10-Q
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, DC 20549
FORM 10-Q
(Mark one)
x
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2015
OR
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
 
22-1901645
(State of incorporation)
 
(IRS employer identification no.)
1 South Jersey Plaza, Folsom, NJ 08037
(Address of principal executive offices, including zip code)
(609) 561-9000
(Registrant’s telephone number, including area code)
 
Common Stock
 
 
($1.25 par value per share)
 
New York Stock Exchange
(Title of each class)
 
(Name of exchange on which registered)
Securities registered pursuant to Section 12(g) of the Act: None
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 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
As of November 2, 2015 there were 69,294,447 shares of the registrant’s common stock outstanding.



TABLE OF CONTENTS
 
 
PageNo.
 
 
PART I
FINANCIAL INFORMATION
 
 
 
 
Item 1.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Item 2.
Item 3.
Item 4.
 
 
 
PART II
OTHER INFORMATION
 
 
 
 
Item 1.
Item 1A.
Item 6.
 
 
 

Table of Contents

Item 1. Unaudited Condensed Consolidated Financial Statements
 
SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)
(In Thousands Except for Per Share Data)
 
Three Months Ended
September 30,
 
2015
 
2014
Operating Revenues:
 
 
 
Utility
$
57,507

 
$
60,756

Nonutility
83,555

 
61,671

Total Operating Revenues
141,062

 
122,427

Operating Expenses:
 

 
 

Cost of Sales - (Excluding depreciation)
 

 
 

 - Utility
21,808

 
23,205

 - Nonutility
77,316

 
52,868

Operations
33,150

 
29,939

Maintenance
4,188

 
3,275

Depreciation
18,422

 
16,057

Energy and Other Taxes
1,231

 
1,196

Total Operating Expenses
156,115

 
126,540

Operating Loss
(15,053
)
 
(4,113
)
 
 
 
 
Other Income and Expense
2,241

 
3,419

Interest Charges
(8,107
)
 
(6,768
)
Loss Before Income Taxes
(20,919
)
 
(7,462
)
Income Taxes
10,968

 
8,325

Equity in Loss of Affiliated Companies
(2,581
)
 
(5,139
)
Loss from Continuing Operations
(12,532
)
 
(4,276
)
Loss from Discontinued Operations - (Net of tax benefit)
(91
)
 
(120
)
Net Loss
$
(12,623
)
 
$
(4,396
)
 
 
 
 
Basic Earnings Per Common Share:
 

 
 

Continuing Operations
$
(0.18
)
 
$
(0.07
)
Discontinued Operations
—

 
—

Basic Earnings Per Common Share
$
(0.18
)
 
$
(0.07
)
 
 
 
 
Average Shares of Common Stock Outstanding - Basic
68,607

 
66,332

 
 
 
 
Diluted Earnings Per Common Share:
 

 
 

Continuing Operations
$
(0.18
)
 
$
(0.07
)
Discontinued Operations
—

 
—

Diluted Earnings Per Common Share
$
(0.18
)
 
$
(0.07
)
 
 
 
 
Average Shares of Common Stock Outstanding - Diluted
68,607

 
66,332

 
 
 
 
Dividends Declared Per Common Share
$
0.25

 
$
0.24


The accompanying notes are an integral part of the unaudited condensed consolidated financial statements. All share and per share amounts were adjusted for all periods presented for the 2-for-1 stock split, effected in the form of a stock dividend, effective on May 8, 2015. See Note 1.

1
Table of Contents


SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)
(In Thousands Except for Per Share Data)
 
Nine Months Ended
September 30,
 
2015
 
2014
Operating Revenues:
 
 
 
Utility
$
399,332

 
$
339,988

Nonutility
302,393

 
265,911

Total Operating Revenues
701,725

 
605,899

Operating Expenses:
 

 
 

Cost of Sales - (Excluding depreciation)
 

 
 

 - Utility
191,683

 
150,905

 - Nonutility
240,093

 
232,253

Operations
108,813

 
99,941

Maintenance
12,114

 
9,715

Depreciation
52,671

 
46,543

Energy and Other Taxes
4,693

 
4,390

Total Operating Expenses
610,067

 
543,747

Operating Income
91,658

 
62,152

 
 
 
 
Other Income and Expense
7,522

 
9,972

Interest Charges
(24,182
)
 
(20,698
)
Income Before Income Taxes
74,998

 
51,426

Income Taxes
(2,366
)
 
5,966

Equity in Loss of Affiliated Companies
(17,970
)
 
(3,756
)
Income from Continuing Operations
54,662

 
53,636

Loss from Discontinued Operations - (Net of tax benefit)
(441
)
 
(513
)
Net Income
$
54,221

 
$
53,123

 
 
 
 
Basic Earnings Per Common Share:
 

 
 

Continuing Operations
$
0.80

 
$
0.81

Discontinued Operations
(0.01
)
 
—

Basic Earnings Per Common Share
$
0.79

 
$
0.81

 
 
 
 
Average Shares of Common Stock Outstanding - Basic
68,491

 
65,932

 
 
 
 
Diluted Earnings Per Common Share:
 

 
 

Continuing Operations
$
0.80

 
$
0.81

Discontinued Operations
(0.01
)
 
—

Diluted Earnings Per Common Share
$
0.79

 
$
0.81

 
 
 
 
Average Shares of Common Stock Outstanding - Diluted
68,689

 
66,082

 
 
 
 
Dividends Declared per Common Share
$
0.75

 
$
0.71


The accompanying notes are an integral part of the unaudited condensed consolidated financial statements. All share and per share amounts were adjusted for all periods presented for the 2-for-1 stock split, effected in the form of a stock dividend, effective on May 8, 2015. See Note 1.

2
Table of Contents


SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)
(In Thousands)
 
 
Three Months Ended
September 30,
 
2015
 
2014
Net Loss
$
(12,623
)
 
$
(4,396
)
 
 
 
 
Other Comprehensive Loss, Net of Tax:*
 

 
 

 
 
 
 
Unrealized Loss on Available-for-Sale Securities
(177
)
 
(613
)
Unrealized Gain on Derivatives - Other
52

 
66

Other Comprehensive (Loss) Income of Affiliated Companies
(96
)
 
63

 
 
 
 
Other Comprehensive Loss - Net of Tax*
(221
)
 
(484
)
 
 
 
 
Comprehensive Loss
$
(12,844
)
 
$
(4,880
)
 
 
 
 
 
Nine Months Ended
September 30,
 
2015
 
2014
Net Income
$
54,221

 
$
53,123

 
 
 
 
Other Comprehensive Income (Loss), Net of Tax:*
 
 
 
 
 
 
 
Unrealized Loss on Available-for-Sale Securities
(153
)
 
(397
)
Unrealized Gain on Derivatives - Other
171

 
198

Other Comprehensive Loss of Affiliated Companies
(132
)
 
(37
)
 
 
 
 
Other Comprehensive Loss - Net of Tax*
(114
)
 
(236
)
 
 
 
 
Comprehensive Income
$
54,107

 
$
52,887


* For 2015, determined using a combined average statutory tax rate of 40%. For 2014, determined using a combined statutory tax rate of 41%.

The accompanying notes are an integral part of the unaudited condensed consolidated financial statements.

3
Table of Contents

SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)
(In Thousands)
 
 
Nine Months Ended
September 30,
 
2015
 
2014
Net Cash Provided by Operating Activities
$
151,886

 
$
109,042

 
 
 
 
Cash Flows from Investing Activities:
 

 
 

Capital Expenditures
(234,550
)
 
(203,918
)
Purchase of Available for Sale Securities
(6,059
)
 
—

Net Proceeds from Sale of (Purchase of) Restricted Investments in Margin Account
22,947

 
(4,815
)
Net Sale of Restricted Investments from Escrowed Loan Proceeds
101

 
—

Investment in Long-Term Receivables
(13,784
)
 
(4,881
)
Proceeds from Long-Term Receivables
6,556

 
5,075

Notes Receivable
(9,919
)
 
—

Purchase of Company-Owned Life Insurance
(1,764
)
 
(1,172
)
Investment in Affiliate
(6,099
)
 
—

Advances on Notes Receivable - Affiliate
(2,163
)
 
(3,472
)
Repayment of Notes Receivable - Affiliate
3,835

 
4,761

 
 
 
 
Net Cash Used in Investing Activities
(240,899
)
 
(208,422
)
 
 
 
 
Cash Flows from Financing Activities:
 

 
 

Net Borrowings from (Repayments of) Short-Term Credit Facilities
105,700

 
(204,500
)
Proceeds from Issuance of Long-Term Debt
80,000

 
329,000

Principal Repayments of Long-Term Debt
(74,100
)
 
(21,000
)
Payments for Issuance of Long-Term Debt
(8
)
 
(2,159
)
Dividends on Common Stock
(34,397
)
 
(31,121
)
Proceeds from Sale of Common Stock
9,705

 
29,125

 
 
 
 
Net Cash Provided by Financing Activities
86,900

 
99,345

 
 
 
 
Net Decrease in Cash and Cash Equivalents
(2,113
)
 
(35
)
Cash and Cash Equivalents at Beginning of Period
4,171

 
3,818

 
 
 
 
Cash and Cash Equivalents at End of Period
$
2,058

 
$
3,783


The accompanying notes are an integral part of the unaudited condensed consolidated financial statements.

4
Table of Contents

SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)
(In Thousands)
 
September 30,
2015
 
December 31,
2014
Assets
 
 
 
Property, Plant and Equipment:
 
 
 
Utility Plant, at original cost
$
2,151,526

 
$
2,002,966

Accumulated Depreciation
(431,327
)
 
(413,597
)
Nonutility Property and Equipment, at cost
691,565

 
622,079

Accumulated Depreciation
(100,218
)
 
(77,345
)
 
 
 
 
Property, Plant and Equipment - Net
2,311,546

 
2,134,103

 
 
 
 
Investments:
 

 
 

Available-for-Sale Securities
14,371

 
8,922

Restricted
43,365

 
65,451

Investment in Affiliates
53,237

 
68,351

 
 
 
 
Total Investments
110,973

 
142,724

 
 
 
 
Current Assets:
 

 
 

Cash and Cash Equivalents
2,058

 
4,171

Accounts Receivable
213,113

 
251,892

Unbilled Revenues
22,035

 
62,608

Provision for Uncollectibles
(10,320
)
 
(7,910
)
Notes Receivable
9,919

 
—

Notes Receivable - Affiliate
13,765

 
14,657

Natural Gas in Storage, average cost
53,263

 
63,246

Materials and Supplies, average cost
1,937

 
2,125

Deferred Income Taxes - Net
67,421

 
57,748

Prepaid Taxes
17,303

 
14,106

Derivatives - Energy Related Assets
60,536

 
85,368

Other Prepayments and Current Assets
27,904

 
18,686

 
 
 
 
Total Current Assets
478,934

 
566,697

 
 
 
 
Regulatory and Other Noncurrent Assets:
 

 
 

Regulatory Assets
339,192

 
357,160

Derivatives - Energy Related Assets
17,138

 
13,905

Unamortized Debt Issuance Costs
8,813

 
9,795

Notes Receivable - Affiliate
36,019

 
36,799

Contract Receivables
26,081

 
19,236

Notes Receivable
7,882

 
7,882

Other
62,930

 
61,124

 
 
 
 
Total Regulatory and Other Noncurrent Assets
498,055

 
505,901

 
 
 
 
Total Assets
$
3,399,508

 
$
3,349,425

 
The accompanying notes are an integral part of the unaudited condensed consolidated financial statements.

5
Table of Contents

SOUTH JERSEY INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)
(In Thousands)
 
September 30,
2015
 
December 31,
2014
Capitalization and Liabilities
 
 
 
Equity:
 
 
 
Common Stock
$
85,909

 
$
85,418

Premium on Common Stock
449,792

 
438,384

Treasury Stock (at par)
(290
)
 
(330
)
Accumulated Other Comprehensive Loss
(30,372
)
 
(30,258
)
Retained Earnings
441,789

 
439,218

 
 
 
 
Total Equity
946,828

 
932,432

 
 
 
 
Long-Term Debt
937,391

 
859,491

 
 
 
 
Total Capitalization
1,884,219

 
1,791,923

 
 
 
 
Current Liabilities:
 

 
 

Notes Payable
351,400

 
245,700

Current Portion of Long-Term Debt
77,909

 
149,909

Accounts Payable
189,122

 
272,998

Customer Deposits and Credit Balances
20,886

 
17,958

Environmental Remediation Costs
46,307

 
30,430

Taxes Accrued
2,353

 
2,328

Derivatives - Energy Related Liabilities
86,793

 
109,744

Dividends Payable
17,268

 
—

Interest Accrued
6,121

 
7,088

Pension Benefits
1,515

 
1,550

Other Current Liabilities
7,287

 
12,480

 
 
 
 
Total Current Liabilities
806,961

 
850,185

 
 
 
 
Deferred Credits and Other Noncurrent Liabilities:
 

 
 

Deferred Income Taxes - Net
350,062

 
344,520

Investment Tax Credits
37

 
149

Pension and Other Postretirement Benefits
103,046

 
115,373

Environmental Remediation Costs
82,575

 
97,742

Asset Retirement Obligations
43,055

 
42,502

Derivatives - Energy Related Liabilities
23,490

 
19,926

Derivatives - Other
11,518

 
10,732

Regulatory Liabilities
62,461

 
41,899

Finance Obligation
18,912

 
19,659

Other
13,172

 
14,815

 
 
 
 
Total Deferred Credits and Other Noncurrent Liabilities
708,328

 
707,317

 
 
 
 
Commitments and Contingencies  (Note 11)


 


 
 
 
 
Total Capitalization and Liabilities
$
3,399,508

 
$
3,349,425

 
The accompanying notes are an integral part of the unaudited condensed consolidated financial statements.

6
Table of Contents

 Notes to Unaudited Condensed 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.

▪
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 Exploration, LLC (SJEX) owns oil, gas and mineral rights in the Marcellus Shale region of Pennsylvania.

▪
Marina Energy, LLC (Marina) develops and operates on-site energy-related projects.

▪
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 as well as on a time and materials basis.

▪
SJI Midstream, LLC (Midstream) was formed in 2014 to invest in a project to build a 100-mile natural gas pipeline in Pennsylvania and New Jersey.

BASIS OF PRESENTATION — The condensed 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 condensed consolidated financial statements reflect all normal and recurring adjustments needed to fairly present SJI’s financial position, operating results and cash flows at the dates and for the periods presented. SJI’s businesses are subject to seasonal fluctuations and, accordingly, this interim financial information should not be the basis for estimating the full year’s operating results. As permitted by the rules and regulations of the Securities and Exchange Commission (SEC), the accompanying unaudited condensed consolidated financial statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). These financial statements should be read in conjunction with SJI’s 2014 Annual Report on Form 10-K for a more complete discussion of the Company’s accounting policies and certain other information.

On February 26, 2015, the Board of Directors approved an amendment to SJI's Certificate of Incorporation to increase the authorized number of shares of common stock from 60,000,000 shares to 120,000,000 shares. The principal purpose of the increase was to permit a two-for-one split of all the issued shares of SJI's common stock, effected pursuant to a stock dividend of one share of common stock for each outstanding share of common stock, payable May 8, 2015 to shareholders of record at the close of business on April 17, 2015. All references to number of shares and per share information in the condensed consolidated financial statements and related notes have been adjusted for all periods presented to reflect this stock split.

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). State sales tax is recorded as a liability when billed to customers and is not included in revenue or operating expenses. The PUA is included in both utility revenue and energy and other taxes and totaled $0.2 million for each of the three months ended September 30, 2015 and 2014, and $1.0 million and $0.8 million for the nine months ended September 30, 2015 and 2014, respectively.
 
IMPAIRMENT OF LONG-LIVED ASSETS - SJI reviews the carrying amount of long-lived assets for possible impairment whenever events or changes in circumstances indicate that such amounts may not be recoverable. For the nine months ended September 30, 2015 and 2014, no impairments were identified.


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Table of Contents

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. No impairment charges were recorded during the nine months ended September 30, 2015 or 2014. As of both September 30, 2015 and December 31, 2014, $8.9 million related to interests in proved and unproved properties in Pennsylvania, net of amortization, is included with Nonutility Property and Equipment and Other Noncurrent Assets on the condensed consolidated balance sheets.
 
TREASURY STOCK – SJI uses the par value method of accounting for treasury stock. As of September 30, 2015 and December 31, 2014, SJI held 231,749 and 263,578 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 Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 740 - “Income Taxes”.  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 Marina are recognized on the flow through method, which may result in variations in the customary relationship between income taxes and pre-tax income for interim periods.

NEW ACCOUNTING PRONOUNCEMENTS — Other than as described below, no new accounting pronouncement issued or effective during 2015 or 2014 had, or is expected to have, a material impact on the condensed consolidated financial statements.

In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU supersedes the revenue recognition requirements in FASB ASC 605, Revenue Recognition, and in most industry-specific topics. The new guidance identifies how and when entities should recognize revenue. The new rules establish a core principle requiring the recognition of revenue to depict the transfer of promised goods or services to customers in an amount reflecting the consideration to which the entity expects to be entitled in exchange for such goods or services. The new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40); Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern. The new guidance requires management of a company to evaluate whether there is substantial doubt about the company's ability to continue as a going concern. This ASU is effective for the annual reporting period ending after December 15, 2016, and for interim and annual reporting periods thereafter, with early adoption permitted. The Company does not expect this standard to have an impact on its consolidated financial statements upon adoption.

In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810) - Amendments to the Consolidation Analysis, which changes the analysis to be performed in determining whether certain types of legal entities should be consolidated. Specifically, the standard amends the evaluation of whether (a) fees paid to a decision maker or a service provider represent a variable interest, (b) a limited partnership or similar entity has the characteristics of a Variable Interest Entity ("VIE") and (c) a reporting entity is the primary beneficiary of a VIE. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015, with early adoption permitted. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In April 2015, the FASB issued ASU 2015-03, Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. This ASU requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

Also in April 2015, the FASB issued ASU 2015-05, Intangibles-Goodwill and Other-Internal-Use Software (Subtopic 350-40). This ASU provides guidance to customers (a) in determining whether a cloud computing arrangement includes a software license, and (b) on how the arrangement should be accounted for, depending on whether or not it includes a software license. The amended guidance is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.


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In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory. This ASU states that inventory for which cost is determined using a method other than last-in, first-out (LIFO) or the retail method should be subsequently measured at the lower of cost or net realizable value (NRV), rather than at the lower of cost or market. The standard is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2016. Management is currently determining the impact that adoption of this guidance will have on the Company's financial statement results.

In August 2015, the FASB issued ASU 2015-13, Derivatives and Hedging (Topic 815): Application of the Normal Purchases and Normal Sales Scope Exception to Certain Electricity Contracts within Nodal Energy Markets. This ASU clarifies that for a contract involving the purchase or sale of electricity on a forward basis, companies have the option to elect the normal purchases and normal sales scope exception. Since such contracts meet the physical delivery criterion when the delivery location is within a nodal energy market (i.e., an interconnected electricity grid operated by an independent system operator with established price points at each node or hub location), the ASU notes that it does not constitute net settlement and, consequently, does not cause such a contract to fail to meet the physical delivery criterion. The standard is effective immediately and should be applied prospectively to qualifying contracts existing on August 10, 2015, the date the ASU was issued. The adoption of this standard did not have an impact on the Company's financial statement results.

In August 2015, the FASB issued ASU 2015-15, Interest - Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements. This ASU states that, given the absence of authoritative guidance for debt issuance costs related to line-of-credit arrangements within ASU 2015-03 (defined above), the SEC staff would not object to an entity deferring and presenting such costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of credit arrangement. The adoption of this standard did not have an impact on the Company's financial statement results.

2.
STOCK-BASED COMPENSATION PLAN:

On April 30, 2015, the shareholders of SJI approved the adoption of the Company's 2015 Omnibus Equity Compensation Plan (Plan), replacing the Amended and Restated 1997 Stock-Based Compensation Plan that had terminated on January 26, 2015. Under the Plan, shares may be issued to SJI’s officers (Officers), non-employee directors (Directors) and other key employees. No options were granted or outstanding during the nine months ended September 30, 2015 and 2014.  No stock appreciation rights have been issued under the plans. During the nine months ended September 30, 2015 and 2014, SJI granted 158,929 and 136,906 restricted shares, respectively, to Officers and other key employees under the plans.  Performance-based 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 0% to 200% of the original share units granted.

In 2015, SJI also granted time-based shares of restricted stock, one-third of which vests annually over a three-year period and is limited to 100% payout. Vesting of time-based grants is contingent upon SJI achieving a return on equity (ROE) of at least 7% during the initial year of the grant and meeting the service requirement. Provided that the 7% ROE requirement is met in the initial year, payout is solely contingent upon the service requirement being met in years two and three of the grant. In 2015, Officers and other key employees were granted 47,678 shares of time-based restricted stock, which are included in the shares noted above.

Grants containing market-based performance targets 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 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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Table of Contents

Through 2014, grants containing earnings-based targets were based on SJI's earnings per share (EPS) growth rate relative to a peer group to measure performance. Beginning in 2015, earning-based performance targets include predefined EPS and return on equity (ROE) goals to measure performance. As EPS-based and ROE-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 targets.

During the nine months ended September 30, 2015 and 2014, SJI granted 26,338 and 23,220 restricted shares, respectively, to Directors.  Shares issued to Directors 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 September 30, 2015 and the assumptions used to estimate the fair value of the awards:

 
Grants
 
Shares Outstanding
 
Fair Value Per Share
 
Expected Volatility
 
Risk-Free Interest Rate
Officers & Key Employees -
2013 - TSR
 
45,622

 
$
22.19

 
21.1
%
 
0.40
%
 
2013 - EPS
 
45,622

 
$
25.59

 
N/A

 
N/A

 
2014 - TSR
 
51,349

 
$
21.31

 
20.0
%
 
0.80
%
 
2014 - EPS
 
51,349

 
$
27.22

 
N/A

 
N/A

 
2015 - TSR
 
34,574

 
$
26.31

 
16.0
%
 
1.10
%
 
2015 - EPS, ROE, Time
 
88,919

 
$
29.47

 
N/A

 
N/A

 
 
 
 
 
 
 
 
 
 
Directors -
2015
 
26,338

 
$
29.21

 
N/A

 
N/A

 

 


 


 


 



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 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 three and nine months ended September 30, 2015 and 2014 (in thousands):

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
2014
 
2015
 
2014
Officers & Key Employees
$
654

$
584

 
$
1,964

 
$
1,751

Directors
205

159

 
577

 
475

Total Cost
859

743

 
2,541

 
2,226

 
 
 
 
 
 
 
Capitalized
(92
)
(70
)
 
(270
)
 
(210
)
Net Expense
$
767

$
673

 
$
2,271

 
$
2,016


As of September 30, 2015, there was $3.8 million of total unrecognized compensation cost related to nonvested stock-based compensation awards granted under the Plan. That cost is expected to be recognized over a weighted average period of 1.8 years.


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Table of Contents

The following table summarizes information regarding restricted stock award activity during the nine months ended September 30, 2015, excluding accrued dividend equivalents:

 
Officers &Other Key Employees
 
Directors
 
Weighted
Average
Fair Value
Nonvested Shares Outstanding, January 1, 2015
223,876

 
23,220

 
$
24.40

  Granted
158,929

 
26,338

 
$
28.67

  Cancelled/Forfeited
(65,370
)
 
—

 
$
26.56

  Vested
—

 
(23,220
)
 
$
27.26

Nonvested Shares Outstanding, September 30, 2015
317,435

 
26,338

 
$
26.10


Performance targets during the three-year vesting period were not attained for the January 2011 grant that vested at December 31, 2013 or the January 2012 grant that vested at December 31, 2014. As a result, no shares were awarded in 2014 or 2015. During the nine months ended September 30, 2015 and 2014, SJI granted 26,338 and 23,220 shares to its Directors at a market value of $0.8 million and $0.6 million, respectively. The Company has a policy of issuing new shares to satisfy its obligations under the Plan; therefore, there are no cash payment requirements resulting from the normal operation of the 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 condensed consolidated balance sheets.

3.
DISCONTINUED OPERATIONS AND AFFILATIONS:

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 three and nine months ended September 30, 2015 and 2014, were (in thousands, except per share amounts):

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
 
2014
Loss Before Income Taxes:
 
 
 
 
 
 
 
Sand Mining
$
(17
)
 
$
(79
)
 
$
(381
)
 
$
(562
)
Fuel Oil
(123
)
 
(105
)
 
(286
)
 
(227
)
Income Tax Benefits
49

 
64

 
226

 
276

Loss from Discontinued Operations — Net
$
(91
)
 
$
(120
)
 
$
(441
)
 
$
(513
)
Earnings (Loss) Per Common Share from
 
 
 
 
 
 
 

Discontinued Operations — Net:
 
 
 
 
 
 
 

Basic and Diluted
$
—

 
$
—

 
$
(0.01
)
 
$
—


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.

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.


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Table of Contents

PennEast Pipeline Company, LLC (PennEast) - Midstream has a 20% investment in PennEast, which is planning to construct an approximately 100-mile natural gas pipeline that will extend from Northeastern Pennsylvania into New Jersey, with a target completion of late 2017.

During the first nine months of 2015 and 2014, the Company received net repayments from unconsolidated affiliates of $4.4 million and $1.3 million, respectively.  As of September 30, 2015 and December 31, 2014, the outstanding balance of Notes Receivable – Affiliate was $49.8 million and $51.5 million, respectively. As of September 30, 2015, approximately $38.9 million of these notes are secured by property, plant and equipment of the affiliates, accrue interest at 7.5% and are to be repaid through 2025, and the remaining $10.9 million of these notes are unsecured and accrue interest at variable rates.

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 September 30, 2015, the Company had a net asset of approximately $52.4 million included in Investment in Affiliates and Other Noncurrent Liabilities on the condensed 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 September 30, 2015 is limited to its combined equity contributions and the Notes Receivable-Affiliate in the amount of $103.0 million plus the guarantees discussed in Note 11.

The following table presents summarized income statement information of the total balances for Energenic (of which SJI has only a 50% equity interest) accounted for under the equity method (in thousands):
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
 
2014
Revenues
$
18,183

 
$
27,160

 
$
63,812

 
$
83,380

Cost of Sales
$
5,048

 
$
5,390

 
$
16,452

 
$
20,588

Loss from continuing operations
$
(4,984
)
 
$
(4,154
)
 
$
(42,367
)
 
$
(4,139
)
Net Loss
$
(4,984
)
 
$
(4,154
)
 
$
(42,367
)
 
$
(4,139
)

4.
COMMON STOCK:

The following shares were issued and outstanding:

 
2015
Beginning Balance, January 1 (See Note 1)
68,334,860

New Issues During the Period:
 

Dividend Reinvestment Plan
366,262

Stock-Based Compensation Plan
26,338

Ending Balance, September 30
68,727,460


The par value ($1.25 per share) of stock issued was recorded in Common Stock and the net excess over par value of approximately $11.4 million 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 198,222 and 150,592 for the nine months ended September 30, 2015 and 2014, respectively. For the three months ended September 30, 2015 and 2014, incremental shares of 187,758 and 148,664, respectively, were not included in the denominator for the diluted EPS calculation because they would have an antidilutive effect on EPS. These shares relate to SJI's restricted stock as discussed in Note 2.


12
Table of Contents

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 $9.7 million and $29.1 million of equity capital through the DRP during the nine months ended September 30, 2015 and 2014, respectively.

5.
FINANCIAL INSTRUMENTS:

RESTRICTED INVESTMENTS — Marina is required to maintain escrow accounts related to ongoing capital projects as well as unused loan proceeds pending approval of construction expenditures. As of September 30, 2015 and December 31, 2014, the escrowed funds, including interest earned, totaled $2.6 million and 1.7 million, respectively.

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 September 30, 2015 and December 31, 2014, the balances in these accounts totaled $40.8 million and $63.7 million, respectively. The carrying amounts of the Restricted Investments approximate their fair values at September 30, 2015 and December 31, 2014, which would be included in Level 1 of the fair value hierarchy (See Note 13 - Fair Value of Financial Assets and Financial Liabilities).

INVESTMENT IN AFFILIATES - During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20-year contracts 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, Energenic subsidiaries began providing full energy services to the complex. 

In June 2014, the parent company of the hotel, casino and entertainment complex filed petitions in U. S. Bankruptcy Court to facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014. Energenic subsidiaries continued to provide limited energy services to the complex during the shutdown period under a temporary agreement with the trustee. The hotel, casino and entertainment complex was sold in April 2015. The Energenic subsidiaries are currently providing limited services to the complex under a short-term agreement with the new owner. However, the Energenic subsidiaries have not been able to secure a permanent or long-term energy services agreement with the new owner.
As a result, management of the Company and Energenic have evaluated the carrying value of the investment in this project and a related note receivable. Based on the current situation, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings during the second quarter of 2015 due to the reduction in the carrying value of the investment in this project recorded by Energenic. This charge is included in Equity in Loss of Affiliated Companies for the nine months ended September 30, 2015 on the condensed consolidated statements of income. Estimating the fair value of an investment is highly judgmental and involves the use of significant estimates and assumptions. Actual results may differ significantly from those used to develop this estimate.
As of September 30, 2015, the Company, through its investment in Energenic, had a remaining net asset of approximately $2.0 million included in Investment in Affiliates on the condensed consolidated balance sheets related to this project. In addition, the Company had approximately $13.9 million included in Notes Receivable - Affiliate on the condensed consolidated balance sheets, due from Energenic, which is secured by certain assets of the central energy center. This note is subject to a reimbursement agreement that secures reimbursement for the Company, from its joint venture partner, of a proportionate share of any amounts that are not repaid.

Management will continue to monitor the situation surrounding the complex and will evaluate the carrying value of the investment and the note receivable as future events occur.

NOTE RECEIVABLE - In June 2015, SJG advanced $10.0 million to a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey. The Note bears interest at 1.0% for an initial term of six months, with the borrower’s option to extend the term for two additional terms of three months each. SJG holds a first lien security interest on land in Atlantic City as collateral against this Note.  The carrying amount of this receivable approximates its fair value at September 30, 2015, which would be included in Level 2 of the fair value hierarchy (See Note 13 - Fair Value of Financial Assets and Financial Liabilities).


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Table of Contents

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 $13.3 million and $15.0 million as of September 30, 2015 and December 31, 2014, respectively. The current portion of these receivables is reflected in Accounts Receivable and the non-current portion is reflected in Contract Receivables on the condensed 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 September 30, 2015 and December 31, 2014.  The annualized amortization to interest is not material to the Company’s condensed consolidated financial statements.  The carrying amounts of these receivables approximate their fair value at September 30, 2015 and December 31, 2014, which would be included in Level 2 of the fair value hierarchy (See Note 13 - Fair Value of Financial Assets and Financial Liabilities).

CREDIT RISK - As of September 30, 2015, approximately $8.8 million, or 11.4%, of the current and noncurrent Derivatives – Energy Related Assets are transacted with one counterparty. This counterparty 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 condensed consolidated balance sheets of $23.7 million as of both September 30, 2015 and December 31, 2014. In addition, the Company included repayments from ACB to Marina on the construction loan within the Finance Obligation on the condensed 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 condensed 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 condensed consolidated statements of income is not significant. As a result, the Company recorded $18.9 million and $19.7 million, net of amortization, within Finance Obligation on the condensed consolidated balance sheets at September 30, 2015 and December 31, 2014, 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 September 30, 2015 and December 31, 2014, 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 13 - Fair Value of Financial Assets and Financial Liabilities). The estimated fair values of SJI's long-term debt, including current maturities, as of September 30, 2015 and December 31, 2014, were $1,072.3 million and $1,058.5 million, respectively.  The carrying amounts of SJI's long-term debt, including current maturities, as of September 30, 2015 and December 31, 2014, were $1,015.3 million and $1,009.4 million, respectively.


14
Table of Contents

6.
SEGMENTS OF BUSINESS:

SJI operates in several different reportable operating segments which reflect the financial information regularly evaluated by the chief operating decision maker. These segments are as follows:

•
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 activities of Midstream are a part of the Corporate & Services segment.
 
SJI groups its nonutility operations into two categories: Energy Group and Energy Services. Energy Group includes wholesale energy, retail gas and other, and retail electric operations. Energy Services includes 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):

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
 
2014
Operating Revenues:
 
 
 
 
 
 
 
Gas Utility Operations
$
58,634

 
$
60,952

 
$
402,104

 
$
340,656

Energy Group:
 
 
 
 
 
 
 
     Wholesale Energy Operations
9,352

 
(3,538
)
 
77,973

 
28,898

Retail Gas and Other Operations
11,757

 
18,900

 
67,900

 
95,281

Retail Electric Operations
44,240

 
29,961

 
110,203

 
98,233

     Subtotal Energy Group
65,349

 
45,323

 
256,076

 
222,412

Energy Services:
 
 
 
 
 
 
 
On-Site Energy Production
18,898

 
16,453

 
47,606

 
42,196

Appliance Service Operations
2,290

 
2,319

 
7,346

 
7,610

Subtotal Energy Services
21,188

 
18,772

 
54,952

 
49,806

Corporate & Services
6,925

 
7,001

 
23,776

 
21,324

Subtotal
152,096

 
132,048

 
736,908

 
634,198

Intersegment Sales
(11,034
)
 
(9,621
)
 
(35,183
)
 
(28,299
)
Total Operating Revenues
$
141,062

 
$
122,427

 
$
701,725

 
$
605,899


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Table of Contents


 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
 
2014
Operating (Loss) Income:
 

 
 

 
 
 
 
Gas Utility Operations
$
(2,501
)
 
$
3,368

 
$
82,649

 
$
75,813

Energy Group:
 
 
 
 
 
 
 
     Wholesale Energy Operations
(11,813
)
 
(10,314
)
 
3,675

 
(20,437
)
Retail Gas and Other Operations
(4,821
)
 
(390
)
 
(1,581
)
 
1,387

Retail Electric Operations
1,034

 
373

 
1,026

 
(521
)
     Subtotal Energy Group
(15,600
)
 
(10,331
)
 
3,120

 
(19,571
)
Energy Services:
 
 
 
 
 
 
 
On-Site Energy Production
2,265

 
2,171

 
3,960

 
4,547

Appliance Service Operations
216

 
60

 
411

 
322

  Subtotal Energy Services
2,481

 
2,231

 
4,371

 
4,869

Corporate and Services
567

 
619

 
1,518

 
1,041

Total Operating (Loss) Income
$
(15,053
)
 
$
(4,113
)
 
$
91,658

 
$
62,152


 
 
 
 
 
 
 
Depreciation and Amortization:
 

 
 

 
 
 
 
Gas Utility Operations
$
14,911

 
$
12,942

 
$
43,317

 
$
38,375

Energy Group:
 
 
 
 
 
 
 
     Wholesale Energy Operations
191

 
37

 
238

 
123

Retail Gas and Other Operations
39

 
19

 
79

 
61

     Subtotal Energy Group
230

 
56

 
317

 
184

Energy Services:
 
 
 
 
 
 
 
On-Site Energy Production
7,650

 
6,540

 
22,158

 
18,480

Appliance Service Operations
85

 
68

 
232

 
202

  Subtotal Energy Services
7,735

 
6,608

 
22,390

 
18,682

Corporate and Services
261

 
(41
)
 
961

 
413

Total Depreciation and Amortization
$
23,137

 
$
19,565

 
$
66,985

 
$
57,654


 
 
 
 
 
 
 
Interest Charges:
 

 
 

 
 
 
 
Gas Utility Operations
$
4,809

 
$
4,046

 
$
15,112

 
$
12,680

Energy Group:
 
 
 
 
 
 
 
     Wholesale Energy Operations
150

 
74

 
280

 
190

Retail Gas and Other Operations
—

 
43

 
120

 
237

     Subtotal Energy Group
150

 
117

 
400

 
427

Energy Services:
 
 
 
 
 
 
 
On-Site Energy Production
2,433

 
1,835

 
6,409

 
6,110

Corporate and Services
2,857

 
2,376

 
8,784

 
6,016

Subtotal
10,249

 
8,374

 
30,705

 
25,233

Intersegment Borrowings
(2,142
)
 
(1,606
)
 
(6,523
)
 
(4,535
)
Total Interest Charges
$
8,107

 
$
6,768

 
$
24,182

 
$
20,698



16
Table of Contents

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
 
2014
Income Taxes:
 

 
 

 
 
 
 
Gas Utility Operations
$
(2,871
)
 
$
534

 
26,593

 
25,440

Energy Group:
 
 
 
 
 
 
 
     Wholesale Energy Operations
(4,615
)
 
(3,896
)
 
2,238

 
(7,077
)
Retail Gas and Other Operations
(2,038
)
 
(121
)
 
(370
)
 
895

Retail Electric Operations
422

 
152

 
419

 
(213
)
     Subtotal Energy Group
(6,231
)
 
(3,865
)
 
2,287

 
(6,395
)
Energy Services:
 
 
 
 
 
 
 
On-Site Energy Production
(2,015
)
 
(5,092
)
 
(26,923
)
 
(25,521
)
Appliance Service Operations
94

 
39

 
191

 
227

  Subtotal Energy Services
(1,921
)
 
(5,053
)
 
(26,732
)
 
(25,294
)
Corporate and Services
55

 
59

 
218

 
283

Total Income Taxes
$
(10,968
)
 
$
(8,325
)
 
$
2,366

 
$
(5,966
)
 
 
 
 
 
 
 
 
Property Additions:
 
 
 
 
 
 
 
Gas Utility Operations
$
55,335

 
$
56,414

 
$
160,836

 
$
148,012

Energy Group:
 
 
 
 
 
 
 
     Wholesale Energy Operations
4

 
—

 
383

 
10

Retail Gas and Other Operations
642

 
563

 
1,763

 
960

     Subtotal Energy Group
646

 
563

 
2,146

 
970

Energy Services:
 
 
 
 
 
 
 
On-Site Energy Production
36,805

 
22,194

 
67,226

 
47,769

Appliance Service Operations
51

 
8

 
379

 
14

  Subtotal Energy Services
36,856

 
22,202

 
67,605

 
47,783

Corporate and Services
193

 
1,144

 
1,794

 
2,725

Total Property Additions
$
93,030

 
$
80,323

 
$
232,381

 
$
199,490


 
September 30, 2015
 
December 31, 2014
Identifiable Assets:
 
 
 
Gas Utility Operations
$
2,288,303

 
$
2,185,672

Energy Group:
 
 
 
     Wholesale Energy Operations
240,476

 
366,119

Retail Gas and Other Operations
37,658

 
53,073

Retail Electric Operations
46,148

 
23,682

     Subtotal Energy Group
324,282

 
442,874

Energy Services:
 
 
 
On-Site Energy Production
711,194

 
675,937

Appliance Service Operations
4,080

 
3,105

Subtotal Energy Services
715,274

 
679,042

Discontinued Operations
1,582

 
1,758

Corporate and Services
590,392

 
527,691

Intersegment Assets
(520,325
)
 
(487,612
)
Total Identifiable Assets
$
3,399,508

 
$
3,349,425



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7.
RATES AND REGULATORY ACTIONS:

SJG is subject to the rules and regulations of the New Jersey Board of Public Utilities (BPU).

In May 2015, the BPU approved an $18.2 million decrease in annual revenues collected from customers through the Societal Benefits Clause ("SBC") charge and the Transportation Initiation Clause ("TIC") charge, comprised of a $6.2 million decrease in revenues from the Remediation Adjustment Clause (“RAC”) component of the SBC, an $11.5 million decrease in revenues from the Clean Energy Program (“CLEP”) component of the SBC and a $0.5 million decrease in TIC revenues, effective June 1, 2015. The decreases in the RAC and CLEP components of the SBC are primarily driven by the accumulation of prior year over-recoveries, as rate recovery exceeded program costs. The decrease in the TIC is being caused by a decrease in costs. The SBC and TIC allow SJG to recover costs associated with certain State-mandated programs.

In June 2015, SJG filed its annual Energy Efficiency Tracker (“EET”) rate adjustment petition, requesting a $7.6 million decrease in revenues to continue recovering the costs of, and the allowed return on, prior investments associated with energy efficiency programs ("EEPs"). SJG's original EEPs, approved by the BPU in 2009, and its EEP extension, approved by the BPU in 2013, ended in July 2013 and June 2015, respectively. The revenue requirements associated with these prior investments decrease over time as they are amortized and recovered. Also contributing to the revenue decrease is the forecasted October 2015 over-recovery of $1.7 million, which further reduces the revenue requirement for the upcoming EET year. This petition is currently pending.

In August 2015, the BPU approved a two year extension of SJG's EEPs through August 31, 2017, with a program budget of $36.3 million. SJG will recover the costs of these programs, and earn an allowed return on its investments, through the EET rate recovery mechanism that has been utilized for its EEPs since 2009. The BPU’s approval also permitted SJG to adjust its EET rate effective September 1, 2015 to increase annual revenues by $2.6 million to recover the projected costs of, and the allowed return on, the first year of its investments in the EEPs.

In September 2015, the BPU approved SJG’s request, related to its Storm Hardening and Reliability Program (“SHARP”), to increase annual revenues from base rates by $4.0 million to reflect approximately $36.6 million of investments made for storm hardening efforts for the period July 2014 through June 2015. This base rate adjustment became effective on October 1, 2015.

Also in September 2015, the BPU approved SJG's annual Basic Gas Supply Service (“BGSS”) and Conservation Incentive Program (“CIP”) rate adjustment petition, which requested a $39.7 million decrease in annual revenues to be implemented on October 1, 2015, comprised of a $28.4 million decrease in BGSS revenues and an $11.3 million decrease in CIP revenues. The level of BGSS revenues is based on forecasted gas costs and customer usage information for the upcoming BGSS/CIP year, which runs from October to September. SJG’s request is based on decreases in forecasted gas commodity costs for the upcoming BGSS/CIP year. The decrease in CIP revenues is caused primarily by higher than normal customer usage caused by weather that was 10.4% colder than normal during the 2014-2015 winter season.

Additionally, in September 2015, the BPU approved the statewide Universal Service Fund (“USF”) budget of $46.4 million for all the State’s gas utilities. SJG’s portion of the total budget is approximately $5.2 million. Effective October 1, 2015, the BPU approved a $3.4 million decrease to SJG’s USF recoveries.

The BGSS, CIP and USF revenue decreases noted above do not impact SJG's earnings. They represent decreases in the cash requirements of SJG corresponding to lower costs and/or the return of previously over-recovered costs associated with each respective mechanism.

There have been no other significant regulatory actions or changes to SJG's rate structure since December 31, 2014. See Note 10 to the Consolidated Financial Statements in Item 8 of SJI's Annual Report on Form 10-K for the year ended December 31, 2014.


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8.
REGULATORY ASSETS & REGULATORY LIABILITIES:

There have been no significant changes to the nature of the Company’s regulatory assets and liabilities since December 31, 2014 which are described in Note 11 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014.

Regulatory Assets consisted of the following items (in thousands):

 
September 30, 2015
 
December 31, 2014
Environmental Remediation Costs:
 
 
 
Expended - Net
$
32,797

 
$
29,540

Liability for Future Expenditures
125,466

 
124,308

Deferred Asset Retirement Obligation Costs
31,976

 
31,584

Deferred Pension and Other Postretirement Benefit Costs
99,040

 
99,040

Deferred Gas Costs - Net
19,187

 
32,202

Societal Benefit Costs Receivable
—

 
385

Deferred Interest Rate Contracts
7,918

 
7,325

Energy Efficiency Tracker
545

 
11,247

Pipeline Supplier Service Charges
4,192

 
5,441

Pipeline Integrity Cost
4,544

 
3,431

AFUDC - Equity Related Deferrals
11,188

 
10,781

Other Regulatory Assets
2,339

 
1,876

 
 
 
 
Total Regulatory Assets
$
339,192

 
$
357,160


DEFERRED GAS COSTS - NET - Over/under collections of gas costs are monitored through SJG's Basic Gas Supply Service (BGSS) mechanism. Net undercollected gas costs are classified as a regulatory asset and net overcollected gas costs are classified as a regulatory liability. Derivative contracts used to hedge natural gas purchases are also included in the BGSS, subject to BPU approval. The reduction in deferred gas costs from December 31, 2014 was due to gas costs recovered from customers exceeding the actual cost of the commodity incurred during 2015 as a result of lower natural gas prices and an increase in the BGSS rate effective October 2014. SJG's BGSS mechanism is designed to overcollect gas costs during the winter season when usage is highest.

ENERGY EFFICIENCY TRACKER - This regulatory asset primarily represents energy efficiency measures installed in customer homes and businesses. The decrease from December 31, 2014 is due to higher recoveries in the first nine months of 2015 resulting from extremely cold weather during the first half of the year.

Regulatory Liabilities consisted of the following items (in thousands):

 
September 30, 2015
 
December 31, 2014
Excess Plant Removal Costs
$
34,040

 
$
35,940

Conservation Incentive Program Payable
18,616

 
4,700

Societal Benefit Costs
9,805

 
—

Other Regulatory Liabilities
—

 
1,259

 
 
 
 
Total Regulatory Liabilities
$
62,461

 
$
41,899

 
EXCESS PLANT REMOVAL COSTS - Represents amounts accrued in excess of actual utility plant removal costs incurred to date. The decrease in the balance from year end is due to an amortization as a credit to depreciation expense as required as part of SJG's September 2014 base rate increase.

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CONSERVATION INCENTIVE PROGRAM (CIP) PAYABLE – The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. Actual usage per customer was greater than the established baseline during 2014 and more notably during the first nine months of 2015 resulting in a payable. This is primarily the result of extremely cold weather experienced in the region during the first half of the year.  

SOCIETAL BENEFIT COSTS (SBC) - This regulatory liability primarily represents the excess recoveries over the expenses incurred under the New Jersey Clean Energy Program which is a mechanism designed to recover costs associated with energy efficiency and renewable energy programs. The change from a $0.4 million regulatory asset to a $9.8 million regulatory liability is due to current SBC rates which are producing recoveries greater than SBC costs. In July 2014, SJG made its annual 2014-2015 SBC filing requesting a decrease in SBC revenues, in part, to avoid this liability. The petition was approved and new rates went into effect on June 1, 2015.

9.
PENSION AND OTHER POSTRETIREMENT BENEFITS:

For the three and nine months ended September 30, 2015 and 2014, 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
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015

2014
 
2015
 
2014
Service Cost
$
1,334

 
$
813

 
$
4,003

 
$
3,383

Interest Cost
2,792

 
2,661

 
8,376

 
8,051

Expected Return on Plan Assets
(3,697
)
 
(3,262
)
 
(11,092
)
 
(9,792
)
Amortizations:
 
 
 

 
 
 
 
Prior Service Cost
53

 
45

 
159

 
131

Actuarial Loss
2,652

 
1,398

 
7,956

 
4,250

Net Periodic Benefit Cost
3,134

 
1,655

 
9,402

 
6,023

Capitalized Benefit Cost
(1,216
)
 
(577
)
 
(3,649
)
 
(2,285
)
   Deferred Benefit Cost
(341
)
 
—

 
(666
)
 
—

Total Net Periodic Benefit Expense
$
1,577

 
$
1,078

 
$
5,087

 
$
3,738


 
Other Postretirement Benefits
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015

2014
 
2015
 
2014
Service Cost
$
279

 
$
168

 
$
837

 
$
668

Interest Cost
743

 
659

 
2,230

 
2,139

Expected Return on Plan Assets
(748
)
 
(688
)
 
(2,245
)
 
(2,062
)
Amortizations:
 
 
 

 

 
 
Prior Service Cost
152

 
38

 
456

 
114

Actuarial Loss
336

 
245

 
1,007

 
731

Net Periodic Benefit Cost
762

 
422

 
2,285

 
1,590

Capitalized Benefit Cost
(264
)
 
(42
)
 
(792
)
 
(460
)
   Deferred Benefit Cost
(89
)
 
—

 
(168
)
 
—

Total Net Periodic Benefit Expense
$
409

 
$
380

 
$
1,325

 
$
1,130


Capitalized benefit costs reflected in the table above relate to SJG’s construction program. Deferred benefit costs relate to SJG's deferral of incremental expense associated with the adoption of new mortality tables (RP-2014 base table with MP-2014 generational projection scale) in 2015. Deferred benefit costs are expected to be recovered through rates as part of SJG's next base rate case.


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SJI contributed $15.0 million to the pension plans in January 2015. No contributions were made to the pension plans during 2014. Payments related to the unfunded supplemental executive retirement plan (SERP) are expected to approximate $1.5 million in 2015. SJG also has a regulatory obligation to contribute approximately $3.6 million annually to the other postretirement benefit plans’ trusts, less direct costs incurred.

See Note 12 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014, for additional information related to SJI’s pension and other postretirement benefits.

10.
LINES OF CREDIT:
 
Credit facilities and available liquidity as of September 30, 2015 were as follows (in thousands):

Company
 
Total Facility
 
Usage
 
Available Liquidity
 
Expiration Date
SJG:
 
 
 
 
 
 
 
 
Commercial Paper Program/Revolving Credit Facility
 
$
200,000

 
$
89,900

(A)
$
110,100

 
May 2018
Uncommitted Bank Lines
 
10,000

 
—

 
10,000

 
Various
 
 
 
 
 
 
 
 
 
Total SJG
 
210,000

 
89,900

 
120,100

 
 
 
 
 
 
 
 
 
 
 
SJI:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Revolving Credit Facility
 
400,000

 
270,200

(B)
129,800

 
February 2018
 
 
 
 
 
 
 
 
 
Total SJI
 
400,000

 
270,200

 
129,800

 
 
 
 
 
 
 
 
 
 
 
Total
 
$
610,000

 
$
360,100


$
249,900

 
 

(A) Includes letters of credit outstanding in the amount of $0.6 million.
(B) Includes letters of credit outstanding in the amount of $8.1 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. Borrowings under these credit facilities are at market rates. The weighted average interest rate on these borrowings, which changes daily, was 1.03% and 0.83% at September 30, 2015 and 2014, respectively. Average borrowings outstanding under these credit facilities, not including letters of credit, during the nine months ended September 30, 2015 and 2014 were $310.8 million and $291.6 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the nine months ended September 30, 2015 and 2014 were $432.4 million and $390.7 million, respectively.

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 September 30, 2015.

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 its $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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11.
COMMITMENTS AND CONTINGENCIES:

GUARANTEES — The Company has recorded a liability of $0.6 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the condensed consolidated balance sheets as of September 30, 2015 for the fair value of the following guarantees:

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 agreements 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 guarantees 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 the Landfills are unable to meet certain financial obligations as they become due. As of September 30, 2015, 50% of the currently outstanding debt is $8.2 million.

In May 2012, UMM Energy Partners, LLC (UMM), a wholly-owned subsidiary of Energenic, in 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. As of September 30, 2015, SJI has guaranteed up to $2.4 million. 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. SJI holds variable interests in UMM but is not the primary beneficiary.

As of September 30, 2015, SJI had issued $5.7 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.

COLLECTIVE BARGAINING AGREEMENTS — Unionized personnel represent approximately 44.0% of our workforce at September 30, 2015. 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 and SJESP employees represented by the IBEW operate under collective bargaining agreements that run through February 2017. The remaining unionized employees are represented by the IAM and operate under collective bargaining agreements that run through August 2017.

STANDBY LETTERS OF CREDIT — As of September 30, 2015, SJI provided $8.1 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. SJG provided a $0.6 million letter of credit under its revolving credit facility to support the remediation of environmental conditions at certain locations in SJG's service territory. The Company has also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facilities 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.  


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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 $3.2 million and$2.9 million related to all claims in the aggregate as of September 30, 2015 and December 31, 2014, 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.

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. There have been no changes to the status of the Company’s environmental remediation efforts since December 31, 2014 as described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014.

12.
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 September 30, 2015, the Company had outstanding derivative contracts intended to limit the exposure to market risk on 55.5 MMdts (1 MMdts = one million decatherms) of expected future purchases of natural gas, 44.8 MMdts of expected future sales of natural gas, 2.9 MMmwh (1 MMmwh = one million megawatt hours) of expected future purchases of electricity and 2.8 MMmwh of expected future sales of electricity. In addition to these derivative contracts, the Company has basis and index related purchase and sales contracts totaling 226.3 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 condensed 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.

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 condensed 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 (AOCL) 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.

There have been no significant changes to the Company’s active interest rate swaps since December 31, 2014, which are described in Note 16 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014.


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The fair values of all derivative instruments, as reflected in the condensed consolidated balance sheets as of September 30, 2015 and December 31, 2014, are as follows (in thousands):

Derivatives not designated as hedging instruments under GAAP
 
September 30, 2015
 
December 31, 2014
 
 
Assets
 
Liabilities
 
Assets
 
Liabilities
Energy-related commodity contracts:
 
 
 
 
 
 
 
 
Derivatives – Energy Related – Current
 
$
60,536

 
$
86,793

 
$
85,368

 
$
109,744

Derivatives – Energy Related – Non-Current
 
17,138

 
23,490

 
13,905

 
19,926

Interest rate contracts:
 
 
 
 
 
 

 
 

Derivatives - Other
 
—

 
11,518

 
—

 
10,732

Total derivatives not designated as hedging instruments under GAAP
 
77,674

 
121,801

 
99,273

 
140,402

 
 
 
 
 
 
 
 
 
Total Derivatives
 
$
77,674

 
$
121,801

 
$
99,273

 
$
140,402


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 condensed consolidated balance sheets. As of September 30, 2015 and December 31, 2014, information related to these offsetting arrangements were as follows (in thousands):
As of September 30, 2015
 
 
 
 
 
 
 
 
 
 
 
 
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
 
$
77,674

 
$
—

 
$
77,674

 
$
(30,785
)
(A)
$
—

 
$
46,889

Derivatives - Energy Related Liabilities
 
$
(110,283
)
 
$
—

 
$
(110,283
)
 
$
30,785

(B)
$
30,856

 
$
(48,642
)
Derivatives - Other
 
$
(11,518
)
 
$
—

 
$
(11,518
)
 
$
—

 
$
—

 
$
(11,518
)

As of December 31, 2014
 
 
 
 
 
 
 
 
 
 
 
 
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
 
$
99,273

 
$
—

 
$
99,273

 
$
(39,747
)
(A)
$
—

 
$
59,526

Derivatives - Energy Related Liabilities
 
$
(129,670
)
 
$
—

 
$
(129,670
)
 
$
39,747

(B)
$
53,897

 
$
(36,026
)
Derivatives - Other
 
$
(10,732
)
 
$
—

 
$
(10,732
)
 
$
—

 
$
—

 
$
(10,732
)

(A) The balances at September 30, 2015 and December 31, 2014 were related to derivative liabilities which can be net settled against derivative assets.

(B) The balances at September 30, 2015 and December 31, 2014 were related to derivative assets which can be net settled against derivative liabilities.


24
Table of Contents

The effect of derivative instruments on the condensed consolidated statements of income for the three and nine months ended September 30, 2015 and 2014 are as follows (in thousands):

 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
Derivatives in Cash Flow Hedging Relationships under GAAP
 
2015
 
2014
 
2015
 
2014
Interest Rate Contracts:
 
 
 
 
 
 
 
 
Losses recognized in AOCL on effective portion
 
$
—

 
$
—

 
$
—

 
$
—

Losses reclassified from AOCL into income (a)
 
$
(93
)
 
$
(112
)
 
$
(303
)
 
$
(336
)
Gains (losses) recognized in income on ineffective portion (a)
 
$
—

 
$
—

 
$
—

 
$
—


(a) Included in Interest Charges

 
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
Derivatives Not Designated as Hedging Instruments under GAAP
 
2015
 
2014
 
2015
 
2014
Losses on energy-related commodity contracts (a)
 
$
(11,992
)
 
$
(1,633
)
 
$
(4,014
)
 
$
(30,429
)
(Losses) gains on interest rate contracts (b)
 
(435
)
 
202

 
(192
)
 
(103
)
 
 
 
 
 
 
 
 
 
Total
 
$
(12,427
)
 
$
(1,431
)
 
$
(4,206
)
 
$
(30,532
)

(a)  Included in Operating Revenues - Nonutility
(b)  Included in Interest Charges

Net realized loss of $1.6 million and $1.2 million associated with SJG's energy-related financial commodity contracts for the three months ended September 30, 2015 and 2014, respectively, and a loss of $6.4 million and a gain of$2.4 million for the nine months ended September 30, 2015 and 2014, 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, as applicable, 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 September 30, 2015, is $44.3 million.  If the credit risk-related contingent features underlying these agreements were triggered on September 30, 2015, the Company would have been required to settle the instruments immediately or post collateral to its counterparties of approximately $39.8 million after offsetting asset positions with the same counterparties under master netting arrangements.

13.
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.


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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.

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 September 30, 2015
Total
 
Level 1
 
Level 2
 
Level 3
Assets
 
 
 
 
 
 
 
Available-for-Sale Securities (A)
$
14,371

 
$
5,759

 
$
8,612

 
$
—

Derivatives – Energy Related Assets (B)
77,674

 
9,991

 
27,351

 
40,332

 
$
92,045

 
$
15,750

 
$
35,963

 
$
40,332

 
 
 
 
 
 
 
 
Liabilities
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Derivatives – Energy Related Liabilities (B)
$
110,283

 
$
34,536

 
$
20,750

 
$
54,997

Derivatives – Other (C)
11,518

 
—

 
11,518

 
—

 
$
121,801

 
$
34,536

 
$
32,268

 
$
54,997


As of December 31, 2014
Total
 
Level 1
 
Level 2
 
Level 3
Assets
 
 
 
 
 
 
 
Available-for-Sale Securities (A)
$
8,922

 
$
5,952

 
$
2,970

 
$
—

Derivatives – Energy Related Assets (B)
99,273

 
21,675

 
43,093

 
34,505

 
$
108,195

 
$
27,627

 
$
46,063

 
$
34,505

 
 
 
 
 
 
 
 
 Liabilities
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Derivatives – Energy Related Liabilities (B)
$
129,670

 
$
49,009

 
$
40,548

 
$
40,113

Derivatives – Other (C)
10,732

 
—

 
10,732

 
—

 
$
140,402

 
$
49,009

 
$
51,280

 
$
40,113


(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.


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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.

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):

Type
Fair Value at September 30, 2015
Valuation Technique
Significant Unobservable Input
Range [Weighted Average]
 
 
Assets
Liabilities
 
 
 
 
Forward Contract - Natural Gas
$19,113
$35,812
Discounted Cash Flow
Forward price (per dt)

$0.95 - $9.83 [$0.45]
(A)
Forward Contract - Electric


$21,219
$19,185
Discounted Cash Flow
Fixed electric load profile (on-peak)
8.47% - 100.00% [56.44%]
(B)
Fixed electric load profile (off-peak)
0.00% - 91.53% [43.56%]
(B)

Type
Fair Value at December 31, 2014
Valuation Technique
Significant Unobservable Input
Range [Weighted Average]
 
 
Assets
Liabilities
 
 
 
 
Forward Contract - Natural Gas
$26,485
$33,882
Discounted Cash Flow
Forward price (per dt)

$(2.04) - $7.83 [$(0.30)]
(A)
Forward Contract - Electric


$8,020
$6,231
Discounted Cash Flow
Fixed electric load profile (on-peak)
8.06% - 100.00% [55.97%]
(B)
Fixed electric load profile (off-peak)
0.00% - 91.94% [44.03%]
(B)

(A) Represents the range, along with the weighted average, of forward prices for the sale and purchase of natural gas.
(B) Represents the range, along with the weighted average, of the percentage of contracted usage that is loaded during on-peak hours versus off-peak.

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The changes in fair value measurements of Derivatives – Energy Related Assets and Liabilities for the three and nine months ended September 30, 2015 and 2014, using significant unobservable inputs (Level 3), are as follows (in thousands):

 
Three Months Ended
September 30, 2015
 
Nine Months Ended
September 30, 2015
Balance at beginning of period
$
(2,544
)
 
$
(5,608
)
Other changes in fair value from continuing and new contracts, net
(10,725
)
 
(12,787
)
Transfers in/(out) of Level 3 (A)
—

 
2,054

Settlements
(1,396
)
 
1,676

 
 
 
 
Balance at end of period
$
(14,665
)
 
$
(14,665
)

 
Three Months Ended
September 30, 2014
 
Nine Months Ended
September 30, 2014
Balance at beginning of period
$
(4,769
)
 
$
8,095

Other changes in fair value from continuing and new contracts, net
(423
)
 
(14,799
)
Settlements
2,493

 
4,005

 
 
 
 
Balance at end of period
$
(2,699
)
 
$
(2,699
)

(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 nine months ended September 30, 2015, $2.1 million of net derivative assets were transferred from Level 2 to Level 3, due to decreased observability of market data.

Total losses included in earnings for the three and nine months ended September 30, 2015 that are attributable to the change in unrealized losses relating to those assets and liabilities included in Level 3 still held as of September 30, 2015, are $10.7 million and $12.8 million, respectively.  These losses are included in Operating Revenues-Nonutility on the condensed consolidated statements of income.

14.
LONG-TERM DEBT:

In June 2015, the Company redeemed at maturity $64.0 million aggregate principal amount of 2.39% Senior Notes.

In August 2015, SJG retired $10.0 million aggregate principal amount of 5.387% Medium Term Notes at maturity.

In September 2015, SJG issued $80.0 million of long-term debt under a $200.00 million aggregate syndicated bank term facility. The total outstanding amount under this facility as of September 30, 2015 was $139.0 million. The Company did not issue any other long-term debt during the nine months ended September 30, 2015.

Also in September 2015, SJG redeemed early $0.1 million of the $25.0 million aggregate principal amount variable rate demand bonds that were issued in September 2008. SJG had previously spent all but $0.1 million of the debt proceeds and was permitted under the debt agreement to utilize those remaining funds to redeem the debt early.

No other debt was redeemed during the nine months ended September 30, 2015.


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15.
ACCUMULATED OTHER COMPREHENSIVE LOSS:

The following tables summarize the changes in accumulated other comprehensive loss (AOCL) for the three and nine months ended September 30, 2015 (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 July 1, 2015 (a)
$
(27,663
)
 
$
(2,331
)
 
$
(51
)
 
$
(106
)
 
$
(30,151
)
   Other comprehensive loss before reclassifications
—

 
—

 
(276
)
 
—

 
(276
)
   Amounts reclassified from AOCL (b)
—

 
52

 
99

 
(96
)
 
55

Net current period other comprehensive income (loss)
—

 
52

 
(177
)
 
(96
)
 
(221
)
Balance at September 30, 2015 (a)
$
(27,663
)
 
$
(2,279
)
 
$
(228
)
 
$
(202
)
 
$
(30,372
)


 
 
 
 
 
 
 
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, 2015 (a)
$
(27,663
)
$
(2,450
)
$
(75
)
$
(70
)
$
(30,258
)
   Other comprehensive income before reclassifications
—

—

(227
)
—

(227
)
   Amounts reclassified from AOCL (b)
—

171

74

(132
)
113

Net current period other comprehensive income (loss)
—

171

(153
)
(132
)
(114
)
Balance at September 30, 2015 (a)
$
(27,663
)
$
(2,279
)
$
(228
)
$
(202
)
$
(30,372
)

(a) For 2015, determined using a combined average statutory tax rate of 40%. For 2014, 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 three and nine months ended September 30, 2015:

 
Amounts Reclassified from AOCL (in thousands)
 
Affected Line Item in the Condensed Consolidated Statements of Income
Three Months Ended
September 30, 2015
 
Nine Months Ended
September 30, 2015
 
Unrealized Gain on Derivatives-Other - interest rate contracts designated as cash flow hedges
$
93

 
$
303

 
Interest Charges
   Income Taxes
(41
)
 
(132
)
 
Income Taxes (a)
 
$
52

 
$
171

 
 
 
 
 
 
 
 
Unrealized Loss on Available-for-Sale Securities
$
168

 
$
127

 
Other Income
   Income Taxes
(69
)
 
(53
)
 
Income Taxes (a)
 
$
99

 
$
74

 
 
 
 
 
 
 
 
Loss of Affiliated Companies
$
(158
)
 
$
(218
)
 
Equity in Loss of Affiliated Companies
   Income Taxes
62

 
86

 
Income Taxes (a)
 
$
(96
)
 
$
(132
)
 
 
 
 
 
 
 
 
Losses from reclassifications for the period net of tax
$
55

 
$
113

 
 

(a) For 2015, determined using a combined average statutory tax rate of 40%.

16.
SUBSEQUENT EVENT:

In October 2015, SJI entered into an unsecured $50.0 million term loan, which matures in October 2020.  This agreement replaces existing facilities that were set to expire in October 2015.


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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Forward-Looking Statements and Risk Factors — Certain statements contained in this Quarterly Report 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 and are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. 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 following: general economic conditions on an international, national, state and local level; weather conditions in our marketing areas; changes in commodity costs; changes in the availability of natural gas; “non-routine” or “extraordinary” disruptions in our distribution system; regulatory, legislative and court decisions; competition; the availability and cost of capital; costs and effects of legal proceedings and environmental liabilities; the failure of customers, suppliers or business partners to fulfill their contractual obligations; and changes in business strategies.

A discussion of these and other risks and uncertainties may be found in the Company’s Annual Report on Form 10-K for the year ended December 31, 2014 and in other filings made by us with the Securities and Exchange Commission (SEC). These cautionary statements should not be construed by you to be exhaustive and they are made only as of the date of this Quarterly Report on Form 10-Q, or in any document incorporated by reference, at the date of such document. While South Jersey Industries, Inc. (SJI or 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.

Critical Accounting Policies — Estimates and Assumptions — Management must make estimates and assumptions that affect the amounts reported in the condensed consolidated financial statements and related disclosures. Actual results could differ from those estimates. Five types of transactions presented in our condensed consolidated financial statements require a significant amount of judgment and estimation. These relate to regulatory accounting, derivatives, environmental remediation costs, pension and other postretirement employee benefit costs, and revenue recognition. A discussion of these estimates and assumptions may be found in SJI's Annual Report on Form 10-K for the year ended December 31, 2014.

New Accounting Pronouncements — See detailed discussions concerning New Accounting Pronouncements and their impact on SJI in Note 1 to the condensed consolidated financial statements.

Regulatory Actions — Other than the changes discussed in Note 7 to the condensed consolidated financial statements, there have been no significant regulatory actions since December 31, 2014. See detailed discussion concerning Regulatory Actions in Note 10 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014.

Environmental Remediation —There have been no significant changes to the status of the Company’s environmental remediation efforts since December 31, 2014. See detailed discussion concerning Environmental Remediation Costs in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014.


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RESULTS OF OPERATIONS:

SJI operates in several different reportable operating segments. These segments are as follows:

•
Gas utility operations (SJG) consist primarily of natural gas distribution to residential, commercial and industrial customers.
•
Wholesale energy operations include the activities of South Jersey Resources Group, LLC (SJRG) and South Jersey Exploration, LLC (SJEX).
•
South Jersey Energy Company (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 Energy, LLC (Marina's) thermal energy facility and other energy-related projects.
•
Appliance service operations includes South Jersey Energy Service Plus, LLC (SJESP’s) servicing of appliances under warranty via a subcontractor arrangement as well as on a time and materials basis. 
•
The activities of Midstream are a part of the Corporate & Services segment.
 
SJI groups its nonutility operations into two categories: Energy Group and Energy Services. Energy Group includes wholesale energy, retail gas and other, and retail electric operations. Energy Services includes on-site energy production and appliance service operations.

Net Loss for the three months ended September 30, 2015 increased $8.2 million to a net loss of $12.6 million compared with the same period in 2014, primarily as a result of the following:

•
The income contribution from the gas utility operations at SJG for the three months ended September 30, 2015 decreased $4.4 million to a net loss of $3.4 million due primarily to the write-off of additional uncollectible customer accounts receivable during the third quarter of 2015, as discussed under "Operations" below, along with additional depreciation expense and a realized gain on the sale of available-for-sale securities at SJG during the third quarter of 2014 that did not recur in 2015.

•
The income contribution from SJE for the three months ended September 30, 2015 decreased $2.4 million to a net loss of $2.3 million due primarily to the change in unrealized gains and losses on forward financial contracts used to mitigate price risk on retail gas as discussed under "Operating Revenues – Nonutility" below.

•
The income contribution from the wholesale energy operations at SJRG for the three months ended September 30, 2015 decreased $0.9 million to a net loss of $7.3 million due primarily to an approximately $3.8 million decrease resulting from the change in unrealized gains and losses on derivatives used by the wholesale energy operations to mitigate natural gas commodity price risk, as discussed under "Operating Revenues - Energy Group" below, partially offset by an approximately $2.9 million increase related to higher daily trading margins as discussed under "Gross Margin - Energy Group" below.

Net Income for the nine months ended September 30, 2015 increased $1.1 million to $54.2 million compared with the same period in 2014, primarily as a result of the following:

•
The income contribution from the wholesale energy operations at SJRG for the nine months ended September 30, 2015 increased $14.8 million to $2.2 million due primarily to an approximately $17.8 million increase resulting from the change in unrealized gains and losses on derivatives used by the wholesale energy operations to mitigate natural gas commodity price risk, as discussed under "Operating Revenues - Energy Group" below, partially offset by an approximately $3.0 million decrease related to lower daily trading margins and lower storage volumes sold as discussed under "Gross Margin - Energy Group" below.

•
The income contribution from the gas utility operations at SJG for the nine months ended September 30, 2015 increased $1.9 million to $44.4 million due primarily to the settlement of SJG's base rate case, continued investment in SJG's accelerated infrastructure programs and customer growth over the prior year. This was partially offset by the write-off of additional uncollectible customer accounts receivable, primarily in the third quarter of 2015, and higher depreciation and interest expense resulting from continued investment in utility property, plant and equipment.

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•
The income contribution from on-site energy production at Marina for the nine months ended September 30, 2015 decreased $14.8 million to $6.2 million due primarily to the impact of a reduction in the carrying amount of an investment at one of Energenic's operating subsidiaries, of which Marina has a 50% equity interest (see Note 5 to the condensed consolidated financial statements). Also contributing to the decrease is the timing of the investment tax credits available on renewable energy facilities as compared to the prior year.

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:

•
The wholesale energy operations at SJRG purchases and holds natural gas in storage to earn a profit margin from its ultimate sale in the future. The wholesale energy operations 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.

•
The retail electric operations at 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, (a) 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, (b) 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 (c) 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 three and nine months ended September 30, 2015 and 2014, 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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•
For the nine months ended September 30, 2015, Economic Earnings includes net losses of $1.5 million (net of tax) from affiliated companies that were previously not included in Economic Earnings. These adjustments are the result of a reserve for uncollectible accounts recorded by an Energenic subsidiary that owns and operates a central energy center and energy distribution system for a hotel, casino and entertainment complex in Atlantic City, New Jersey (see Note 5 to the condensed consolidated financial statements). In prior periods this charge was being excluded from Economic Earnings until the total economic impact of the proceedings were realized. During the second quarter of 2015, the Company, through its investment in Energenic, reduced the carrying value of the investment in this project. As such, this charge is now being included in Economic Earnings for the nine months ended September 30, 2015.

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 the three months ended September 30, 2015 decreased $1.6 million to a net loss of $5.0 million compared with the same period in 2014 primarily as a result of the following:

•
The income contribution from the gas utility operations at SJG for the three months ended September 30, 2015 decreased $4.4 million to a net loss of $3.4 million due primarily to the write-off of additional uncollectible customer accounts receivable during the third quarter of 2015, as discussed under "Operations" below, along with additional depreciation expense and a realized gain on the sale of available-for-sale securities at SJG during the third quarter of 2014 that did not recur in 2015.

•
Economic Earnings from the wholesale energy operations at SJRG for the three months ended September 30, 2015 increased $2.9 million to a net loss of $2.5 million due primarily to higher daily trading margins as discussed under "Gross Margin - Energy Group" below.

Economic Earnings for the nine months ended September 30, 2015 decreased $17.0 million to $55.8 million compared with the same period in 2014 primarily as a result of the following:

•
Economic Earnings from on-site energy production at Marina for the nine months ended September 30, 2015 decreased $16.3 million to $4.8 million due primarily to the impact of a reduction in the carrying amount of an investment at one of Energenic's operating subsidiaries, of which Marina has a 50% equity interest (see Note 5 to the condensed consolidated financial statements). Also contributing to the decrease is the timing of the investment tax credits available on renewable energy facilities as compared to the prior year.

•
Economic Earnings from the wholesale energy operations at SJRG for the nine months ended September 30, 2015 decreased $3.0 million to $2.8 million due primarily to lower daily trading margins and lower storage volumes sold as discussed under "Gross Margin - Energy Group" below.

•
Economic Earnings from the gas utility operations at SJG for the nine months ended September 30, 2015 increased $1.9 million to $44.4 million due primarily to the settlement of SJG's base rate case, continued investment in SJG's accelerated infrastructure programs and customer growth over the prior year. This was partially offset by the write-off of additional uncollectible customer accounts receivable, primarily in the third quarter of 2015, and higher depreciation and interest expense resulting from continued investment in utility property, plant and equipment.


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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 for the three and nine months ended September 30 (in thousands except per share data):
 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
 
2014
(Loss) Income from Continuing Operations
$
(12,532
)
 
$
(4,276
)
 
$
54,662

 
$
53,636

Minus/Plus:
 
 
 
 
 
 
 
Unrealized Mark-to-Market Losses on Derivatives
7,560

 
936

 
2,670

 
18,816

Realized (Gains)/Losses on Inventory Injection Hedges
15

 
(29
)
 
52

 
391

Net Loss from Affiliated Companies (A)
—

 
—

 
(1,524
)
 
—

Other (B)
(25
)
 
(25
)
 
(75
)
 
(75
)
Economic Earnings
$
(4,982
)
 
$
(3,394
)
 
$
55,785

 
$
72,768

 
 
 
 
 
 
 
 
Earnings per Share from Continuing Operations (C)
$
(0.18
)
 
$
(0.07
)
 
$
0.80

 
$
0.81

Minus/Plus:
 
 
 
 
 
 
 
Unrealized Mark-to-Market Losses on Derivatives
0.11

 
0.02

 
0.04

 
0.29

Net Loss from Affiliated Companies (A)
—

 
—

 
(0.02
)
 
—

Economic Earnings per Share
$
(0.07
)
 
$
(0.05
)
 
$
0.82

 
$
1.10



35
Table of Contents

The effect of derivative instruments not designated as hedging instruments under GAAP in the condensed consolidated statements of income (see Note 12 to the condensed consolidated financial statements) is as follows (gains (losses) in thousands):

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
 
2014
Losses on energy related commodity contracts
$
(11,992
)
 
$
(1,633
)
 
$
(4,014
)
 
$
(30,429
)
(Losses) gains on interest rate contracts
(435
)
 
202

 
(192
)
 
(103
)
                         Total before income taxes
(12,427
)
 
(1,431
)
 
(4,206
)
 
(30,532
)
                         Income taxes (D)
4,971

 
584

 
1,683

 
12,472

                     Total after income taxes
(7,456
)
 
(847
)
 
(2,523
)
 
(18,060
)
Unrealized mark-to-market losses on derivatives held by affiliated companies, net of tax (D)
(104
)
 
(89
)
 
(147
)
 
(756
)
Total unrealized mark-to-market losses on derivatives
(7,560
)
 
(936
)
 
(2,670
)
 
(18,816
)
Realized (losses) gains on inventory injection hedges, net of tax (D)
(15
)
 
29

 
(52
)
 
(391
)
Net Loss from Affiliated Companies (A)
—

 
—

 
1,524

 
—

Other (B)
25

 
25

 
75

 
75

Total reconciling items between income (losses) from continuing operations and economic earnings
$
(7,550
)
 
$
(882
)
 
$
(1,123
)
 
$
(19,132
)

(A) Resulting from a reserve for uncollectible accounts recorded by an Energenic subsidiary that owns and operates a central energy center and energy distribution system for a hotel, casino and entertainment complex in Atlantic City, New Jersey (see Note 5 to the condensed consolidated financial statements). In prior periods this charge was being excluded from Economic Earnings until the total economic impact of the proceedings were realized. During the second quarter of 2015, the Company, through its investment in Energenic, reduced the carrying value of the investment in this project. As such, this charge is now being included in Economic Earnings for the nine months ended September 30, 2015.

(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) All per share amounts were adjusted for the 2-for-1 stock split, effective on May 8, 2015. See Note 1 to the condensed consolidated financial statements.

(D) For 2015, determined using a combined average statutory tax rate of 40%. For 2014, determined using a combined statutory tax rate of 41%.

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Table of Contents

The following tables summarize the composition of selected gas utility operations data for the three and nine months ended September 30 (in thousands, except for degree day data):

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
2014
Utility Throughput – decatherms (dt):
 
 
 
 
 
 
Firm Sales -
 
 
 
 
 
 
Residential
1,499

 
1,407

 
18,788

17,425

Commercial
593

 
544

 
4,944

4,026

Industrial
113

 
18

 
378

208

Cogeneration & Electric Generation
781

 
273

 
1,277

828

Firm Transportation -
 
 
 
 
 
 
Residential
141

 
169

 
1,933

2,463

Commercial
920

 
643

 
5,292

5,175

Industrial
2,760

 
3,105

 
8,777

9,774

Cogeneration & Electric Generation
1,840

 
4,143

 
4,918

7,332

 
 
 
 
 
 
 
Total Firm Throughput
8,647

 
10,302

 
46,307

47,231

 
 
 
 
 
 
 
Interruptible Sales
—

 
—

 
20

—

Interruptible Transportation
346

 
258

 
998

964

Off-System Sales
2,031

 
2,489

 
8,652

6,007

Capacity Release
16,018

 
11,958

 
45,008

42,617

 
 
 
 
 
 
 
Total Throughput - Utility
27,042

 
25,007

 
100,985

96,819



 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
2014
Utility Operating Revenues:
 
 
 
 
 
 
Firm Sales -
 
 
 
 
 
 
Residential
$
25,986

 
$
24,149

 
$
238,571

$
184,436

Commercial
7,616

 
7,489

 
54,726

44,939

Industrial
1,032

 
278

 
4,154

2,945

Cogeneration & Electric Generation
2,619

 
1,487

 
4,907

5,148

Firm Transportation -
 
 
 
 
 
 
Residential
1,533

 
1,886

 
12,360

14,741

Commercial
4,292

 
3,577

 
22,769

21,540

Industrial
5,888

 
6,240

 
17,488

19,214

Cogeneration & Electric Generation
947

 
3,350

 
3,943

6,924

 
 
 
 
 
 
 
Total Firm Revenues
49,913

 
48,456

 
358,918

299,887

 
 
 
 
 
 
 

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Table of Contents

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
2014
Interruptible Sales
—

 
—

 
298

2

Interruptible Transportation
312

 
311

 
1,076

1,170

Off-System Sales
5,586

 
10,032

 
35,682

33,998

Capacity Release
2,460

 
1,840

 
5,118

4,688

Other
363

 
313

 
1,012

911

 
58,634

 
60,952

 
402,104

340,656

Less: Intercompany Sales
(1,127
)
 
(196
)
 
(2,772
)
(668
)
Total Utility Operating Revenues
57,507

 
60,756

 
399,332

339,988

Less:
 
 
 

 
 
 
Cost of Sales - Utility (Excluding depreciation)
21,808

 
23,205

 
191,683

150,905

Conservation Recoveries*
1,648

 
3,453

 
18,772

19,171

RAC Recoveries*
2,281

 
2,021

 
6,842

6,064

EET Recoveries*
769

 
1,128

 
2,816

3,179

Revenue Taxes
164

 
153

 
952

764

Utility Margin**
$
30,837

 
$
30,796

 
$
178,267

$
159,905

 
 
 
 
 
 
 
Margin:
 

 
 

 
 
 
Residential
$
17,628

 
$
15,462

 
$
131,731

$
111,533

Commercial and Industrial
11,631

 
9,529

 
56,613

46,986

Cogeneration and Electric Generation
1,270

 
1,566

 
3,650

4,013

Interruptible
19

 
9

 
103

43

Off-System Sales & Capacity Release
670

 
625

 
2,748

1,745

Other Revenues
889

 
609

 
2,144

1,720

Margin Before Weather Normalization & Decoupling
32,107

 
27,800

 
196,989

166,040

CIP Mechanism
(1,822
)
 
2,721

 
(20,218
)
(6,698
)
EET Mechanism
552

 
275

 
1,496

563

Utility Margin**
$
30,837

 
$
30,796

 
$
178,267

$
159,905

 
 
 
 
 
 
 
Degree Days:
3

 
26

 
3,343

3,288


*Represents expenses for which there is a corresponding credit in operating revenues.  Therefore, such recoveries have no impact on SJG's financial results.
**Utility Margin is further defined under the caption "Margin - Gas Utility Operations" below.

Throughput - Gas Utility Operations - Total gas throughput increased 2.0 MMdts and 4.2 MMdts during the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. Capacity release increased 4.1 MMdts and 2.4 MMdts during the three and nine months ended September 30, 2015, respectively, as the market for long-haul capacity increased during the third quarter, thereby increasing throughput for both the quarter and year-to-date. The increase in Off-System sales (OSS) was primarily related to opportunities created on the interstate pipeline as a result of extremely cold weather in the northeast region of the country during the first quarter of 2015, which contributed to a 2.6 MMdts increase on a year-to-date basis over 2014.


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Table of Contents

Firm throughput decreased 1.7 MMdts and 0.9 MMdts during the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. This was the result of a significant decrease in transportation of commodity to a cogeneration facility during the third quarter of 2015, compared to the same period in 2014, as reflected under "Firm Transportation - Cogeneration & Electric Generation" in the Throughput table above. During the third quarter of 2014, this facility had a disruption in its alternate supply of natural gas and turned to SJG to meet its operating needs. That disruption has since been remedied, resulting in lower firm transportation throughput in 2015.
Conservation Incentive Program (CIP) - Gas Utility Operations - The effects of the CIP on net income of the gas utility operations for the three and nine months ended September 30, 2015 and 2014 and the associated weather comparisons are as follows ($’s in millions):

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
2015
 
2014
Net Income Impact:
 
 
 
 
 
 
 
CIP – Weather Related
$
—

 
$
—

 
$
(7.3
)
 
$
(5.7
)
CIP – Usage Related
(1.1
)
 
1.6

 
(4.7
)
 
1.7

Total Net Income Impact
$
(1.1
)
 
$
1.6

 
$
(12.0
)
 
$
(4.0
)
 
 
 
 
 
 
 
 
Weather Compared to 20-Year Average
n/a

 
n/a
 
14.7% Colder

 
13.4% Colder

Weather Compared to Prior Year
n/a

 
n/a
 
1.7% Colder

 
8.9% Colder


Operating Revenues  - Gas Utility Operations - Revenues decreased $3.2 million, or 5.3% during the three months ended September 30, 2015 compared with the same period in the prior year, after eliminating intercompany transactions, due to lower OSS, partially offset by higher firm sales. Lower OSS unit volume, coupled with lower unit prices, resulted in a $4.4 million decrease in OSS revenues during the three months ended September 30, 2015, compared with the same period in 2014. However, the impact of changes in OSS activity does not have a material impact on the earnings of SJG, as SJG is required to return 85% of the profits of such activity to its ratepayers. Earnings from OSS can be seen in the "Margin" table above.

Total firm revenue increased $1.5 million for the three months ended September 30, 2015, as a result of a 22.1% increase in SJG’s rate for natural gas recoveries, effective October 1, 2014. This increased revenue by approximately $2.5 million during the three months ended September 30, 2015, compared to the same period in 2014. While changes in natural gas costs and Basic Gas Supply Service (“BGSS”) recoveries fluctuate from period to period, SJG does not profit from the sale of the commodity. Therefore, fluctuations in Operating Revenue and Cost of Sales, such as those caused by the recovery of an incremental $2.5 million in gas costs during the third quarter of 2015, did not impact on SJG’s profitability. Also contributing to higher firm revenue was the addition of 6,893 customers compared with the same period in 2014. Partially offsetting the increase in firm revenues was a significant decrease in transportation service to a cogeneration facility during the third quarter of 2015, compared to the same period in 2014. During the third quarter of 2014, this facility had a disruption in its alternate supply of natural gas and turned to SJG to meet its operating needs. That disruption has since been remedied, resulting in lower firm transportation revenue in 2015.
Revenues increased $59.3 million, or 17.4%, during the nine months ended September 30, 2015 compared with the same period in the prior year, after eliminating intercompany transactions, due to higher firm sales and OSS. Total firm revenue increased $59.0 million for the nine months ended September 30, 2015, as a result of the settlement of SJG’s base rate case and a 22.1% increase in SJG’s rate for natural gas recoveries, both effective October 1, 2014. These two events increased revenue by approximately $15.5 million and $37.4 million, respectively, during the nine months ended September 30, 2015, compared to the same period in 2014. As previously stated, SJG does not profit from the sale of commodity; therefore, the recovery of an incremental $37.4 million in gas costs during 2015 has no impact on SJG’s profitability. Also contributing to higher revenue were 2.5% colder weather and the addition of 6,893 additional customers compared with the same period in 2014. While colder weather increased firm sales revenue, the revenue increase has little impact on SJG profitability under the operation of the Conservation Incentive Program, as discussed below under the captions, “Conservation Incentive Program (CIP) - Gas Utility Operations” and Margin - Gas Utility Operations.”


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Table of Contents

Higher OSS unit volume, partially offset by lower unit prices, resulted in a $1.7 million increase in OSS revenues during the nine months ended September 30, 2015, compared with the same period in 2014. Extremely cold weather in the northeast region of the country lead to greater demand during the first quarter of 2015, creating opportunity for SJG to increase revenue from such sales. However, the impact of changes in OSS activity does not have a material impact on the earnings of SJG, as SJG is required to return 85% of the profits of such activity to its ratepayers. Earnings from OSS can be seen in the “Margin” table above.
Operating Revenues - Energy Group -  Combined revenues for the Energy Group, net of intercompany transactions, increased $19.2 million, or 43.3%, to $63.6 million, and $33.1 million, or 15.2%, to $251.5 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014.

Revenues from retail gas operations at SJE, net of intercompany transactions, decreased $7.1 million, or 37.6%, and $27.6 million, or 29.0%, for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. Excluding the change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $4.5 million and $3.2 million, revenues decreased $2.6 million, or 13.9%, and $24.4 million, or 25.6%, for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014.

A summary of SJE's retail gas revenue is as follows (in millions):

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
Change
 
2015
 
2014
 
Change
SJE Retail Gas Revenue
$
11.8

 
$
18.9

 
$
(7.1
)
 
$
67.6

 
$
95.2

 
$
(27.6
)
Add: Unrealized Losses (Subtract: Unrealized Gains)
4.3

 
(0.2
)
 
4.5

 
3.3

 
0.1

 
3.2

SJE Retail Gas Revenue, Excluding Unrealized Losses (Gains)
$
16.1

 
$
18.7

 
$
(2.6
)
 
$
70.9


$
95.3


$
(24.4
)

The decrease in revenues for the three and nine months ended September 30, 2015 compared with the same periods in 2014 was mainly due to a 31.8% and 38.6%, respectively, decrease in the average monthly New York Mercantile Exchange (NYMEX) settle price. Also contributing to the nine month period decrease is a 3.0% decrease in sales volumes compared with the same period in 2014. Sales volumes totaled 18,464,278 and 19,040,688 dekatherms for the nine months ended September 30, 2015 and 2014, respectively.

Revenues from retail electric operations at SJE, net of intercompany transactions, increased $13.4 million, or 45.9%, and $11.6 million, or 12.3%, for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(0.3) million and $(1.1) million, revenues increased $13.1 million, or 44.7%, and $10.5 million, or 11.0%, for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014.


40
Table of Contents

A summary of revenues from retail electric operations at SJE is as follows (in millions):

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
Change
 
2015
 
2014
 
Change
SJE Retail Electric Revenue
$
42.6

 
$
29.2

 
$
13.4

 
$
106.3

 
$
94.7

 
$
11.6

Add: Unrealized Losses (Subtract: Unrealized Gains)
(0.2
)
 
0.1

 
(0.3
)
 
(0.3
)
 
0.8

 
(1.1
)
SJE Retail Electric Revenue, Excluding Unrealized Losses (Gains)
$
42.4

 
$
29.3

 
$
13.1

 
$
106.0

 
$
95.5

 
$
10.5


The increase in revenues from retail electric operations at SJE as defined above for the three months and nine months ended September 30, 2015 compared with the same periods in 2014 was mainly due to a 33.9% and 18.7% increase in sales volumes, respectively. Partially offsetting the nine month comparative period change was a 9.1% decrease in the average monthly sales price, which was driven by a lower average Locational Marginal Price (LMP) per megawatt hour. 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. The 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 financial 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 financial contracts, resulting in the realization of the profit margin expected when the transactions were initiated. The retail electric operations at SJE serve both fixed and market-priced customers.

Revenues from wholesale energy operations at SJRG, net of intercompany transactions, increased $12.9 million and $49.2 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $6.0 million and $(28.5) million and adjusting for the change in realized gains and losses on all hedges attributed to inventory injection transactions of $0.1 million and $(0.5) million to align them with the related cost of inventory in the period of withdrawal, revenues from the wholesale energy operations at SJRG increased $19.0 million and $20.2 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014.

A summary of revenues from wholesale energy operations at SJRG is as follows (in millions):

 
Three Months Ended
September 30,
 
Nine Months Ended
September 30,
 
2015
 
2014
 
Change
 
2015
 
2014
 
Change
SJRG Revenue
$
9.3

 
$
(3.6
)
 
$
12.9

 
$
77.5

 
$
28.3

 
$
49.2

Add: Unrealized Losses (Subtract: Unrealized Gains)
7.8

 
1.8

 
6.0

 
1.0

 
29.5

 
(28.5
)
Add:  Realized Losses (Subtract: Realized Gains) on Inventory Injection Hedges
—

 
(0.1
)
 
0.1

 
0.1

 
0.6

 
(0.5
)
SJRG Revenue, Excluding Unrealized Losses (Gains) and  Realized Losses (Gains) on Inventory Injection Hedges
$
17.1

 
$
(1.9
)
 
$
19.0

 
$
78.6

 
$
58.4

 
$
20.2


The increase in revenues from the wholesale energy operations at SJRG as defined above for the three and nine months ended September 30, 2015 compared with the same periods in 2014 was due mainly to revenues earned on a gas supply contract with an electric generation facility that began operations in the second half of 2014. Partially offsetting the nine month comparative period change was a 19.0% decrease in storage volumes sold. As discussed in Note 1 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014, revenues and expenses related to the energy trading activities of the wholesale energy operations at SJRG are presented on a net basis in Operating Revenues – Nonutility on the condensed consolidated income statement.


41
Table of Contents

Operating Revenues - Energy Services -  Combined revenues for Energy Services, net of intercompany transactions, increased $2.6 million, or 15.3%, to $19.9 million, and $3.4 million, or 7.1%, to $50.9 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014.
Revenues from on-site energy production at Marina, net of intercompany transactions, increased $2.7 million, or 17.9%, and $3.6 million, or 9.1%, for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. primarily due to several new renewable energy projects that began operations over the past twelve months, along with higher prices on solar renewable energy credits (SRECs) compared to the previous year.

Revenues from appliance service operations at SJESP, net of intercompany transactions, did not change significantly for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014.

Margin - Gas Utility Operations - The gas utility operations margin is defined as natural gas revenues less natural gas costs, regulatory rider expenses and related volumetric and revenue-based energy taxes. SJG believes that margin provides a more meaningful basis for evaluating utility operations than revenues since natural gas costs, regulatory rider expenses and related energy taxes 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 (BPU) through SJG’s BGSS clause.

Total margin was relatively flat at $30.8 million for each of the three month periods ended September 30, 2015 and 2014, as residential, commercial and industrial margin increased in 2015, offset by the CIP tracking mechanism as discussed below. Total margin increased $18.4 million, or 11.5% for the nine months ended September 30, 2015 compared with the same period in 2014. The increase is primarily due to increases in rates as a result of the settlement of SJG's base rate case effective October 1, 2014 which increased margin by approximately $15.5 million for the nine months ended September 30, 2015, compared with the same period in 2014. In addition, SJG added 6,893 customers over the 12-month period ended September 30, 2015, contributing approximately $2.3 million in additional margin during the nine months ended September 30, 2015, compared with the same period of 2014.
The CIP tracking mechanism adjusts earnings when actual usage per customer experienced during the period varies from an established baseline usage per customer. As reflected in the margin and CIP tables above, the CIP mechanism reduced margin by $1.8 million, or $1.1 million after taxes, for the three month period ended September 30, 2015, primarily due to higher customer usage. The CIP mechanism protected $2.7 million, or $1.6 million after taxes, of margin for the three months ended September 30, 2014, that would have been lost due to lower customer usage.

The CIP mechanism reduced margin by $20.2 million, or $12.0 million after taxes, and $6.7 million, or $4.0 million after taxes, during the nine month periods ended September 30, 2015 and 2014, respectively, primarily due to weather that was colder than average. Also, during the nine month period ended September 30, 2015, higher customer usage contributed $7.8 million, or $4.7 million after taxes to the reduction in margin noted above.

Gross Margin - Nonutility -  Gross margin for the nonutility businesses is defined as revenue less all costs that are directly related to the production, sale 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 condensed 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 in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014, revenues and expenses related to the energy trading activities of the wholesale energy operations at SJRG are presented on a net basis in Operating Revenues - Nonutility on the condensed consolidated income statement.

Gross Margin - Energy Group - For the three and nine months ended September 30, 2015, combined gross margins for Energy Group decreased $5.0 million to a loss of $10.0 million and increased $24.3 million to $20.2 million, respectively, compared with the same periods in 2014. These changes were primarily due to the following:

•
Gross margin from SJE’s retail gas and other operations decreased $4.6 million to a loss of $3.5 million and $3.4 million to $2.3 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. Excluding the change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $4.5 million and $3.2 million, gross margin decreased $0.1 million and $0.2 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. These three and nine month comparative period changes were not significant. Excluding the impact of the unrealized gains/losses discussed above, gross margin as a percentage of Operating Revenues did not change significantly for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014.

42
Table of Contents


•
Gross margin from SJE’s retail electric operations increased $0.6 million to $2.1 million and $1.5 million to $4.7 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $(0.3) million and $(1.1) million, gross margins increased $0.3 million and $0.4 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. These three and nine month comparative period changes were not significant. Excluding the impact of the unrealized gains/losses discussed above, gross margin as a percentage of Operating Revenues did not change significantly for the three and nine months ended September 30, 2015 compared with the same periods in 2014.

•
Gross margin from the wholesale energy operations at SJRG decreased $0.8 million to a loss of $8.6 million and increased $26.4 million to $13.2 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. Excluding the impact of the net change in unrealized gains and losses recorded on forward financial contracts due to price volatility of $6.0 million and $(28.5) million and adjusting for the change in realized gains and losses on all hedges attributed to inventory injection transactions of $0.1 million and $(0.5) million to align them with the related cost of inventory in the period of withdrawal as discussed above, gross margin for the wholesale energy operations at SJRG increased $5.3 million and decreased $2.6 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014. The increase in gross margin for the three months ended September 30, 2015 compared with the same period in 2014 was due mainly to higher margins on daily energy trading activities. The decrease in gross margin for the nine months ended September 30, 2015 compared with the same period in 2014 was due mainly to lower margins on daily energy trading activities in the first quarter of 2015, along with a decrease in storage volumes sold.

The wholesale energy operations at 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 September 30, 2015, the wholesale energy operations had 9.1 Bcf of storage and 484,073 dts/day of transportation under contract.

Gross Margin - Energy Services - For the three and nine months ended September 30, 2015, combined gross margins for Energy Services increased $2.4 million to $16.3 million and $4.3 million to $42.1 million, respectively, compared with the same periods in 2014. These changes were primarily due to the following:
•
Gross margin from on-site energy production at Marina increased $2.3 million to $15.1 million and $4.3 million to $38.7 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014 mainly due to several new higher margin renewable energy projects that began operations over the past twelve months, along with higher prices on solar renewable energy credits (SRECs) compared to the previous year. Gross margin as a percentage of Operating Revenues did not change significantly for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014

•
Gross margin from appliance service operations at SJESP did not change significantly for the three and nine months ended September 30, 2015 compared with the same periods in 2014.


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Operating Expenses - A summary of net changes in operations expense for the three and nine months ended September 30, follows (in thousands):

 
Three Months Ended September 30,
2015 vs. 2014
 
Nine Months Ended September 30,
2015 vs. 2014
Gas Utility Operations
$
2,017

 
$
6,902

Nonutility:
 
 
 
Energy Group:
 
 
 
   Wholesale Energy Operations
392

 
1,807

   Retail Gas and Other Operations
(86
)
 
(312
)
   Retail Electric Operations
(185
)
 
(133
)
      Subtotal Energy Group
121

 
1,362

Energy Services:
 
 
 
   On-Site Energy Production
1,113

 
1,236

   Appliance Service Operations
(98
)
 
(139
)
Subtotal Energy Services
1,015

 
1,097

     Total Nonutility
1,136

 
2,459

Intercompany Eliminations and Other
58

 
(489
)
Total Operations Expense
$
3,211

 
$
8,872


Operations - Gas utility operations expense increased $2.0 million and $6.9 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014.  The increase primarily resulted from the write-off of additional uncollectible customer accounts receivable during the third quarter of 2015 at SJG, as a result of an increase in the aging of receivables following a very cold winter season. Changes in the uncollectible reserve are the result of fluctuations in levels of customer accounts receivables balances. Accounts receivable was higher as of September 30, 2015 due to higher customer billing rates, as approved by the BPU effective October 1, 2014, in addition to customer growth over the 12-month period ended September 30, 2015.

Nonutility operations expense increased $1.1 million and $2.5 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014 primarily due to additional personnel, governance and compliance costs incurred to support continued growth.

Maintenance - Maintenance expense increased $0.9 million and $2.4 million during the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014 primarily due to the BPU-approved amortization and recovery of previously deferred maintenance costs, primarily those associated with a federally mandated pipeline integrity management program. These amortizations are being recovered through an offsetting amount in revenues.

Depreciation - Depreciation increased $2.4 million and $6.1 million during the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014 due primarily to the increased investment in property, plant and equipment by the gas utility operations of SJG and on-site energy production at Marina.

Energy and Other Taxes - The change in energy and other taxes for the three and nine months ended September 30, 2015 compared with the same periods in 2014 was not significant.

Other Income and Expense - Other income and expense decreased $1.2 million and $2.4 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014 due primarily to a realized gain on the sale of available-for-sale securities at SJG during the third quarter of 2014 that did not recur in 2015. Also contributing to the nine month comparative period decrease is a settlement of litigation at SJEX in the second quarter of 2014 that did not recur in 2015.


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Interest Charges – Interest charges increased $1.3 million and $3.5 million for the three and nine months ended September 30, 2015, respectively, compared with the same periods in 2014 primarily due to higher amounts of long-term debt outstanding at SJI and SJG, along with lower capitalization of interest costs on construction at the gas utility operations of SJG during 2015. This was a result of the roll-in of capital investments under SJG's Accelerated Infrastructure Replacement Program (AIRP) into base rates effective October 1, 2014 and a lower allowance for debt funds used during construction as a result of placing two major technology systems in service during the fourth quarter of 2014. AIRP investments are approved by the BPU to accrue interest on construction until such time they are rolled into base rates.

Income Taxes – Income tax benefit increased $2.6 million for the three months ended September 30, 2015 compared with the same period in 2014 due primarily to a higher loss before income taxes, offset by a lower effective tax rate due to a projected increase in the investment tax credits available on renewable energy facilities at Marina. Income taxes went from a $6.0 million benefit for the nine months ended September 30, 2014 to a $2.4 million expense for the nine months ended September 30, 2015 due primarily to higher income before income taxes, along with a higher effective tax rate due to the timing of the investment tax credits available on renewable energy facilities at Marina.

Equity in Loss of Affiliated Companies – Equity in loss of affiliated companies decreased $2.6 million for the three months ended September 30, 2015 compared with the same period in 2014 due primarily to a reserve for uncollectible accounts established at one of Energenic's operating subsidiaries during the third quarter of 2014 that did not recur in 2015. Equity in loss of affiliated companies increased $14.2 million for the nine months ended September 30, 2015 compared with the same period in 2014 due primarily to the 2015 reduction in the carrying amount of an investment in the Energenic subsidiaries that operate the central energy center for a hotel, casino and entertainment complex in Atlantic City, New Jersey (see Note 5 to the condensed consolidated financial statements), partially offset by a reserve for uncollectible accounts established at one of Energenic's operating subsidiaries during the third quarter of 2014 that did not recur in 2015.

Discontinued Operations — The results 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 $151.9 million and $109.0 million in the first nine months of 2015 and 2014, 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.  Operating activities in the first nine months of 2015 produced more net cash than the same period in 2014 primarily as a result of higher collections of gas costs under the BGSS at the utility that were deferred in 2014 as a result of the extremely cold weather experienced during the 2014 winter. This benefit was partially offset by a $15.0 million pension contribution made by SJI as a result of a decline in the discount rate and new mortality tables released at the end of 2014, both of which negatively impacted the funding status of the pension plans. No such contribution was made in 2014. 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.

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 investing activities, which are primarily construction projects, for the first nine months of 2015 and 2014 amounted to $240.9 million and $208.4 million, respectively. We estimate the net cash outflows for investing activities for fiscal years 2015, 2016 and 2017 at SJI to be approximately $373.3 million, $381.3 million and $521.6 million, respectively. The high level of investing activities for 2015, 2016 and 2017 is due to a combination of the AIRP and a major pipeline project to support an electric generation facility, both at SJG.  Also contributing to the high level of investing activities are anticipated solar projects at Marina and SJI Midstream investments. The Company expects to use short-term borrowings under lines of credit from commercial banks and the commercial paper program to finance these investing activities as incurred. From time to time, the Company may refinance the short-term debt with long-term debt.


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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 condensed 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 decreased by $22.9 million in the first nine months of 2015, compared with an increase of $4.8 million in the same period of 2014.

During the first nine months of 2015 and 2014, the Company received net repayments from unconsolidated affiliates of $4.4 million and $1.3 million, respectively.

In June 2015, SJG advanced $10.0 million to a not-for-profit organization formed to spur economic development in Atlantic City, New Jersey. The note bears interest at 1.0% for an initial term of six months, with the borrower’s option to extend the term for two additional terms of three months each. SJG holds a first lien security interest on land in Atlantic City as collateral against this note.
 
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 is refinanced with long-term debt.

Credit facilities and available liquidity as of September 30, 2015 were as follows (in thousands):

Company
 
Total Facility
 
Usage
 
Available Liquidity
 
Expiration Date
SJG:
 
 
 
 
 
 
 
 
Commercial Paper Program/Revolving Credit Facility
 
$
200,000

 
$
89,900

(A)
$
110,100

 
May 2018
Uncommitted Bank Lines
 
10,000

 
—

 
10,000

 
Various
 
 
 
 
 
 
 
 
 
Total SJG
 
210,000

 
89,900

 
120,100

 
 
 
 
 
 
 
 
 
 
 
SJI:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Revolving Credit Facility
 
400,000

 
270,200

(B)
129,800

 
February 2018
 
 
 
 
 
 
 
 
 
Total SJI
 
400,000

 
270,200

 
129,800

 
 
 
 
 
 
 
 
 
 
 
Total
 
$
610,000

 
$
360,100

 
$
249,900

 
 

(A) Includes letters of credit outstanding in the amount of $0.6 million.
(B) Includes letters of credit outstanding in the amount of $8.1 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 September 30, 2015. Borrowings under these credit facilities are at market rates. The weighted average borrowing cost, which changes daily, was 1.03% and 0.83% at September 30, 2015 and 2014, respectively.  Average borrowings outstanding under these credit facilities, not including letters of credit, during the nine months ended September 30, 2015 and 2014 were $310.8 million and $291.6 million, respectively. The maximum amounts outstanding under these credit facilities, not including letters of credit, during the nine months ended September 30, 2015 and 2014 were $432.4 million and $390.7 million, respectively. 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.


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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 its $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. 

In June 2015, the Company redeemed at maturity $64.0 million aggregate principal amount of 2.39% Senior Notes.

In August 2015, SJG retired $10.0 million aggregate principal amount of 5.387% Medium Term Notes at maturity.

In September 2015, SJG issued $80.0 million of long-term debt under a $200.00 million aggregate syndicated bank term facility. The total outstanding amount under this facility as of September 30, 2015 was $139.0 million.
Also in September, SJG redeemed early $0.1 million of the $25.0 million aggregate principal amount variable rate demand bonds that were issued in September 2008. SJG had previously spent all but $0.1 million of the debt proceeds and was permitted under the debt agreement to utilize those remaining funds to redeem the debt early.

SJI raises equity capital through its Dividend Reinvestment Plan (DRP). Shares of common stock offered by the DRP have been issued directly by SJI from its authorized but unissued shares of common stock. SJI raised $9.7 million and $29.1 million of equity capital through the DRP during the nine months ended September 30, 2015 and 2014, respectively.

SJI’s capital structure was as follows:

 
As of September 30, 2015
 
As of December 31, 2014
Equity
40.9
%
 
42.6
%
Long-Term Debt
43.9
%
 
46.2
%
Short-Term Debt
15.2
%
 
11.2
%
Total
100.0
%
 
100.0
%

SJI has paid dividends on its common stock for 64 consecutive years and has increased that dividend each year for the last fifteen years.  The Company's goal is 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:

Environmental Remediation - Costs for remediation projects, net of insurance reimbursements, for the first nine months of 2015 and 2014 amounted to net cash outflows of $10.9 million and $4.8 million, respectively. Total net cash outflows for remediation projects are expected to be $17.7 million, $41.3 million and $24.0 million for 2015, 2016 and 2017, respectively.  As discussed in Notes 10 and 15 to the Consolidated Financial Statements in Item 8 of SJI’s 10-K for the year ended December 31, 2014, certain environmental costs are subject to recovery from insurance carriers and ratepayers.

Standby Letters of Credit - As of September 30, 2015, SJI provided $8.1 million of standby letters of credit through its revolving credit facility to enable SJE to market retail electricity and for various construction and operating activities. SJG provided a $0.6 million letter of credit under its revolving credit facility to support the remediation of environmental conditions at certain locations in SJG's service territory. The Company also provided $87.6 million of additional letters of credit under separate facilities outside of the revolving credit facilities 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.

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Contractual Obligations - There were no significant changes to the Company’s contractual obligations described in Note 15 to the Consolidated Financial Statements in Item 8 of SJI’s Annual Report on Form 10-K for the year ended December 31, 2014, except for (a) commodity supply purchase obligations, which increased approximately $160.1 million due to the addition of a 15-year gas supply contract which began in September 2015 at SJG; (b) long-term debt, which increased due to the issuance of $80.0 million under an aggregate syndicated bank term facility at SJG; and (c) construction obligations, which increased $35.0 million in total since December 31, 2014 due to solar projects entered into at Marina.

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 $0.6 million which is included in Other Noncurrent Liabilities with a corresponding increase in Investment in Affiliates on the condensed consolidated balance sheets as of September 30, 2015 for the fair value of the following guarantees:

•
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 agreements 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 guarantees 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 the Landfills are unable to meet certain financial obligations as they become due. As of September 30, 2015, 50% of the currently outstanding debt is $8.2 million.

•
In May 2012, UMM Energy Partners, LLC (UMM), a wholly-owned subsidiary of Energenic, in 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. As of September 30, 2015, SJI has guaranteed up to $2.4 million. 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. SJI holds variable interests in UMM but is not the primary beneficiary.

•
As of September 30, 2015, SJI had issued $5.7 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.

During 2011, subsidiaries of Energenic, in which Marina has a 50% equity interest, entered into 20-year contracts 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, Energenic subsidiaries began providing full energy services to the complex. 

In June 2014 the parent company of the hotel, casino and entertainment complex filed petitions in U. S. Bankruptcy Court to facilitate a sale of substantially all of its assets. The complex ceased normal business operations in September 2014. Energenic subsidiaries continued to provide limited energy services to the complex during the shutdown period under a temporary agreement with the trustee. The hotel, casino and entertainment complex was sold in April 2015. The Energenic subsidiaries are currently providing limited services to the complex under a short-term agreement with the new owner. However, the Energenic subsidiaries have not been able to secure a permanent or long-term energy services agreement with the new owner.


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As a result, management of the Company and Energenic have evaluated the carrying value of the investment in this project and a related note receivable. Based on the current situation, the Company recorded a $7.7 million (net of tax) non-cash charge to earnings during the second quarter of 2015 due to the reduction in the carrying value of the investment in this project recorded by Energenic. This charge is included in Equity in Loss of Affiliated Companies for the nine months ended September 30, 2015 on the condensed consolidated statements of income.

As of September 30, 2015, the Company, through its investment in Energenic, had a remaining net asset of approximately $2.0 million included in Investment in Affiliates on the condensed consolidated balance sheets related to the project. In addition, the Company had approximately $13.9 million included in Notes Receivable - Affiliate on the condensed consolidated balance sheets, due from Energenic, which is secured by certain assets of the central energy center. This note is subject to a reimbursement agreement that secures reimbursement for the Company, from its joint venture partner, of a proportionate share of any amounts that are not repaid.

Management will continue to monitor the situation surrounding the complex and will evaluate the carrying value of the investment and the note receivable as future events occur.

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 $3.2 million and $2.9 million related to all claims in the aggregate as of September 30, 2015 and December 31, 2014, 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 3. Quantitative and Qualitative Disclosures About Market Risk

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 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.

The retail gas operations of SJE transact 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. The retail electric operations of SJE use forward physical and financial contracts to mitigate commodity price risk on fixed price electric contracts. 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 a net pre-tax unrealized loss of $12.0 million and $1.6 million in earnings during the three months ended September 30, 2015 and 2014, respectively, and a net pre-tax unrealized loss of $4.0 million and $30.4 million during the nine months ended September 30, 2015 and 2014, respectively, which are included with realized losses in Operating Revenues — Nonutility.  


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The fair value and maturity of these energy-related contracts determined under the mark-to-market method as of September 30, 2015 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
$
9,952

 
$
39

 
$
—

 
$
9,991

Prices provided by other external sources
22,960

 
4,343

 
48

 
27,351

Prices based on internal models or other valuation methods
27,624

 
12,637

 
71

 
40,332

 
 
 
 
 
 
 
 
Total
$
60,536

 
$
17,019

 
$
119

 
$
77,674

 
 
 
 
 
 
 
 
Liabilities
 

 
 

 
 

 
 

Source of Fair Value
Maturity
 <1 Year
 
Maturity
1 -3 Years
 
Maturity
Beyond 3Years
 
Total
Prices actively quoted
$
27,713

 
$
6,797

 
$
26

 
$
34,536

Prices provided by other external sources
19,826

 
924

 
—

 
20,750

Prices based on internal models or other valuation methods
39,267

 
15,448

 
282

 
54,997

 
 
 
 
 
 
 
 
Total
$
86,806

 
$
23,169

 
$
308

 
$
110,283


•
NYMEX (New York Mercantile Exchange) is the primary national commodities exchange on which natural gas is traded. Volumes of our NYMEX contracts included in the table above under "Prices actively quoted" are 21.8 million dekatherms (dts) with a weighted average settlement price of $3.43 per dt.
•
Basis represents the differential to the NYMEX natural gas futures contract for delivering gas to a specific location Volumes of our basis contracts, along with volumes of our discounted index related purchase and sales contracts included in the table above under "Prices provided by other external sources" and "Prices based on internal models or other valuation methods" are 226.3 million dts with a weighted average settlement price of $(1.20) per dt.
•
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. Volumes of our Fixed Price Gas Daily contracts included in the table above under "Prices provided by other external sources" are 11.1 million dts with a weighted average settlement price of $3.25 per dt.
•
Volumes of electric included in the table above under "Prices based on internal models or other valuation methods" are 0.1 million mwh with a weighted average settlement price of $44.73 per mwh.

A reconciliation of SJI’s estimated net fair value of energy-related derivatives follows (in thousands):

Net Derivatives — Energy Related Liabilities, January 1, 2015
$
(30,397
)
Contracts Settled During Nine Months Ended September 30, 2015, Net
25,591

Other Changes in Fair Value from Continuing and New Contracts, Net
(27,803
)
 
 
Net Derivatives — Energy Related Liabilities, September 30, 2015
$
(32,609
)

Interest Rate Risk — Our exposure to interest-rate risk relates to short-term and long-term variable-rate borrowings. Variable-rate debt outstanding, including short-term and long-term debt, at September 30, 2015 was $667.5 million and averaged $559.1 million during the first nine months of 2015. A hypothetical 100 basis point (1%) increase in interest rates on our average variable-rate debt outstanding would result in a $3.4 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: 2014 - 1 b.p. decrease; 2013 - 16 b.p. decrease; 2012 - 9 b.p. decrease; 2011 - 33 b.p. increase; and 2010 – 13 b.p. decrease.  At September 30, 2015, our average interest rate on variable-rate debt was 1.10%.


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We typically 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 September 30, 2015, the interest costs on $697.4 million of our long-term debt was either at a fixed rate or hedged via an interest rate derivative.

As of September 30, 2015, SJI’s active interest rate swaps were as follows:

Amount
 
Fixed Interest Rate
 
Start Date
 
Maturity
 
Type
 
Obligor
$
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 September 30, 2015, approximately $8.8 million, or 11.4%, of the current and noncurrent Derivatives – Energy Related Assets are transacted with one counterparty. This counterparty 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.

As of September 30, 2015, SJRG had $91.0 million of Accounts Receivable under sales contracts. Of that total, 79.0% 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 4. 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 Securities Exchange Act) as of September 30, 2015. 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.

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 Securities Exchange Act, during the fiscal quarter ended September 30, 2015 that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.


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PART II — OTHER INFORMATION

Item l. Legal Proceedings

Information required by this Item is incorporated by reference to Part I, Item 2, Pending Litigation, beginning on page 49. 

Item 1A. Risk Factors

There have been no material changes in our risk factors from those disclosed in Part I, Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2014.

Item 6. Exhibits
(a)  Exhibits

Exhibit No.
 
Description
 
 
 
31.1
 
Certification of Chief Executive Officer Pursuant to Rule 13a-14(a) of the Exchange Act.
 
 
 
31.2
 
Certification of Chief Financial Officer Pursuant to Rule 13a-14(a) of the Exchange Act.
 
 
 
32.1
 
Certification of Chief Executive Officer Pursuant to Rule 13a-14(b) of the Exchange Act as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code).
 
 
 
32.2
 
Certification of Chief Financial Officer Pursuant to Rule 13a-14(b) of the Exchange Act as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code).
 
 
 
101
 
The following financial statements from South Jersey Industries’ Quarterly Report on Form 10-Q for the three and nine months ended September 30, 2015, filed with the Securities and Exchange Commission on November 5, 2015, formatted in XBRL (eXtensible Business Reporting Language): (i) the Condensed Consolidated Statements of Income; (ii) the Condensed Consolidated Statements of Comprehensive Income; (iii) the Condensed Consolidated Statements of Cash Flows; (iv) the Condensed Consolidated Balance Sheets and (v) the Notes to Condensed Consolidated Financial Statements.


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SIGNATURES

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

 
 
SOUTH JERSEY INDUSTRIES, INC.
 
 
(Registrant)
 
 
 
 
Dated:
November 5, 2015
By:
/s/ Stephen H. Clark
 
 
 
Stephen H. Clark
 
 
 
Chief Financial Officer
 
 
 
(Principal Financial Officer)

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