UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES ~~EXCHANGE ACT OF 1934~~

~~For~~EXCHANGE ~~the~~ACT ~~quarterly~~OF ~~period ended September 30, 2013~~ 1934

For the quarterly period ended June 30, 2014

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES ~~EXCHANGE ACT OF 1934~~

EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number 333-110979

SOUTHERN STAR CENTRAL CORP.

(Exact name of registrant as specified in its charter)



Delaware	04-3712210
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

4700 Highway 56, Owensboro, Kentucky	42301
(Address of principal executive offices)	(Zip Code)

Registrant’s telephone number, including area code: (270) 852-5000

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 ¨~~

~~Indicate~~file bysuch ~~check mark whether the registrant has submitted electronically and posted on its corporate Web site~~reports), ~~if any, every Interactive Data File required to be submitted~~ and ~~posted pursuant to Rule 405 of Regulation S-T~~ (~~§232.405 of this chapter~~2) has ~~during~~been ~~the~~subject ~~preceding~~to 12such ~~months~~filing ~~(or~~requirements for ~~such shorter period that~~ the ~~registrant~~past ~~was required to submit and post such files)~~90 days. Yes x No ¨

Indicate by check mark whether the registrant ishas asubmitted ~~large~~electronically ~~accelerated~~and ~~filer,~~posted anon ~~accelerated~~its ~~filer,~~corporate aWeb ~~non-accelerated filer~~site, orif ~~a smaller reporting company. See the definitions of “large accelerated filer~~any,” ~~“accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.~~

every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this

chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such

files). Yes x No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a

smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company”

in Rule 12b-2 of the Exchange Act.



Large accelerated filer	¨	Accelerated filer	¨
Non-accelerated filer	x	Smaller reporting company	¨

(Do not check if a smaller reporting company)

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ¨ No x

As of ~~November~~August 8, ~~2013~~2014, registrant had 100 shares of common stock outstanding.

~~2013~~2014 FORM 10-Q

FOR THE QUARTERLY PERIOD ENDED ~~SEPTEMBER~~JUNE 30, ~~2013~~2014

SOUTHERN STAR CENTRAL CORP.

		Page
	PART I. Financial Information
Item 1.	Consolidated Financial Statements and Supplementary Data (Unaudited*)
	Consolidated Balance Sheets	3
	Consolidated Statements of Net Income	5
	Consolidated Statements of Cash Flows	7
	Notes to the Consolidated Financial Statements	8
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	17
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	26
Item 4.	Controls and Procedures	26
	PART II. Other Information
Item 1.	Legal Proceedings	26
Item 1A.	Risk Factors	2726
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds.	2729
Item 3.	Defaults Upon Senior Securities	2729
Item 4.	Mine Safety Disclosures	2729
Item 5.	Other Information	2729
Item 6.	Exhibits	2829
	* December 31, 2012 balance sheet was derived from our audited balance sheet.
	* December 31, 2013 balance sheet was derived from our audited balance sheet.

Table of Contents

PART I - FINANCIAL INFORMATION

Item 1. Consolidated Financial Statements and Supplementary Data

SOUTHERN STAR CENTRAL CORP. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

	September 30, 2013				December 31, 2012
		June 30, 2014				December 31, 2013
	~~(Unaudited)~~	(Unaudited)
	~~(In thousands)~~	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	~~12,204~~$	101,485		$	~~37,467~~$	18,388
Receivables:
Trade	~~17,897~~	19,796			~~19,651~~	27,049
Income taxes	~~1,886~~	937			~~1,068~~	7,394
Transportation, exchange and fuel gas	~~8,652~~	10,172			~~8,075~~	5,947
Other	~~2,608~~	12,105			~~5,165~~	2,659
Inventories	~~11,151~~	11,357			~~10,350~~	10,679
Deferred income taxes	~~2,352~~	1,668			~~1,536~~	1,847
Costs recoverable from customers	~~750~~	350			~~3,990~~	750
Prepaid expenses	~~1,049~~	3,097			~~4,874~~	5,274
Other	~~609~~	644			~~489~~	608
Total current assets	~~59,158~~	161,611			~~92,665~~	80,595
Property, Plant and Equipment, at cost:
Natural gas transmission plant	~~713,581~~	769,787			~~652,780~~	755,984
Other natural gas plant	~~35,239~~	56,760			~~36,403~~	44,666
	748,820				689,183
		826,547				800,650
Less – Accumulated depreciation and amortization	~~(25,838~~	(50,176	)	)	~~(7,208~~	(33,835	)	)
Property, plant and equipment, net	~~722,982~~	776,371			~~681,975~~	766,815
Other Assets:
Goodwill	~~470,962~~	470,962			~~470,962~~	470,962
Costs recoverable from customers	~~83,322~~	53,372			~~85,267~~	54,048
Other deferred and noncurrent assets	3,555				3,993
Postretirement benefits other than pensions		3,991				2,921
Total other assets	557,839				560,222
Other deferred and noncurrent assets		11,428				2,242
Total Assets	$	1,339,979			$	1,334,862
Total other assets		539,753				530,173
Total Assets		$	1,477,735			$	1,377,583

The accompanying Notes to the Consolidated Financial Statements are an integral part of these statements.

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SOUTHERN STAR CENTRAL CORP. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS



	June 30, 2014		December 31, 2013
	(Unaudited)
	(In thousands)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:
Payables:
Trade	$	9,242	$	13,564
Transportation, exchange and fuel gas	2,783		5,862
Income taxes	608		4,385
Revolving credit agreement	—		100,000
Other	7,637		6,124
Accrued taxes, other than income taxes	8,570		7,561
Accrued interest	3,567		7,035
Accrued payroll and employee benefits	8,110		10,650
Provision for rate and regulatory matters	—		4,446
Costs refundable to customers	9,138		88
Capitalized lease obligation due in one year	—		280
Current portion of long-term debt	64,873		—
Other accrued liabilities	3,674		6,636
Total current liabilities	118,202		166,631

Long-Term Debt:
Capitalized lease obligation	—		3,950
Other long-term debt	779,853		482,952
Total long-term debt	779,853		486,902

Other Liabilities and Deferred Credits:
Deferred income taxes	112,854		101,356
Postretirement benefits other than pensions	24,400		24,019
Asset retirement obligations	1,558		1,731
Costs refundable to customers	4,910		3,793
Environmental remediation	835		222
Accrued pension	26,574		24,444
Other	1,140		1,039
Total other liabilities and deferred credits	172,271		156,604

Stockholder’s Equity:
Common stock, $.01 par value, 100 shares authorized and issued,
100 shares outstanding at June 30, 2014 and December 31, 2013	—		—
Premium on capital stock and other paid-in capital	399,866		559,921
Retained earnings	7,543		7,525
Total stockholder’s equity	407,409		567,446
Total Liabilities and Stockholder’s Equity	$	1,477,735	$	1,377,583

	September 30, 2013		December 31, 2012
	(Unaudited)
	(In thousands)
LIABILITIES AND STOCKHOLDER’S EQUITY
Current Liabilities:
Payables:
Trade	$	13,722	$	8,712
Transportation, exchange and fuel gas	6,800		11,315
Income taxes	373		380
Revolving credit agreement	35,000		40,000
Other	11,332		6,481
Accrued taxes, other than income taxes	11,929		7,090
Accrued interest	6,250		6,908
Accrued payroll and employee benefits	8,577		9,842
Costs refundable to customers	1,855		3
Capitalized lease obligation due in one year	280		265
Other accrued liabilities	4,376		3,907
Total current liabilities	100,494		94,903
Long-Term Debt:
Capitalized lease obligation	3,950		4,230
Other long-term debt	483,266		484,178
Total long-term debt	487,216		488,408
Other Liabilities and Deferred Credits:
Deferred income taxes	96,002		86,905
Postretirement benefits other than pensions	39,386		38,932
Asset retirement obligations	1,881		1,798
Costs refundable to customers	296		177
Environmental remediation	280		450
Accrued pension	44,018		39,760
Other	1,050		302
Total other liabilities and deferred credits	182,913		168,324
Stockholder’s Equity:
Common stock, $.01 par value, 100 shares authorized and issued, 100 shares outstanding at September 30, 2013 and December 31, 2012	—		—
Premium on capital stock and other paid-in capital	564,149		574,571
Retained earnings	5,207		8,656
Total stockholder’s equity	569,356		583,227
Total Liabilities and Stockholder’s Equity	$	1,339,979	$	1,334,862

The accompanying Notes to the Consolidated Financial Statements are an integral part of these statements.

Table of Contents

SOUTHERN STAR CENTRAL CORP. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF NET INCOME

(UNAUDITED)

	Successor								Predecessor
		For the Three Months Ended June 30, 2014				For the Three Months Ended June 30, 2013
	For the Three Months Ended September 30, 2013				For the Period September 24 through September 30, 2012				For the Period July 1 through September 23, 2012
		(In thousands)
	(In thousands)								(In thousands)
Operating Revenues:
Operating Revenues:
Transportation		$	51,579			$	44,976
Transportation	$	45,449			$	3,525			$	42,914
Storage		7,510				5,655
Storage	7,749				651				7,635
Other revenue		255				214
Other revenue	146				12				139
Total operating revenues		59,344				50,845
Total operating revenues	53,344				4,188				50,688
Operating Costs and Expenses:
Operating Costs and Expenses:
Operations and maintenance		15,235				14,739
Operations and maintenance	13,599				1,373				11,088
Administrative and general		9,687				9,662
Administrative and general	10,505				762				9,356
Depreciation and amortization		9,579				9,033
Depreciation and amortization	8,779				674				7,889
Taxes, other than income taxes		4,797				4,666
Taxes, other than income taxes	4,455				345				4,070
Total operating costs and expenses		39,298				38,100
Total operating costs and expenses	37,338				3,154				32,403
Operating Income		20,046				12,745
Operating Income	16,006				1,034				18,285
Other (Income) Deductions:
Other (Income) Deductions:
Interest expense		8,832				7,693
Interest expense	7,712				579				7,542
Interest income		(9		)		(9		)
Interest income	(8		)		(1		)		(10		)
Gain on reacquired debt		(936		)		—
Miscellaneous other income	~~(333~~	(190	)	)	~~(16~~	(190	)	)	~~(150~~		)
Total other deductions	~~7,371~~	7,697			~~562~~	7,494			~~7,382~~
Income Before Income Taxes	~~8,635~~	12,349			~~472~~	5,251			~~10,903~~
Provision for Income Taxes	~~3,427~~	4,806			~~184~~	2,045			~~4,300~~
Net Income (a)	$	~~5,208~~$	7,543		$	~~288~~$	3,206		$	~~6,603~~

(a) Net income ~~approximates~~equals comprehensive income.

The accompanying Notes to the Consolidated Financial Statements are an integral part of these statements.

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SOUTHERN STAR CENTRAL CORP. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF NET INCOME

(UNAUDITED)

	Successor								Predecessor
		For the Six Months Ended June 30, 2014				For the Six Months Ended June 30, 2013
	For the Nine Months Ended September 30, 2013				For the Period September 24 through September 30, 2012				For the Period January 1 through September 23, 2012
		(In thousands)
	(In thousands)								(In thousands)
Operating Revenues:
Operating Revenues:
Transportation		$	106,322			$	91,750
Transportation	$	137,199			$	3,525			$	134,867
Storage		14,432				11,868
Storage	19,617				651				22,357
Other revenue		471				344
Other revenue	490				12				512
Total operating revenues		121,225				103,962
Total operating revenues	157,306				4,188				157,736
Operating Costs and Expenses:
Operating Costs and Expenses:
Operations and maintenance		25,938				26,479
Operations and maintenance	40,078				1,373				36,372
Administrative and general		19,947				19,850
Administrative and general	30,355				762				28,624
Depreciation and amortization		19,008				18,173
Depreciation and amortization	26,952				674				25,114
Taxes, other than income taxes		9,754				9,196
Taxes, other than income taxes	13,651				345				12,708
Total operating costs and expenses		74,647				73,698
Total operating costs and expenses	111,036				3,154				102,818
Operating Income		46,578				30,264
Operating Income	46,270				1,034				54,918
Other (Income) Deductions:
Other (Income) Deductions:
Interest expense		16,908				15,379
Interest expense	23,091				579				23,735
Interest income		(17		)		(20		)
Interest income	(28		)		(1		)		(37		)
Gain on reacquired debt		(936		)		—
Miscellaneous other income	~~(616~~	(301	)	)	~~(16~~	(283	)	)	~~(637~~		)
Total other deductions	~~22,447~~	15,654			~~562~~	15,076			~~23,061~~
Income Before Income Taxes	~~23,823~~	30,924			~~472~~	15,188			~~31,857~~
Provision for Income Taxes	~~9,390~~	12,091			~~184~~	5,963			~~12,511~~
Net Income (a)	$	~~14,433~~$	18,833		$	~~288~~$	9,225		$	~~19,346~~

(a) Net income ~~approximates~~equals comprehensive income.

The accompanying Notes to the Consolidated Financial Statements are an integral part of these statements.

Table of Contents

SOUTHERN STAR CENTRAL CORP. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)

	Successor								Predecessor
		For the Six Months Ended June 30, 2014				For the Six Months Ended June 30, 2013
	For the Nine Months Ended September 30, 2013				For the Period September 24 through September 30, 2012				For the Period January 1 through September 23, 2012
		(In thousands)
	(In thousands)								(In thousands)
OPERATING ACTIVITIES:
OPERATING ACTIVITIES:
Net income		$	18,833			$	9,225
Net income	$	14,433			$	288			$	19,346
Adjustments to reconcile to net cash provided by operating activities:
Adjustments to reconcile to net cash provided by operating activities:
Depreciation and amortization		19,008				18,173
Depreciation and amortization	26,952				674				25,114
Deferred income taxes		11,677				6,002
Deferred income taxes	8,281				288				10,359
Provision for rate and regulatory matters		(4,446		)		—
Amortization of debt (premium) discount and expense	(412		)		(17		)		1,304
Gain on reacquired debt		(936		)		—
Receivables	3,493				(4,014		)		9,307
Amortization of debt premium and expense		(19		)		(286		)
Inventories	(801		)		(29		)		(2,214		)
Receivables		4,181				2,292
Other current assets	3,736				186				3,200
Inventories		(678		)		(718		)
Payables and accrued liabilities	3,578				4,045				(5,815		)
Other current assets		2,141				2,556
Other, including changes in noncurrent assets and liabilities	7,878				(42		)		(606		)
Payables and accrued liabilities		(11,869		)		(4,322		)
Net cash provided by operating activities	67,138				1,379				59,995
Other, including changes in noncurrent assets and liabilities		3,514				4,668
INVESTING ACTIVITIES:
Net cash provided by operating activities		41,406				37,590
Property, plant and equipment:
INVESTING ACTIVITIES:
Capital expenditures, net of allowance for fundsused during construction	(55,903		)		(2,696		)		(37,312		)
Property, plant and equipment:
Proceeds from sales and salvage values, net of costs of removal	(2,282		)		63				246
Capital expenditures, net of allowance for funds used during construction		(28,437		)		(28,833		)
Net cash used in investing activities	(58,185		)		(2,633		)		(37,066		)
Proceeds from sales and salvage values, net of costs of removal		(1,257		)		(1,813		)
FINANCING ACTIVITIES:
Net cash used in investing activities		(29,694		)		(30,646		)
Common dividends/return of capital	(28,304		)		(5,095		)		(13,712		)
FINANCING ACTIVITIES:
Revolving credit agreement payments	(5,000		)		—				—
Proceeds from debt issuance		550,000				—
Capital lease payments	(265		)		—				(250		)
Retirement of long-term debt		(185,758		)		—
Debt issuance costs	~~(647~~	(9,757	)	)	(5	(637	)	)	~~(1,217~~		)
Net cash used in financing activities	(34,216		)		(5,100		)		(15,179		)
Common dividends/return of capital		(178,870		)		(18,869		)
Net change in cash and cash equivalents	(25,263		)		(6,354		)		7,750
Issuance of debt - Revolving credit agreement		45,000				15,000
Cash and cash equivalents at beginning of period	37,467				31,251				23,501
Payment of debt - Revolving credit agreement		(145,000		)		(20,000		)
Cash and cash equivalents at end of period	$	12,204			$	24,897			$	31,251
Capital lease payments		(4,230		)		(130		)
Supplemental Disclosure of Cash Flow Information:
Net cash provided by (used in) financing activities		71,385				(24,636		)
Cash paid during the period for:
Net change in cash and cash equivalents		83,097				(17,692		)
Interest (net of amounts capitalized)	$	24,159			$	—			$	23,870
Cash and cash equivalents at beginning of period		18,388				37,467
Income tax, net	1,934				—				3,675
Cash and cash equivalents at end of period		$	101,485			$	19,775
Noncash Investing Transaction:
Supplemental Disclosure of Cash Flow Information:
Additions to capital expenditures included in Payables: Other	9,232				4,913				—
Cash paid (received) during the period for:
Interest (net of amounts capitalized)		$	20,397			$	15,550
Income tax, net		(2,266		)		1,674
Noncash Investing Transaction:
Additions to capital expenditures included in Payables: Other		4,588				3,738

The accompanying Notes to the Consolidated Financial Statements are an integral part of these statements.

Table of Contents

SOUTHERN STAR CENTRAL CORP. AND SUBSIDIARIES

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

1. Description of Business

Southern Star

Southern Star Central Corp., or Southern Star, ~~was~~is a wholly-owned subsidiary of ~~EFS~~MSIP-SSCC Holdings, LLC, or ~~EFS~~Holdings, ~~through~~which ~~September~~is ~~23,~~owned ~~2012. GE~~by ~~Energy Financial Services, Inc., or GE, and~~ Morgan Stanley Infrastructure Partners and certain other affiliated investment funds managed by Morgan Stanley Infrastructure, Inc., or MSIP~~, indirectly held all of the outstanding capital stock of EFS through this date~~.

On August 23, 2012, GE entered into an agreement to sell to MSIP its 60% economic stake and 50% voting stake in Southern Star through the sale of its interests in EFS, or the Sale. The Sale was consummated on September 24, 2012, constituting a change in control and resulting in a new basis of accounting for Southern Star. In connection with the Sale, EFS changed its name to MSIP-SSCC Holdings, LLC, or Holdings. See Note 3 for further information regarding the Sale.

Southern Star was incorporated in Delaware in September 2002 and operates as a holding company for its regulated natural gas pipeline operations and development opportunities. Southern Star Central Gas Pipeline, Inc., or Central, is Southern Star’s only operating subsidiary and the sole source of its operating revenues and cash flows.

The term “the Company” denotes Southern Star Central Corp. and its subsidiaries.

Central

Central is an interstate natural gas transportation company that owns and operates a natural gas pipeline system located in Colorado, Kansas, Missouri, Nebraska, Oklahoma, Texas and Wyoming. The system serves customers in these seven states, including major metropolitan areas in Kansas and Missouri, which are its main market areas.

Central’s system has a mainline delivery capacity of approximately 2.4 billion cubic feet, or Bcf, of natural gas per day and is composed of approximately 6,000 miles of mainline and branch transmission and storage pipelines including 4041 compressor stations with approximately ~~208~~206,000 certificated horsepower.

Central'’s principal service is the delivery of natural gas to local natural gas distribution companies in the major metropolitan areas it serves. At ~~September~~June 30, ~~2013~~2014, Central had transportation customer contracts with approximately ~~130~~136 ~~customers~~shippers. Transportation shippers include natural gas distribution companies, municipalities, intrastate pipelines, direct industrial users, electrical generators and natural gas marketers and producers. Central transports natural gas to approximately ~~528~~532 delivery ~~locations~~points, including distribution companies and municipalities, power plants, interstate and intrastate pipelines, and large and small industrial and commercial customers.

Central operates eight underground storage fields with an aggregate natural gas storage capacity of approximately 47 Bcf and aggregate delivery capacity of approximately 1.3 Bcf of natural gas per day. Central’s customers inject natural gas into these fields when demand is low and withdraw it to supply their requirements in times of peak demand. During periods of peak demand, approximately half of the natural gas delivered to customers is supplied from these fields. Storage capacity enables Central’s system to operate more uniformly and efficiently during the year, as well as allowing it to offer storage services in addition to its transportation services.

Central is subject to regulation by the Federal Energy Regulatory Commission, or the FERC, under the Natural Gas Act of 1938, or NGA, and under the Natural Gas Policy Act of 1978, or NGPA, and as such, its rates and charges for the transportation of natural gas in interstate commerce, the extension, enlargement or abandonment of jurisdictional facilities, and its accounting, among other things, are subject to regulation. Central holds certificates of public convenience and necessity issued by the FERC authorizing the siting, ownership and operation of its pipelines and related facilities, including storage fields, which are considered jurisdictional and for which certificates are required or available under the NGA.

2. Basis of Presentation

On August 23, 2012, GE Energy Financial Services, Inc., or GE, entered into an agreement to sell to MSIP its interests in the Company, or the Sale. The Sale resulted in a change in control and a new basis of accounting for Southern Star, as required by the Business Combinations Topic 805 of the Accounting Standards Codification, or the ASC. The total consideration, ~~has~~including ~~been “pushed down” and allocated to~~ the ~~assets~~estimated ~~and~~fair ~~liabilities~~value of ~~the Company. The Company~~MSIP's ~~financial~~original ~~statements~~40% ~~related~~economic tointerest, ~~periods~~has ~~prior~~been to“pushed ~~the~~down” ~~Sale reflect the historical accounting basis in the Company's assets~~ and ~~liabilities~~allocated ~~and are labeled Predecessor, while the periods subsequent~~ to the ~~Sale are labeled Successor and reflect the allocation of purchase price to all~~ assets ~~acquired~~ and liabilities ~~assumed~~of in the ~~Sale~~Company. ~~Therefore, the Company's Consolidated Statements of Net Income and Cash Flows for the~~

~~Table~~statements are subject to any year-end audit adjustments which may be necessary, in the opinion of ~~Contents~~management, all adjustments (consisting of normal recurring adjustments) considered necessary for a fair presentation, have been included. These consolidated financial statements should be read in conjunction with the Company’s 2013 Annual Report on Form 10-K filed with the SEC on March 28, 2014.

period ending September 23, 2012 each reflect the operations of the Predecessor. The Company's Consolidated Statements of Net Income and Cash Flows for the period ending September 30, 2013, the Consolidated Statements of Net Income and Cash Flows for the period September 24, 2012 through September 30, 2012, and the Consolidated Balance Sheets as of December 31, 2012 and September 30, 2013, each reflect the operations and financial position of the Successor.

The accompanying consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States, or GAAP, for interim financial reporting and SEC regulations. The interim consolidated financial statements are unaudited, with the exception of the accompanying Consolidated Balance Sheet as of December 31, 2012 which is derived from the audited financial statements for the 2012 fiscal year. Although the interim statements are subject to any year-end audit adjustments which may be necessary, in the opinion of management, all adjustments (consisting of normal recurring adjustments) considered necessary for a fair presentation, have been included. These consolidated financial statements should be read in conjunction with the Company’s 2012 Annual Report on Form 10-K filed with the SEC on March 26, 2013 as amended by Form 10-K/A filed with the SEC on April 9, 2013.

3. Acquisition

OnThe ~~August~~Sale ~~23,~~was ~~2012,~~consummated GEon ~~entered~~September ~~into~~24, an2012. ~~agreement~~As toCentral’s ~~sell~~rates toare ~~MSIP~~regulated ~~its~~by ~~60%~~the ~~economic~~FERC, ~~stake~~ and ~~50% voting stake in~~ the ~~Company~~FERC ~~through~~does ~~the~~not ~~sale~~allow ofrecovery ~~its interests~~ in ~~EFS.~~rates ~~The~~of ~~Sale,~~amounts ~~which constituted a change~~ in ~~control,~~excess ~~was~~of ~~consummated~~original ~~on September 24~~cost, ~~2012.~~many ~~The~~of ~~push-down~~Central’s ~~basis~~historical ofassets ~~accounting~~and ~~was~~liabilities ~~used~~approximate totheir ~~record~~respective ~~the~~estimated fair ~~value~~values ~~adjustments~~at ~~for~~the ~~assets~~date ~~and liabilities~~ of ~~Southern Star at~~ the ~~acquisition~~change ~~date~~in control. ~~The~~Based ~~total~~on ~~consideration included~~ the ~~estimated~~allocation ~~fair value~~ of ~~MSIP's~~the ~~original~~total ~~40%~~consideration, ~~economic~~the ~~interest~~Company ~~and~~recorded ~~the~~approximately ~~fair~~$471.0 million ~~value~~ of ~~cash~~Goodwill ~~and equity consideration exchanged~~ in the ~~Sale~~Consolidated Balance Sheets.

As Central’s rates are regulated by the FERC, and the FERC does not allow recovery in rates of amounts in excess of original cost, many of Central’s historical assets and liabilities approximated their estimated fair values at the date of the change in control. The following summarizes the allocation of the total consideration to the assets acquired and the liabilities assumed of the Company at the date of the change in control (expressed in thousands):

Cash and cash equivalents	$	31,251
Receivables	25,782
Inventories	9,408
Other current assets	4,505
Regulatory assets - current	750
Property, plant and equipment	657,060
Regulatory assets - noncurrent	78,990
Other assets	4,432
Regulatory liabilities - current	(2,311		)
Capitalized lease obligation due in one year	(265		)
Current liabilities - other	(43,213		)
Long-term debt	(484,494		)
Capitalized lease obligation	(4,230		)
Regulatory liabilities - noncurrent	(145		)
Deferred tax liability	(91,016		)
Other long-term liabilities	(73,746		)
Goodwill	470,962
Fair values of assets and liabilities	$	583,720

Based on the allocation of the total consideration, the Company recorded approximately $471.0 million of Goodwill in the Consolidated Balance Sheet. At September 24, 2012, the fair value of Southern Star’s 6.75% Notes was approximately $254.8 million. The estimated fair value of each of the Notes was calculated by utilizing an income approach whereby the future cash flows were discounted at estimated current cost of funding rates. The fair value measurement of these Notes is classified as Level 2. Central's debt was not adjusted as a result of the Sale since Central is a rate regulated entity as discussed above.

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4. Accounting Policies

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of Southern Star and its subsidiaries, all of which are wholly-owned. All intercompany balances and transactions have been eliminated in consolidation.

Use of Estimates

The preparation of the accompanying consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported on the accompanying consolidated financial statements and notes. Actual results could differ from those estimates.

Reclassifications

Certain prior period amounts have been reclassified to conform with current period presentation with no effect on previously reported earnings or equity.

Revenue Recognition

Revenues for sales of products are recognized in the period of delivery and revenues from services are recognized in the period the service is provided based on contractual terms and related volumes. The FERC regulatory processes and procedures govern the tariff and rates that Central is permitted to charge to customers for its services. Key determinants in the ratemaking process are (1) contracted capacity assumptions, (2) costs of providing service, including depreciation expense, and (3) allowed rate of return, including the equity component of a pipeline’s capital structure and related income taxes. Accordingly, at any given time, some of the collected revenues may be subject to possible refunds required by final order of the FERC. Central records estimates of rate refund liabilities based on its and other third-party regulatory proceedings, advice of counsel and estimated total exposure, as discounted and risk-weighted. As a result of Central's recent settlement with the FERC on its current rates, on May 29, 2014, Central issued refund checks for revenues collected in excess of settlement rates in the amount of $9.3 million, including interest.

Goodwill

In connection with the Sale, Southern Star recorded $471.0 million of goodwill, representing the excess of the total purchase consideration over the estimated fair value of the assets acquired and liabilities assumed. Goodwill is tested annually for impairment on October 1, or more frequently if management determines that a triggering event may have occurred that would more likely than not reduce the estimated fair value of the Company below its carrying value. Goodwill impairment charges are not subject to rate recovery. No events have occurred during 2014 that would more likely than not reduce the estimated fair value of the Company below its carrying value.

Income Taxes

Deferred taxes are recorded under the liability method. Deferred taxes are provided on temporary differences between the book and tax basis of the assets and liabilities pursuant to the Income Taxes Topic 740 of the ASC, or ASC 740.

In accordance with ASC 740, the Company records interest related to uncertain tax positions as a part of Interest expense on the accompanying Consolidated Statements of Net Income. Any penalties ~~are~~would be recognized as part of Miscellaneous expense on the accompanying Consolidated Statements of Net Income. ~~The~~As of June 30, 2014 and 2013, the Company ~~does~~did not have a liability for tax penalties or interest related to uncertain tax positions ~~for any period presented~~.

The Company operates under a Federal and State Income Tax Policy that governs the allocation and payment of tax liabilities of Holdings, Southern Star and Central. This policy provides that Southern Star will file consolidated tax returns on behalf of itself, Holdings and Central and will pay all taxes shown thereon to be due. Central generally makes payments to Southern Star for its federal and state income tax liabilities as though it were filing a separate return. Southern Star has an obligation to indemnify Central for any liability that Central incurs for taxes of the affiliated group of which Southern Star and Central are members under Treasury Regulations Section 1.1502-6 and similar state statutes.9

The Company operates under a Federal and State Income Tax Policy that governs the allocation and payment of tax liabilities of Holdings, Southern Star and Central. This policy provides that Southern Star will file consolidated tax returns on behalf of itself, Holdings and Central and will pay all taxes shown thereon to be due. Holdings and Central generally make payments to Southern Star for their federal and state income tax liabilities as though they were filing separate returns. Southern Star has an obligation to indemnify Holdings and Central for any liability that they incur for taxes of the affiliated group of which Southern Star, Holdings and Central are members under Treasury Regulations Section 1.1502-6 and similar state statutes.

Gas Receivables/Payables

In the course of providing transportation and storage services to customers, Central may receive different quantities of natural gas from a shipper than quantities delivered on behalf of that shipper. These transactions result in imbalances, which are repaid or recovered in cash or through the receipt or delivery of natural gas in the future. Customer imbalances to be repaid or recovered in-kind are recorded in Transportation, exchange and fuel gas receivables/payables on the accompanying Consolidated Balance Sheets. Settlement of imbalances requires agreement between ~~Central~~the pipeline and shippers as to allocations of volumes to specific transportation contracts and timing of delivery of natural gas based on operational conditions.

Asset Retirement Obligations

In accordance with the Asset Retirement and Environmental Obligations Topic 410 of the ASC, Central recorded an asset retirement obligation, or ARO, for the remediation of asbestos existing on its system. The asbestos existing on Central’s system is primarily in building materials and pipe coatings used prior to the Clean Air Act of 1973. The Clean Air Act of 1973 established the National Emission Standards for Hazardous Air Pollutants, or ~~the~~ NESHAPs, that regulate the use of asbestos. The amount of the regulatory asset and the related ARO liability on the accompanying Consolidated Balance ~~Sheet~~Sheets at ~~September~~June 30, ~~2013~~2014 was $0.51 million and $1.96 million, respectively. The amount of the regulatory asset and the related ARO liability on the accompanying Consolidated Balance ~~Sheet~~Sheets at December 31, ~~2012~~2013 was $0.64 million and $1.87 million, respectively.

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Fair Value Measurements

The Fair Value Measurements and Disclosures Topic 820 of the ASC, or ASC 820, which defines fair value, establishes a framework for measuring fair value in accordance with GAAP, and expands disclosures about fair value measurements to include the methods and assumptions used to measure fair value and the effect of fair value measures on earnings. ASC 820 requires the fair value of an asset or liability to be based on market-based measures which reflect the credit risk of the Company.

The carrying amounts of the Company's current and long-term portions of its long-term debt on the Consolidated Balance Sheets and their estimated fair values are set forth below. ~~These~~ The estimated fair market values of the Company’s 65.75125% ~~Registered~~Senior Notes, ~~6.75% Unregistered Notes,~~ and Central's 6.0% Notes were calculated by discounting the Notes’' cash flows by ~~the~~their ~~current~~respective yield rates as determined by recent market activity. The carrying value of ~~notes~~Central's Term Loan approximates fair market value due to the variable interest rate associated with ~~similar~~the ~~characteristics,~~Term asLoan. ~~recent~~The ~~transactions~~fair value measurements of ~~its~~the 65.75125% ~~Registered~~Senior Notes, as well as Central's 6.750% ~~Unregistered~~ Notes, and Term Loan, are classified as Level 2. The estimated fair market value of the Company’s 6.075% Registered and Unregistered Notes ~~were~~equal ~~not~~the ~~available~~undiscounted ~~due~~amount toof ~~market~~principle ~~inactivity.~~and ~~These~~interest ~~instruments~~to ~~are~~be ~~classified~~paid asupon ~~Level~~redemption 2on July 16, 2014.

September 30, 2013

December 31, 2012

June 30, 2014

December 31, 2013

(In Thousands)

~~(In Thousands)~~

Carrying Amount

Fair Value

Carrying Amount

Fair Value

6.0% Senior Notes due 2016

229,~~796~~853

~~255~~246,~~949~~301

229,~~739~~815

~~264~~255,~~145~~113

6.75% Registered Senior Notes due 2016

~~202~~53,~~776~~937

~~202~~54,~~076~~764

~~203~~202,~~551~~510

~~203~~201,~~856~~169

6.75% Unregistered Senior Notes due 2016

5010,~~694~~936

5011,~~519~~104

50,~~888~~628

50,~~964~~292

5.125% Senior Notes due 2022

450,000

457,852

—

Term Loan due 2016

100,000

—

5. Financing

At ~~September~~ June 30, ~~2013~~2014 and December 31, ~~2012~~2013, long-term debt consisted of the following (expressed in thousands):

	September 30, 2013				December 31, 2012
		June 30, 2014				December 31, 2013
6.0% Senior Notes due 2016	$	230,000			$	230,000
Long-term debt:
6.75% Registered Senior Notes due 2016	~~200,000~~	$	53,412		~~200,000~~	$	200,000
6.75% Unregistered Senior Notes due 2016	~~50,000~~	10,830			~~50,000~~	50,000
Long-term capitalized lease obligation	3,950				4,230
5.125% Senior Notes due 2022		450,000				—
Unamortized debt premium	3,470				4,439
Term Loan due 2016		100,000				—
Unamortized debt discount	(204		)		(261		)
6.0% Senior Notes due 2016		230,000				230,000
Total long-term debt	$	487,216			$	488,408
Long-term portion of capitalized lease obligation		—				3,950
Unamortized debt premium		631				3,137
Unamortized debt discount		(147		)		(185		)
Total long-term debt		844,726				486,902
Less current portion of long-term debt		64,873				—
Total long-term debt, non-current		$	779,853			$	486,902

6.75% Registered Senior Notes

AtPrior ~~September 30~~to June 16, ~~2013~~2014, Southern Star had outstanding $200.0 million of 6.75% Notes registered under the Securities Act of 1933, as amended., ~~The~~or ~~Bank~~6.75% ofRegistered ~~New York Mellon Trust Company, N~~Notes.A. ~~serves~~Interest ason ~~trustee pursuant to~~ the ~~related indenture~~6.75% ~~Interest~~Registered isNotes was payable semi-annually on March 1 and September 1 ~~of each year~~. Prior to the Sale, the related issuance costs were being amortized over the life of the 6.75% Registered Notes utilizing the straight line method which approximated the effective interest method. As of September 24, 2012, there were no issuance costs related to the 6.75% Registered Notes included in the Consolidated Balance ~~Sheet~~Sheets as such costs were ~~eliminated~~not recognized as part of the purchase price allocation. However, the premium established as a result of recognizing the debt acquired at fair value in conjunction with the Sale ~~will~~was bebeing amortized over the remaining period of the 6.75% Registered Notes utilizing the effective interest method. The 6.75% Registered Notes ~~mature~~were ~~on March 1, 2016. The 6.75% Registered Notes are~~ Southern Star’'s senior unsecured obligations and ~~rank~~ranked equal in right of payment to all of its existing and future unsecured indebtedness and ~~are~~were effectively junior to any secured indebtedness of Southern Star to the extent of the value of the assets securing such indebtedness, if any.

~~The~~On ~~declaration~~June ~~and~~2, ~~payment~~2014, ofSouthern ~~dividends~~Star orlaunched ~~distributions~~a tender offer pursuant to ~~equity~~which ~~holders,~~it ~~under~~offered ~~the~~to purchase all of its outstanding 6.75% Registered Notes. ~~indenture~~As part of this tender offer, ~~are~~Southern ~~subject~~Star solicited consents to, ~~with~~amend the indenture governing the 6.75% Registered Notes to eliminate substantially all of the covenants and certain ~~limited~~events ~~exceptions~~of default. As of June 13, a2014, ~~minimum~~Southern ~~fixed~~Star ~~charge~~had ~~coverage~~received ~~ratio~~valid tenders and ~~cumulative~~consents ~~available~~from ~~cash~~holders ~~flows~~of ~~from~~$146.6 ~~operations~~million orin aaggregate ~~leverage~~principal ~~ratio~~amount of its 6.75% Registered Notes, ~~subject~~which torepresented ~~certain~~73.3% ~~conditions~~of the outstanding aggregate principal amount of the 6.75% Registered Notes. On June 16, as2014, ~~defined~~these inoffers were accepted for payment and a Gain on reacquired debt totaling $0.7 million was recorded. At June 30, 2014, Southern Star had a remaining principal balance of $53.4 million for the ~~indenture~~6.75% Registered Notes reflected on the accompanying Consolidated Balance Sheets.

~~The~~On July 16, 2014 Southern Star completed the redemption of the remaining 6.75% Registered Notes ~~are~~by ~~subject~~paying toapproximately ~~certain~~$54.8 ~~covenants~~million, ~~that~~including ~~restrict,~~principle ~~among~~and ~~other~~interest. The ~~things,~~remaining ~~Southern~~6.75% ~~Star~~Registered ~~and~~Notes ~~its~~had ~~subsidiaries’~~a ~~ability~~carrying tovalue ~~make~~of ~~investments,~~$53.9 ~~incur~~million. An additional ~~indebtedness,~~gain ~~pay~~of ~~dividends~~$0.5 ormillion ~~make~~was ~~distributions~~recognized onas ~~capital~~a ~~stock~~result orof the redemption of the remaining 6.75% Registered Notes.

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redeem or repurchase capital stock, create liens, incur dividend or other payment restrictions affecting subsidiaries, merge or consolidate with other entities and enter into transactions with affiliates. Southern Star has the right to redeem all or part of the 6.75% Registered Notes at premiums defined in the indenture.

6.75% Unregistered Senior Notes

AtPrior ~~September 30~~to June 16, ~~2013~~2014, Southern Star had outstanding $50.0 million aggregate principal amount of 6.75% Senior Notes due 2016~~. The~~, ~~Bank~~or of6.75% ~~New~~Unregistered ~~York Mellon Trust Company, N~~Notes.A. ~~serves~~Interest ason ~~trustee under~~ the ~~related indenture~~6. ~~Interest~~75% isUnregistered Notes was payable semi-annually on March 1 and September 1 ~~of each year~~. Prior to the Sale, the related issuance costs were being amortized over the life of the 6.75% Unregistered Notes utilizing the straight line method which approximated the effective interest method. As of September 24, 2012, there were no issuance costs related to the 6.75% Unregistered Notes included in the Consolidated Balance ~~Sheet~~Sheets as such costs were ~~eliminated~~not recognized as part of the purchase price allocation. However, the premium established as a result of ~~the~~recognizing ~~Sale will be amortized over~~ the ~~remaining~~debt ~~period~~acquired ofat ~~the~~fair ~~6.75%~~value ~~Unregistered Notes utilizing the effective interest method. The 6.75% Unregistered Notes will mature on March 1, 2016. The 6.75% Unregistered Notes are senior unsecured obligations and rank equal~~ in ~~rights~~conjunction ofwith ~~payment to all of Southern Star’s existing and future unsecured indebtedness and are effectively junior to any secured indebtedness of Southern Star to~~ the ~~extent~~Sale ofwas ~~the~~being ~~value~~amortized ofover the ~~assets~~remaining ~~securing~~period such indebtedness, if any. All covenants, restrictions, and other terms and conditions are identical to those for the 6.75% Registered Notes described above. Southern Star has the right to redeem all or part of the 6.75% Unregistered ~~Notes at premiums defined in the indenture.~~

Notes utilizing the effective interest method. The 6.75% Unregistered Notes were senior unsecured obligations and ranked equal in rights of payment to all of Southern Star's existing and future unsecured indebtedness and were effectively junior to any secured indebtedness of Southern Star to the extent of the value of the assets securing such indebtedness, if any.

On June 2, 2014, Southern Star launched a tender offer pursuant to which it offered to purchase all of its outstanding 6.75% Unregistered Notes. As part of this tender offer, Southern Star solicited consents to amend the indenture governing the 6.75% Unregistered Notes to eliminate substantially all of the covenants and certain events of default. As of June 13, 2014, Southern Star had received valid tenders and consents from holders of $39.2 million in aggregate principal amount of its 6.75% Unregistered Notes, which represented 78.3% of the outstanding aggregate principal amount of the 6.75% Unregistered Notes. On June 16, 2014, these offers were accepted for payment and a Gain on reacquired debt totaling $0.2 million was recorded. At June 30, 2014, Southern Star had a remaining principal balance of $10.8 million for the 6.75% Unregistered Notes reflected on the accompanying Consolidated Balance Sheets.

On July 16, 2014 Southern Star completed the redemption of the remaining 6.75% Unregistered Notes by paying approximately $11.1 million, including principle and interest. The remaining 6.75% Unregistered Notes had a carrying value of $10.8 million. An additional gain of $0.1 million was recognized as a result of the redemption of the remaining 6.75% Unregistered Notes.

5.125% Senior Notes

On June 16, 2014, Southern Star completed a private offering, pursuant to Rule 144A of the Securities Act, of $450.0 million aggregate principal amount of 5.125% Senior Notes due 2022, or 5.125% Notes, the proceeds of which, along with the proceeds obtained through Central's term loan (discussed below), were used to retire the 6.75% Registered and Unregistered Notes, including related expenses, to pay the issuance costs of the new offering, to issue a $160.0 million dividend, to pay the outstanding balance of the Company's revolving credit agreement, and for general corporate purposes. In connection with the offering, Southern Star entered into an indenture, or 5.125% Notes Indenture, dated June 16, 2014 by and between Southern Star and The Bank of New York Mellon Trust Company, N.A., as trustee. Interest is payable semi-annually on January 15 and July 15 of each year, beginning on January 15, 2015. The 5.125% Notes will mature on July 15, 2022. The 5.125% Notes are Southern Star’s senior unsecured obligations and rank equal in right of payment to all of its future senior unsecured debt and senior in right of payment to all of its future subordinated debt, and are effectively subordinated to any of its existing and future secured indebtedness, including indebtedness under its amended and restated revolving credit facility, to the extent of the value of the assets securing such indebtedness.

The 5.125% Notes are subject to certain covenants that restrict, among other things, Southern Star and its subsidiaries’ ability to make investments, incur additional indebtedness, pay dividends or make distributions on capital stock or redeem or repurchase capital stock, create liens, incur dividend or other payment restrictions affecting subsidiaries, merge or consolidate with other entities and enter into transactions with affiliates. Southern Star has the right to redeem all or part of the 5.125% Notes at premiums defined in the 5.125% Notes Indenture.

Credit Agreement

On July 3, 2012, the Company entered into a $65.0 million four-year revolving credit agreement, or Credit Agreement, among several banks and other financial institutions or entities from time to time party to the Credit Agreement, or the Lenders, and Royal Bank of Canada, as Administrative Agent, pursuant to which the Lenders agreed to make revolving credit loans to the Company. Effective March 22, 2013, the Credit Agreement was amended and the total aggregate commitment was extended to $125.0 million. On June 16, 2014 the Credit Agreement was again amended and the total aggregate commitment was decreased to $50.0 million. Under the Credit Agreement, letters of credit may be issued by the Administrative Agent or by one or more of the other Lenders in an aggregate amount not to exceed $10.0 million.

Borrowings under the Credit Agreement bear interest at a rate per annum equal to, at the Company’s option, either (a) an alternate base rate or (b) a rate based on the rates applicable for deposits in the interbank market for U.S. Dollars or the applicable currency in which the loans are made plus an applicable margin. The applicable margin for each revolving loan will be adjusted in relation to the Company’s then current unsecured debt ratings. Additionally, the Company pays a commitment fee for the average daily unused amount of the facility, payable quarterly in arrears, and certain fees with respect to letters of credit issued under the Credit Agreement. At June 30, 2014, the Company had no amounts outstanding under the revolving credit facility. There were no outstanding letters of credit issued under the Credit Agreement as of June 30, 2014.

In connection with the Credit Agreement, and pursuant to a pledge agreement dated as of July 3, 2012, among the Company, Central and the Administrative Agent, the Company pledged as collateral its equity interests in Central and certain future acquired subsidiaries.

The Credit Agreement contains negative covenants that, subject to significant exceptions, limit the ability of the Company and its Restricted Subsidiaries to, among other things, (i) incur debt, (ii) engage in new lines of business, (iii) incur liens, (iv) engage in mergers, consolidations, liquidations and dissolutions, (v) dispose of substantially all of the assets of the Company and its subsidiaries, (vi) make investments, loans, advances, guarantees and acquisitions, (vii) make certain restricted payments and (viii) enter into transactions with affiliates. The covenants require the Company to comply on a quarterly basis with capitalization ratios with respect to the Company and Central and a minimum fixed charge coverage ratio. The Credit Agreement contains events of defaults that are customary for a facility of this nature. If an event of default occurs, the commitments of the Lenders to lend under the facility may be terminated and the maturity of the amounts outstanding may be accelerated. At September 30, 2013, the Company had $35.0 million outstanding under its revolving credit facility with a weighted-average interest rate of 2.4%. There were no outstanding letters of credit issued under the Credit Agreement as of September 30, 2013.

Central’s 6.0% Senior Notes

At September 30, 2013, Central had outstanding $230.0 million aggregate principal amount of 6.0% Senior Notes due 2016, or 6.0% Notes. The Bank of New York Mellon Trust Company, N.A. serves as trustee under the related indenture. Interest is payable semi-annually on June 1 and December 1 of each year. The related issuance costs and debt discount are being amortized over the life of the 6.0% Notes utilizing the straight line method which approximates the effective interest method. The 6.0% Notes mature on June 1, 2016 and have an overall effective interest rate of 6.17%. The 6.0% Notes are Central’s senior unsecured obligations and rank equal in right of payment to all of its existing and future unsecured

~~Table~~The Credit Agreement contains negative covenants that, subject to significant exceptions, limit the ability of ~~Contents~~the Company and its Restricted Subsidiaries to, among other things, (i) incur debt, (ii) engage in new lines of business, (iii) incur liens, (iv) engage in mergers, consolidations, liquidations and dissolutions, (v) dispose of substantially all of the assets of the Company and its subsidiaries, (vi) make investments, loans, advances, guarantees and acquisitions, (vii) make certain restricted payments and (viii) enter into transactions with affiliates. The covenants require the Company to comply on a quarterly basis with a leverage ratio and a minimum fixed charge coverage ratio with respect to the Company and a capitalization ratio with respect to Central. The Credit Agreement contains events of defaults that are customary for a facility of this nature. If an event of default occurs, the commitments of the Lenders to lend under the facility may be terminated and the maturity of the amounts outstanding may be accelerated.

~~indebtedness~~Term and are effectively junior to the secured indebtedness of Central to the extent of the value of the assets securing such indebtedness, if any. The 6.0% Notes are structurally senior to the 6.75% Notes. Loan

On June 16, 2014, Central entered into an unsecured $100.0 million term loan, or Term Loan, among several banks and other financial institutions or entities from time to time party thereto as lenders and Royal Bank of Canada, as administrative agent, pursuant to which the lenders agreed to make a term loan to Central. The Term Loan will mature on June 1, 2016.

Borrowings under the Term Loan bear interest at a rate per annum equal to, at Central’s option, either (a) an alternate base rate or (b) a rate based on the rates applicable for deposits in the interbank market for U.S. Dollars or the applicable currency in which loans are made plus an applicable margin. The applicable margin for the term loan is, in the case of borrowings bearing interest in accordance with clause (a) above, 0.75% and in the case of borrowings bearing interest in accordance with clause (b) above, 1.75%. Interest is paid at various times throughout the year depending on the option Central elects, but in intervals no longer than three months. The interest rate as of June 30, 2014 was 4.0%.

The Term Loan includes negative covenants that, subject to significant exceptions, limit the ability of Central and its restricted subsidiaries to, among other things (i) incur liens, (ii) engage in mergers, consolidations, liquidations and dissolutions and (iii) enter into transactions with affiliates. The covenants require Central to comply on a quarterly basis with a capitalization ratio and a minimum fixed charge coverage ratio. The Term Loan contains events of default that are customary for a facility of this nature. If an event of default occurs under the Term Loan, the maturity of the amounts outstanding thereunder may be accelerated.

Central’s 6.0% Senior Notes

At June 30, 2014, Central had outstanding $230.0 million aggregate principal amount of 6.0% Senior Notes due 2016, or 6.0% Notes. The Bank of New York Mellon Trust Company, N.A. serves as trustee under the related indenture. Interest is payable semi-annually on June 1 and December 1. The related issuance costs are being amortized over the life of the 6.0% Notes utilizing the straight line method. The 6.0% Notes mature on June 1, 2016 and have an overall effective interest rate of 6.17%. The 6.0% Notes are Central’s senior unsecured obligations and rank equal in right of payment to all of its existing and future unsecured indebtedness and are effectively junior to the secured indebtedness of Central to the extent of the value of the assets securing such indebtedness, if any. The 6.0% Notes are structurally senior to the 5.125% and 6.75% Notes.

The 6.0% Notes are subject to certain covenants that restrict, among other things, Central’s ability to create liens, enter into sale and leaseback transactions or merge or consolidate with other entities. Central has the option to call the 6.0% Notes at any time at a make-whole premium as defined in the indenture.

Capital Lease ~~Obligation~~

In 2004, Central entered into a 20-year capital lease with the Owensboro-Daviess County Industrial Development Authority, or the Authority, for use of a headquarters building in Owensboro, Kentucky. Central iswas the borrower under a $9.0 million loan agreement dated as of January 1, 2004 between Central and the Authority pursuant to which the Authority financed the cost of Central’s office facility in Daviess County, Kentucky. In connection with this financing, the Authority issued Series 2004A and 2004B bonds under an indenture dated as of January 1, 2004 between the Authority and U.S. Bank, N. A., asor ~~trustee~~Trustee. ~~Ownership of the facility will transfer to Central for a nominal fee upon expiration of the lease in 2024.~~ Approximately $7.1 million of assets are included in Property, plant and equipment as a capital lease and ~~are~~were being amortized over the same life as similar assets. Amortization of the assets is included in Depreciation and amortization in the accompanying unaudited Consolidated Financial Statements. The overall effective interest rate on the obligation iswas 6.29%. Principal and interest ~~are~~were paid semi-annually. Central ~~has~~had the option to prepay all 2004A bonds on or after January 1, 2014 and all 2004B bonds on or after February 1, 2014.

and transfer ownership of the headquarters building to Central, the completion of which is anticipated by the end of the third quarter.

Other

As of ~~September~~June 30, ~~2013~~2014, the Company was in compliance with the covenants of all outstanding debt instruments.

6. Commitments and Contingencies

Regulatory and Rate Matters and Related Litigation

Fuel Filing

Central recovers the natural gas it uses for fuel on its operating system and gas losses it incurs on its system in-kind from its customers via a fuel reimbursement charge placed on the volumes of gas transported through the system. The reimbursement charge is established through an annual fuel tracker filed with the FERC.

General Rate Issues

On May 31, 2013, Central filed a general rate case under FERC Docket No. RP13-941, to be effective December 1, 2013. The FERC issued a suspension order dated July 5, 2013 accepting and suspending the proposed tariff records to be effective December 1, 2013, subject to refund and conditions, and the outcome of a hearing. ~~FERC~~On ~~issued~~November an26, ~~order~~2013, Central submitted a filing that reflected suspended rates, which Central requested be moved into effect on ~~July~~December 101, 2013, ~~assigning~~subject to refund of revenues collected in excess of settlement rates, consistent with the FERC's orders in this proceeding. The motion rates reflect adjustments required by the FERC's orders and regulations. Pursuant to the principles of settlement reached with active parties in the case, Central filed, and the FERC approved, an interim rate reduction to be effective February 1, 2014. Such interim rates were the settlement rates. Central filed a Stipulation and Agreement on March 7, 2014 that the Administrative Law Judge certified to ~~hold~~the aFERC ~~pre-hearing~~on ~~conference~~March ~~and~~26, ~~establishing~~2014. ~~procedural~~On ~~time~~April ~~standards~~23, 2014 the FERC issued an Order approving the proposed settlement, which became final on May 23, 2014. The ~~pre-hearing~~settlement ~~conference~~rates ~~was~~will ~~held~~increase onCentral’s ~~July~~revenues 24approximately $28.0 million above revenues for the 12 months ended February 28, 2013, ~~and~~the anbase ~~"Order~~period ~~Adopting~~covered ~~Protective~~in ~~Order"~~its ~~and~~filing. Central anissued ~~"Order~~refund ~~Establishing~~checks ~~Procedural~~for ~~Schedule~~revenues ~~and~~collected ~~Rules~~in excess of ~~Conduct~~settlement ofrates in the ~~Hearing"~~amount ~~were~~of ~~issued~~$9.3 million, including interest, on ~~July~~May 29, ~~2013~~2014. The ~~first~~final ~~settlement~~report ~~conference~~of isrefunds ~~scheduled~~was tofiled bewith ~~held~~the FERC on ~~November~~June 2019, ~~2013~~2014.

Environmental and Safety Matters

Environmental

Central has identified polychlorinated biphenyl, or PCB, contamination in air compressor systems, soils, and related properties at certain compressor station sites and has been involved in negotiations with the U.S. Environmental Protection Agency, or EPA, and state agencies to develop screening, sampling, and cleanup programs. In addition, negotiations with certain environmental agencies concerning investigative and remedial actions relative to potential mercury contamination at certain natural gas metering sites ~~are~~have ~~on-going~~commenced. Central ~~has received "No-Further-Action" letters from the states of Kansas, Missouri and Oklahoma for mercury cleanup. Central~~ had accrued an undiscounted liability of approximately $1.02 million at ~~September~~June 30, ~~2013~~2014 and $1.20 million at December 31, ~~2012~~2013, representing the current estimate of future environmental testing and cleanup costs, most of which is expected to be incurred over the next three to four years. However, timing is highly dependent upon State and Federal negotiations.

Central is subject to federal, state and local statutes, rules and regulations relating to environmental protection, including the National Environmental Policy Act, the Clean Water Act, the Clean Air Act and the Resource Conservation and Recovery Act. These laws and regulations can result in capital, operating and other costs. These laws and regulations generally subject Central to inspections and require it to obtain and comply with a wide variety of environmental licenses, permits and other approvals. Under the Clean Air Act, the EPA has promulgated regulations addressing emissions from equipment present at typical natural gas compressor stations. These regulations include NESHAPs for reciprocating internal combustion engines, stationary turbines, and glycol dehydration equipment in addition to regulations that address regional transport of ozone. On August 20, 2010, the EPA promulgated new emission standards that apply to certain of Central’s existing reciprocating engines. These new standards, with an initial compliance date of October 19, 2013, require the installation of emission control devices on some of Central’s existing operations. Based on an analysis of these regulations, management does not expect there to be a material impact to Central's existing operations. On September 22, 2009, the EPA promulgated a mandatory reporting rule concerning the emission of certain gases, commonly referred to as “greenhouse gases,” that imposes requirements for some of Central’s existing operations. There are also other potential state or federal regulations or legislation related to greenhouse gas emissions that could impact Central’s existing operations if promulgated. Central continues to monitor the progress of any proposed rules or legislation and will determine any impact once the regulations have been promulgated.

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approvals. Under the Clean Air Act, the EPA has promulgated regulations addressing emissions from equipment present at typical natural gas compressor stations. These regulations include NESHAPs for reciprocating internal combustion engines, stationary turbines, and glycol dehydration equipment in addition to regulations that address regional transport of ozone. On August 20, 2010, the EPA promulgated emission standards that apply to certain of Central’s existing reciprocating engines. These standards had an initial compliance date of October 19, 2013, and required the installation of emission control devices on some of Central’s existing operations. On September 22, 2009, the EPA promulgated a mandatory reporting rule concerning the emission of certain gases, commonly referred to as “greenhouse gases,” or GHG, that imposes requirements for some of Central’s existing operations. To date, GHG regulations have not resulted in a material impact to Central's operations; however, there are also other potential state or federal regulations or legislation related to GHG emissions that could impact Central’s existing operations if promulgated. Central continues to monitor the progress of any proposed rules or legislation and will determine any impact once the regulations have been promulgated.

All of Central’s facilities are located in areas currently designated as being in “attainment” of all National Ambient Air Quality Standards, or NAAQS. The EPA is currently in the process of preparing area designations under revisions to the ozone NAAQS that were promulgated in March 2008. Based on the EPA's latest projections it appears that most, if not all, areas housing Central’s operations will continue to be in attainment with the 2008 (current) ozone NAAQS.

Central considers environmental assessment, remediation costs and costs associated with compliance with environmental standards to be recoverable through rates, as they are prudent costs incurred in the ordinary course of business. The actual costs incurred will depend on the actual amount and extent of contamination discovered, the final cleanup standards mandated by the EPA or other governmental authorities, and other factors.

Legal Issues

Will Price, et al. v. El Paso Natural Gas Co., et al., Case No. 99 C 30, District Court, Stevens County, Kansas, or Price Litigation I

In this putative class action filed May 28, 1999, the named plaintiffs, or Plaintiffs, have sued over 50 defendants, including Central. Asserting theories of civil conspiracy, aiding and abetting, accounting and unjust enrichment, their Fourth Amended Class Action Petition alleges that the defendants have under measured the volume of, and therefore have underpaid for, the natural gas they have obtained from or measured for Plaintiffs. Plaintiffs seek unspecified actual damages, attorney fees, pre- and post-judgment interest, and reserved the right to plead for punitive damages. On August 22, 2003, an answer to that pleading was filed on behalf of Central. Despite a denial by the Court on April 10, 2003 of their original motion for class certification, the Plaintiffs continued to seek the certification of a class. The Plaintiffs’ motion seeking class certification for a second time was fully briefed and the Court heard oral argument on the motion on April 1, 2005. On September 18, 2009, the Court denied the Plaintiffs’ motion for class certification. The Plaintiffs filed a motion to reconsider that ruling on October 2, 2009. The defendants, including Central, filed a response in opposition to the Plaintiffs’ motion for reconsideration on January 18, 2010. The Plaintiffs filed a reply and oral argument, which was presented before a different judge, was heard on February 10, 2010. By order dated March 31, 2010, the Court denied the Plaintiffs’ October 2, 2009 motion to reconsider the earlier denial of class certification. The Plaintiffs did not file for interlocutory review of the March 31, 2010 order, but through their counsel they have initiated certain discovery to which Central and other defendants have objected. In late June of 2011, certain defendants other than Central filed motions for summary judgment seeking, among other things, a ruling on the legal issue of whether or not Plaintiffs' civil conspiracy claim could be based upon their underlying unjust enrichment claim. In January of 2012, the Court issued an order concluding that under Kansas law a conspiracy claim could be so based. These defendants petitioned for interlocutory review of that ruling, but the Court of Appeals of Kansas denied their request on February 23, 2012. It is unknown whether Plaintiffs will follow through on discovery and/or otherwise proceed with the litigation on a non-class basis. Central cannot predict the outcome of this litigation or estimate a range of reasonably possible losses, if any.

Will Price, et al. v. El Paso Natural Gas Co., et al., Case No. 03 C 23, District Court, Stevens County, Kansas, or Price Litigation II

~~Table~~All of ~~Contents~~Central’s facilities are located in areas currently designated as being in “attainment” of all National Ambient Air Quality Standards, or NAAQS. The EPA is currently in the process of preparing area designations under revisions to the ozone NAAQS that were promulgated in March 2008. Based on the EPA’s latest projections it appears that all areas housing Central’s operations will continue to be in attainment with the 2008 (current) ozone NAAQS.

~~motion to reconsider that ruling on October 2, 2009. The defendants, including~~ Central, ~~filed~~considers aenvironmental ~~response in opposition to the Plaintiffs’ motion for reconsideration on January 18~~assessment, ~~2010.~~remediation ~~The~~costs ~~Plaintiffs filed a reply~~ and ~~oral~~costs ~~argument,~~associated ~~which~~with ~~was~~compliance ~~presented~~with ~~before~~environmental astandards ~~different~~to ~~judge,~~be ~~was~~recoverable ~~heard~~through ~~on February 10~~rates, ~~2010.~~as Bythey ~~order~~are ~~dated~~prudent ~~March~~costs ~~31,~~incurred ~~2010,~~in the ~~Court~~ordinary ~~denied~~course ~~the Plaintiffs’ October 2, 2009 motion to reconsider the earlier denial~~ of ~~class certification~~business. The ~~Plaintiffs~~actual ~~did~~costs ~~not~~incurred ~~file~~will ~~for~~depend ~~interlocutory~~on ~~review of~~ the ~~March~~actual ~~31,~~amount ~~2010 order, but through their counsel they have initiated certain discovery to which Central~~ and ~~other~~extent ~~defendants have objected. In late June~~ of ~~2011,~~contamination ~~certain defendants other than Central filed motions for summary judgment seeking~~discovered, ~~among~~the ~~other~~final ~~things,~~cleanup astandards ~~ruling~~mandated onby the ~~legal~~EPA ~~issue of whether~~ or ~~not~~other ~~Plaintiffs'~~governmental ~~civil conspiracy claim could be based upon their underlying unjust enrichment claim. In January of 2012~~authorities, the Court issued an order concluding that under Kansas law a conspiracy claim could be so based. These defendants petitioned for interlocutory review of that ruling, but the Court of Appeals of Kansas denied their request on February 23, 2012. It is unknown whether Plaintiffs will follow through on discovery and~~/or~~ ~~otherwise~~other ~~proceed with the litigation on a non-class basis~~factors. ~~Central cannot predict the outcome of this litigation or estimate a range of reasonably possible losses, if any.~~

Summary of Commitments and Contingencies

In connection with the purchase of Central by Southern Star from The Williams Companies, Inc., or Williams, in 2002, a Litigation Cooperation Agreement was executed pursuant to which Williams agreed to cooperate in and assist with the defense of Central with respect to the Price Litigation. Pursuant to that agreement, Williams agreed to provide information and data to Central, make witnesses available as necessary, assist Central in becoming a party to certain Joint Defense Agreements, and to cooperate in general with Central in the preparation of its defense.

The Company is subject to claims and legal actions in the normal course of business in addition to those disclosed above. While no assurances can be given, management believes, based on advice of counsel and after consideration of amounts accrued, insurance coverage, potential recovery from customers and other indemnification arrangements, that the ultimate resolution of these matters will not have a material adverse effect upon the Company’s future financial position, results of operations, or cash flows. Costs incurred to date of defending pending cases have not been material.

7. Income Taxes

The Company’s effective tax rate for the ~~nine~~six-months ended ~~September~~June 30, ~~2013~~2014 was 39.41%. ~~The~~compared ~~Company's~~to ~~effective~~39.3% ~~tax rate~~ for the same period ~~September~~ended ~~24, 2012 through September~~ June 30, ~~2012 and the period January 1, 2012 through September 23, 2012 was 39~~2013.~~0% and 39.3%, respectively.~~ The effective tax rate in excess of the federal statutory rate of 35.0% is primarily due to the impact of state income taxes.

In accordance with ASC 740, the Company records interest related to uncertain tax positions as a part of Interest expense on the accompanying Consolidated Statements of Net Income. Any penalties are recognized as part of Miscellaneous expense on the accompanying Consolidated Statements of Net Income. The Company does not have a liability for tax penalties or interest related to uncertain tax positions for any period presented.

As of ~~September~~June 30, ~~2013~~2014, the Company remained subject to examination by Federal and State jurisdictions for the tax years beginning in 2010 and forward for Federal and 2004 and forward for State, in some cases due to net operating losses carried forward.

8. Dividends and Related Restrictions

Certain of the Company’s debt instruments contain restrictions on ~~the~~ declaration and payments of dividends or distributions to equity holders, subject to a minimum fixed charge coverage ratio and cumulative available cash flows from operations or a leverage ratio, subject to certain conditions, as defined in the related debt agreements. The Company currently meets all minimum requirements and pays dividends in compliance with such restrictions.

9. Employee Benefit Plans

~~The~~Central ~~Compensation~~maintains –two ~~Retirement~~pension ~~Benefits~~plans, ~~Topic 715 of~~ the ~~ASC,~~Union orPension ~~ASC~~Plan ~~715,~~and ~~requires companies to recognize~~ the ~~funded~~Non-Union ~~status~~Pension ofPlan, ~~their defined benefit pension~~ and ~~other~~a postretirement benefit ~~plans~~other asthan apension net liability or asset in their balance sheets and to recognize changes in that funded status in the year in which changes occur through comprehensive income. As it is appropriate for the Company to apply the accounting prescribed by the Regulated Operations Topic 980 of the ASCplan, ~~the Company does not recognize changes in the funded status in comprehensive income but recognizes them as changes to the related regulatory asset~~ or ~~liability, pending future recovery or refund through its rates~~PBOP.

~~Pursuant~~The toUnion ~~ASC~~Pension ~~715,~~Plan nois ~~portion~~a noncontributory defined benefit plan open to all employees of the ~~related~~Company ~~liabilities~~who: (1) are ~~classified~~covered asby ~~current~~the ~~because~~collective ~~plan~~bargaining ~~assets~~agreement ~~exceed~~between the ~~value~~Company ofand ~~benefit~~the ~~obligations~~International ~~expected~~Union toof beOperating ~~paid~~Engineers ~~within~~Local No. 351, previously the 12International ~~months~~Union ~~ending~~of ~~September~~Operating ~~30,~~Engineers ~~2014~~Local No. ~~In addition~~647, noAFL-CIO ~~plan~~and ~~assets~~any ~~are~~successors ~~expected~~thereto, to(2) behave ~~returned~~attained toage ~~the~~21, ~~Company~~and ~~during~~(3) ~~the~~have 12completed ~~months~~one ~~ending~~year ~~September~~of 30employment containing 1,000 ~~2014~~hours or more of service in a 12-month period.

The Non-Union Pension Plan is a noncontributory defined benefit plan. The plan is open to all employees of the Company who are not represented by any collective bargaining agreement, have attained age 21, and completed one year of employment containing 1,000 hours or more of service in a 12-month period.

The PBOP provides postretirement medical and life insurance benefits to certain employees who retire under Central's retirement plans. The PBOP is contributory for medical and, for some retired employees, contributory for life insurance benefits in excess of specified limits. Eligible employees under these plans are those hired prior to various qualifying dates, the latest of which is December 31, 1995, who qualify for retirement benefits, and who meet certain service and other requirements.

~~Table~~The terms of ~~Contents~~the RP08-350 rate settlement allowed Central to recover, in its rates, $9.5 million annually for pension benefits and postretirement benefits other than pensions. Central must fund the amounts recovered into irrevocable trusts established solely for the provision of the aforementioned benefits in a manner that permits Central to maximize the tax deductibility of the deposits and adhere to minimum and maximum funding requirements. Central’s $9.5 million annual funding requirement could only be reduced by amounts funded in excess of recoveries in prior years. As of December 31, 2013, Central’s funding was equivalent to its RP08-350 recoveries.

The terms of the ~~RP08~~RP13-~~350~~941 rate settlement, ~~allow~~which received final approval by the FERC on April 23, 2014 and became final on May 23, 2014, allows Central to recover, in its rates, approximately $97.58 million annually for pension benefits and postretirement benefits other than pensions. Central must fund the amounts recovered into irrevocable trusts established solely for the provision of the aforementioned benefits in a manner that permits Central to maximize the tax deductibility of the deposits and adhere to minimum and maximum funding requirements. Central’s $97.58 million annual funding requirement may only be reduced by amounts funded in excess of recoveries in prior years. ~~As of December 31, 2012, Central’s funding was $0.9 million in excess of its recoveries.~~

The Compensation - Retirement ~~Plan~~Benefits Topic 715 of the ASC, or ASC 715, requires companies to recognize the funded status of their defined benefit pension and other postretirement benefit plans as a net liability or asset in their balance sheets and to recognize changes in that funded status in the year in which changes occur through comprehensive income. As it is appropriate for the Company to apply the accounting prescribed by the Regulated Operations Topic 980 of the ASC, the Company does not recognize changes in the funded status in comprehensive income but recognizes them as changes to the related regulatory asset or liability, pending future recovery or refund through its rates.

~~Pension~~Pursuant ~~expense~~to ~~for~~ASC ~~the~~715, ~~Company's~~no ~~pension~~portion ~~plans~~of ~~was~~the ~~$5.6~~related ~~million,~~liabilities ~~$0.2~~are ~~million,~~classified ~~and~~as ~~$6.9~~current ~~million~~because ~~for~~plan ~~the~~assets ~~nine-month~~exceed ~~period~~the ~~ended~~value ~~September~~of ~~30,~~benefit ~~2013~~obligations ~~(Successor),~~expected ~~the~~to ~~period~~be ~~September~~paid ~~24,~~within ~~2012~~the ~~through~~12 ~~September~~months ending June 30, ~~2012~~2015. ~~(Successor)~~In addition, ~~and~~no ~~the~~plan ~~period~~assets ~~January~~are 1,expected ~~2012~~to ~~through~~be ~~September~~returned ~~23,~~to ~~2012~~the ~~(Predecessor)~~Company during the 12 months ending June 30, ~~respectively~~2015.

Components of the Company’'s net periodic pension expense for the indicated plans are as follows (expressed in thousands):

	Successor							Predecessor
	Pension Plans						PBOP Plan
	For the Nine Months Ended September 30, 2013			For the Period September 24 through September 30, 2012				For the Period January 1 through September 23, 2012
	For the Six Months Ended June 30, 2014			For the Six Months Ended June 30, 2013			For the Six Months Ended June 30, 2014				For the Six Months Ended June 30, 2013
Union Retirement Plan
Components of net periodic benefit expense:
Components of net periodic pension expense:
Service cost	$	2,798		$	3,483		$	293			$	338
Service cost	$	1,244		$	32			$	1,240
Interest cost	1,268			1,275			1,253				1,245
Interest cost	622			19				712
Expected return on plan assets	(1,298		)	(1,438		)	(1,368		)		(1,148		)
Expected return on plan assets	(591		)	(26		)		(969		)
Recognized actuarial gain	(350		)	—			(867		)		—
Recognized actuarial loss	—			8				341
Regulatory recovery of costs	1,311			421			689				574
Employee transfers	(135		)	—				(32		)
Net periodic benefit expense	$	3,729		$	3,741		$	—			$	1,009
Settlement recognition	3			—				972
Regulatory recovery of costs	2,147			39				443
Net periodic pension expense	$	3,290		$	72			$	2,707
Non-Union Retirement Plan
Components of net periodic pension expense:
Service cost	$	3,826		$	81			$	3,112
Interest cost	1,272			28				1,074
Expected return on plan assets	(1,419		)	(34		)		(1,313		)
Recognized actuarial loss	—			21				833
Employee transfers	135			—				32
Regulatory (accrual)/recovery of costs	(1,493		)	17				495
Net periodic pension expense	$	2,321		$	113			$	4,233

The Company made contributions to ~~the~~these ~~pension~~ plans totaling $0.73 million and $70.27 million for the ~~nine~~six-month ~~period~~periods ended ~~September~~ June 30, ~~2013~~2014 ~~(Successor)~~ and ~~for the period January 1~~2013, ~~2012 through September 23, 2012 (Predecessor),~~ respectively, and anticipates funding an additional $58.21 million byto ~~November~~the ~~30,~~pension ~~2013. The~~and ~~Company~~PBOP ~~made~~plans noduring ~~contributions for~~ the ~~period~~remainder ~~September~~of ~~24, 2012 through September 30, 2012 (Successor)~~2014.

Postretirement Benefits Other than Pensions

Central’s Retiree Medical Coverage Plan, or Retiree Medical Plan, provides medical and life insurance postretirement benefits to certain employees who retire under Central’s retirement plans. The Retiree Medical Plan is contributory for medical and, for some retired employees, contributory for life insurance benefits in excess of specified limits. Eligible employees under

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these plans are those hired prior to various qualifying dates, the latest of which is December 31, 1995, who qualify for retirement benefits, and who meet certain service and other requirements.

The benefits for qualified union employees are funded through a trust agreement under the Southern Star Voluntary Employees’ Beneficiary Association for Collectively Bargained Employees, or Union VEBA, and the benefits for qualified non-union employees are funded through a separate trust agreement under the Southern Star Voluntary Employees’ Beneficiary Association for Non-Collectively Bargained Employees, or Non-Union VEBA. Funding is made in accordance with the requirements under Central’s latest rate settlement with the FERC.

The following table sets forth the components of net periodic postretirement benefit costs for the periods indicated (expressed in thousands):

	Successor						Predecessor
	For the Nine Months Ended September 30, 2013			For the Period September 24 through September 30, 2012			For the Period January 1 through September 23, 2012
Components of net periodic benefit expense:
Service cost	$	446		$	11		$	426
Interest cost	1,723			47			1,811
Expected return on plan assets	(1,716		)	(41		)	(1,587		)
Recognized actuarial loss	—			64			2,460
Regulatory recovery/(accrual) of costs	1,061			(81		)	(3,110		)
Net periodic benefit expense	$	1,514		$	—		$	—

The Company did not make any contributions to this plan for the nine-month period ended September 30, 2013 (Successor), the period September 24, 2012 through September 30, 2012 (Successor), or the period January 1, 2012 through September 23, 2012 (Predecessor). The Company anticipates funding $1.9 million by November 30, 2013.

10. Related Party Transactions

~~Prior~~Southern toStar ~~the~~has ~~Sale, Central had~~ an ~~Operating~~Administrative ~~Company~~ Services Agreement, ~~or Operating Services Agreement,~~ with ~~EFS~~MSIP ~~Services,~~Southern ~~LLC,~~Star ~~or EFS Services~~L.L.C., an affiliate of ~~GE.~~MSIP, ~~Pursuant~~ to ~~the~~provide ~~Operating Services Agreement, EFS Services provided~~ certain ~~consulting~~administrative services to ~~Central~~Southern ~~for~~Star aand ~~service fee of $1~~Holdings.0 ~~million~~Pursuant ~~per~~to ~~year, plus~~ the ~~reimbursement~~terms of ~~reasonable~~this ~~expenses~~agreement, upthe toparties ~~$0.2~~are ~~million~~not inpaid a ~~12-month~~fee ~~period~~for ~~incurred~~their ~~by EFS Services in providing such~~ services.; ~~Central~~however, ~~paid~~they ~~approximately~~are ~~$0.7~~entitled ~~million for service fees and expenses~~ to ~~EFS~~be ~~Services~~reimbursed for ~~the~~reasonable ~~period~~expenses ~~January~~incurred 1,in ~~2012~~providing ~~through~~such ~~September 23, 2012~~services. ~~The~~No ~~Operating~~significant ~~Services~~expenses ~~Agreement~~were ~~terminated~~incurred onduring ~~September~~the ~~24,~~six-month ~~2012~~periods asended aJune 30, ~~result~~2014 ofand ~~the Sale~~2013.

~~Southern Star had an Administrative Services Agreement with EFS Services to provide certain administrative services to Southern Star and Holdings~~11. ~~Pursuant~~New toAccounting ~~the~~Guidance ~~Administrative~~Pending Services Agreement, EFS Services was not paid a fee for its services; however, it was entitled to be reimbursed for reasonable expenses incurred in providing such services. No significant expenses were incurred during the period January 1, 2012 through September 23, 2012. The Administrative Services Agreement terminated on September 24, 2012 as a result of the Sale. Adoption

On ~~January~~May 2328, ~~2012~~2014, ~~Southern~~the ~~Star~~FASB ~~entered~~issued ~~into~~Accounting anStandards ~~Administrative~~Update ~~Services~~2014-09, ~~Agreement~~“Revenue ~~with~~from ~~MSIP~~Contracts ~~Southern~~with ~~Star~~Customers ~~L.L.C.,~~(Topic ~~an affiliate of MSIP~~606),” toor ~~provide~~ASU ~~certain administrative services to Southern Star and Holdings~~2014-09. ~~Pursuant~~The tocore ~~the~~principle ~~terms~~ of ~~this agreement,~~ the ~~parties~~guidance ~~are~~is ~~not~~that ~~paid~~an aentity ~~fee~~should ~~for~~recognize ~~their~~revenue ~~services;~~to ~~however,~~depict ~~they~~the ~~are~~transfer ~~entitled~~of topromised begoods ~~reimbursed~~or ~~for~~services ~~reasonable~~to ~~expenses~~customers ~~incurred~~ in ~~providing~~an ~~such~~amount ~~services.~~that Noreflects ~~significant~~the ~~expenses~~consideration ~~were~~to ~~incurred~~which ~~during~~ the ~~nine-month~~entity ~~period~~expects ~~ended~~to ~~September~~be ~~30,~~entitled ~~2013~~in ~~(Successor),~~exchange ~~the~~for ~~period~~those ~~September~~goods ~~24,~~or ~~2012~~services. ~~through~~To ~~September~~achieve ~~30,~~that ~~2012~~core ~~(Successor)~~principle, oran ~~the~~entity ~~period~~should ~~January~~apply ~~23,~~the ~~2012~~following ~~through September 23, 2012 (Predecessor).~~steps:

Step 1: Identify the contract with a customer.

Step 2: Identify the performance obligations in the contract.

Step 3: Determine the transaction price.

Step 4: Allocate the transaction price to the performance obligations in the contract.

Step 5: Recognize revenue when (or as) the entity satisfies a performance obligation.

ASU 2014-09 will supersede the revenue recognition requirements in the Revenue Recognition Topic 605 of the ASC and most industry-specific guidance, and creates the Revenue from Contracts with Customers Topic 606 of the ASC. ASU 2014-09 will be effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. Early application is not permitted. Management is currently evaluating the effect that the provisions of this ASU will have on the Company’s consolidated financial statements.

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

References to “Southern Star” refer to Southern Star Central Corp. and references to “we,” “us,” “our,” and “the Company,” refer to Southern Star Central Corp. and to its wholly-owned subsidiary, Southern Star Central Gas Pipeline, Inc., or Central.

17This management’s discussion and analysis of our financial condition and results of operations should be read in conjunction with our 2013 Annual Report on Form 10-K filed with the SEC on March 28, 2014. This discussion contains forward-looking statements about our business, operations and industry that involve risks and uncertainties such as statements regarding our plans, objectives, expectations and intentions. Our future results and financial condition may differ materially from those we currently anticipate as a result of the factors we describe under “Forward-Looking Statements” and elsewhere in this document.

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This management’s discussion and analysis of our financial condition and results of operations should be read in conjunction with our 2012 Annual Report on Form 10-K filed with the SEC on March 26, 2013 as amended by Form 10-K/A filed with the SEC on April 9, 2013. This discussion contains forward-looking statements about our business, operations and industry that involve risks and uncertainties such as statements regarding our plans, objectives, expectations and intentions. Our future results and financial condition may differ materially from those we currently anticipate as a result of the factors we describe under “Forward-Looking Statements” and elsewhere in this document.

All accounting and reporting policies contained herein conform with accounting principles generally accepted in the United States, or GAAP. The financial information contained herein has been prepared in accordance with the rules and regulations of the SEC.

FORWARD-LOOKING STATEMENTS

The information in this report includes forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. These forward-looking statements relate to anticipated financial performance, management’s plans and objectives for future operations, business prospects, outcome of regulatory proceedings, market conditions and other matters. Words such as “anticipate,” “believe,” “estimate,” “expect,” “intend,” “plan,” “objective,” and other similar expressions identify some of the statements that are forward-looking. These statements are based on management’s beliefs and assumptions and on information currently available to management. Actual results could differ materially from those contemplated by the forward-looking statements. In addition to any assumptions and other factors referred to specifically in connection with such statements, factors that could cause actual results to differ materially from those contemplated in any forward-looking statement include, among others, the following:

•

future utilization of pipeline capacity, which can depend on energy prices and the prices for natural gas available on our system, competition from other pipelines and alternative fuels, the general level of natural gas demand, decisions by customers not to renew expiring natural gas transportation contracts, adequate supplies of natural gas, the construction or abandonment of natural gas customer facilities, weather conditions and other factors beyond our control;

• operational risks and limitations of our pipeline ~~system~~and storage systems and of interconnected pipeline systems;


•	our ability to raise capital and fund capital expenditures in a cost-effective manner;

• changes in federal, state or local laws and regulations to which we are subject, including allowed rates of return and related regulatory matters, regulatory disclosure obligations, the regulation of financial dealings between us and our affiliates, and tax, environmental, safety and employment laws and regulations;


•	our ability to manage costs;


•	the ability of our customers to pay for our services;


•	environmental liabilities that are not covered by an indemnity or insurance;


•	our ability to expand into new markets as well as our ability to maintain existing markets;

~~• our ability to obtain governmental and regulatory approval of various expansion projects, as well as our ability to maintain and comply with such approvals;~~17


•	our ability to obtain governmental and regulatory approval of various expansion projects as well as our ability to maintain and comply with such approvals;


•	the cost and effects of legal and administrative proceedings;


•	the effect of accounting interpretations and changes in accounting policies;


•	restrictive covenants contained in various debt instruments applicable to us and our subsidiaries which may restrict our ability to pursue our business strategies;

• strikes or work stoppages by Central’'s employees;


•	changes in general economic, market or business conditions; and


•	economic repercussions from terrorist activities and the government’s response to such terrorist activities.

18Other factors and assumptions not identified above, including without limitation, those described under Item 1A “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2013 filed with the SEC on March 28, 2014, may also impact these forward-looking statements. The failure of those other assumptions to be realized, as well as other factors, which may or may not occur, may also cause actual results to differ materially from those projected. Except as required by law, we assume no obligation to update forward-looking statements to reflect actual results, changes in assumptions or changes in other factors affecting forward-looking statements.

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Other factors and assumptions not identified above, including without limitation, those described under Item 1A “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2012 filed with the SEC on March 26, 2013 as amended by Form 10-K/A filed with the SEC on April 9, 2013, may also impact these forward-looking statements. The failure of those other assumptions to be realized, as well as other factors, which may or may not occur, may also cause actual results to differ materially from those projected. Except as required by law, we assume no obligation to update forward-looking statements to reflect actual results, changes in assumptions or changes in other factors affecting forward-looking statements.

General

Southern Star

Southern Star Central Corp., or Southern Star, ~~was~~is a wholly-owned subsidiary of ~~EFS~~MSIP-SSCC Holdings, LLC, or ~~EFS~~Holdings, ~~through~~which ~~September~~is ~~23,~~owned ~~2012.~~by ~~GE Energy Financial Services, Inc., or GE, and~~ Morgan Stanley Infrastructure Partners and certain other affiliated investment funds managed by Morgan Stanley Infrastructure, Inc., or MSIP~~, indirectly held all of the outstanding capital stock of EFS during these periods~~.

~~On August 23, 2012, GE entered into an agreement to sell to MSIP its 60% economic stake and 50% voting stake in~~ Southern Star ~~through~~was ~~the~~incorporated ~~sale~~in ofDelaware ~~its interests~~ in ~~EFS, or the Sale. The Sale was consummated on~~ September ~~24,~~2002 ~~2012, constituting a change in control~~ and ~~resulting~~operates inas a ~~new~~holding ~~basis~~company ~~of accounting~~ for ~~Southern~~its ~~Star.~~regulated Innatural ~~connection~~gas ~~with~~pipeline ~~the~~operations ~~Sale,~~and ~~EFS~~development ~~changed~~opportunities. ~~its~~Southern ~~name~~Star toCentral ~~MSIP-SSCC~~Gas ~~Holdings~~Pipeline, ~~LLC~~Inc., or ~~Holdings.~~Central, ~~See~~is ~~Note~~Southern 3Star’s ofonly ~~the~~subsidiary ~~accompanying~~and ~~Notes to~~ the ~~Consolidated~~sole ~~Financial~~source ~~Statements~~of ~~for~~its ~~further~~operating ~~information~~revenues ~~regarding~~and ~~the~~cash ~~Sale~~flows.

Southern Star was incorporated in Delaware in September 2002 and operates as a holding company for its regulated natural gas pipeline operations. Southern Star Central Gas Pipeline, Inc., or Central, is Southern Star’s only subsidiary and the sole source of its operating revenues and cash flows.

The terms “we,” “us,” “our” and “the Company” denote Southern Star Central Corp. and its subsidiaries.

The Business

Southern Star is the parent company of Central, our only operating subsidiary and the sole source of our operating revenues and cash flows. Central owns and operates an approximately 6,000 mile natural gas pipeline and associated natural gas storage facilities in the Midwestern United States. Central’s primary markets are regulated local natural gas distribution companies, municipalities, intrastate pipelines, electric generation plants and industrial customers in Missouri, Kansas, Oklahoma, and parts of Colorado, Nebraska, Wyoming, and Texas.

Central is an interstate natural gas pipeline engaged in the transportation and storage of natural gas. As such, Central’s rates, facilities and services are regulated by the Federal Energy Regulatory Commission, or the FERC. Central’s services are provided under both short-term and long-term contracts, subject to a FERC-accepted tariff which governs substantially all terms and conditions of service. The substantial majority of Central’s business is conducted under long-term contracts ranging from one to 15 years. ~~In 2012, the Company's two major customers extended contracts set to expire in 2013 for an additional five-year period.~~ Total average remaining contract life ~~of all contracts~~ on a volume-weighted basis at ~~September~~June 30, ~~2013~~2014 was approximately ~~five~~four years.

On May 31, 2013, Central filed a general rate case under FERC Docket No. RP13-941, to be effective December 1, 2013. The FERC issued a suspension order dated July 5, 2013 accepting and suspending the proposed tariff records to be effective December 1, 2013, subject to refund and conditions, and the outcome of a hearing. ~~FERC~~On ~~issued~~November an26, ~~order~~2013, Central submitted a filing that reflected suspended rates, which Central requested be moved into effect on ~~July~~December 101, 2013, ~~assigning~~subject anto ~~Administrative~~refund ~~Law~~of ~~Judge~~revenues tocollected ~~hold~~in aexcess ~~pre-hearing~~of ~~conference~~settlement ~~and~~rates, ~~establishing~~consistent ~~procedural~~with ~~time~~the ~~standards~~FERC's orders in this proceeding. The ~~pre-hearing~~motion ~~conference~~rates ~~was~~reflect ~~held~~adjustments onrequired ~~July~~by ~~24,~~the ~~2013~~FERC's orders and anregulations. ~~"Order~~Pursuant ~~Adopting~~to ~~Protective~~the ~~Order"~~principles of settlement reached with active parties in the case, Central filed, and the FERC approved, an ~~"Order~~interim ~~Establishing~~rate ~~Procedural~~reduction ~~Schedule~~to be effective February 1, 2014. Such interim rates were the settlement rates. Central filed a Stipulation and ~~Rules~~Agreement ofon ~~Conduct~~March of7, 2014 that the ~~Hearing"~~Administrative ~~were~~Law ~~issued~~Judge certified to the FERC on ~~July~~March 2926, ~~2013~~2014. ~~The~~On ~~first~~April ~~settlement~~23, ~~conference~~2014 isthe ~~scheduled~~FERC toissued bean ~~held~~Order approving the proposed settlement, which became final on ~~November~~May 2023, ~~2013~~2014. The settlement required Central to make refunds to

its customers for revenues collected in excess of settlement rates, which were issued on May 29, 2014 in the amount of $9.3 million, including interest.

Central’s rates are regulated by the FERC and are designed to provide an allowed rate of return on equity after recovering its costs of service, assuming that its service and contract levels remain constant. As such, Central’s opportunities to grow profits and cash flows are generally limited to its ability to acquire new business on its existing pipeline system or expand into new areas or services. Expansion of its pipeline system or provision of new services generally requires authorization from the FERC. Our risk of declining profits or cash flows are primarily related to Central’s ability to maintain its current service levels at its current rates, including the renewal of long-term contracts on substantially equivalent terms, and our ability to prudently manage our costs. We expect to continue to manage our operating costs and to renew expiring contracts on favorable terms.

19Pipeline and storage integrity regulations and changes in environmental laws and regulations may increase our operating costs and/or capital expenditures as required for testing, permitting, monitoring or installation of new equipment and other compliance with new regulations. Central remains on schedule to meet all compliance regulations and expects that operating costs associated with such regulations will continue to be recovered in the rates it charges for its services.

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Pipeline and storage integrity regulations continue to increase our operating costs for integrity testing, permitting and other compliance with new regulations. Central remains on schedule to meet all compliance regulations and expects that operating costs associated with such regulations will continue to be recovered in the rates it charges for its services.

Changes in environmental laws and regulations may also increase our operating costs and/or capital expenditures as required for monitoring or installation of new equipment. Central expects operating and capital costs associated with such regulations to be recovered in the rates it charges for its services.

Central’s ability to maintain current service levels at its current rates is impacted by both its access to natural gas supplies and competition. Central’s access to multiple sources of natural gas supply and its unique storage capabilities, due to the strategic location of its storage facilities within its major market areas, are strengths that aid in limiting our downside risks. The competing interstate pipelines generally offer less diverse geographic access to natural gas supply and less competitively priced, flexible on-system storage.

In addition, we proactively seek growth opportunities that will further strengthen our financial position and results of operations. ~~The costs we incur for many of our growth opportunities may be reimbursed by the operator of the gas supply or delivery point.~~

On ~~April~~February 41, 2013, Central ~~completed~~was selected by Black Hills subsidiary, Cheyenne Light Fuel & Power, as the ~~installation~~gas transportation provider for the Cheyenne Prairie power generation project in Cheyenne, WY. The project consists of a ~~new~~five-mile ~~delivery~~lateral ~~point~~line ~~for~~and ~~service~~delivery tometer ~~Linn~~station ~~Energy's~~in ~~Sublette~~Laramie ~~Station~~County, WY. This expansion ~~was~~is supported by a ~~five~~seven-year, seven-month firm transportation contract for 510,000 ~~Dths~~Dekatherms, or Dth/day ~~that~~and ~~was~~is expected to be effective ~~September~~October 1, ~~2012~~2014. The expansion is expected to generate revenues of $0.38 million annually.

On ~~February~~April 19, ~~2013~~2014, Central ~~was~~announced ~~selected~~a bybinding ~~Black~~open ~~Hills~~season ~~subsidiary,~~for ~~Cheyenne~~the ~~Light~~“2014 ~~Fuel~~System &Expansion” ~~Power,~~to asprovide ~~the~~opportunities ~~gas transportation provider~~ for ~~the~~shippers ~~Cheyenne~~to ~~Prairie~~add ~~power~~incremental ~~generation~~transportation ~~project~~on inits ~~Cheyenne, WY~~system. ~~The~~Central ~~project~~is ~~consists~~currently ofin athe ~~five-mile~~process ~~lateral~~of ~~line~~evaluating ~~and~~bids ~~delivery~~received ~~meter~~during ~~station~~that inopen ~~Laramie~~season. ~~County~~Additionally, ~~WY.~~on ~~This~~June ~~expansion~~25, is2014 ~~supported~~Central byannounced a ~~seven~~non-binding ~~year~~open ~~and~~season ~~seven~~for ~~month~~the ~~firm~~“Sooner ~~transportation~~Trails” ~~contract~~project ~~for~~to ~~10,000~~transport ~~Dths/day~~gas ~~and~~to isthe ~~expected~~Bennington, toOK bearea ~~effective~~for ~~October~~interconnects 1,with ~~2014~~downstream pipelines. The ~~expansion~~two isopen ~~expected~~seasons have the potential to ~~generate~~add ~~revenues~~incremental oftransportation ~~$0.7~~revenue ~~million~~for ~~annually~~Central.

On May 14, 2013, Central concluded an open season for the "Blackwell to Shidler Expansion Project" to reserve capacity for the Oklahoma Municipal Power Authority~~, or OMPA~~. The project is supported by a 10-year transportation agreement for approximately 6,000 ~~Dths~~Dth/day and is expected to be effective January 1, 2015. The expansion is expected to generate revenues of $0.35 million annually.

Central ~~concluded~~continues anprogress ~~Open~~toward ~~Season~~completion onof ~~December 7, 2012 and finalized agreements with two shippers on May 21, 2013 for~~ the "Straight Blackwell Expansion Project" to expand capacity on its Straight-Blackwell system. ~~The~~Work ~~expansion~~has ~~will~~been ~~require~~completed ~~the~~on ~~installation~~two ofnew or modified receipt points and one new ~~meter~~delivery ~~stations,~~point. Completion of the expansion requires the installation of pressure regulators and hydrostatic testing to allow for a pipeline operating pressure ~~uprate~~increase. The project is supported by five-year and ten-year firm transportation agreements for approximately 225,000 ~~Dths~~Dth/day and is expected to be effective October 1, 2014. The project is expected to generate revenues of $6.8 million annually.

~~Central~~Additional ~~concluded~~gas ansupply ~~Open~~opportunities ~~Season~~for shippers on the Central system were added in March and April 1,2014. ~~2013~~Central ~~for~~completed ~~the~~an ~~"Sedalia~~upgrade ~~Expansion~~to ~~Project"~~its Superior Perkins location to ~~reserve~~increase ~~capacity~~the ondesign ~~its~~to ~~Sedalia~~15,000 ~~Line.~~Dth/day, ~~The~~completed ~~project~~an isupgrade ~~supported~~to byits aSuperior ~~20-year~~Bellmon ~~firm~~location ~~transportation~~to ~~agreement~~increase ~~for~~the ~~approximately~~design 11to 90,000 ~~Dths~~Dth/day, ofand ~~capacity~~completed ~~and~~a isnew ~~expected~~interconnect towith beTallgrass ~~effective~~Interstate ~~November~~Gas 1Transmission for an additional 25,000 ~~2013~~Dth/day. ~~The~~Upgrades ~~project~~to isadditional and new points are expected to ~~generate~~add ~~revenues~~an incremental 95,000 Dth/day of ~~$0.5~~supplies ~~million~~for ~~annually.~~the system.

The costs we incur for many of our gas supply opportunities are reimbursed by the operator of the gas supply point.

Basis of Presentation and Sale Accounting

~~The~~As discussed in Note 1 of the accompanying Notes to the Consolidated Financial Statements, the Sale resulted in a change in control and a new basis of accounting for Southern Star, as required by the Business Combinations Topic 805 of the Accounting Standards ~~Codifications~~Codification, or the ASC. The total consideration ~~has been "pushed down" and allocated to our assets and liabilities. Our financial statements~~, ~~related~~including ~~to periods prior to~~ the ~~Sale,~~estimated ~~reflect~~fair ~~the~~value ~~previous~~of ~~accounting basis in the Company~~MSIP's ~~assets~~original ~~and~~40% ~~liabilities~~economic ~~and are labeled Predecessor~~interest, ~~while~~has ~~the~~been ~~periods~~“pushed ~~subsequent~~down” ~~to the Sale are labeled Successor~~ and ~~reflect~~allocated ~~the allocation of purchase price~~ to ~~all~~the assets ~~acquired~~ and liabilities ~~assumed in the Sale. Therefore, our Consolidated Statements~~ of ~~Net Income and Cash Flows for~~ the ~~period ending September 23, 2012 each reflect the operations of the Predecessor~~Company. Our Consolidated Statements of Net Income and Cash Flows for the period ending September 30, 2013, the Consolidated Statements of Net Income and Cash Flows for the period September 24, 2012 through September 30, 2012, and the Consolidated Balance Sheets as of December 31, 2012 and September 30, 2013, each reflect the operations and financial position of the Successor.

Critical Accounting Policies

Our discussion and analysis of our financial condition, results of operations, liquidity and capital resources is based on our financial statements, which have been prepared in accordance with GAAP. GAAP requires that we make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and the related disclosure of contingent assets and liabilities. We base these estimates on historical experience and on various other assumptions that we consider reasonable under the circumstances. We evaluate our estimates on an on-going basis. Actual results may differ from these estimates. There have been no significant changes to our Critical Accounting Policies as included in our 2013 Annual Report on Form 10-K filed with the SEC on March 28, 2014.

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assets and liabilities. We base these estimates on historical experience and on various other assumptions that we consider reasonable under the circumstances. We evaluate our estimates on an on-going basis. Actual results may differ from these estimates. There have been no significant changes to our Critical Accounting Policies as included in our 2012 Annual Report on Form 10-K filed with the SEC on March 26, 2013 as amended by Form 10-K/A filed with the SEC on April 9, 2013, except as noted below.

Results of Operations

Results of operations for all periods presented include the operations of Central, our only operating subsidiary. ~~All periods include the application of purchase accounting.~~ The ~~periods~~following ~~subsequent to September 23, 2012 reflect the impact of the Sale. For~~ discussion ~~purposes, we have combined the results~~ of ~~operations for~~ the ~~Successor~~changes ~~and~~in ~~Predecessor~~our periods of 2012 because we believe it facilitates the comparison of 2013 operating and financial performance to 2012 and because the operations of Southern Star have not changed as a result of the Sale. Pro forma results of operations ~~are~~includes ~~not presented, as the~~ only ~~continuing~~material ~~impacts~~line ofitems ~~the~~from ~~Sale on~~ the ~~results~~accompanying ofConsolidated ~~operations~~Statements ~~are those discussed in Note 3~~ of ~~the~~Operations ~~accompanying~~or ~~Notes~~line toitems ~~the~~with ~~Consolidated~~a ~~Financial~~material ~~Statements~~change.

Comparison of the Three Months Ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013

Operating revenues ~~decreased~~were $159.53 million, orand 2$50.8%, ~~to $53.3~~ million for the three-month ~~period~~periods ended ~~September~~June 30, ~~2013~~2014 asand ~~compared~~2013, torespectively, ~~the~~an ~~three-month~~$8.5 ~~period~~million, ~~ended~~or ~~September 30~~16.7%, ~~2012~~increase. The ~~decrease~~increase is primarily due to ~~lower~~the ~~transportation~~RP13-941 ~~revenues~~rate ~~as a result of lower interruptible charges and lower incremental park and loan services, as well as lower storage capacity revenues~~settlement.

Operations and maintenance expenses were $1315.62 million and $1214.57 million for the three-month periods ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013, respectively, a $10.15 million, or 93.14%, increase. The increase is primarily due to higher expenses in the ~~third~~second quarter of ~~2013~~2014 for ~~pipeline~~engine ~~integrity~~overhauls, ~~management~~supplies, labor, ~~vehicle expense~~ and ~~compressor~~right-of-way ~~maintenance~~clearing, offset partially by lower expenses for ~~professional~~integrity ~~services and environmental remediation~~management.

~~Administrative~~Depreciation and ~~general~~amortization expenses were $109.56 million and $109.10 million for the three-month periods ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013, respectively, a $0.46 million, or 36.80%, increase. The increase is primarily due to ~~higher~~asset ~~expenses~~additions into the ~~third~~2014 ~~quarter~~depreciable ofbase ~~2013~~ for ~~computer~~transmission ~~software maintenance~~mains, ~~employee~~software ~~benefits~~development and ~~commitment~~storage ~~fees associated with the Company's line of credit, offset partially by higher expenses transferred to capital~~lines.

~~Depreciation~~Taxes ~~and~~other ~~amortization~~than ~~expenses~~income taxes were $84.8 million and $84.67 million for the three-month periods ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013, respectively, a $0.21 million, or 2.58%, increase. The increase is primarily due to ~~asset~~higher ~~additions~~miscellaneous totaxes ~~the~~during ~~2013 depreciable base for transmission mains~~2014.

Interest expense was $78.78 million and $87.17 million for the three-month periods ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013, respectively, a $01.41 million, or 514.08%, ~~decrease~~increase. The ~~decrease~~increase is a result of ~~the~~higher ~~change~~interest inand ~~the~~ amortization ofexpense ~~debt~~associated ~~discounts/premiums~~with asthe aCompany's ~~result~~revolving ofcredit ~~the~~agreement, ~~Sale~~and in the ~~third~~issuance ~~quarter~~of ~~2012,~~$450.0 asmillion ~~further~~of ~~discussed~~5.125% inSenior Notes. See Note 35 of the accompanying Notes to the Consolidated Financial Statements for further discussion of our long-term debt.

~~Miscellaneous~~Gain ~~other~~on ~~income,~~reacquired ~~net~~debt ~~increased~~was by $0.29 million ~~to $0.3 million~~ for the three-month period ended ~~September~~June 30, ~~2013~~2014, asa ~~compared~~$0.9 tomillion increase from the three-month period ended ~~September~~June 30, ~~2012~~2013. The increase is ~~primarily~~a ~~due~~result toof ~~higher~~the ~~equity~~gain inrecognized ~~allowance~~from ~~for~~the ~~funds~~extinguishment ~~used~~of ~~during~~the ~~construction~~Company's as6.75% aSenior ~~result~~Notes ~~of increased capital spending~~ in ~~2013~~June 2014.

The provision for income taxes ~~were~~was $3.4.8 million and $42.50 million for the three-month periods ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013, respectively, a $12.18 million, ~~or 23~~increase.6% ~~decrease.~~ The ~~decrease~~increase is commensurate with ~~lower~~higher ~~2013~~2014 pre-tax income.

Comparison of the ~~Nine~~Six Months Ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013

Operating revenues were $~~157~~121.32 million and $~~161~~104.90 million for the ~~nine~~six-month periods ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013, respectively, a $417.62 million, or 216.96% ~~decrease~~increase. The ~~decrease~~increase is primarily due to ~~lower storage capacity revenues resulting from a more normal winter season compared to~~ the ~~milder~~RP13-941 ~~winter~~rate ~~season in 2012 and lower revenue from incremental park and loan services~~settlement.

Operations and maintenance expenses ~~increased~~were by $225.39 million, orand 6$26.~~2%,~~5 million for the ~~nine~~six-month ~~period~~periods ended ~~September~~June 30, ~~2013~~2014 ~~compared~~and to2013, ~~the~~respectively, ~~nine-month~~a ~~period~~$0.6 ~~ended September 30~~million, ~~2012~~or 2.0% decrease. The ~~increase~~decrease is primarily due to lower expenses in 2014 for integrity management, offset partially by higher labor and engine overhauls.

2120

~~Table~~Depreciation ofand ~~Contents~~amortization expenses were $19.0 million and $18.2 million for the six-month periods ended June 30, 2014 and 2013, respectively, a $0.8 million, or 4.6%, increase. The increase is primarily due to asset additions to the 2014 depreciable base for transmission mains, software development and storage lines.

~~expenses~~Taxes inother ~~2013~~than income taxes were $9.8 million and $9.2 million for ~~labor~~the six-month periods ended June 30, ~~pipeline~~2014 ~~integrity~~and ~~management~~2013, ~~outside~~respectively, ~~contracting~~a $0.6 million, ~~lube~~or ~~oil~~a 6.1% increase. The increase is primarily due to higher ad-valorem taxes as a result of higher property, plant and ~~well~~equipment ~~testing,~~being ~~offset~~placed ~~partially~~in byservice ~~lower~~during ~~expenses~~2013 ~~for~~and ~~environmental~~higher ~~remediation~~payroll and ~~compressor~~miscellaneous ~~maintenance~~taxes during 2014.

~~Administrative~~Interest ~~and~~expense ~~general~~was ~~expenses were~~ $3016.49 million and $2915.4 million for the ~~nine~~six-month periods ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013, respectively, a $1.05 million, or 39.39%, increase. The increase is ~~primarily~~a ~~due~~result toof higher ~~expenses~~interest inand ~~2013~~amortization ~~for~~expense ~~computer~~associated ~~software~~with ~~maintenance,~~the ~~employee~~Company's ~~benefits,~~revolving ~~labor~~credit agreement, and ~~fees~~the ~~associated~~issuance ~~with~~of ~~the~~$450.0 ~~Company's~~million ~~line~~of 5.125% Senior Notes. See Note 5 of ~~credit,~~the ~~offset~~accompanying ~~partially~~Notes byto ~~lower~~the ~~expenses~~Consolidated ~~for~~Financial ~~professional~~Statements ~~services~~for ~~and~~further ~~higher~~discussion ~~expenses~~of ~~transferred~~our tolong-term ~~capital~~debt.

~~Depreciation~~Gain ~~and~~on ~~amortization~~reacquired ~~expenses~~debt ~~were~~was $~~27.~~0 ~~million and $25~~.89 million for the ~~nine~~six-month ~~periods~~period ended ~~September~~June 30, ~~2013 and 2012~~2014, ~~respectively,~~ a $10.29 million, orincrease ~~4.5%~~from ~~increase.~~the six-month period ended June 30, 2013. The increase is ~~primarily~~a ~~due~~result toof ~~asset~~the ~~additions~~gain torecognized from the ~~2013~~extinguishment ~~depreciable~~of ~~base~~the ~~for~~Company's ~~transmission~~6.75% ~~mains~~Senior Notes in June 2014.

~~Taxes,~~The ~~other~~provision ~~than~~for income taxes, ~~were~~was $1312.71 million and $136.10 million for the ~~nine~~six-month periods ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013, respectively, a $0.6.1 million, or 4102.68%, increase. The increase is ~~primarily~~commensurate ~~due~~with to higher ~~expenses~~2014 ~~for ad~~pre-~~valorem~~ tax ~~in 2013~~income.

Interest expense was $23.1 million and $24.3 million for the nine-month periods ended September 30, 2013 and 2012, respectively, a $1.2 million, or 5.0%, decrease. The decrease is a result of the change in the amortization of debt discounts/premiums as a result of the Sale in the third quarter 2012, as further discussed in Note 3 of the accompanying Notes to the Consolidated Financial Statements.

The provision for income taxes was $9.4 million and $12.7 million for the nine-month periods ended September 30, 2013 and 2012, respectively, a $3.3 million, or 26.0% decrease. The decrease is commensurate with lower 2013 pre-tax income.

Liquidity and Capital Resources

We expect to ~~have sufficient funds to~~ fund our capital and other liquidity requirements ~~over the next 12 months~~ with cash on hand, and from cash flows from operating activities ~~and by drawing on a credit facility that was established in 2012~~, as discussed below.

Net cash provided by operating activities for the ~~nine~~six-month periods ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013 was $6741.14 million and $6137.46 million, respectively. Net cash from operating activities was higher in ~~2013~~2014 primarily due to ~~the~~higher ~~timing~~2014 ofoperating ~~payments~~income, ofexcluding ~~accounts payable~~depreciation, ~~lower~~resulting ~~pension~~from ~~funding~~higher inrates ~~2013~~billed ~~and~~pursuant ~~fewer~~to ~~purchases~~Central's ofgeneral ~~material~~rate ~~and~~case ~~supplies~~under ~~inventory~~FERC inDocket ~~2013~~No. ~~compared to 2012~~RP13-941. The increase was partially offset by ~~lower~~payment ~~2013~~of ~~operating~~rate ~~income,~~refunds ~~excluding depreciation,~~ and ~~higher~~a ~~employee~~2013 ~~incentive~~insurance ~~payments in 2013~~settlement. ~~Funding~~General torate ~~our~~issues ~~pension~~are ~~plans is~~ further discussed in Note 96 of the accompanying Notes to the Consolidated Financial Statements.

Net cash used in investing activities for the ~~nine~~six-month periods ended ~~September~~June 30, ~~2013~~2014 and ~~2012~~2013 was $5829.27 million and $3930.76 million, respectively. Cash used in investing activities was ~~higher~~lower in ~~2013~~2014 primarily due to ~~higher~~lower expenditures for maintenance capital, partially offset by higher capital expenditures for expansion projects.

Net cash ~~used~~provided inby financing activities for the ~~nine~~six-month ~~periods~~period ended ~~September~~June 30, ~~2013~~2014 ~~and 2012~~ was $3471.24 million ~~and~~compared to net cash used of $2024.36 million for the six-month period ended June 30, ~~respectively~~2013. The ~~increase~~change is primarily due to athe net cash provided by the issuance of Central's $5100.0 million ~~reduction~~Term inLoan and the ~~outstanding~~Company's ~~balance~~issuance of ~~the~~$450.0 ~~Company's~~million ~~credit~~of ~~facility~~5.125% Senior Notes in ~~2013~~June 2014, partially offset by the redemptions of the 6.75% Senior Notes, repayments of amounts due under the Revolving Credit Agreement and ~~higher~~Capital ~~2013~~Lease as well as higher dividend payments in 2014.

6.75% Registered Senior Notes

AtPrior ~~September 30~~to June 16, ~~2013~~2014, we had outstanding $200.0 million of 6.75% Notes registered under the Securities Act of 1933, as amended, or 6.75% Registered Notes. ~~The~~Interest ~~Bank~~on ~~of New York Mellon Trust Company, N.A. serves as trustee pursuant to~~ the ~~related indenture~~6.75% ~~Interest~~Registered isNotes was payable semi-annually on March 1 and September 1 ~~of each year~~. Prior to the Sale, the related issuance costs were being amortized over the life of the 6.75% Registered Notes utilizing the straight line method which approximated the effective interest method. As of September 24, 2012, there were no issuance costs related to the 6.75% Registered Notes included in ~~our~~the Consolidated Balance ~~Sheet~~Sheets as ~~all~~such costs were ~~written~~not ~~off~~recognized as part of the purchase price allocation. However, the premium established as a result of recognizing the debt acquired at fair value in conjunction with the Sale ~~will~~was bebeing amortized over the remaining period of the 6.75% Registered Notes utilizing the effective interest method. The 6.75% Registered Notes ~~mature~~were ~~on March 1, 2016. The 6.75% Registered Notes are~~ Southern Star’'s senior unsecured obligations and ~~rank~~ranked equal in right of payment to all of its existing and future unsecured indebtedness and ~~are~~were effectively junior to any secured indebtedness of Southern Star to the extent of the value of the assets securing such indebtedness, if any.

22On June 2, 2014, Southern Star launched a tender offer pursuant to which it offered to purchase all of its outstanding 6.75% Registered Notes. As part of this tender offer, Southern Star solicited consents to amend the indenture governing the 6.75% Registered Notes to eliminate substantially all of the covenants and certain events of default. As of June 13, 2014, Southern Star had received valid tenders and consents from holders of $146.6 million in aggregate principal amount of its 6.75% Registered Notes, which represented 73.3% of the outstanding aggregate principal amount of the 6.75% Registered

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~~The~~Notes. On ~~declaration~~June ~~and~~16, ~~payment~~2014, ofthese ~~dividends~~offers orwere ~~distributions~~accepted tofor ~~equity~~payment ~~holders,~~and ~~under~~a ~~the~~Gain ~~6.75%~~on ~~Registered~~reacquired ~~Notes~~debt ~~indenture,~~totaling ~~are~~$0.7 ~~subject~~million ~~to,~~was ~~with~~recorded. ~~certain~~At ~~limited~~June ~~exceptions~~30, a2014, ~~minimum~~Southern ~~fixed~~Star ~~charge~~had ~~coverage~~a ~~ratio~~remaining ~~and~~principal ~~cumulative~~balance ~~available~~of ~~cash~~$53.4 ~~flows~~million ~~from~~for ~~operations~~the or6.75% aRegistered ~~leverage~~Notes ~~ratio,~~reflected ~~subject~~on tothe ~~certain~~accompanying ~~conditions,~~Consolidated asBalance ~~defined in the indenture~~Sheets.

~~The~~On ~~6.75%~~July ~~Registered Notes are subject to certain covenants that restrict~~16, ~~among~~2014 ~~other things,~~ Southern Star ~~and~~completed ~~its~~the ~~subsidiaries’~~redemption ~~ability~~of tothe ~~make~~remaining ~~investments,~~6.75% ~~incur~~Registered ~~additional~~Notes ~~indebtedness,~~by ~~pay~~paying ~~dividends~~approximately or$54.8 ~~make distributions on capital stock or redeem or repurchase capital stock~~million, ~~create~~including ~~liens,~~principle ~~incur~~and ~~dividend~~interest. The orremaining ~~other~~6.75% ~~payment~~Registered ~~restrictions~~Notes ~~affecting~~had ~~subsidiaries,~~a ~~merge~~carrying orvalue ~~consolidate~~of ~~with~~$53.9 ~~other~~million. ~~entities~~An ~~and~~additional ~~enter~~gain ~~into~~of ~~transactions with affiliates~~$0.5 Wemillion ~~have~~was ~~the~~recognized ~~right~~as toa ~~redeem~~result ~~all~~of orthe ~~part~~redemption of the remaining 6.75% Registered Notes ~~at premiums defined in the indenture~~.

6.75% Unregistered Senior Notes

AtPrior ~~September 30~~to June 16, ~~2013~~2014, we had outstanding $50.0 million aggregate principal amount of 6.75% Senior Notes due 2016, or 6.75% Unregistered Notes. ~~The~~Interest ~~Bank~~on ~~of New York Mellon Trust Company, N.A. serves as trustee under~~ the ~~related indenture~~6.75% ~~Interest~~Unregistered isNotes was payable semi-annually on March 1 and September 1 ~~of each year~~. Prior to the Sale, the related issuance costs were being amortized over the life of the 6.75% Unregistered Notes utilizing the straight line method which approximated the effective interest method. As of September 24, 2012, there were no issuance costs related to the 6.75% Unregistered Notes included in ~~our~~the Consolidated Balance ~~Sheet~~Sheets as ~~all~~such costs were ~~written~~not ~~off~~recognized as part of the purchase price allocation. However, the premium established as a result of recognizing the debt acquired at fair value in conjunction with the Sale ~~will~~was bebeing amortized over the remaining period of the 6.75% Unregistered Notes utilizing the effective interest method. The 6.75% Unregistered Notes ~~will~~were ~~mature on March 1, 2016. The 6.75% Unregistered Notes are~~ senior unsecured obligations and ~~rank~~ranked equal in rights of payment to all of Southern Star’'s existing and future unsecured indebtedness and ~~are~~were effectively junior to any secured indebtedness of Southern Star to the extent of the value of the assets securing such indebtedness, if any. All covenants, restrictions, and other terms and conditions are identical to those for the 6.75% Registered Notes described above. We have the right to redeem all or part of the 6.75% Unregistered Notes at premiums defined in the indenture.

5.125% Senior Notes

On June 16, 2014, we completed a private offering, pursuant to Rule 144A of the Securities Act, of $450.0 million aggregate principal amount of 5.125% Senior Notes due 2022, or 5.125% Notes, the proceeds of which, along with the proceeds obtained through Central's term loan (discussed below), were used to retire the 6.75% Registered and Unregistered Notes, including related expenses, to pay the issuance costs of the new offering, to issue a $160.0 million dividend, to pay the outstanding balance of the Company's revolving credit agreement, and for general corporate purposes. In connection with the offering, Southern Star entered into an indenture, or 5.125% Notes Indenture, dated June 16, 2014 by and between Southern Star and The Bank of New York Mellon Trust Company, N.A., as trustee. Interest is payable semi-annually on January 15 and July 15 of each year, beginning on January 15, 2015. The 5.125% Notes will mature on July 15, 2022. The 5.125% Notes are Southern Star’s senior unsecured obligations and rank equal in right of payment to all of its future senior unsecured debt and senior in right of payment to all of its future subordinated debt, and are effectively subordinated to any of its existing and future secured indebtedness, including indebtedness under its amended and restated revolving credit facility, to the extent of the value of the assets securing such indebtedness.

Credit Agreement

The Credit Agreement contains negative covenants that, subject to significant exceptions, limit the ability of the Company and its Restricted Subsidiaries to, among other things, (i) incur debt, (ii) engage in new lines of business, (iii) incur liens, (iv) engage in mergers, consolidations, liquidations and dissolutions, (v) dispose of substantially all of the assets of the Company and its subsidiaries, (vi) make investments, loans, advances, guarantees and acquisitions, (vii) make certain restricted payments and (viii) enter into transactions with affiliates. The covenants require the Company to comply on a quarterly basis with ~~capitalization~~a ~~ratios~~leverage ratio and a minimum fixed charge coverage ratio with respect to the Company and ~~Central and~~ a ~~minimum~~capitalization ~~fixed~~ratio ~~charge~~with ~~coverage~~respect ~~ratio~~to Central. The Credit Agreement contains events of ~~default~~defaults that are customary for a facility of this nature. If an event of default occurs, the commitments of the Lenders to lend under the facility may be terminated and the maturity of the amounts outstanding may be accelerated.

Term Loan

Central’s 6.0% Senior Notes

At ~~September~~June 30, ~~2013~~2014, Central had outstanding $230.0 million aggregate principal amount of 6.0% Senior Notes due 2016, or 6.0% Notes. The Bank of New York Mellon Trust Company, N.A. serves as trustee under the related indenture. Interest is payable semi-annually on June 1 and December 1 ~~of each year~~. The related issuance costs are being amortized over the life of

~~Table~~the 6.0% Notes utilizing the straight line method. The 6.0% Notes mature on June 1, 2016 and have an overall effective interest rate of ~~Contents~~6.17%. The 6.0% Notes are Central’s senior unsecured obligations and rank equal in right of payment to all of its existing and future unsecured indebtedness and are effectively junior to the secured indebtedness of Central to the extent of the value of the assets securing such indebtedness, if any. The 6.0% Notes are structurally senior to the 5.125% and 6.75% Notes.

the life of the 6.0% Notes utilizing the straight line method which approximates the effective interest method. The 6.0% Notes mature on June 1, 2016 and have an overall effective interest rate of 6.17%. The 6.0% Notes are Central’s senior unsecured obligations and rank equal in right of payment to all of its existing and future unsecured indebtedness and are effectively junior to the secured indebtedness of Central to the extent of the value of the assets securing such indebtedness, if any. The 6.0% Notes are structurally senior to the 6.75% Notes.

Capital Lease ~~Obligation~~

In 2004, Central ~~has~~entered into a 20-year capital lease with the Owensboro-Daviess County Industrial Development Authority, or the Authority, for use of a headquarters building in Owensboro, Kentucky. Central iswas the borrower under a $9.0 million loan agreement dated as of January 1, 2004 between Central and the Authority pursuant to which the Authority financed the cost of Central’s office facility in Daviess County, Kentucky. In connection with ~~the~~this financing, the Authority issued Series 2004A and 2004B bonds under an indenture dated as of January 1, 2004 between the Authority and U.S. Bank, N. A., asor ~~trustee~~Trustee. ~~Ownership~~Approximately $7.1 million of ~~the~~assets ~~facility~~are ~~will~~included ~~transfer~~in toProperty, ~~Central~~plant ~~for~~and equipment as a ~~nominal~~capital ~~fee~~lease ~~upon~~and ~~expiration~~were being amortized over the same life as similar assets. Amortization of the ~~lease~~assets is included in ~~2024~~Depreciation and amortization in the accompanying unaudited Consolidated Financial Statements. The overall effective interest rate on the obligation iswas 6.29%. Principal and interest ~~are~~were paid semi-annually. Central ~~has~~had the option to prepay all 2004A bonds on or after January 1, 2014 and all 2004B bonds on or after February 1, 2014.

On June 2, 2014, Central prepaid all of the outstanding Series 2004A and Series 2004B bonds for approximately $4.2 million, which included interest and fees. Central is currently working with the Authority and the Trustee to terminate the lease and transfer ownership of the headquarters building to Central, the completion of which is anticipated by the end of the third quarter.

Other

As of September 30, 2013, we had 466 full-time employees at Central and none at Southern Star. Central has a collective bargaining agreement with the International Union of Operating Engineers Local No. 351, or Union, previously International Union of Operating Engineers Local No. 647, covering 138 field employees. The collective bargaining agreement was ratified on January 4, 2013 and expires on April 1, 2017.

We operate under a Federal and State Income Tax Policy that governs the allocation and payment of tax liabilities of Holdings, Southern Star and Central. This policy provides that Southern Star will file consolidated tax returns on behalf of itself, Holdings and Central and will pay all taxes shown thereon to be due. Central generally makes payments to Southern Star for its federal and state income tax liabilities as though it were filing a separate return. Southern Star has an obligation to indemnify Central for any liability that Central incurs for taxes of the affiliated group of which Southern Star and Central are members under Treasury Regulations Section 1.1502-6 and similar state statutes.

At ~~September~~June 30, ~~2013~~2014, we were in compliance with the covenants of all outstanding debt instruments. See Note 5 of the accompanying Notes to the Consolidated Financial Statements for further discussion of our debt instruments.

Other

Contractual Obligations and Commitments

We ~~expect to~~ have estimated capital expenditures of $~~127~~66.80 million in ~~2013,~~2014. ~~including~~We ~~approximately~~expect ~~$23.3~~to ~~million~~fund ~~for~~2014 ~~projects~~capital ~~under~~expenditures ~~our~~with ~~pipeline~~cash ~~integrity~~on ~~management~~hand ~~program~~and from cash flows from operating activities.

Central expects to contribute aapproximately ~~total of~~ $7.8.4 million to its Retirement and ~~Postretirement~~Post Retirement Medical Benefit Plans in ~~2013~~2014. See Note 9 of the accompanying Notes to the Consolidated Financial Statements for further discussion of our employee benefit plans.

Contractual obligations and commitments are expected to be funded with cash flows from operating activities, ~~and~~borrowings byunder ~~drawing~~the ~~upon~~Credit ~~cash~~Agreement ~~available~~or ~~pursuant~~by toaccessing ~~the~~capital ~~Credit~~markets, ~~Agreement~~if needed and available.

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Contingencies

See Note 6 of the accompanying Notes to the Consolidated Financial Statements for further information that may cause operating and financial uncertainties.

Effects of Inflation

Central generally has experienced increased costs inover ~~recent~~the last three years due to the effect of inflation on the cost of labor and benefits, materials and supplies, and property, plant and equipment. A portion of the increased expenses resulting from labor, materials and supplies can directly affect income through increased operating and administrative costs. The cumulative impact of inflation over a number of years has resulted in increased costs for current replacement of productive facilities. The majority of Central’s property, plant, equipment and inventory is subject to ratemaking treatment, and under current FERC practices, recovery is limited to authorized historical costs. While amounts in excess of historical cost are not recoverable under current FERC practices, we believe Central will be allowed to recover and earn a return based on the increased actual costs incurred when existing facilities are replaced. Cost-based regulation, along with competition and other market factors, limit Central’s ability to price services or products to reflect increased costs resulting from inflation.

Dodd-Frank Act

Certain interpretive guidance has been issued by the Commodity Futures Trading Commission, or CFTC, regarding its final rule further defining the term “swap” in accordance with Section 712(b)(1) of the Dodd-Frank Wall Street Reform and Consumer Protection Act, or Dodd-Frank Act. This guidance has raised concerns for the interstate pipeline industry as to the application of the CFTC’s rules regarding facility usage agreements that employ “two-part” rate structures consisting of a “demand” or “reservation” charge and other usage fees and those rules’ application to natural gas transportation and storage agreements and other transactions that utilize two-part rates, but that are currently regulated exclusively by the FERC. This regulation took effect October 12, 2012, although the CFTC accepted comments up to that date for further revisions and clarifications to the interpretive guidance previously issued.

Absent further guidance by the CFTC, the current rule arguably subjects all of Central’s two-part rate transportation and storage service agreements, as well as all of its capacity release transactions, to CFTC jurisdiction, creating additional recordkeeping and reporting burdens.

The Interstate Natural Gas Association of America, or INGAA, has filed on behalf of its members, including Central, two pleadings with the CFTC requesting that the interpretive guidance at issue be amended or clarified to exempt two-part fee service transactions already regulated by the FERC from further CFTC regulation under the Dodd-Frank Act. On October 9, 2012, INGAA filed a “Request for Clarification and No-Action Relief Regarding Commission Interpretive Guidance on Transportation and Storage Agreements with Two-Part Fee Structure Set Forth in the Commission’s Swap Definition Final Rule”. Besides requesting clarification that two-part rate interstate service agreements do not meet the definition of “swap” under the CFTC’s new regulations, this filing also requests the CFTC issue a no-action letter stating it will not take or recommend any enforcement action if INGAA’s member companies, including Central, do not treat such agreements as subject to the swap definition, at least for as long as and until the CFTC issues a final clarification, revision or response to the comments concerning such rule.

On October 12, 2012, INGAA submitted its “Comments on Joint Final Rule and Interpretations on Further Definition of ‘Swap’, ‘Security-Based Swap’, and ‘Security-Based Swap Agreement’; Mixed Swap; Security-Based Swap Agreement Recordkeeping (RIN No. 3038-AD46),” to the CFTC on behalf of its members, including Central. These comments contain supporting arguments and facts, which if accepted by the CFTC (and modification of the rules or interpretive guidance was implemented by the CFTC), would effectively exempt the transactions of concern to Central and all other INGAA members from CFTC jurisdiction and avoid any additional regulatory requirements.

In addition on October 12, 2012, the FERC submitted similar comments to the CFTC consistent with INGAA and its members’ position. On November 14, 2012, the CFTC's Office of General Counsel issued a Response to Frequently Asked Questions, or FAQ, clarifying that "Two-Part" rate structures are not "options" within the meaning of the CFTC rules, supporting the position taken by INGAA and its members. While Central cannot state with complete certainty that INGAA will be successful in its efforts to modify the CFTC interpretive guidance on this issue, it believes INGAA’s filings have addressed Central’s concerns and provided sufficient protection from any risk of non-compliance with the CFTC rules, at least for the short-term.

~~Table~~supporting arguments and facts, which if accepted by the CFTC (and modification of ~~Contents~~the rules or interpretive guidance was implemented by the CFTC), would effectively exempt the transactions of concern to Central and all other INGAA members from CFTC jurisdiction and avoid any additional regulatory requirements.

Seasonality

Substantially all of Central’s operating revenues are generated from fixed daily reservation fees for transportation and~~/or~~ storage services. As a result, fluctuations in natural gas prices and actual volumes transported and stored have a limited impact on Central’s operating revenues. Since the fixed daily reservation fees are generally consistent from month to month, Central’s operating revenues do not fluctuate materially from season to season.

Generally, construction and maintenance on Central’s pipeline occur ~~from~~during May through October when volume throughput is usually lower than during the winter heating season. As such, operating and maintenance expenses are ~~generally~~typically higher in the second and third quarters and the majority of our capital expenditures are incurred during this time.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

With the exception of our ~~revolving~~Credit ~~credit~~Agreement ~~facility~~and Term Loan, for which the interest ~~rate~~rates isare periodically reset, our debt has been issued at fixed rates. For fixed rate debt, changes in interest rates affect the fair value of the debt instruments but do not directly affect earnings or cash flows. ~~At September 30~~ However, ~~2013,~~a ~~the~~100 ~~weighted-average~~basis ~~interest~~point ~~rate~~change ofin ~~our~~interest ~~long-term~~rates ~~debt~~would ~~was~~result ~~6.15%.~~in ~~Our~~a ~~long-term debt issues, consisting of~~ $~~200.0~~1 million ~~6.75%~~corresponding ~~Registered~~change ~~Notes, $50.0 million 6.75% Unregistered Notes and $230.0 million 6.0% Notes, each mature~~ in ~~2016.~~annual ~~The~~interest ~~$4.0~~expense ~~million~~for ~~balance of~~ our ~~capital~~variable ~~lease obligation matures serially through 2024 and carries a fixed effective interest~~ rate ~~of 6.29%. Our~~ long-term debt ~~at September 30, 2013 had a carrying value of $483~~.3 ~~million.~~ At ~~September~~ June 30, ~~2013~~2014, the ~~fair~~weighted-average ~~value~~interest rate of our ~~6.75%~~fixed ~~Registered Notes, 6.75% Unregistered Notes,~~ and ~~6.0%~~variable ~~Notes~~long-term debt was ~~approximately $202.1 million, $50.~~5 ~~million, and $255~~.~~9 million, respectively. These fair market values were estimated by discounting the 6.75~~67% ~~Registered Notes', 6.75% Unregistered Notes',~~ and 64.000% ~~Notes’ cash flows by the current yield rate of notes with similar characteristics, as recent transactions were not available due to recent market inactivity~~respectively. At September 30, 2013, the Company had $35.0 million outstanding under our revolving credit facility with a weighted-average interest rate of 2.4%. There were no outstanding letters of credit issued under the Credit Agreement as of September 30, 2013.

Our $230.0 million (6.0% Senior Notes) and $100.0 million (Term Loan) long-term debt issues mature in 2016, while our $450.0 million (5.125% Senior Notes) long-term debt issue matures in 2022. Our long-term debt at June 30, 2014, excluding the current portion of our long-term debt, had a carrying value of $779.9 million, while the fair value of our 5.125% Senior Notes, and Central's 6.0% Notes and Term Loan, were approximately $457.9 million, $246.3 million, and $100.0 million, respectively. The estimated fair market values of the Company’s 5.125% Senior Notes and Central's 6.0% Notes were calculated by discounting the Notes' cash flows by their respective yield rates as determined by recent market activity. The carrying value of Central's Term Loan approximates fair market value due to the variable interest rate associated with the Term Loan. At June 30, 2014, the Company had no amounts outstanding, nor any outstanding letters of credit issued, under the revolving credit facility.

Item 4. Controls and Procedures

Disclosure Controls and Procedures – As of ~~September~~June 30, ~~2013~~2014, we, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, evaluated the effectiveness of our disclosure controls and procedures as defined in ~~Exchange Act~~ Rules 13a – 15(e) and 15d – 15(e) of the Securities Exchange Act of 1934, as amended. Based upon that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the disclosure controls and procedures were effective as of ~~September~~June 30, ~~2013~~2014.

Changes in Internal Control Over Financial Reporting – There has been no change in our internal control over financial reporting during the quarter ended ~~September~~June 30, ~~2013~~2014, that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II - OTHER INFORMATION

Item 1. Legal Proceedings

~~Will Price, et al~~None. ~~v. El Paso Natural Gas Co., et al., Case No. 99 C 30, District Court, Stevens County, Kansas, or Price Litigation I~~

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defendants petitioned for interlocutory review of that ruling, but the Court of Appeals of Kansas denied their request on February 23, 2012. It is unknown whether Plaintiffs will follow through on discovery and/or otherwise proceed with the litigation on a non-class basis. Central cannot predict the outcome of this litigation or estimate a range of reasonably possible losses, if any.

Will Price, et al. v. El Paso Natural Gas Co., et al., Case No. 03 C 23, District Court, Stevens County, Kansas, or Price Litigation II

In this putative class action filed May 12, 2003, the named Plaintiffs from Case No. 99 C 30 (discussed above) have sued the same defendants, including Central. Asserting substantially identical legal and/or equitable theories, as in Price Litigation I, this petition alleges that the defendants have under measured the British thermal units, or Btu, content of, and therefore have underpaid for, the natural gas they have obtained from or measured for Plaintiffs. Plaintiffs seek unspecified actual damages, attorney fees, pre- and post-judgment interest, and reserved the right to plead for punitive damages. On November 10, 2003, an answer to that pleading was filed on behalf of Central. The Plaintiffs’ motion seeking class certification, along with Plaintiffs’ second class certification motion in Price Litigation I, was fully briefed and the Court heard oral argument on this motion on April 1, 2005. On September 18, 2009, the Court denied the Plaintiffs’ motion for class certification. The Plaintiffs filed a motion to reconsider that ruling on October 2, 2009. The defendants, including Central, filed a response in opposition to the Plaintiffs’ motion for reconsideration on January 18, 2010. The Plaintiffs filed a reply and oral argument, which was presented before a different judge, was heard on February 10, 2010. By order dated March 31, 2010, the Court denied the Plaintiffs’ October 2, 2009 motion to reconsider the earlier denial of class certification. The Plaintiffs did not file for interlocutory review of the March 31, 2010 order, but through their counsel they have initiated certain discovery to which Central and other defendants have objected. In late June of 2011, certain defendants other than Central filed motions for summary judgment seeking, among other things, a ruling on the legal issue of whether or not Plaintiffs' civil conspiracy claim could be based upon their underlying unjust enrichment claim. In January of 2012, the Court issued an order concluding that under Kansas law a conspiracy claim could be so based. These defendants petitioned for interlocutory review of that ruling, but the Court of Appeals of Kansas denied their request on February 23, 2012. It is unknown whether Plaintiffs will follow through on discovery and/or otherwise proceed with the litigation on a non-class basis. Central cannot predict the outcome of this litigation or estimate a range of reasonably possible losses, if any.

Item 1A. Risk Factors

See our ~~2012~~2013 Annual Report on Form 10-K filed with the SEC on March 2628, ~~2013~~2014, asor ~~amended~~2013 byAnnual ~~Form 10-K/A filed with the SEC on April 9~~Report, ~~2013,~~ which includes a detailed discussion of our risk factors under “Item 1A,. “Risk Factors”.” NoExcept ~~updates~~as set forth below, there have been no material changes to this information. The following risk factors are ~~necessary~~updated from the comparably titled risk factors included in our 2013 Annual Report. All capitalized terms used in the following risk factors and not otherwise defined herein shall have the respective meanings assigned to such terms in our 2013 Annual Report.

Changes in our regulatory environment and events in the energy markets are beyond our control and may significantly affect our costs and access to capital markets.

Our rates and operations are subject to regulation by federal regulators as well as the actions of the federal and state legislatures and, in some respects, state and local regulators. Additionally, because of the volatility of natural gas prices, the bankruptcy filings by certain energy companies and investigations by governmental authorities into energy trading activities, many energy and utility businesses have generally been under increased scrutiny by the public, state and federal regulators, the capital markets, government anti-trust agencies and the rating agencies. Furthermore, the nature and degree of regulation of natural gas companies has changed significantly during the past 30 years, and any further additional changes in regulations or new interpretation of existing regulations may result in increased costs or impede our ability to access capital markets.

We are subject to numerous environmental laws and regulations that may increase our cost of operations, or expose us to liabilities, some of which may not be recoverable through rates.

Laws and regulations relating to environmental protection can result in increased capital expenditures required for compliance, operating costs and other expenditures. These laws and regulations generally require us to observe operational limitations, control pollution and avoid hazardous substance releases. In addition, many of our facilities and operations must obtain permits for construction or operation, including reviews of environmental impact by federal and state agencies. Such environmental laws impose restrictions on the generation, handling, treatment, storage, disposal and transportation of certain materials and wastes.

These requirements of environmental laws and regulations are complex, can impose penalties for inadvertent and unintentional violations, and may expose us to claims and litigation that cannot be predicted or avoided. We cannot predict the initiation, outcome or effect of any action or litigation that may arise from applicable environmental regulations or from normal operations, accidental releases or violations.

Existing environmental laws and regulations may be revised and new laws and regulations may be adopted or become applicable to us. Similarly, the terms of permits issued for construction or operation may change over time. New or revised laws, regulations and permits may result in increased and unexpected compliance costs or additional operating restrictions, and could have a material adverse effect on our business, financial position or results of operations. Regulations and permit requirements under the Clean Air Act are constantly changing and becoming more restrictive, which could impose material capital costs, and operational changes, upon our facilities and business.

Regulation under the federal Clean Air Act is driven partly by the locations of facilities that are subject to regulation under the Clean Air Act. Those that are located in areas that fail to meet federal ambient air quality standards (known as “non-attainment areas”) are subject to more restrictive and sometimes retroactive air regulatory requirements. All of Central’s compressor stations are located in areas currently designated as being in attainment of the NAAQS, so we do not project any mandatory emission reductions at this time based on non-attainment requirements. However, EPA reviews and revisits attainment designations periodically based on ambient monitoring data and may redesignate areas as not being in attainment. At least one of our facilities is located in an area under consideration for such reclassification. Such changes in regulatory status can result in material new requirements, including retrofit requirements. It is not possible to predict with certainty whether any areas where our compressor stations are located could become non-attainment areas in the future.

We have an active program to identify and clean up contamination at our facilities. In general, the known contamination is limited to soils within the property boundaries of the sites. Our facilities are known to be contaminated by polychlorinated biphenyls, or PCBs, natural gas liquids and mercury, to varying degrees. Most known contamination is contained, capped or otherwise not required to be removed or remediated. As of December 31, 2013, we were aware of mercury contamination that requires characterization at approximately nine of our meter sites, covering three states with remediation anticipated at all nine sites. While the annual cleanup costs associated with such matters in recent years has normally not exceeded $1.0 million in operating costs, cleanup requirements are subject to governmental agency discretion and changing circumstances, making actual cleanup costs difficult to predict. We have an accrued liability of approximately

$1.0 million as of December 31, 2013, representing our estimate of future cleanup costs, most of which is expected to be expended within three to four years.

Certain environmental laws impose strict, joint and several liability for costs required to clean up and restore sites where hazardous substances have been disposed or otherwise released. Accordingly, in addition to being liable for environmental costs relating to properties we currently own, we may be liable for costs of cleaning up contamination caused by releases of hazardous substances at properties that we do not own or operate or have not owned or operated, or at properties to which hazardous substances originating from our business were transported. We have one such pending matter that we do not believe is material, but may be subject to additional or future claims that are presently unknown to us.

Furthermore, in connection with improvements and modifications to our facilities and operations, we sometimes require governmental permits and approvals that are time consuming and uncertain. We may not be able to obtain all environmental regulatory approvals in the future that are necessary for our business and may not be able to obtain them at the time required to execute business plans. If there is a delay in obtaining any required environmental regulatory approval, including for future expansion projects, or if we fail to obtain, maintain or comply with any such approval, operations at our affected facilities could be temporarily limited or subjected to additional costs, which could have a material adverse effect on our business, financial position and results of operations.

Some environmental costs may be recovered through rates as an ordinary cost of conducting business and complying with laws. Most environmental costs are not recoverable from third parties, either through indemnities or insurance. Some environmental costs, such as those incurred to clean up past releases of hazardous substances, may be excluded from rate or other recovery. Therefore, some of our environmental costs may adversely affect our financial position and ability to make payments of principal or interest on our securities or other forms of indebtedness.

Climate change legislation or regulation could result in increased operating and capital costs for us.

Greenhouse gas emissions have been associated with warming of the Earth’s atmosphere and climate change. As a result, EPA and some state agencies have taken steps to require reporting and regulation of greenhouse gas emissions. New major stationary sources are required to obtain construction permits that include greenhouse gas emission limits, but our facilities were constructed before such limits went into effect and are not subject to greenhouse gas limits applicable to new major sources. Existing facilities are, however, required to report greenhouse gas emissions. Methane, a primary component of natural gas, and carbon dioxide, a byproduct of the burning of natural gas, are examples of greenhouse gases. Both are emitted by our operations, including from our compressor stations, and are reported by Central as required. Greenhouse gas regulation is subject to change, and the requirements relating to such regulation could affect our operations, as well as those of our customers, making the production, use, transport and combustion of natural gas more expensive. Passage of climate control legislation or new regulations issued by EPA or analogous state agencies that regulate or restrict emissions of greenhouse gases could result in changes to the consumption and demand for natural gas and carbon dioxide produced from our source fields and could have adverse effects on our business, financial position, results of operations and prospects.

Decreases in the availability of natural gas supplies could have a significant negative impact on our revenues and results of operations.

Our operating results are dependent upon our customers having access to adequate supplies of natural gas. We depend on having access to multiple sources of gas production so that customers can satisfy their total gas requirements and have the opportunity to source gas at the lowest overall delivered cost. Moreover, we do not have the ability to operate our pipeline system at full capacity without access to multiple gas sources. The ability of producers to maintain production is dependent on the prevailing market price of natural gas, the exploration and production budgets of the major and independent gas companies, the depletion rate of existing sources, the success of new sources, environmental concerns, regulatory initiatives and other matters beyond our control.

A major factor in the price and supply of natural gas is the availability of gas trapped in shale and other rock formations that may be extracted by high-pressure fracturing and directional drilling, or “fracking”. This practice is relatively new and is being scrutinized carefully for environmental and other impacts, such as subsidence or increasing earthquake risk. Environmental groups are actively seeking to oppose projects that utilize fracking, and are seeking increased regulation. Curtailment of or significant regulating of fracking could adversely affect price and supply of natural gas, and therefore affect our business and financial position.

Additionally, some of our customers deliver gas to our pipeline system through other pipelines. Operational failures on those other pipelines, such as reductions in pressure or volume, or interruptions in service due to maintenance activities or

unanticipated emergencies, could result in lower volumes of gas being available to us for transportation. We cannot provide assurance that production or supplies of natural gas available to our customers will be maintained at sufficient levels to sustain our expected volume of transportation commitments on our pipeline system or that multiple sources of gas will remain available to provide our customers with access to sufficient low cost supplies. If the availability of natural gas supplies decreases, our revenues and results of operations could be adversely affected.

Department of Transportation and other pipeline safety regulations may impose significant costs and liabilities on us.

The U.S. Department of Transportation, or DOT, through the Pipeline and Hazardous Materials Safety Administration, regulates all aspects of the design, construction, operation and maintenance of our pipeline facilities. Failure to comply with these regulations could result in the assessment of fines or penalties against the Company. These regulations require, among other things, that pipeline operators engage in a regular program of pipeline integrity testing to assess, evaluate, repair and validate the integrity of their pipelines within areas of high consequence. Determination of such high consequence areas, for natural gas transmission pipelines, is primarily based on population. In response to these regulations, we have developed a pipeline integrity program to conduct pipeline integrity tests on a risk-prioritized basis. Depending on the results of these integrity tests and other integrity program activities, we could incur significant and unexpected capital and operating expenditures, not included in our current budgets, in order to conduct remedial activities on our pipeline to ensure our continued safe and reliable operation.

While such programs reduce the risk of pipeline failures, accidents and explosions, they do not eliminate such risks. Recent pipeline incidents in the U.S. have heightened regulatory and public concerns about pipeline safety requirements. As a result, a number of proposed rules and possible federal legislative actions have been introduced which could impose restrictions on Central’s operations or require more stringent testing to ensure pipeline integrity. Adherence to such final regulations could increase our costs of compliance with pipeline integrity and safety regulations, which could have an adverse effect on our business, financial position and results of operations. As with other regulatory areas, the relevant legislation and regulations are subject to change and new interpretations, any of which could impose new requirements upon our business, and result in increased capital or operating costs.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

None.

Item 5. Other Information

None.

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Item 6. Exhibits

4.91	Indenture, dated as of June 16, 2014, between Southern Star Central Corp. and The Bank of New York Mellon Trust Company, N.A., as trustee.
10.111	Third Amendment, dated as of June 16, 2014, by and among the Company, Royal Bank of Canada, as a lender and issuing lender, Bank of America, N.A., as a lender, and Royal Bank of Canada, as administrative agent.
10.121	Credit Agreement, dated as of June 16, 2014, by and among Central, the several banks and other financial institutions or entities from time to time party thereto and Royal Bank of Canada, as administrative agent.
31.1	—Certificate of Jerry L. Morris, Chief Executive Officer of Southern Star Central Corp., pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	—Certificate of Susanne W. Harris, Chief Financial Officer of Southern Star Central Corp., pursuant to Section 302 of the Sarbanes-Oxley Act 2002.
32	—Certificate of Jerry L. Morris, Chief Executive Officer of Southern Star Central Corp., and Susanne W. Harris, Chief Financial Officer of Southern Star Central Corp., pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema Document
101.CAL	XBRL Taxonomy Calculation Linkbase Document
101.DEF	XBRL Taxonomy Extension Definitions Document
101.LAB	XBRL Taxonomy Label Linkbase Document
101.PRE	XBRL Taxonomy Presentation Linkbase Document

_________________________

28(1) Incorporated by reference from Southern Star Central Corp.'s Report on Form 8-K filed with the SEC on June 18, 2014.

~~Table of Contents~~30

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.

	SOUTHERN STAR CENTRAL CORP.
November 8, 2013	By:	/s/ JERRY L. MORRIS
August 8, 2014	By:	/s/ JERRY L. MORRIS
		Jerry L. MorrisPresident and Chief Executive Officer
November 8, 2013	By:	/s/ SUSANNE W. HARRIS
August 8, 2014	By:	/s/ SUSANNE W. HARRIS
		Susanne W. HarrisVice President, Chief Financial Officer and Treasurer

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INDEX TO EXHIBITS

4.91	Indenture, dated as of June 16, 2014, between Southern Star Central Corp. and The Bank of New York Mellon Trust Company, N.A., as trustee.
10.111	Third Amendment, dated as of June 16, 2014, by and among the Company, Royal Bank of Canada, as a lender and issuing lender, Bank of America, N.A., as a lender, and Royal Bank of Canada, as administrative agent.
10.121	Credit Agreement, dated as of June 16, 2014, by and among Central, the several banks and other financial institutions or entities from time to time party thereto and Royal Bank of Canada, as administrative agent.
31.1	—Certificate of Jerry L. Morris, Chief Executive Officer of Southern Star Central Corp., pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	—Certificate of Susanne W. Harris, Chief Financial Officer of Southern Star Central Corp., pursuant to Section 302 of the Sarbanes-Oxley Act 2002.
32	—Certificate of Jerry L. Morris, Chief Executive Officer of Southern Star Central Corp., and Susanne W. Harris, Chief Financial Officer of Southern Star Central Corp., pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema Document
101.CAL	XBRL Taxonomy Calculation Linkbase Document
101.DEF	XBRL Taxonomy Extension Definitions Document
101.LAB	XBRL Taxonomy Label Linkbase Document
101.PRE	XBRL Taxonomy Presentation Linkbase Document

_________________________

30(1) Incorporated by reference from Southern Star Central Corp.'s Report on Form 8-K filed with the SEC on June 18, 2014.

~~Table of Contents~~32

Exhibit 31.1

CERTIFICATION PURSUANT TO RULES 13a – 14(a) OR 15d – 14(a)

UNDER THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Jerry L. Morris, Chief Executive Officer of Southern Star Central Corp., certify that:


1.	I have reviewed this quarterly report on Form 10-Q of Southern Star Central Corp.;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a - 15(e) and 15d - 15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a -15(f) and 15d – 15(f)) for the registrant and have:


(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


(c)	Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


(d)	Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and


5.	The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):


(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and


(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

	Signature	Title	Date
By:	/s/ JERRY L. MORRIS	Chief Executive Officer	~~November~~August 8, ~~2013~~2014
	Jerry L. Morris

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Exhibit 31.2

CERTIFICATION PURSUANT TO RULES 13a – 14(a) OR 15d – 14(a)

UNDER THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Susanne W. Harris, Chief Financial Officer of Southern Star Central Corp., certify that:


1.	I have reviewed this quarterly report on Form 10-Q of Southern Star Central Corp.;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a - 15(e) and 15d - 15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a -15(f) and 15d – 15(f)) for the registrant and have:


(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


(c)	Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


(d)	Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and


5.	The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):


(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and


(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

	Signature	Title	Date
By:	/s/ SUSANNE W. HARRIS	Chief Financial Officer	~~November~~August 8, ~~2013~~2014
	Susanne W. Harris

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Exhibit 32

CERTIFICATION PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

(18 U.S.C. SECTION 1350)

In connection with the Quarterly Report on Form 10-Q of Southern Star Central Corp. (the Company), a Delaware corporation, for the quarter ended ~~September~~June 30, ~~2013~~2014 as filed with the Securities and Exchange Commission on the date hereof (the Report), each of the undersigned, Jerry L. Morris, Chief Executive Officer of the Company, and Susanne W. Harris, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of his/her knowledge, that:


(1)	The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and


(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of and for the periods presented in the Report.

The foregoing certification is provided solely for purposes of complying with the provisions of Section 906 of the Sarbanes-Oxley Act of 2002 and is not intended to be used or relied upon for any other purpose.

	Signature	Title	Date
By:	/s/ JERRY L. MORRIS	Chief Executive Officer	~~November~~August 8, ~~2013~~2014
	Jerry L. Morris
By:	/s/ SUSANNE W. HARRIS	Chief Financial Officer	~~November~~August 8, ~~2013~~2014
	Susanne W. Harris

A signed original of this written statement required by Section 906 has been provided to Southern Star Central Corp. and will be retained by Southern Star Central Corp. and furnished to the Securities and Exchange Commission or staff upon request.

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