,451 | |||||||
Service Cost | 5,421 | 4,533 | 1,139 | 1,037 | |||||||||||
Interest Cost | 9,439 | 9,622 | 2,730 | 3,001 | |||||||||||
Actuarial (Gain) Loss | (14,272 | ) | 23,952 | (6,361 | ) | 3,861 | |||||||||
Retiree Contributions | — | — | 388 | 342 | |||||||||||
Benefits Paid | (8,582 | ) | (8,708 | ) | (4,320 | ) | (3,913 | ) | |||||||
Benefit Obligation at End of Year | $ | 216,395 | $ | 224,389 | $ | 62,355 | $ | 68,779 | |||||||
Change in Plan Assets: | |||||||||||||||
Fair Value of Plan Assets at Beginning of Year | $ | 150,160 | $ | 116,718 | $ | 36,032 | $ | 31,896 | |||||||
Actual Return on Plan Assets | 22,556 | 15,935 | 5,621 | 4,263 | |||||||||||
Employer Contributions | 13,959 | 26,215 | 3,932 | 3,444 | |||||||||||
Retiree Contributions | — | — | 388 | 342 | |||||||||||
Benefits Paid | (8,582 | ) | (8,708 | ) | (4,320 | ) | (3,913 | ) | |||||||
Fair Value of Plan Assets at End of Year | $ | 178,093 | $ | 150,160 | $ | 41,653 | $ | 36,032 | |||||||
Funded Status at End of Year: | $ | (38,302 | ) | $ | (74,229 | ) | $ | (20,701 | ) | $ | (32,747 | ) | |||
Amounts Related to Unconsolidated Affiliate | (7 | ) | 161 | 365 | 375 | ||||||||||
Accrued Net Benefit Cost at End of Year | $ | (38,309 | ) | $ | (74,068 | ) | $ | (20,336 | ) | $ | (32,372 | ) | |||
Amounts Recognized in the Statement of Financial Position Consist of: | |||||||||||||||
Current Liabilities | $ | (1,275 | ) | $ | (1,272 | ) | $ | — | $ | — | |||||
Noncurrent Liabilities | (37,034 | ) | (72,796 | ) | (20,336 | ) | (32,372 | ) | |||||||
Net Amount Recognized at End of Year | $ | (38,309 | ) | $ | (74,068 | ) | $ | (20,336 | ) | $ | (32,372 | ) | |||
Amounts Recognized in Regulatory Assets Consist of: | |||||||||||||||
Prior Service Costs | $ | 634 | $ | 842 | $ | 952 | $ | 758 | |||||||
Net Actuarial Loss | 41,998 | 67,871 | 15,700 | 26,426 | |||||||||||
$ | 42,632 | $ | 68,713 | $ | 16,652 | $ | 27,184 | ||||||||
Amounts Recognized in Accumulated Other Comprehensive Loss Consist of (pre-tax): | |||||||||||||||
Prior Service Costs | $ | 69 | $ | 111 | $ | 150 | $ | 68 | |||||||
Net Actuarial Loss | 27,505 | 35,320 | 3,560 | 4,127 | |||||||||||
$ | 27,574 | $ | 35,431 | $ | 3,710 | $ | 4,195 | ||||||||
The projected benefit obligation (PBO) and accumulated benefit obligation (ABO) of SJI's qualified employee pension plans were $178.8 million and $163.6 million, respectively, as of December 31, 2013; and $186.4 million and $168.9 million, respectively, as of December 31, 2012. The ABO of these plans exceeded the value of the plan assets as of December 31, 2012. The value of these assets can be seen in the table above. The PBO and ABO for SJI's non-funded SERP were $37.6 million and $36.6 million, respectively, as of December 31, 2013; and $38.0 million and $36.3 million, respectively, as of December 31, 2012. The SERP obligation is reflected in the tables above and has no assets.
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The weighted-average assumptions used to determine benefit obligations at December 31 were:
Pension Benefits | Other Postretirement Benefits | ||||||||||
2013 | 2012 | 2013 | 2012 | ||||||||
Discount Rate | 5.09 | % | 4.26 | % | 4.91 | % | 4.14 | % | |||
Rate of Compensation Increase | 3.50 | % | 3.25 | % | 3.50 | % | 3.25 | % | |||
The weighted-average assumptions used to determine net periodic benefit cost for years ended December 31 were:
Pension Benefits | Other Postretirement Benefits | ||||||||||||||||
2013 | 2012 | 2011 | 2013 | 2012 | 2011 | ||||||||||||
Discount Rate | 4.26 | % | 5.03 | % | 5.78 | % | 4.14 | % | 4.92 | % | 5.55 | % | |||||
Expected Long-Term Return on Plan Assets | 7.50 | % | 7.50 | % | 8.00 | % | 6.60 | % | 6.60 | % | 7.00 | % | |||||
Rate of Compensation Increase | 3.25 | % | 3.25 | % | 3.25 | % | 3.25 | % | 3.25 | % | 3.25 | % | |||||
All obligations disclosed herein reflect the use of the RP 2000 mortality tables.
The discount rates used to determine the benefit obligations at December 31, 2013 and 2012, which are used to determine the net periodic benefit cost for the subsequent year, were based on a portfolio model of high-quality investments with maturities that match the expected benefit payments under our pension and other postretirement benefit plans.
The expected long-term return on plan assets (“return”) has been determined by applying long-term capital market projections provided by our pension plan Trustee to the asset allocation guidelines, as defined in the Company's investment policy, to arrive at a weighted average return. For certain other equity securities held by an investment manager outside of the control of the Trustee, the return has been determined based on historic performance in combination with long-term expectations. The return for the other postretirement benefits plan is determined in the same manner as discussed above; however, the expected return is reduced based on the taxable nature of the underlying trusts.
The assumed health care cost trend rates at December 31 were:
2013 | 2012 | ||||
Medical Care and Drug Cost Trend Rate Assumed for Next Year | 7.00 | % | 7.00 | % | |
Dental Care Cost Trend Rate Assumed for Next Year | 4.75 | % | 4.75 | % | |
Rate to which Cost Trend Rates are Assumed to Decline (the Ultimate Trend Rate) | 4.75 | % | 4.75 | % | |
Year that the Rate Reaches the Ultimate Trend Rate | 2023 | 2019 | |||
Assumed health care cost trend rates have a significant effect on the amounts reported for SJI's postretirement health care plans. A one-percentage-point change in assumed health care cost trend rates would have the following effects (in thousands):
1-Percentage- Point Increase | 1-Percentage- Point Decrease | ||||||
Effect on the Total of Service and Interest Cost | $ | 188 | $ | (149 | ) | ||
Effect on Postretirement Benefit Obligation | $ | 2,947 | $ | (2,483 | ) | ||
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PLAN ASSETS - The Company's overall investment strategy for pension plan assets is to achieve a diversification by asset class, style of manager, and sector and industry limits to achieve investment results that match the actuarially assumed rate of return, while preserving the inflation adjusted value of the plans. The Company has implemented this diversification strategy primarily with commingled common/collective trust funds. The target allocations for pension plan assets are 28-48 percent U.S. equity securities, 13-25 percent international equity securities, 32-42 percent fixed income investments, and 2-14 percent to all other types of investments. Equity securities include investments in commingled common/collective trust funds as well as large-cap and mid-cap companies. Fixed income securities include commingled common/collective trust funds, group annuity contracts for pension payments, and hedge funds. Other types of investments include investments in private equity funds and real estate funds that follow several different strategies.
The strategy recognizes that risk and volatility are present to some degree with all types of investments. We seek to avoid high levels of risk at the total fund level through diversification by asset class, style of manager, and sector and industry limits. Specifically prohibited investments include, but are not limited to, venture capital, margin trading, commodities and securities of companies with less than $250.0 million capitalization (except in the small-cap portion of the fund where capitalization levels as low as $50.0 million are permissible). These restrictions are only applicable to individual investment managers with separately managed portfolios and do not apply to mutual funds or commingled trusts.
SJI evaluated its pension and other postretirement benefit plans' asset portfolios for the existence of significant concentrations of credit risk as of December 31, 2013. Types of concentrations that were evaluated include, but are not limited to, investment concentrations in a single entity, type of industry, foreign country, and individual fund. As of December 31, 2013, there were no significant concentrations (defined as greater than 10 percent of plan assets) of risk in SJI's pension and other postretirement benefit plan assets.
GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques. This hierarchy groups assets into three distinct levels, as fully described in Note 17, that will serve as the basis for presentation throughout the remainder of this Note.
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The fair values of SJI's pension plan assets at December 31, 2013 and 2012 by asset category are as follows (in thousands):
Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
As of December 31, 2013 | |||||||||||||||
Cash / Cash Equivalents: | |||||||||||||||
Common/Collective Trust Funds (a) | $ | 416 | $ | — | $ | 416 | $ | — | |||||||
STIF-Type Instrument (b) | 1,177 | — | 1,177 | — | |||||||||||
Equity securities: | |||||||||||||||
Common/Collective Trust Funds - U.S. (a) | 51,837 | — | 51,837 | — | |||||||||||
Common/Collective Trust Funds - International (a) | 34,093 | — | 34,093 | — | |||||||||||
U.S. Large-Cap (c) | 11,661 | 11,661 | — | — | |||||||||||
U.S. Mid-Cap (c) | 4,135 | 4,135 | — | — | |||||||||||
International (c) | 3,664 | 3,664 | — | — | |||||||||||
Fixed Income: | |||||||||||||||
Common/Collective Trust Funds (a) | 45,847 | — | 45,847 | — | |||||||||||
Guaranteed Insurance Contract (d) | 11,322 | — | — | 11,322 | |||||||||||
Hedge Funds (e) | 4,154 | — | — | 4,154 | |||||||||||
Other types of investments: | |||||||||||||||
Private Equity Fund (f) | 3,046 | — | — | 3,046 | |||||||||||
Common/Collective Trust Fund - Real Estate (g) | 6,741 | — | — | 6,741 | |||||||||||
Total | $ | 178,093 | $ | 19,460 | $ | 133,370 | $ | 25,263 | |||||||
Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
As of December 31, 2012 | |||||||||||||||
Cash / Cash Equivalents: | |||||||||||||||
Common/Collective Trust Funds (a) | $ | 600 | $ | — | $ | 600 | $ | — | |||||||
STIF-Type Instrument (b) | 1,056 | — | 1,056 | — | |||||||||||
Equity securities: | |||||||||||||||
Common/Collective Trust Funds - U.S. (a) | 42,373 | — | 42,373 | — | |||||||||||
Common/Collective Trust Funds - International (a) | 29,491 | — | 29,491 | — | |||||||||||
U.S. Large-Cap (c) | 8,963 | 8,963 | — | — | |||||||||||
U.S. Mid-Cap (c) | 5,275 | 5,275 | — | — | |||||||||||
U.S. Small-Cap (c) | 10 | 10 | — | — | |||||||||||
International (c) | 1,838 | 1,838 | — | — | |||||||||||
Fixed Income: | |||||||||||||||
Common/Collective Trust Funds (a) | 38,880 | — | 38,880 | — | |||||||||||
Guaranteed Insurance Contract (d) | 12,449 | — | — | 12,449 | |||||||||||
Other types of investments: | |||||||||||||||
Private Equity Fund (f) | 3,216 | — | — | 3,216 | |||||||||||
Common/Collective Trust Fund - Real Estate (g) | 6,009 | — | — | 6,009 | |||||||||||
Total | $ | 150,160 | $ | 16,086 | $ | 112,400 | $ | 21,674 | |||||||
(a) | This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate). These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active markets and prices for these assets are readily observable. Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments. |
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(b) | This category represents short-term investment funds held for the purpose of funding disbursement payment arrangements. Underlying assets are valued based on quoted prices in active markets, or where quoted prices are not available, based on models using observable market information. Since not all values can be obtained from quoted prices in active markets, these funds are classified as Level 2 investments. |
(c) | This category of equity investments represents a managed portfolio of common stock investments in five sectors: telecommunications, electric utilities, gas utilities, water and energy. These common stocks are actively traded on exchanges and price quotes for these shares are readily available. These common stocks are classified as Level 1 investments. |
(d) | This category represents SJI's Group Annuity contracts with a nationally recognized life insurance company. The contracts are the assets of the plan, while the underlying assets of the contracts are owned by the contract holder. Valuation is based on a formula and calculation specified within the contract. Since the valuation is based on the reporting entity's own assumptions, these contracts are classified as Level 3 investments. |
(e) | This category represents a collection of underlying funds which are all domiciled outside of the United States. All of the underlying fund managers are based in the U.S.; however, they do not necessarily trade only in U.S. markets. The fair value of these funds is determined by the underlying fund's general partner or manager. These funds are classified as Level 3 investments. |
(f) | This category represents a limited partnership/commingled trust which includes several investments in U.S. leveraged buyout, venture capital, and special situation funds. Fund valuations are reported on a 90 day lag and, therefore, the value reported herein represents the market value as of September 30, 2013 and 2012, respectively. The fund's investments are stated at fair value, which is generally based on the valuations provided by the general partners or managers of such investments. Fund investments are illiquid and resale is restricted. These funds are classified as Level 3 investments. |
(g) | This category represents real estate common/collective trust fund investments through a commingled employee benefit trust. These commingled funds are part of a direct investment in a pool of real estate properties. These funds are valued by investment managers on a periodic basis using pricing models that use independent appraisals from sources with professional qualifications. Since these valuation inputs are not highly observable, the real estate funds are classified as Level 3 investments. |
Fair Value Measurement Using Significant
Unobservable Inputs (Level 3)
(In thousands)
Guaranteed | Private | ||||||||||||||||||
Insurance | Hedge | Equity | Real | ||||||||||||||||
Contract | Funds | Funds | Estate | Total | |||||||||||||||
Balance at January 1, 2012 | $ | 12,274 | $ | — | $ | 3,212 | $ | 5,460 | $ | 20,946 | |||||||||
Actual return on plan assets: | |||||||||||||||||||
Relating to assets still held at the reporting date | 1,219 | — | (190 | ) | 549 | 1,578 | |||||||||||||
Relating to assets sold during the period | (12 | ) | — | 604 | — | 592 | |||||||||||||
Purchases, Sales and Settlements | (1,032 | ) | — | (410 | ) | — | (1,442 | ) | |||||||||||
Balance at December 31, 2012 | 12,449 | — | 3,216 | 6,009 | 21,674 | ||||||||||||||
Actual return on plan assets: | |||||||||||||||||||
Relating to assets still held at the reporting date | (179 | ) | 154 | 76 | 732 | 783 | |||||||||||||
Relating to assets sold during the period | 17 | — | 431 | — | 448 | ||||||||||||||
Purchases, Sales and Settlements | (965 | ) | 4,000 | (677 | ) | — | 2,358 | ||||||||||||
Balance at December 31, 2013 | $ | 11,322 | $ | 4,154 | $ | 3,046 | $ | 6,741 | $ | 25,263 | |||||||||
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As with the pension plan assets, the Company's overall investment strategy for post-retirement benefit plan assets is to achieve a diversification by asset class, style of manager, and sector and industry limits to achieve investment results that match the actuarially assumed rate of return, while preserving the inflation adjusted value of the plans. The Company has implemented this diversification strategy with a mix of common/collective trust funds and mutual funds. The target allocations for post-retirement benefit plan assets are 33-43 percent U.S. equity securities, 20-30 percent international equity securities, and 32-42 percent fixed income investments. Equity securities include investments in large-cap, mid-cap and small-cap companies within mutual funds or common/collective trust funds. Fixed income securities within the common/collective trust fund include primarily investment grade, U.S. Government and mortgage-backed financial instruments.
The fair values of SJI's other postretirement benefit plan assets at December 31, 2013 and 2012 by asset category are as follows (in thousands):
Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
As of December 31, 2013: | |||||||||||||||
Equity Securities: | |||||||||||||||
Common/Collective Trust Funds - U.S. (a) | $ | 13,098 | $ | — | $ | 13,098 | $ | — | |||||||
Common/Collective Trust Funds - International (a) | 10,586 | — | 10,586 | — | |||||||||||
Mutual Fund - U.S. Large-Cap (b) | 2,969 | 2,969 | — | — | |||||||||||
Fixed Income: | |||||||||||||||
Corporate Bonds (a) | 15,000 | — | 15,000 | — | |||||||||||
Total | $ | 41,653 | $ | 2,969 | $ | 38,684 | $ | — | |||||||
Asset Category | Total | Level 1 | Level 2 | Level 3 | |||||||||||
As of December 31, 2012: | |||||||||||||||
Equity Securities: | |||||||||||||||
Common/Collective Trust Funds - U.S. (a) | $ | 10,992 | $ | — | $ | 10,992 | $ | — | |||||||
Common/Collective Trust Funds - International (a) | 9,340 | — | 9,340 | — | |||||||||||
Mutual Fund - U.S. Large-Cap (b) | 2,563 | 2,563 | — | — | |||||||||||
Fixed Income: | |||||||||||||||
Corporate Bonds (a) | 13,137 | — | 13,137 | — | |||||||||||
Total | $ | 36,032 | $ | 2,563 | $ | 33,469 | $ | — | |||||||
(a) | This category represents common/collective trust fund investments through a commingled employee benefit trust (excluding real estate). These commingled funds are not traded publicly; however, the majority of the underlying assets held in these funds are stocks and bonds that are traded on active markets and prices for these assets are readily observable. Also included in these funds are interest rate swaps, asset-backed securities, mortgage-backed securities and other investments with observable market values. Holdings in these commingled funds are classified as Level 2 investments. |
(b) | This category represents mutual fund investments. The mutual funds are actively traded on exchanges and price quotes for the shares are readily available. These mutual funds are classified as Level 1 investments. |
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FUTURE BENEFIT PAYMENTS - The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid during the following years (in thousands):
Pension Benefits | Other Postretirement Benefits | ||||||
2014 | $ | 9,210 | $ | 4,438 | |||
2015 | $ | 9,842 | $ | 4,574 | |||
2016 | $ | 10,289 | $ | 4,660 | |||
2017 | $ | 10,801 | $ | 4,743 | |||
2018 | $ | 12,256 | $ | 4,767 | |||
2019 - 2023 | $ | 73,827 | $ | 25,293 | |||
CONTRIBUTIONS - SJI contributed $12.7 million and $25.0 million to the pension plans during the year ended December 31, 2013 and 2012, respectively. No pension plan contributions are planned for 2014. Payments related to the unfunded SERP plan are expected to approximate $1.3 million in 2014 and have remained consistent over the past few years. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to its other postretirement benefit plans’ trusts, less costs incurred directly by SJG.
DEFINED CONTRIBUTION PLAN - SJI offers an Employees' Retirement Savings Plan (Savings Plan) to eligible employees. For employees eligible for participation in SJI's defined benefit pension plan, SJI matches 50% of participants' contributions up to 6% of base compensation. For employees who are not eligible for participation in SJI's defined benefit pension plans, SJI matches 50% of participants' contributions up to 8% of base compensation. Employees not eligible for the pension plans also receive a year-end contribution of $1,000, if 10 or fewer years of service, or $1,500, if more than 10 years of service. The amount expensed and contributed for the matching provision of the Savings Plan approximated $1.7 million, $1.6 million, and $1.5 million for the years ended December 31, 2013, 2012 and 2011, respectively.
13. | LINES OF CREDIT: |
Credit facilities and available liquidity as of December 31, 2013 were as follows (in thousands):
Company | Total Facility | Usage | Available Liquidity | Expiration Date | ||||||||||
SJG: | ||||||||||||||
Commercial Paper Program/Revolving Credit Facility | $ | 200,000 | $ | 65,500 | $ | 134,500 | May 2018 | |||||||
Uncommitted Bank Lines | 10,000 | — | 10,000 | August 2014 | ||||||||||
Total SJG | 210,000 | 65,500 | 144,500 | |||||||||||
SJI: | ||||||||||||||
Revolving Credit Facility | 400,000 | 315,200 | 84,800 | February 2018 (A) | ||||||||||
Total SJI | 400,000 | 315,200 | 84,800 | |||||||||||
Total | $ | 610,000 | $ | 380,700 | $ | 229,300 | ||||||||
(A) Includes letters of credit outstanding in the amount of $26.8 million.
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The SJG facilities are restricted as to use and availability specifically to SJG; however, if necessary, the SJI facilities can also be used to support SJG’s liquidity needs. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.04%, 1.10% and 1.12% at December 31, 2013, 2012 and 2011, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2013 and 2012 were $325.6 million and $355.3 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the years ended December 31, 2013 and 2012 were $459.0 million and $462.2 million, respectively.
SJG renewed its $10.0 million line of credit during the third quarter of 2013.
In October 2013, SJI entered into an unsecured $50.0 million term loan, which matures in October 2015. This agreement replaces existing facilities that were set to expire in November 2013.
The SJI and SJG facilities are provided by a syndicate of banks and contain one financial covenant limiting the ratio of indebtedness to total capitalization (as defined in the respective credit agreements) to not more than 0.65 to 1, measured at the end of each fiscal quarter. SJI and SJG were in compliance with this covenant as of December 31, 2013.
SJG manages a commercial paper program under which SJG may issue short-term, unsecured promissory notes to qualified investors up to a maximum aggregate amount outstanding at any time of $200.0 million. The notes have fixed maturities which vary by note, but may not exceed 270 days from the date of issue. Proceeds from the notes are used for general corporate purposes. SJG uses the commercial paper program in tandem with the new $200.0 million revolving credit facility and does not expect the principal amount of borrowings outstanding under the commercial paper program and the credit facility at any time to exceed an aggregate of $200.0 million.
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14. | LONG-TERM DEBT: |
Outstanding Long-Term Debt at December 31 consisted of the following:
2013 | 2012 | ||||||||
Long-Term Debt (A): | |||||||||
South Jersey Gas Company: | |||||||||
First Mortgage Bonds: (B) | |||||||||
4.46% | Series due 2013 (C) | $ | — | $ | 10,500 | ||||
5.027% | Series due 2013 (C) | — | 14,500 | ||||||
4.52% | Series due 2014 | 11,000 | 11,000 | ||||||
5.115% | Series due 2014 | 10,000 | 10,000 | ||||||
5.387% | Series due 2015 | 10,000 | 10,000 | ||||||
5.437% | Series due 2016 | 10,000 | 10,000 | ||||||
4.6% | Series due 2016 | 17,000 | 17,000 | ||||||
4.657% | Series due 2017 | 15,000 | 15,000 | ||||||
7.97% | Series due 2018 | 10,000 | 10,000 | ||||||
7.125% | Series due 2018 | 20,000 | 20,000 | ||||||
5.587% | Series due 2019 | 10,000 | 10,000 | ||||||
3.00% | Series due 2024 (D) | 50,000 | 50,000 | ||||||
3.03% | Series due 2024 (D) | 35,000 | 35,000 | ||||||
3.63% | Series due 2025 | 10,000 | 10,000 | ||||||
4.84% | Series due 2026 | 15,000 | 15,000 | ||||||
4.93% | Series due 2026 | 45,000 | 45,000 | ||||||
4.03% | Series due 2027 | 45,000 | 45,000 | ||||||
4.01% | Series due 2030 (E) | 50,000 | — | ||||||
3.74% | Series due 2032 | 35,000 | 35,000 | ||||||
5.55% | Series due 2033 | 32,000 | 32,000 | ||||||
6.213% | Series due 2034 | 10,000 | 10,000 | ||||||
5.45% | Series due 2035 | 10,000 | 10,000 | ||||||
Series A 2006 Bonds at variable rates due 2036 (F) | 25,000 | 25,000 | |||||||
Marina Energy LLC: (G) | |||||||||
Series A 2001 Bonds at variable rates due 2031 | 20,000 | 20,000 | |||||||
Series B 2001 Bonds at variable rates due 2021 | 25,000 | 25,000 | |||||||
Series A 2006 Bonds at variable rates due 2036 | 16,400 | 16,400 | |||||||
South Jersey Industries (H) | |||||||||
2.39% | Series A 2012 Notes due 2015 | 64,000 | 64,000 | ||||||
2.71% | Series B 2012 Notes due 2017 | 16,000 | 16,000 | ||||||
3.46% | Series C 2012 Notes due 2022 | 35,000 | 35,000 | ||||||
South Jersey Industries Term Loan at variable rates due 2015 (I) | 50,000 | — | |||||||
Total Long-Term Debt Outstanding | 701,400 | 626,400 | |||||||
Less Current Maturities | (21,000 | ) | (25,000 | ) | |||||
Total Long-Term Debt | $ | 680,400 | $ | 601,400 | |||||
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(A) | Long-term debt maturities and sinking funds requirements for the succeeding five years are as follows (in thousands): 2014, $21,000; 2015, $74,909; 2016, $27,909; 2017, $31,909; 2018, $28,000. |
(B) | The First Mortgage dated October 1, 1947, as supplemented, securing the First Mortgage Bonds constitutes a direct first mortgage lien on substantially all utility plant. |
(C) | In July 2013, SJG called its $10.5 million, 4.46% MTN due July 2013 and $14.5 million, 5.027% MTN due September 2013. |
(D) | In September 2012, SJG issued $50.0 million of 3.00% aggregate principal amount of MTN's due September 2024. In November 2012, SJG issued $35.0 million of 3.03% aggregate principal amount of MTN's due November 2024. |
(E) | In November 2013, SJG issued $50.0 million of 4.01% aggregate principal amount of its MTN's due November 2030. |
(F) | These variable rate demand bonds bear interest at a floating rate that resets weekly. The interest rate as of December 31, 2013 was 0.07%. Liquidity support on these bonds is provided under a separate letter of credit facility that expires in August, 2015. These bonds contain no financial covenants. |
(G) | Marina has issued $61.4 million of unsecured variable-rate revenue bonds through the New Jersey Economic Development Authority (NJEDA). The variable rates at December 31, 2013 for the Series A 2001, Series B 2001, and Series A 2006 bonds were 0.08%, 0.18% and 0.08% respectively. The interest rate on all but $27.1 million of the bonds has been effectively fixed via interest rate swaps at 4.41% until January 2026. These bonds contain no financial covenants. Liquidity support on these bonds is provided under a letter of credit facility from a commercial bank that expires in August, 2015. |
(H) | In June 2012, the Company issued $115.0 million aggregate principal amount of long-term debt, consisting of the following: (a) $64.0 million aggregate principal amount of 2.39% Senior Notes due June 2015; (b) $16.0 million aggregate principal amount of 2.71% Senior Notes due June 2017; and (c) $35.0 million aggregate principal amount of 3.46% Senior Notes due June 2022. |
(I) | In October 2013, SJI entered into an unsecured, variable-rate term loan of $50.0 million, which matures in October 2015. This agreement replaces existing facilities that were set to expire in November 2013. The variable rate at December 31, 2013 was 1.22%. These notes have been reclassified from Notes Payable-Banks to Long-Term Debt on the consolidated balances sheets, but are not included in the consolidated statement of cash flows as the reclassification is considered a non-cash financing activity. |
In December 2011, SJG received approval from the BPU to issue up to $200.0 million in long-term debt under its MTN program by September 2014. At December 31, 2013, $30.0 million was available under this program.
15. | COMMITMENTS AND CONTINGENCIES: |
GAS SUPPLY CONTRACTS - In the normal course of business, SJG and SJRG have entered into long-term contracts for natural gas supplies, firm transportation and gas storage service. The transportation and storage service agreements with interstate pipeline suppliers were made under FERC approved tariffs. SJRG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services is approximately $0.4 million per month. SJG's cumulative obligation for demand charges and reservation fees paid to suppliers for these services averages approximately $4.0 million per month and is recovered on a current basis through the BGSS. SJRG has also committed to purchase a minimum of 545,500 dts/d and up to 810,000 dts/d of natural gas, from various suppliers, for terms ranging from three to ten years at index based prices.
PENDING LITIGATION - The Company is subject to claims arising in the ordinary course of business and other legal proceedings. The Company has been named in, among other actions, certain product liability claims related to our former sand mining subsidiary. We accrue liabilities related to these claims when we can reasonably estimate the amount or range of amounts of probable settlement costs or other charges for these claims. The Company has accrued approximately $3.0 million and $3.1 million related to all claims in the aggregate as of December 31, 2013 and 2012, respectively. Management does not believe that it is reasonably possible that there will be a material change in the Company's estimated liability in the near term and does not currently anticipate the disposition of any known claims that would have a material effect on the Company's financial position, results of operations or cash flows.
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COLLECTIVE BARGAINING AGREEMENTS — Unionized personnel represent approximately 45.0% of our workforce at December 31, 2013. The Company has collective bargaining agreements with two unions that represent these employees: the International Brotherhood of Electrical Workers (IBEW) Local 1293 and the International Association of Machinists and Aerospace Workers (IAM) Local 76. SJG employees represented by the IBEW operate under a collective bargaining agreement that runs through February 28, 2017. SJESP employees represented by the IBEW operated under a collective bargaining agreement that was set to expire February 28, 2014, however a new collective bargaining agreement was agreed to which commences on March 1, 2014 and runs through February 28, 2017. The remaining unionized employees represented by the IAM operate under a collective bargaining agreement that expires in August 2014.
GUARANTEES - As of December 31, 2013, SJI, the parent company, has issued guarantees to third parties on behalf of its consolidated subsidiaries. These guarantees were issued to guarantee payment to third parties with whom SJI's consolidated subsidiaries have commodity supply contracts and for Marina's construction and operating activities. As of December 31, 2013, these guarantees support future firm commitments of SJI's consolidated subsidiaries and $114.4 million of the Accounts Payable already recorded on SJI's consolidated balance sheet.
The Company has recorded a liability of $0.7 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the consolidated balance sheets as of December 31, 2013 for the fair value of the following guarantees:
In April 2007, SJI guaranteed certain obligations of LVE Energy Partners, LLC (LVE) an unconsolidated joint venture in which Marina had a 50% equity interest. LVE entered into a 25-year contract with a resort developer to design, build, own and operate a district energy system and central energy center for a planned resort in Las Vegas, Nevada. LVE began construction of the facility in 2007 and expected to provide full energy service in 2010 when the resort was originally scheduled to be completed. LVE suspended construction of the district energy system and central energy center in January 2009 after the resort developer’s announcement that it was delaying the completion of construction of the resort.
In March 2013, the resort developer purchased substantially all of the assets of LVE. As a result, the guarantees provided by SJI of certain performance obligations of LVE under the operating agreements between LVE and the resort developer were canceled.
During the twelve months ended December 31, 2013, the Company received $57.9 million of repayments of advances to LVE and a $7.9 million note receivable from a third party. As of December 31, 2013, LVE was dissolved and the Company incurred a $0.8 million charge to write-off the remaining interest. During 2013, SJI provided support to LVE of approximately $3.2 million to cover interest and other project related costs.
SJI has guaranteed certain obligations of WC Landfill Energy, LLC (WCLE) and BC Landfill Energy, LLC (BCLE), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. WCLE and BCLE have entered into agreements through 2018 and 2027, respectively, with the respective county governments to lease and operate facilities that will produce electricity from landfill methane gas. Although unlikely, the maximum amount that SJI could be obligated for, in the event that WCLE and BCLE do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due, is approximately $4.2 million each year. SJI and its partner in these joint ventures have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees. SJI holds variable interests in WCLE and BCLE but is not the primary beneficiary.
In December 2013, SJI entered into an agreement to guarantee certain obligations of WCLE, SC Landfill Energy, LLC, SX Landfill Energy, LLC, FC Landfill Energy, LLC, and AC Landfill Energy, LLC (collectively, the "Landfills"), unconsolidated joint ventures in which Marina has a 50% equity interest through Energenic. The landfills have entered into long-term debt agreements which run through 2020. Although unlikely, SJI could be liable through the guarantee for 50% of the outstanding debt along with any interest related to the debt in the event the landfills do not meet minimum specified levels of operating performance and no mitigating action is taken, or are unable to meet certain financial obligations as they become due. As of December 31, 2013, 50% of the currently outstanding debt is $9.7 million. As a result, the Company has recorded a liability of $0.5 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the consolidated balance sheets as of December 31, 2013.
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In February 2011, ACR Energy Partners, LLC (ACR), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 20 year contract with a developer to build, own and operate a central energy center and energy distribution system for a new hotel, casino and entertainment complex in Atlantic City, New Jersey. The complex commenced operations in April 2012 and as a result, ACR is providing full energy services to the complex. Marina and its joint venture partner have agreed to provide a $5.0 million letter of credit to support certain operating performance obligations of ACR under the operating agreements between ACR and the developer. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI to or on behalf of ACR.
In May 2012, UMM Energy Partners, LLC (UMM), a wholly-owned subsidiary of Energenic, of which Marina has a 50% equity interest, entered into a 30 year contract with a public university to build, own and operate a combined heating, cooling and power system for its main campus in New Jersey. The system commenced commercial operations in September 2013. SJI has guaranteed certain obligations of UMM under the operating and lease agreements between UMM and the university, for the terms of the agreements, commencing with the first year of operations. SJI has guaranteed up to $2.2 million for the first year. This amount is adjusted each year based upon the Consumer Price Index. SJI and its partner in this joint venture have entered into reimbursement agreements that secure reimbursement for SJI of a proportionate share of any payments made by SJI on these guarantees.
As of December 31, 2013, SJI had issued $6.8 million of parental guarantees on behalf of an unconsolidated subsidiary. These guarantees generally expire within the next two years and were issued to enable our subsidiary to market retail natural gas.
STANDBY LETTERS OF CREDIT — As of December 31, 2013, SJI provided $26.8 million of standby letters of credit through SJI’s revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facility to support variable-rate demand bonds issued through the New Jersey Economic Development Authority (NJEDA) to finance the expansion of SJG’s natural gas distribution system and to finance Marina's initial thermal plant project.
ENVIRONMENTAL REMEDIATION COSTS — SJI incurred and recorded costs for environmental cleanup of 12 sites where SJG or its predecessors operated gas manufacturing plants. SJG stopped manufacturing gas in the 1950s. SJI and some of its nonutility subsidiaries also recorded costs for environmental cleanup of sites where SJF previously operated a fuel oil business and Morie maintained equipment, fueling stations and storage.
SJI successfully entered into settlements with all of its historic comprehensive general liability carriers regarding the environmental remediation expenditures at the SJG sites. Also, SJG had purchased a Cleanup Cost Cap Insurance Policy limiting the amount of remediation expenditures that SJG were required to make at 11 of its sites. This policy provided coverage up to $50.0 million, which was exhausted in 2012.
Since the early 1980s, SJI accrued environmental remediation costs of $342.7 million, of which $219.3 million was spent as of December 31, 2013.
The following table details the amounts expended and accrued for SJI's environmental remediation during the last two years (in thousands):
2013 | 2012 | ||||||
Beginning of Year | $ | 112,098 | $ | 94,160 | |||
Accruals | 22,821 | 30,349 | |||||
Expenditures | (11,490 | ) | (12,411 | ) | |||
End of Year | $ | 123,429 | $ | 112,098 | |||
The balances are segregated between current and noncurrent on the consolidated balance sheets under the captions Current Liabilities and Deferred Credits and Other Noncurrent Liabilities.
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Management estimates that undiscounted future costs to clean up SJG's sites will range from $119.5 million to $223.5 million. Six of SJG's sites comprise the majority of these estimates, the sum of the six sites range from a low of $100.4 million to a high of $192.8 million. SJG recorded the lower end of this range as a liability because a single reliable estimation point is not feasible due to the amount of uncertainty involved in the nature of projected remediation efforts and the long period over which remediation efforts will continue. Recorded amounts include estimated costs based on projected investigation and remediation work plans using existing technologies. Actual costs could differ from the estimates due to the long-term nature of the projects, changing technology, government regulations and site-specific requirements. Significant risks surrounding these estimates include unforeseen market price increases for remedial services, property owner acceptance of remedy selection, regulatory approval of selected remedy and remedial investigative findings.
The remediation efforts at SJG's six most significant sites include the following:
Site 1 - Several interim remedial actions have been completed at the site. Steps remaining to remediate the balance of the site include completion of the remedial investigation of impacted soil and groundwater, selection of the appropriate remedial action, receiving confirmation of regulatory compliance of the selected remedy, and implementation of the approved remedy.
Site 2 - Remediation of the site is underway in accordance with the approved Remedial Action Work plan. Steps remaining to remediate the site include continued excavation of impacted soil and post remediation groundwater monitoring.
Site 3 - Various remedial investigation activities have been completed at this site and a final site remedy has been proposed to the regulatory authority. Steps remaining to remediate the site include receiving confirmation of regulatory compliance of the selected remedy and implementation of the approved remedy.
Site 4 - Remedial investigation activities are ongoing at this site including pilot studies of potential remedial alternatives and continued soil and groundwater investigation. Remaining steps to remediate include completion of the remedial investigation of impacted soil and groundwater, selection of the appropriate remedial action, receiving confirmation of regulatory compliance of the selected remedy, and implementation of the approved remedy.
Sites 5 and 6 - Remedial investigation activities are ongoing at these sites. Remaining steps to remediate include completion of the remedial investigation of impacted soil and groundwater, selection of the appropriate remedial action, receiving confirmation of regulatory compliance of the selected remedy, and implementation of the approved remedy.
With Morie's sale in 1996, EMI assumed responsibility for environmental liabilities currently estimated between $3.0 million and $5.5 million. The information available on these sites is sufficient only to establish a range of probable liability and no point within the range is more likely than any other. Therefore, EMI has accrued the lower end of the range. Changes in the accrual are included in the statements of consolidated income under Loss from Discontinued Operations.
SJI and SJF estimate their potential exposure for the future remediation of six sites where fuel oil operations existed years ago to range from $0.9 million to $1.8 million. The lower end of this range has been recorded under Current Liabilities and Deferred Credits and Other Noncurrent Liabilities as of December 31, 2013.
16. | DERIVATIVE INSTRUMENTS: |
Certain SJI subsidiaries are involved in buying, selling, transporting and storing natural gas and buying and selling retail electricity for their own accounts as well as managing these activities for third parties. These subsidiaries are subject to market risk on expected future purchases and sales due to commodity price fluctuations. The Company uses a variety of derivative instruments to limit this exposure to market risk in accordance with strict corporate guidelines. These derivative instruments include forward contracts, swap agreements, options contracts and futures contracts. As of December 31, 2013, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 17.9 MMdts of expected future purchases of natural gas, 19.1 MMdts of expected future sales of natural gas, 1.3 MMmwh of expected future purchases of electricity and 1.3 MMmwh of expected future sales of electricity. In addition to these derivative contracts, the Company had basis and index related purchase and sales contracts totaling 21.8 MMdts. These contracts, which have not been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives — Energy Related Assets or Derivatives — Energy Related Liabilities on the consolidated balance sheets. The net unrealized pre-tax gains and losses for these energy related commodity contracts are included with realized gains and losses in Operating Revenues – Nonutility.
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As part of its gas purchasing strategy, SJG uses financial contracts through SJRG to limit exposure to forward price risk. The costs or benefits of these short-term contracts are recoverable through SJG's BGSS clause, subject to BPU approval.
SJE transacts commodities on a physical basis and typically does not directly enter into positions that financially settle. SJRG performs this risk management function for SJE and enters into the types of financial transactions noted above.
Management takes an active role in the risk management process and has developed policies and procedures that require specific administrative and business functions to assist in identifying, assessing and controlling various risks. Management reviews any open positions in accordance with strict policies to limit exposure to market risk.
SJI presents revenues and expenses related to its energy trading activities on a net basis in Operating Revenues - Nonutility in the consolidated statements of income consistent with GAAP. This net presentation has no effect on operating income or net income.
The Company has also entered into interest rate derivatives to hedge exposure to increasing interest rates and the impact of those rates on cash flows of variable-rate debt. These interest rate derivatives, some of which have been designated as hedging instruments under GAAP, are measured at fair value and recorded in Derivatives - Other on the consolidated balance sheets. Beginning in July 2012, hedge accounting was discontinued for these derivatives. As a result, unrealized gains and losses on these derivatives, that were previously included in Accumulated Other Comprehensive Loss on the consolidated balance sheets, will be reclassified into earnings over the remaining life of the derivative. These derivatives are expected to mature in 2026.
As of December 31, 2013, SJI's active interest rate swaps were as follows:
Notional Amount | Fixed Interest Rate | Start Date | Maturity | Type of Debt | Obligor | |||||||
$ | 3,900,000 | 4.795% | 12/1/2004 | 12/1/2014 | Taxable | Marina | ||||||
$ | 8,000,000 | 4.775% | 11/12/2004 | 11/12/2014 | Taxable | Marina | ||||||
$ | 14,500,000 | 3.905% | 3/17/2006 | 1/15/2026 | Tax-exempt | Marina | ||||||
$ | 500,000 | 3.905% | 3/17/2006 | 1/15/2026 | Tax-exempt | Marina | ||||||
$ | 330,000 | 3.905% | 3/17/2006 | 1/15/2026 | Tax-exempt | Marina | ||||||
$ | 7,100,000 | 4.895% | 2/1/2006 | 2/1/2016 | Taxable | Marina | ||||||
$ | 12,500,000 | 3.430% | 12/1/2006 | 2/1/2036 | Tax-exempt | SJG | ||||||
$ | 12,500,000 | 3.430% | 12/1/2006 | 2/1/2036 | Tax-exempt | SJG | ||||||
The unrealized gains and losses on interest rate derivatives that are not designated as cash flow hedges are included in Interest Charges. However, for selected interest rate derivatives at SJG, management believes that, subject to BPU approval, the market value upon termination can be recovered in rates and therefore these unrealized losses have been included in Other Regulatory Assets in the consolidated balance sheets.
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The fair values of all derivative instruments, as reflected in the consolidated balance sheets as of December 31, are as follows (in thousands):
Derivatives not designated as hedging instruments under GAAP | 2013 | 2012 | ||||||||||||||
Assets | Liabilities | Assets | Liabilities | |||||||||||||
Energy related commodity contracts: | ||||||||||||||||
Derivatives – Energy Related – Current | $ | 56,327 | $ | 77,993 | $ | 24,242 | $ | 23,828 | ||||||||
Derivatives – Energy Related – Non-Current | 26,451 | 22,131 | 12,297 | 5,403 | ||||||||||||
Interest rate contracts: | ||||||||||||||||
Derivatives - Other | — | 6,676 | — | 13,462 | ||||||||||||
Total derivatives not designated as hedging instruments under GAAP | 82,778 | 106,800 | 36,539 | 42,693 | ||||||||||||
Total Derivatives | $ | 82,778 | $ | 106,800 | $ | 36,539 | $ | 42,693 | ||||||||
The Company enters into derivative contracts with counterparties, some of which are subject to master netting arrangements, which allow net settlements under certain conditions. The Company presents derivatives at gross fair values on the consolidated balance sheets. As of December 31, 2013 and 2012, information related to these offsetting arrangements were as follows (in thousands):
As of December 31, 2013 | ||||||||||||||||||||
Description | Gross amounts of recognized assets/liabilities | Gross amount offset in the balance sheet | Net amounts of assets/liabilities in balance sheet | Gross amounts not offset in the balance sheet | Net amount | |||||||||||||||
Financial Instruments | Cash Collateral Posted | |||||||||||||||||||
Derivatives - Energy Related Assets | 82,778 | — | $ | 82,778 | (28,082 | ) | (A) | (498 | ) | $ | 54,198 | |||||||||
Derivatives - Energy Related Liabilities | (100,124 | ) | — | $ | (100,124 | ) | 28,082 | (B) | 29,639 | $ | (42,403 | ) | ||||||||
Derivatives - Other | (6,676 | ) | — | $ | (6,676 | ) | — | — | $ | (6,676 | ) | |||||||||
As of December 31, 2012 | ||||||||||||||||||||
Description | Gross amounts of recognized assets/liabilities | Gross amount offset in the balance sheet | Net amounts of assets/liabilities in balance sheet | Gross amounts not offset in the balance sheet | Net amount | |||||||||||||||
Financial Instruments | Cash Collateral Posted | |||||||||||||||||||
Derivatives - Energy Related Assets | 36,539 | — | $ | 36,539 | (12,975 | ) | (A) | — | $ | 23,564 | ||||||||||
Derivatives - Energy Related Liabilities | (29,231 | ) | — | $ | (29,231 | ) | 12,975 | (B) | 6,347 | $ | (9,909 | ) | ||||||||
Derivatives - Other | (13,462 | ) | — | $ | (13,462 | ) | — | — | $ | (13,462 | ) | |||||||||
(A) The balances at December 31, 2013 and 2012 were related to derivative liabilities which can be net settled against derivative assets.
(B) The balances at December 31, 2013 and 2012 were related to derivative assets which can be net settled against derivative liabilities.
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The effect of derivative instruments on the consolidated statements of income and comprehensive income for the year ended December 31 is as follows (in thousands):
Derivatives in Cash Flow Hedging Relationships | 2013 | 2012 | 2011 | |||||||||
Interest Rate Contracts: | ||||||||||||
Losses recognized in AOCL on effective portion | $ | — | $ | (752 | ) | $ | (2,773 | ) | ||||
Losses reclassified from AOCL into income (a) | $ | (448 | ) | $ | (594 | ) | $ | (1,435 | ) | |||
Losses recognized in income on ineffective portion (a) | — | — | — | |||||||||
(a) Included in Interest Charges
Derivatives Not Designated as Hedging Instruments under GAAP | 2013 | 2012 | 2011 | |||||||||
(Losses) gains on energy related commodity contracts (a) | $ | (25,823 | ) | $ | (193 | ) | $ | 5,377 | ||||
Gains (losses) on interest rate contracts (b) | 2,760 | 660 | (149 | ) | ||||||||
Total | $ | (23,063 | ) | $ | 467 | $ | 5,228 | |||||
(a) Included in Operating Revenues - Non Utility
(b) Included in Interest Charges
Net realized losses associated with SJG’s energy-related financial commodity contracts of $0.4 million, $15.4 million and $12.9 million for the years ended 2013, 2012 and 2011, respectively, are not included in the above table. These contracts are part of SJG’s regulated risk management activities that serve to mitigate BGSS costs passed on to its customers. As these transactions are entered into pursuant to, and recoverable through, regulatory riders, any changes in the value of SJG’s energy related financial commodity contracts are deferred in Regulatory Assets or Liabilities and there is no impact to earnings.
Certain of the Company’s derivative instruments contain provisions that require immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions in the event of a material adverse change in the credit standing of the Company. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in a liability position on December 31, 2013, is $38.7 million. If the credit-risk-related contingent features underlying these agreements were triggered on December 31, 2013, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $29.8 million after offsetting asset positions with the same counterparties under master netting arrangements.
17. | FAIR VALUE OF FINANCIAL ASSETS AND FINANCIAL LIABILITIES: |
GAAP establishes a hierarchy that prioritizes fair value measurements based on the types of inputs used for the various valuation techniques. The levels of the hierarchy are described below:
• | Level 1: Observable inputs such as quoted prices in active markets for identical assets or liabilities. |
• | Level 2: Inputs other than quoted prices that are observable for the asset or liability, either directly or indirectly; these include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active. |
• | Level 3: Unobservable inputs that reflect the reporting entity’s own assumptions. |
Assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of financial assets and financial liabilities and their placement within the fair value hierarchy.
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For financial assets and financial liabilities measured at fair value on a recurring basis, information about the fair value measurements for each major category is as follows (in thousands):
As of December 31, 2013 | Total | Level 1 | Level 2 | Level 3 | |||||||||||
Assets | |||||||||||||||
Available-for-Sale Securities (A) | $ | 8,716 | $ | 8,716 | $ | — | $ | — | |||||||
Derivatives – Energy Related Assets (B) | 82,778 | 4,385 | 27,182 | 51,211 | |||||||||||
$ | 91,494 | $ | 13,101 | $ | 27,182 | $ | 51,211 | ||||||||
Liabilities | |||||||||||||||
Derivatives – Energy Related Liabilities (B) | $ | 100,124 | $ | 4,236 | $ | 52,772 | $ | 43,116 | |||||||
Derivatives – Other (C) | 6,676 | — | 6,676 | — | |||||||||||
$ | 106,800 | $ | 4,236 | $ | 59,448 | $ | 43,116 | ||||||||
As of December 31, 2012 | Total | Level 1 | Level 2 | Level 3 | |||||||||||
Assets | |||||||||||||||
Available-for-Sale Securities (A) | $ | 7,538 | $ | 787 | $ | 6,751 | $ | — | |||||||
Derivatives – Energy Related Assets (B) | 36,539 | 9,404 | 16,205 | 10,930 | |||||||||||
$ | 44,077 | $ | 10,191 | $ | 22,956 | $ | 10,930 | ||||||||
Liabilities | |||||||||||||||
Derivatives – Energy Related Liabilities (B) | $ | 29,231 | $ | 5,399 | $ | 15,664 | $ | 8,168 | |||||||
Derivatives – Other (C) | 13,462 | — | 13,462 | — | |||||||||||
$ | 42,693 | $ | 5,399 | $ | 29,126 | $ | 8,168 | ||||||||
(A) Available-for-Sale Securities include securities that are traded in active markets and securities that are not traded publicly. The securities traded in active markets are valued using the quoted principal market close prices that are provided by the trustees and are categorized in Level 1 in the fair value hierarchy. The remaining securities consist of funds that are not publicly traded. These funds, which consist of stocks and bonds that are traded individually in active markets, are valued using quoted prices for similar assets and are categorized in Level 2 in the fair value hierarchy.
(B) Derivatives – Energy Related Assets and Liabilities are traded in both exchange-based and non-exchange-based markets. Exchange-based contracts are valued using unadjusted quoted market sources in active markets and are categorized in Level 1 in the fair value hierarchy. Certain non-exchange-based contracts are valued using indicative price quotations available through brokers or over-the-counter, on-line exchanges and are categorized in Level 2. These price quotations reflect the average of the bid-ask mid-point prices and are obtained from sources that management believes provide the most liquid market. For non-exchange-based derivatives that trade in less liquid markets with limited pricing information, model inputs generally would include both observable and unobservable inputs. In instances where observable data is unavailable, management considers the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 as the model inputs generally are not observable.
Significant Unobservable Inputs - Management uses the discounted cash flow model to value Level 3 physical and financial forwards, which calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. Inputs to the valuation model are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third party pricing sources. The validity of the mark-to-market valuations and changes in mark-to-market valuations from period to period are examined and qualified against historical expectations by the risk management function. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
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Level 3 valuation methods for natural gas derivative contracts include utilizing another location in close proximity adjusted for certain pipeline charges to derive a basis value. The significant unobservable inputs used in the fair value measurement of certain natural gas contracts consist of forward prices developed based on industry standard methodologies. Significant increases (decreases) in these forward prices for purchases of natural gas would result in a directionally similar impact to the fair value measurement and for sales of natural gas would result in a directionally opposite impact to the fair value measurement. Level 3 valuation methods for electric represent the value of the contract marked to the forward wholesale curve, as provided by daily exchange quotes for delivered electricity. The significant unobservable inputs used in the fair value measurement of electric contracts consist of fixed contracted electric load profiles; therefore no change in unobservable inputs would occur. Unobservable inputs are updated daily using industry standard techniques. Management reviews and corroborates the price quotations to ensure the prices are observable which includes consideration of actual transaction volumes, market delivery points, bid-ask spreads and contract duration.
(C) Derivatives – Other are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment.
The following table provides quantitative information regarding significant unobservable inputs in Level 3 fair value measurements (in thousands, except for ranges):
Type | Fair Value at December 31, 2013 | Valuation Technique | Significant Unobservable Input | Range [Weighted Average] | |||||
Assets | Liabilities | ||||||||
Forward Contract - Natural Gas | $ | 41,444 | $ | 36,043 | Discounted Cash Flow | Forward price (per dt) | $(1.75) - $6.05 [$(0.79)] | ||
Forward Contract - Electric | $ | 9,767 | $ | 7,073 | Discounted Cash Flow | Fixed electric load profile (on-peak) | 8.06% - 100.00% [54.55%] | ||
Fixed electric load profile (off-peak) | 0.00% - 91.94% [45.45%] | ||||||||
Type | Fair Value at December 31, 2012 | Valuation Technique | Significant Unobservable Input | Range [Weighted Average] | |||
Assets | Liabilities | ||||||
Forward Contract - Natural Gas | 4,340 | 4,986 | Discounted Cash Flow | Forward price (per dt) | $(0.35) - $2.92 [$(0.12)] | ||
Forward Contract - Electric | 6,590 | 3,182 | Discounted Cash Flow | Fixed electric load profile (on-peak) | 21.62% - 100.00% [53.64%] | ||
Fixed electric load profile (off-peak) | 0.00% - 78.38% [46.36%] | ||||||
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The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities at December 31, 2013, using significant unobservable inputs (Level 3), are as follows (in thousands):
Year Ended December 31, 2013 | ||||
Balance at January 1, 2013 | $ | 2,762 | ||
Other changes in fair value from continuing and new contracts, net | 1,573 | |||
Transfers in/(out) of Level 3 (A) | 2,748 | |||
Settlements | 1,012 | |||
Balance at December 31, 2013 | $ | 8,095 | ||
(A) Transfers between different levels of the fair value hierarchy may occur based on the level of observable inputs used to value the instruments from period to period. During the year ended December 31, 2013, $2.7 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data.
Year Ended December 31, 2012 | ||||
Balance at January 1, 2012 | $ | (5,958 | ) | |
Other changes in fair value from continuing and new contracts, net | 2,902 | |||
Settlements | 5,818 | |||
Balance at December 31, 2012 | $ | 2,762 | ||
Total gains for 2013 included in earnings that are attributable to the change in unrealized gains relating to those assets and liabilities still held as of December 31, 2013, is $5.3 million. These gains are included in Operating Revenues-Nonutility on the consolidated statements of income.
18. | ACCUMULATED OTHER COMPREHENSIVE LOSS (AOCL): |
The following table summarizes the changes in accumulated other comprehensive loss (AOCL) for the year ended December 31, 2013 (in thousands):
Postretirement Liability Adjustment | Unrealized Gain (Loss) on Derivatives-Other | Unrealized Gain (Loss) on Available-for-Sale Securities | Other Comprehensive Income (Loss) of Affiliated Companies | Total | |||||||||||||||
Balance at January 1, 2013 (a) | $ | (23,437 | ) | $ | (2,962 | ) | $ | 294 | $ | (5,000 | ) | $ | (31,105 | ) | |||||
Other comprehensive income before reclassifications | 2,699 | 592 | 3,291 | ||||||||||||||||
Amounts reclassified from AOCL (b) | 2,235 | 265 | (489 | ) | 5,043 | 7,054 | |||||||||||||
Net current period other comprehensive income | 4,934 | 265 | 103 | 5,043 | 10,345 | ||||||||||||||
Balance at December 31, 2013 (a) | $ | (18,503 | ) | $ | (2,697 | ) | $ | 397 | $ | 43 | $ | (20,760 | ) | ||||||
(a) Determined using a combined statutory tax rate of 41%.
(b) See table below.
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The following table provides details about reclassifications out of AOCL for the year ended December 31, 2013 (in thousands):
Amounts Reclassified from AOCL | Affected Line Item in the Condensed Consolidated Statements of Income | ||||||
For the Year Ended December 31, 2013 | |||||||
Actuarial Loss on Postretirement Benefits | $ | 3,779 | Operating Expenses: Operations | ||||
Income Taxes | (1,544 | ) | Income Taxes (a) | ||||
$ | 2,235 | ||||||
Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges | $ | 448 | Interest Charges | ||||
Income Taxes | (183 | ) | Income Taxes (a) | ||||
$ | 265 | ||||||
Unrealized Loss on Available-for-Sale Securities | $ | (828 | ) | Other Income | |||
Income Taxes | 339 | Income Taxes (a) | |||||
$ | (489 | ) | |||||
Income of Affiliated Companies | $ | 8,515 | Equity in Loss of Affiliated Companies | ||||
Income Taxes | (3,472 | ) | Income Taxes (a) | ||||
$ | 5,043 | ||||||
Losses from reclassifications for the period net of tax | $ | 7,054 | |||||
19. | SUBSEQUENT EVENTS: |
In January 2014, SJG issued $30.0 million aggregate principal amount of SJG's 4.23% MTN's due January 2030.
In October 2013, SJG filed a petition with the New Jersey Board of Public Utilities to issue up to $200.0 million of long term debt securities in various forms including Medium Term Notes and unsecured debt, with maturities of more than twelve months, over the next three years. This petition was approved in January 2014.
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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Stockholders of
South Jersey Industries, Inc.
Folsom, New Jersey
We have audited the accompanying consolidated balance sheets of South Jersey Industries, Inc. and subsidiaries (the "Company") as of December 31, 2013 and 2012, and the related consolidated statements of income, comprehensive income, cash flows, and changes in equity and comprehensive income for each of the three years in the period ended December 31, 2013. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of South Jersey Industries, Inc. and subsidiaries as of December 31, 2013 and 2012, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2013, in conformity with accounting principles generally accepted in the United States of America.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company's internal control over financial reporting as of December 31, 2013, based on the criteria established in Internal Control-Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 28, 2014 expressed an unqualified opinion on the Company's internal control over financial reporting.
/s/ Deloitte & Touche LLP
Philadelphia, Pennsylvania
February 28, 2014
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Quarterly Financial Data (Unaudited)
(Summarized quarterly results of SJI's operations, in thousands except for per share amounts)
2013 Quarter Ended | 2012 Quarter Ended | |||||||||||||||||||||||||||||||
March 31 | June 30 | Sept. 30 | Dec. 31 | March 31 | June 30 | Sept. 30 | Dec. 31 | |||||||||||||||||||||||||
Operating Revenues | $ | 255,631 | $ | 122,592 | $ | 128,808 | $ | 224,390 | $ | 274,832 | $ | 121,913 | $ | 111,977 | $ | 197,558 | ||||||||||||||||
Expenses: | ||||||||||||||||||||||||||||||||
Cost of Sales - (Excluding depreciation) | 152,301 | 87,827 | 89,160 | 139,703 | 156,868 | 69,519 | 70,549 | 120,866 | ||||||||||||||||||||||||
Operations and Maintenance Including Fixed Charges | 52,226 | 47,114 | 47,789 | 54,674 | 46,071 | 45,467 | 45,970 | 50,072 | ||||||||||||||||||||||||
Income Taxes | 7,772 | (11,632 | ) | (5,533 | ) | (9,621 | ) | 15,884 | (1,072 | ) | (2,576 | ) | (757 | ) | ||||||||||||||||||
Energy and Other Taxes | 3,833 | 1,664 | 1,458 | 2,861 | 3,878 | 1,865 | 1,494 | 2,749 | ||||||||||||||||||||||||
Total Expenses | 216,132 | 124,973 | 132,874 | 187,617 | 222,701 | 115,779 | 115,437 | 172,930 | ||||||||||||||||||||||||
Other Income and Expense | 3,838 | 3,297 | 2,845 | 2,584 | 2,080 | 4,698 | 5,624 | 941 | ||||||||||||||||||||||||
Income (Loss) from Continuing Operations | 43,337 | 916 | (1,221 | ) | 39,357 | 54,211 | 10,832 | 2,164 | 25,569 | |||||||||||||||||||||||
Loss from Discontinued Operations - (Net of tax benefit) | (471 | ) | (28 | ) | (200 | ) | (97 | ) | (136 | ) | (498 | ) | (151 | ) | (383 | ) | ||||||||||||||||
Net Income (Loss) | $ | 42,866 | $ | 888 | $ | (1,421 | ) | $ | 39,260 | $ | 54,075 | $ | 10,334 | $ | 2,013 | $ | 25,186 | |||||||||||||||
Basic Earnings Per Common Share: | ||||||||||||||||||||||||||||||||
Continuing Operations | $ | 1.37 | $ | 0.03 | $ | (0.04 | ) | $ | 1.22 | $ | 1.79 | $ | 0.36 | $ | 0.07 | $ | 0.81 | |||||||||||||||
Discontinued Operations | (0.02 | ) | — | — | — | — | (0.02 | ) | (0.01 | ) | (0.01 | ) | ||||||||||||||||||||
Basic Earnings Per Common Share | $ | 1.35 | $ | 0.03 | $ | (0.04 | ) | $ | 1.22 | $ | 1.79 | $ | 0.34 | $ | 0.07 | $ | 0.80 | |||||||||||||||
Average Shares of Common Stock Outstanding - Basic | 31,757 | 31,949 | 31,984 | 32,259 | 30,249 | 30,393 | 30,861 | 31,465 | ||||||||||||||||||||||||
Diluted Earnings Per Common Share: | ||||||||||||||||||||||||||||||||
Continuing Operations | $ | 1.36 | $ | 0.03 | $ | (0.04 | ) | $ | 1.22 | $ | 1.79 | $ | 0.36 | $ | 0.07 | $ | 0.81 | |||||||||||||||
Discontinued Operations | (0.01 | ) | — | — | — | (0.01 | ) | (0.02 | ) | (0.01 | ) | (0.01 | ) | |||||||||||||||||||
Diluted Earnings Per Common Share | $ | 1.35 | $ | 0.03 | $ | (0.04 | ) | $ | 1.22 | $ | 1.78 | $ | 0.34 | $ | 0.07 | $ | 0.80 | |||||||||||||||
Average Shares of Common Stock Outstanding - Diluted | 31,811 | 32,012 | 31,984 | 32,306 | 30,323 | 30,472 | 30,945 | 31,547 | ||||||||||||||||||||||||
The sum of the quarters for 2013 and 2012 do not equal the year's total due to rounding.
NOTE: | Because of the seasonal nature of the business and the volatility from energy related derivatives, statements for the 3-month periods are not indicative of the results for a full year. |
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Item 9. Changes in and Disagreements with Accountants on
Accounting and Financial Disclosure
None
Item 9A. Controls and Procedures
Evaluation of Disclosure Controls and Procedures
The Company's management, with the participation of its chief executive officer and chief financial officer, evaluated the effectiveness of the design and operation of the Company's disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of December 31, 2013. Based on that evaluation, the Company's chief executive officer and chief financial officer concluded that the disclosure controls and procedures employed at the Company are effective.
Management's Report on Internal Control over Financial Reporting
Management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined under Exchange Act Rules 13a-15(f). The Company's internal control system is designed to provide reasonable assurance to its management and board of directors regarding the preparation and fair presentation of published financial statements. Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of the effectiveness of our internal control over financial reporting based on the framework in Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on our evaluation under that framework, management concluded that our internal control over financial reporting was effective as of December 31, 2013.
The effectiveness of our internal control over financial reporting as of December 31, 2013 has been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in their report which is included under this Item 9A.
Changes in Internal Control over Financial Reporting
There has not been any change in the Company's internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act, during the fiscal quarter ended December 31, 2013 that has materially affected, or is reasonably likely to materially affect, the Company's internal control over financial reporting.
Item 9B. Other Information
None
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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Stockholders of
South Jersey Industries, Inc.
Folsom, New Jersey
We have audited the internal control over financial reporting of South Jersey Industries, Inc. and subsidiaries (the "Company") as of December 31, 2013, based on criteria established in Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal Controls over Financial Reporting. Our responsibility is to express an opinion on the Company's internal control over financial reporting based on our audit.
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
A company's internal control over financial reporting is a process designed by, or under the supervision of, the company's principal executive and principal financial officers, or persons performing similar functions, and effected by the company's board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.
Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2013, based on the criteria established in Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements and financial statement schedules as of and for the year ended December 31, 2013 of the Company and our reports dated February 28, 2014 expressed an unqualified opinion on those consolidated financial statements and financial statement schedules.
/s/ Deloitte & Touche LLP
Philadelphia, Pennsylvania
February 28, 2014
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PART III
Item 10. Directors, Executive Officers and Corporate Governance
Information concerning Directors may be found under the captions “Director Elections”, “Nominees”, “Directors and Management”, “Security Ownership”, "Meetings of the Board of Directors and its Committees", and “The Board of Directors” in our definitive proxy statement for our 2014 Annual Meeting of Shareholders (the “2014 Proxy Statement”), which will be filed within the Commission within 120 days after the close of our fiscal year. Information concerning the members of the Company's Audit Committee and the Company's Audit Committee Financial Expert is also incorporated by reference to the 2014 Proxy Statement under the captions "Meetings of the Board of Directors and its Committees", “Audit Committee” and “Audit Committee Report.” Such information is incorporated herein by reference. Information required by this item relating to the executive officers of SJI is set forth in Item 4-A of this Report.
Code of Ethics
The Company has adopted a Code of Ethics for its Principal Executive, Financial and Accounting Officers. It is available on SJI's website, www.sjindustries.com by clicking “Investors” and then “Corporate Governance.” We will post any amendment to or waiver of the Code to our website.
Item 11. Executive Compensation
Information concerning executive compensation may be found under the caption “Compensation Discussion & Analysis” of our 2014 Proxy Statement. Such information is incorporated herein by reference.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
The information in our 2014 Proxy Statement set forth under the caption “Security Ownership” is incorporated herein by reference.
Item 13. Certain Relationships and Related Transactions, and Director Independence
The information in our 2014 Proxy Statement set forth under the caption “The Board of Directors” and “Certain Relationships” is incorporated herein by reference.
Item 14. Principal Accountant Fees and Services
The information in our 2014 Proxy Statement set forth under the caption “Audit Committee Report” is incorporated herein by reference.
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PART IV
Item 15. Exhibits and Financial Statement Schedules
(a) | Listed below are all financial statements and schedules filed as part of this Report: |
1 - The consolidated financial statements and notes to consolidated financial statements together with the report thereon of Deloitte & Touche LLP, dated February 28, 2014, are filed as part of this Report under Item 8 - Financial Statements and Supplementary Data.
2 - Supplementary Financial Information
Information regarding selected quarterly financial data can be found on page 98 of this Report.
Schedule I - Supplemental Schedules as of December 31, 2013 and 2012 and for the three years ended December 31, 2013, 2012, and 2011 (page 110).
Report of Independent Registered Public Accounting Firm of Deloitte & Touche LLP (page 109).
Schedule II - Valuation and Qualifying Accounts (page 114).
All schedules, other than that listed above, are omitted because the information called for is included in the financial statements filed or because they are not applicable or are not required.
(b) | List of Exhibits (Exhibit Number is in Accordance with the Exhibit Table in Item 601 of Regulation S-K). |
Exhibit Number | Description | Reference | ||
(3)(a)(i) | Certificate of Incorporation of South Jersey Industries, Inc., as amended through April 19, 1984. | Incorporated by reference from Exhibit (4)(a) of Form S-2 (2-91515). | ||
(3)(a)(ii) | Amendment to Certificate of Incorporation relating to two-for-one stock split effective as of April 28, 1987. | Incorporated by reference from Exhibit (4)(e)(1) of Form S-3 (33-1320). | ||
(3)(a)(iii) | Amendment to Certificate of Incorporation relating to director and officer liability. | Incorporated by reference from Exhibit (4)(e)(2) of Form S-3 (33-1320). | ||
(3)(a)(iv) | Amendment to Certificate of Incorporation relating to two-for-one stock split effective as of June 30, 2005. | Incorporated by reference from Exhibit 3 of Form 10-Q of SJI filed on May 10, 2005. | ||
(3)(a)(v) | Amendment to Certificate of Incorporation as of April 23, 2009 establishing the annual election of the South Jersey Industries, Inc. directors | Incorporated by reference from Exhibit 99.2 of Form 8-K filed on April 28, 2009. | ||
(3)(b)(i) | Bylaws of South Jersey Gas Company as amended and restated through January 1, 2013. | Incorporated by reference from Exhibit 3.1 of Form 8-K of SJG as filed January 4, 2013. | ||
(3)(b)(ii) | Bylaws of South Jersey Industries, Inc. as amended and restated through January 24, 2014. | Incorporated by reference from Exhibit 3.2 of Form 8-K of SJI as filed January 24, 2014. | ||
(4)(a) | Form of Stock Certificate for common stock. | Incorporated by reference from Exhibit (4)(a) of Form 10-K for 1985 (1-6364). | ||
(4)(b)(i) | First Mortgage Indenture dated October 1, 1947. | Incorporated by reference from Exhibit (4)(b)(i) of Form 10-K for 1987 (1-6364). | ||
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(4)(b)(ii) | Nineteenth Supplemental Indenture dated as of April 1, 1992. | Incorporated by reference from Exhibit (4)(b)(xvii) of Form 10-K for 1992 (1-6364). | ||
(4)(b)(iii) | Twenty-First Supplemental Indenture dated as of March 1, 1997. | Incorporated by reference from Exhibit (4)(b)(xviv) of Form 10-K for 1997(1-6364). | ||
(4)(b)(iv) | Twenty-Second Supplemental Indenture dated as of October 1, 1998. | Incorporated by reference from Exhibit (4)(b)(ix) of Form S-3 (333-62019). | ||
(4)(b)(v) | Twenty-Third Supplemental Indenture dated as of September 1, 2002. | Incorporated by reference from Exhibit (4)(b)(x) of Form S-3 (333-98411). | ||
(4)(b)(vi) | Twenty-Fourth Supplemental Indenture dated as of September 1, 2005. | Incorporated by reference from Exhibit (4)(b)(vi) of Form S-3 (333-126822). | ||
(4)(b)(vii) | Amendment to Twenty-Fourth Supplemental Indenture dated as of March 31, 2006 | Incorporated by reference from Exhibit 4 of Form 8-K of SJG as filed April 26, 2006. | ||
(4)(b)(viii) | Amendment No. 2 to the Twenty-Fourth Supplemental Indenture dated as of December 20, 2010. | Incorporated by reference from Exhibit (4)(b)(viii) of Form 10-K for 2010 | ||
(4)(b)(ix) | Loan Agreement by and between New Jersey Economic Development Authority and SJG dated April 1, 2006. | Incorporated by reference from Exhibit 10 of Form 8-K of SJG as filed April 26, 2006. | ||
(4)(b)(x) | Twenty-Fifth Supplemental Indenture dated as of March 29, 2012. | Incorporated by reference from Exhibit 4.1 of Form 8-K of SJG as filed April 3, 2012. | ||
(4)(c)(i) | Medium Term Note Indenture of Trust dated October 1, 1998. | Incorporated by reference from Exhibit 4(e) of Form S-3 (333-62019). | ||
(4)(c)(ii) | First Supplement to Indenture of Trust dated as of June 29, 2000. | Incorporated by reference from Exhibit 4.1 of Form 8-K of SJG dated July 12, 2001. | ||
(4)(c)(iii) | Second Supplement to Indenture of Trust dated as of July 5, 2000. | Incorporated by reference from Exhibit 4.2 of Form 8-K of SJG dated July 12, 2001. | ||
(4)(c)(iv) | Third Supplement to Indenture of Trust dated as of July 9, 2001. | Incorporated by reference from Exhibit 4.3 of Form 8-K of SJG dated July 12, 2001. | ||
(4)(c)(v) | Fourth Supplement to Indenture of Trust dated as of February 26, 2010. | Incorporated by reference from Exhibit 4.1 of Form 8-K of SJG dated March 5, 2010. | ||
(10)(a)(i) | Gas storage agreement (GSS) between South Jersey Gas Company and Transco dated October 1, 1993. | Incorporated by reference from Exhibit (10)(d) of Form 10-K for 1993 (1-6364). | ||
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Exhibit Number | Description | Reference | ||
(10)(a)(ii) | Gas storage agreement (LG-A) between South Jersey Gas Company and Transco dated June 3, 1974. | Incorporated by reference from Exhibit (5)(f) of Form S-7 (2-56223). | ||
(10)(a)(iii) | Gas storage agreement (WSS) between South Jersey Resources Group LLC and Transco dated May 1, 2006. | Incorporated by reference from Exhibit (10)(a)(iii) of Form 10-K for 2008. | ||
(10)(a)(iv) | Gas storage agreement (LSS) between South Jersey Gas Company and Transco dated October 1, 1993. | Incorporated by reference from Exhibit (10)(i) of Form 10-K for 1993 (1-6364). | ||
(10)(a)(v) | Gas storage agreement (SS-1) between South Jersey Gas Company and Transco dated May 10, 1987 (effective April 1, 1988). | Incorporated by reference from Exhibit (10)(i)(a) of Form 10-K for 1988 (1-6364). | ||
(10)(b)(i) | Gas storage agreement (SS-2) between South Jersey Gas Company and Transco dated July 25, 1990. | Incorporated by reference from Exhibit (10)(i)(i) of Form 10-K for 1991 (1-6364). | ||
(10)(b)(ii) | Amendment to gas transportation agreement dated December 20, 1991 between South Jersey Gas Company and Transco dated October 5, 1993. | Incorporated by reference from Exhibit (10)(i)(k) of Form 10-K for 1993 (1-6364). | ||
(10)(b)(iii) | CNJEP Service agreement between South Jersey Gas Company and Transco dated June 27, 2005. | Incorporated by reference from Exhibit (10)(i)(l) of Form 10-K for 2005 (1-6364). | ||
(10)(c)(i) | FTS Service Agreement No. 38099 between South Jersey Gas Company and Columbia Gas Transmission Corporation dated November 1, 1993. | Incorporated by reference from Exhibit (10)(k)(n) of Form 10-K for 1993 (1-6364). | ||
(10)(c)(ii) | NTS Service Agreement No. 39305 between South Jersey Gas Company and Columbia Gas Transmission Corporation dated November 1, 1993. | Incorporated by reference from Exhibit (10)(k)(o) of Form 10-K for 1993 (1-6364). | ||
(10)(c)(iii) | FSS Service Agreement No. 38130 between South Jersey Gas Company and Columbia Gas Transmission Corporation dated November 1, 1993. | Incorporated by reference from Exhibit (10)(k)(p) of Form 10-K for 1993 (1-6364). | ||
(10)(d)(i) | SST Service Agreement No. 38086 between South Jersey Gas Company and Columbia Gas Transmission Corporation dated November 1, 1993. | Incorporated by reference from Exhibit (10)(k)(q) of Form 10-K for 1993 (1-6364). | ||
(10)(e)(i)* | Deferred Payment Plan for Directors of South Jersey Industries, Inc., South Jersey Gas Company, Energy & Minerals, Inc., R&T Group, Inc. and South Jersey Energy Company as amended and restated October 21, 1994. | Incorporated by reference from Exhibit (10)(l) of Form 10-K for 1994 (1-6364). | ||
(10)(e)(ii)* | Schedule of Deferred Compensation Agreements. | Incorporated by reference from Exhibit (10)(l)(b) of Form 10-K for 1997 (1-6364). | ||
(10)(e)(iii)* | Form of Officer Change in Control Agreements, effective January 1, 2013, between certain officers and either South Jersey Industries, Inc. or its subsidiaries. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI as filed January 25, 2013. | ||
(10)(e)(iv)* | Schedule of Officer Agreements (filed herewith). | |||
(10)(f)(i)* | Officer Severance Plan (filed herewith). | |||
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(10)(f)(ii)* | Supplemental Executive Retirement Program, as amended and restated effective January 1, 2009 and Form of Agreement between certain SJI or subsidiary officers. | Incorporated by reference from Exhibit (10)(f)(ii) of Form 10-K for 2009. | ||
(10)(f)(iii)* | South Jersey Industries, Inc. 1997 Stock-Based Compensation Plan (As Amended and Restated Effective January 1, 2012). | Incorporated by reference from Exhibit 10.3 of Form 8-K of SJI as filed January 6, 2012. | ||
(10)(g)(i) | Four-Year Revolving Credit Agreement, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated May 2, 2011. | ||
(10)(g)(ii) | Four-Year Revolving Credit Agreement, for SJG. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated May 6, 2011. | ||
(10)(g)(iii) | Note Purchase Agreement dated as of March 1, 2010. | Incorporated by reference from Exhibit 10 of Form 8-K of SJG dated March 5, 2010. | ||
(10)(g)(iv) | Note Purchase Agreement dated as of December 30, 2010. | Incorporated by reference from Exhibit 10 of Form 8-K of SJG dated January 5, 2011. | ||
(10)(g)(v) | Commercial Paper Dealer Agreement, dated as of July 1, 2011, for SJG. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated July 1, 2011. | ||
(10)(g)(vi) | Commercial Paper Dealer Agreement, dated as of January 5, 2012, for SJG. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated January 9, 2012. | ||
(10)(g)(vii) | Letter of Credit Reimbursement Agreements dated as of March 15, 2012. | Incorporated by reference from Exhibit 10.1-10.3 of Form 8-K of SJI dated March 21, 2012. | ||
(10)(g)(viii) | Note Purchase Agreement dated as of April 2, 2012. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated April 3, 2012. | ||
(10)(g)(ix) | Term Loan Credit Agreement, dated as of June 1, 2012, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated June 1, 2012. | ||
(10)(g)(x) | Note Purchase Agreement, dated as of June 28, 2012, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated June 29, 2012. | ||
(10)(g)(xi) | Note Purchase Agreement, dated as of September 20, 2012, for SJG. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated September 25, 2012. | ||
(10)(g)(xii) | First Amendment to Credit Agreement, dated as of February 11, 2013, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated February 14, 2013. | ||
(10)(g)(xiii) | First Amendment to Credit Agreement, dated as of September 27, 2013, for SJG. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated September 30, 2013. | ||
(10)(g)(xiv) | Term Loan Credit Agreement, dated as of October 28, 2013, for SJI. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJI dated October 30, 2013. | ||
(10)(g)(xv) | Note Purchase Agreement, dated as of November 21, 2013, for SJG. | Incorporated by reference from Exhibit 10.1 of Form 8-K of SJG dated November 21, 2013. | ||
(10)(g)(xvi) | Second Amendment to Credit Agreement, dated as of September 27, 2013, for SJI (filed herewith). | |||
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(12) | Calculation of Ratio of Earnings to Fixed Charges (Before Federal Income Taxes) (filed herewith). | |||
(14) | Code of Ethics. | Incorporated by reference from Exhibit 14 of Form 10-K for 2007. | ||
(21) | Subsidiaries of the Registrant (filed herewith). | |||
(23) | Independent Registered Public Accounting Firm's Consent (filed herewith). | |||
(31.1) | Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith). | |||
(31.2) | Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith). | |||
(32.1) | Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (filed herewith). | |||
(32.2) | Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (filed herewith). | |||
(101.INS) | eXtensible Business Reporting Language (XBRL) Instance Document (filed herewith). | |||
(101.SCH) | XBRL Taxonomy Extension Schema (filed herewith). | |||
(101.CAL) | XBRL Taxonomy Extension Calculation Linkbase (filed herewith). | |||
(101.DEF) | XBRL Taxonomy Extension Definition Linkbase (filed herewith). | |||
(101.LAB) | XBRL Taxonomy Extension Label Linkbase (filed herewith). | |||
(101.PRE) | XBRL Taxonomy Extension Presentation Linkbase (filed herewith). | |||
* Constitutes a management contract or a compensatory plan or arrangement.
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SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized.
SOUTH JERSEY INDUSTRIES, INC. | |||
BY: | /s/ Stephen H. Clark | ||
Stephen H. Clark | |||
Chief Financial Officer & Treasurer | |||
Date: | February 28, 2014 | ||
Pursuant to the requirements of the Securities Exchange Act of 1934, this Report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
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Signature | Title | Date | |
/s/ Edward J. Graham | Chairman of the Board & Chief Executive Officer | February 28, 2014 | |
(Edward J. Graham) | (Principal Executive Officer) | ||
/s/ Michael J. Renna | Director, President & Chief Operating Officer | February 28, 2014 | |
(Michael J. Renna) | |||
/s/ Stephen H. Clark | Chief Financial Officer & Treasurer | February 28, 2014 | |
(Stephen H. Clark) | (Principal Financial and Accounting Officer) | ||
/s/ Sarah M. Barpoulis | Director | February 28, 2014 | |
(Sarah M. Barpoulis) | |||
/s/ Thomas A. Bracken | Director | February 28, 2014 | |
(Thomas A. Bracken) | |||
/s/ Keith S. Campbell | Director | February 28, 2014 | |
(Keith S. Campbell) | |||
/s/ Victor A. Fortkiewicz | Director | February 28, 2014 | |
(Victor A. Fortkiewicz) | |||
/s/ Sheila Hartnett-Devlin | Director | February 28, 2014 | |
(Sheila Hartnett-Devlin) | |||
/s/ Walter M. Higgins, III | Director | February 28, 2014 | |
(Walter M. Higgins, III) | |||
/s/ Sunita Holzer | Director | February 28, 2014 | |
(Sunita Holzer) | |||
/s/ Joseph H. Petrowski | Director | February 28, 2014 | |
(Joseph H. Petrowski) | |||
/s/ Frank L. Sims | Director | February 28, 2014 | |
(Frank L. Sims) | |||
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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Stockholders of
South Jersey Industries, Inc.
Folsom, New Jersey
We have audited the consolidated financial statements of South Jersey Industries, Inc. and subsidiaries (the “Company”) as of December 31, 2013 and 2012, and for each of the three years in the period ended December 31, 2013, and the Company's internal control over financial reporting as of December 31, 2013, and have issued our reports thereon dated February 28, 2014; such reports are included elsewhere in this Annual Report on Form 10-K. Our audits also included the financial statement schedules of the Company listed in Item 15(a)2. These financial statement schedules are the responsibility of the Company's management. Our responsibility is to express an opinion based on our audits. In our opinion, such financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.
/s/ Deloitte & Touche LLP
Philadelphia, Pennsylvania
February 28, 2014
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SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED STATEMENTS OF INCOME
(In Thousands)
2013 | 2012 | 2011 | ||||||||||
Management Service Fee Revenues | $ | 16,269 | $ | 15,449 | $ | 13,117 | ||||||
Operating Expenses: | ||||||||||||
Operations | 14,979 | 13,869 | 12,390 | |||||||||
Depreciation | 260 | 183 | 160 | |||||||||
Energy and Other Taxes | 465 | 419 | 611 | |||||||||
Total Operating Expenses | 15,704 | 14,471 | 13,161 | |||||||||
Operating Income (Loss) | 565 | 978 | (44 | ) | ||||||||
Other Income: | ||||||||||||
Equity in Earnings of Subsidiaries | 82,389 | 92,776 | 89,859 | |||||||||
Other | 5,459 | 3,270 | 2,688 | |||||||||
Total Other Income | 87,848 | 96,046 | 92,547 | |||||||||
Interest Charges | 6,004 | 4,219 | 2,648 | |||||||||
Income Taxes | 20 | 29 | (4 | ) | ||||||||
Income from Continuing Operations | 82,389 | 92,776 | 89,859 | |||||||||
Equity in Undistributed Earnings of Discontinued Subsidiaries | (796 | ) | (1,168 | ) | (568 | ) | ||||||
Net Income | $ | 81,593 | $ | 91,608 | $ | 89,291 | ||||||
SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(In Thousands)
2013 | 2012 | 2011 | ||||||||||
Net Income | $ | 81,593 | $ | 91,608 | $ | 89,291 | ||||||
Other Comprehensive Loss - Net of Tax* | ||||||||||||
Postretirement Liability Adjustment | 4,934 | (1,842 | ) | (5,667 | ) | |||||||
Unrealized Gain (Loss) on Available-for-Sale Securities | 103 | 500 | (360 | ) | ||||||||
Unrealized Gain (Loss) on Derivatives | 5,308 | (1,325 | ) | (599 | ) | |||||||
Total Other Comprehensive Income (Loss) - Net of Tax* | 10,345 | (2,667 | ) | (6,626 | ) | |||||||
Comprehensive Income | $ | 91,938 | $ | 88,941 | $ | 82,665 | ||||||
* Determined using a combined statutory tax rate of 41%
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SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED STATEMENTS OF RETAINED EARNINGS
(In Thousands)
2013 | 2012 | 2011 | ||||||||||
Retained Earnings - Beginning | $ | 382,127 | $ | 341,677 | $ | 297,473 | ||||||
Net Income | 81,593 | 91,608 | 89,291 | |||||||||
463,720 | 433,285 | 386,764 | ||||||||||
Dividends Declared - Common Stock | (57,679 | ) | (51,158 | ) | (45,087 | ) | ||||||
Retained Earnings - Ending | $ | 406,041 | $ | 382,127 | $ | 341,677 | ||||||
SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED STATEMENTS OF CASH FLOWS
FOR THE TWELVE MONTHS ENDED DECEMBER 31,
(In Thousands)
2013 | 2012 | 2011 | ||||||||||
CASH PROVIDED BY OPERATING ACTIVITIES | $ | 1,316 | $ | 1,840 | $ | 14,179 | ||||||
CASH FLOWS FROM INVESTING ACTIVITIES: | ||||||||||||
Net (Advances to) Repayment from Associated Companies | (68,900 | ) | (174,593 | ) | 22,957 | |||||||
Capital Expenditures | (360 | ) | (454 | ) | (299 | ) | ||||||
Proceeds from Sale of Property, Plant & Equipment | 6 | 29 | — | |||||||||
Purchase of Company Owned Life Insurance | (5,149 | ) | (4,547 | ) | (4,628 | ) | ||||||
Investment in Affiliate | (25,000 | ) | — | — | ||||||||
Net Cash (Used In) Provided by Investing Activities | (99,403 | ) | (179,565 | ) | 18,030 | |||||||
CASH FLOWS FROM FINANCING ACTIVITIES: | ||||||||||||
Proceeds from Issuance of Long Term Debt | — | 115,000 | — | |||||||||
Payments for Issuance of Long Term Debt | — | (665 | ) | — | ||||||||
Net Borrowing from Lines of Credits | 101,600 | 42,000 | 3,013 | |||||||||
Dividends on Common Stock | (57,679 | ) | (50,942 | ) | (44,975 | ) | ||||||
Proceeds from Sale of Common Stock | 54,028 | 70,241 | 13,436 | |||||||||
Net Cash Provided by (Used In) Financing Activities | 97,949 | 175,634 | (28,526 | ) | ||||||||
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS | (138 | ) | (2,091 | ) | 3,683 | |||||||
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR | 1,969 | 4,060 | 377 | |||||||||
CASH AND CASH EQUIVALENTS AT END OF YEAR | $ | 1,831 | $ | 1,969 | $ | 4,060 | ||||||
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SCHEDULE I - SOUTH JERSEY INDUSTRIES, INC.
CONDENSED BALANCE SHEETS (In Thousands)
2013 | 2012 | |||||||
Assets | ||||||||
Property Plant and Equipment: | ||||||||
Nonutility Property, Plant and Equipment, at cost | $ | 1,506 | $ | 1,165 | ||||
Accumulated Depreciation | (752 | ) | (510 | ) | ||||
Property, Plant and Equipment - Net | 754 | 655 | ||||||
Investments: | ||||||||
Investments in Subsidiaries | 887,671 | 770,127 | ||||||
Available-for-Sale Securities | 21 | 18 | ||||||
Total Investments | 887,692 | 770,145 | ||||||
Current Assets: | ||||||||
Cash and Cash Equivalents | 1,831 | 1,969 | ||||||
Receivable from Associated Companies | 358,620 | 289,635 | ||||||
Accounts Receivable | 46 | 16 | ||||||
Other | 1,510 | 3,401 | ||||||
Total Current Assets | 362,007 | 295,021 | ||||||
Other Noncurrent Assets | 35,882 | 29,624 | ||||||
Total Assets | $ | 1,286,335 | $ | 1,095,445 | ||||
Capitalization and Liabilities | ||||||||
Equity: | ||||||||
Common Stock SJI | ||||||||
Par Value $1.25 a share | ||||||||
Authorized - 60,000,000 shares | ||||||||
Outstanding - 32,715,042 (2013) shares and 31,653,262 (2012) | 40,894 | $ | 39,567 | |||||
Premium on Common Stock | 401,011 | 345,807 | ||||||
Treasury Stock (at par) | (186 | ) | (182 | ) | ||||
Accumulated Other Comprehensive Loss | (20,760 | ) | (31,105 | ) | ||||
Retained Earnings | 406,041 | 382,127 | ||||||
Total Equity | 827,000 | 736,214 | ||||||
Long-Term Debt | 165,000 | 115,000 | ||||||
Current Liabilities: | ||||||||
Notes Payable - Banks | 288,400 | 236,800 | ||||||
Payable to Associated Companies | 257 | 172 | ||||||
Accounts Payable | 322 | 510 | ||||||
Other Current Liabilities | 2,063 | 1,923 | ||||||
Total Current Liabilities | 291,042 | 239,405 | ||||||
Other Noncurrent Liabilities | 3,293 | 4,826 | ||||||
Total Capitalization and Liabilities | $ | 1,286,335 | $ | 1,095,445 | ||||
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South Jersey Industries, Inc.
Part IV
Notes to Condensed Financial Statements
1. | BASIS OF PRESENTATION: |
Pursuant to rules and regulations of the SEC, the unconsolidated condensed financial statements of SJI do not reflect all of the information and notes normally included with financial statements prepared in accordance with GAAP in the United States. Therefore, these condensed financial statements should be read in conjunction with the consolidated financial statements and related notes included under Item 8 in this Form 10-K.
Dividends received from subsidiaries amounted to $12.7 million in 2011. No dividends were received from subsidiaries in 2013 and 2012.
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South Jersey Industries, Inc.
Part IV
SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
(In Thousands)
Col. A | Col. B | Col. C | Col. D | Col. E | ||||||||||||||||
Additions | ||||||||||||||||||||
Classification | Balance at Beginning of Period | Charged to Costs and Expenses | Charged to Other Accounts - Describe (a) | Deductions - Describe (b) | Balance at End of Period | |||||||||||||||
Provision for Uncollectible | ||||||||||||||||||||
Accounts for the Year Ended | ||||||||||||||||||||
December 31, 2013 | $ | 5,924 | $ | 4,245 | $ | (41 | ) | $ | 4,274 | $ | 5,854 | |||||||||
Provision for Uncollectible | ||||||||||||||||||||
Accounts for the Year Ended | ||||||||||||||||||||
December 31, 2012 | $ | 5,337 | $ | 4,932 | $ | 110 | $ | 4,455 | $ | 5,924 | ||||||||||
Provision for Uncollectible | ||||||||||||||||||||
Accounts for the Year Ended | ||||||||||||||||||||
December 31, 2011 | $ | 8,071 | $ | 2,272 | $ | 562 | $ | 5,568 | $ | 5,337 | ||||||||||
(a) Recoveries of accounts previously written off and minor adjustments.
(b) Uncollectible accounts written off.
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