UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

þ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~September 30, 2014~~March 31, 2015

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number 001-16189

NiSource Inc.

(Exact name of registrant as specified in its charter)



Delaware		35-2108964
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

801 East 86th Avenue Merrillville, Indiana		46410
(Address of principal executive offices)		(Zip Code)

(877) 647-5990

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes þ No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (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.)

Yesþ 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. (Check one):

Large accelerated filer þ Accelerated filer ¨

Non-accelerated filer ¨ 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 þ

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date: Common Stock, $0.01 Par Value: ~~315,699,826~~317,377,794 shares outstanding at ~~October~~April 23, ~~2014~~.2015.

NISOURCE INC.

FORM 10-Q QUARTERLY REPORT

FOR THE QUARTER ENDED ~~SEPTEMBER 30, 2014~~MARCH 31, 2015

Table of Contents



			Page

	Defined Terms		3

PART I	FINANCIAL INFORMATION

	Item 1.	Financial Statements - unaudited

		Condensed Statements of Consolidated Income (unaudited)	6

		Condensed Statements of Consolidated Comprehensive Income (unaudited)	7

		Condensed Consolidated Balance Sheets (unaudited)	8

		Condensed Statements of Consolidated Cash Flows (unaudited)	10

		Condensed Statement of Consolidated ~~Common Stockholders'~~ Equity (unaudited)	11

		Notes to Condensed Consolidated Financial Statements (unaudited)	12

	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3430

	Item 3.	Quantitative and Qualitative Disclosures About Market Risk	5850

	Item 4.	Controls and Procedures	5850

PART II	OTHER INFORMATION

	Item 1.	Legal Proceedings	5951

	Item 1A.	Risk Factors	5951

	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	6051

	Item 3.	Defaults Upon Senior Securities	6051

	Item 4.	Mine Safety Disclosures	6051

	Item 5.	Other Information	6051

	Item 6.	Exhibits	6152

	Signature		6253

DEFINED TERMS The following is a list of frequently used abbreviations or acronyms that are found in this report:

NiSource Subsidiaries and Affiliates
Capital Markets	NiSource Capital Markets, Inc.
CER	Columbia Energy Resources, Inc.
CEVCO	Columbia Energy Ventures, LLC
CGORC	Columbia Gas of Ohio Receivables Corporation
Columbia	Columbia Energy Group
Columbia Gulf	Columbia Gulf Transmission Company, LLC
Columbia Midstream	Columbia Midstream Group, LLC
Columbia of Kentucky	Columbia Gas of Kentucky, Inc.
Columbia of Maryland	Columbia Gas of Maryland, Inc.
Columbia of Massachusetts	Bay State Gas Company
Columbia of Ohio	Columbia Gas of Ohio, Inc.
Columbia OpCo	CPG OpCo LP
Columbia of Pennsylvania	Columbia Gas of Pennsylvania, Inc.
Columbia of Virginia	Columbia Gas of Virginia, Inc.
Columbia Transmission	Columbia Gas Transmission, LLC
CPG	Columbia Pipeline Group
CPPL	Columbia Pipeline Partners LP
CPRC	Columbia Gas of Pennsylvania Receivables Corporation
Crossroads Pipeline	Crossroads Pipeline Company
Hardy Storage	Hardy Storage Company, LLC
~~Kokomo Gas~~	~~Kokomo Gas and Fuel Company~~
Millennium	Millennium Pipeline Company, L.L.C.
NARC	NIPSCO Accounts Receivable Corporation
NDC Douglas Properties	NDC Douglas Properties, Inc.
~~NEVCO~~	~~NiSource Energy Ventures, LLC~~
NIPSCO	Northern Indiana Public Service Company
NiSource	NiSource Inc.
NiSource Corporate Services	NiSource Corporate Services Company
NiSource Development Company	NiSource Development Company, Inc.
NiSource Finance	NiSource Finance Corp.
~~Northern Indiana Fuel and Light~~	~~Northern Indiana Fuel and Light Company~~
~~NiSource Midstream~~	~~NiSource Midstream Services, LLC~~
Pennant	Pennant Midstream, LLC

Abbreviations
AFUDC	Allowance for funds used during construction
AOC	Administrative Order by Consent
AOCI	Accumulated Other Comprehensive Income (Loss)
ASU	Accounting Standards Update
BBA	British Banker Association
Bcf	Billion cubic feet
BNS	Bank of Nova Scotia
BTMU	The Bank of Tokyo-Mitsubishi UFJ, LTD.
BTU	British Thermal Unit
CAA	Clean Air Act
CAIR	Clean Air Interstate Rule
~~CAMR~~	~~Clean Air Mercury Rule~~

DEFINED TERMS (continued)

CAMR	Clean Air Mercury Rule
CCRs	Coal Combustion Residuals
CCRM	Capital Cost Recovery Mechanism
CERCLA	Comprehensive Environmental Response Compensation and Liability Act (also known as Superfund)
CO₂	Carbon Dioxide
~~CSAPR~~	~~Cross-State Air Pollution Rule~~
DEP	Department of Environmental Protection
DIMP	Distribution Integrity Management Program
DPU	Department of Public Utilities
DSM	Demand Side Management
Dth	Dekatherm
Dth/d	Dekatherm per day
ECR	Environmental Cost Recovery
ECRM	Environmental Cost Recovery Mechanism
ECT	Environmental Cost Tracker
EERM	Environmental Expense Recovery Mechanism
EPA	United States Environmental Protection Agency
EPS	Earnings per share
FAC	Fuel adjustment clause
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FGD	Flue Gas Desulfurization
FTRs	Financial Transmission Rights
GAAP	Generally Accepted Accounting Principles
GAF	Gas Adjustment Factor
GCIM	Gas Cost Incentive Mechanism
GCR	Gas cost recovery
GHG	Greenhouse gases
gwh	Gigawatt hours
Hilcorp	Hilcorp Energy Company
hp	Horsepower
IDEM	Indiana Department of Environmental Management
IPO	Initial Public Offering
INDIEC	Indiana Industrial Energy Consumers, Inc.
IRP	Infrastructure Replacement Program
IURC	Indiana Utility Regulatory Commission
kV	Kilovolt
LDAF	Local Distribution Adjustment Factor
LDCs	Local distribution companies
LIBOR	London InterBank Offered Rate
LIFO	Last-in, first-out
LNG	Liquefied Natural Gas
MATS	Mercury and Air Toxics Standards
Mcf	Thousand cubic feet
MMcf	Million cubic feet

DEFINED TERMS (continued)

MGP	Manufactured Gas Plant
MISO	Midcontinent Independent System Operator
Mizuho	Mizuho Corporate Bank Ltd.
MLP	Master Limited Partnership
MMDth	Million dekatherms
mw	Megawatts

~~DEFINED TERMS (continued)~~

mwh	Megawatt hours
NAAQS	National Ambient Air Quality Standards
NGL	Natural Gas Liquids
NOV	Notice of Violation
NO₂	Nitrogen dioxide
NOx	Nitrogen oxide
NYMEX	New York Mercantile Exchange
OCI	Other Comprehensive Income (Loss)
OPEB	Other Postretirement Benefits
OUCC	Indiana Office of Utility Consumer Counselor
PEF	Pension Expense Factor
Piedmont	Piedmont Natural Gas Company, Inc.
PM	Particulate matter
PNC	PNC Bank, N.A.
Proposed Separation	On September 28, 2014, NiSource announced that its Board of Directors had approved in principle plans to separate its natural gas pipeline and related businesses into a stand-alone publicly traded company.
PUC	Public Utility Commission
PUCO	Public Utilities Commission of Ohio
RA	Resource Adequacy
RAAF	Residential Assistance Adjustment Factor
RACT	Reasonably Available Control Technology
RBS	Royal Bank of Scotland, PLC
RTO	Regional Transmission Organization
SAVE	Steps to ~~Achieve~~Advance Virginia’s Energy
SEC	Securities and Exchange Commission
SIP	State Implementation Plan
SO₂	Sulfur dioxide
TDSIC	Transmission, Distribution and Storage System Improvement Charge
TUAs	Transmission Upgrade Agreements
VIE	Variable Interest Entities
VSCC	Virginia State Corporation Commission

Table of Contents

PART I

ITEM 1. FINANCIAL STATEMENTS

NiSource Inc.

Condensed Statements of Consolidated Income (unaudited)


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
(in millions, except per share amounts)	2014			2013			2014			2013			2015			2014
Net Revenues	Net Revenues												Net Revenues
Gas Distribution	$	240.3		$	255.1		$	1,878.8		$	1,540.6		$	1,080.7		$	1,215.0
Gas Transportation and Storage	381.7			346.9			1,350.3			1,181.9			628.0			578.5
Electric	424.6			413.4			1,279.4			1,175.2			394.7			450.0
Other	77.3			61.4			271.0			162.8			46.3			77.0
Gross Revenues	1,123.9			1,076.8			4,779.5			4,060.5			2,149.7			2,320.5
Cost of Sales (excluding depreciation and amortization)	230.5			243.0			1,663.5			1,268.3			806.0			1,061.3
Total Net Revenues	893.4			833.8			3,116.0			2,792.2			1,343.7			1,259.2
Operating Expenses
Operation and maintenance	529.5			468.9			1,563.8			1,375.6			574.1			501.2
Depreciation and amortization	153.0			144.5			450.8			431.4			157.5			148.7
Gain on sale of assets, net	(2.9		)	(9.8		)	(19.3		)	(10.2		)
Gain on sale of assets													(5.0		)	(15.7		)
Other taxes	68.0			64.3			242.5			221.7			102.4			101.1
Total Operating Expenses	747.6			667.9			2,237.8			2,018.5			829.0			735.3
Equity Earnings in Unconsolidated Affiliates	12.0			10.5			32.9			25.6			15.4			9.8
Operating Income	157.8			176.4			911.1			799.3			530.1			533.7
Other Income (Deductions)
Interest expense, net	(109.6		)	(103.7		)	(327.8		)	(304.3		)	(111.0		)	(109.1		)
Other, net	9.2			4.7			21.2			22.1			7.1			4.5
Total Other Deductions	(100.4		)	(99.0		)	(306.6		)	(282.2		)	(103.9		)	(104.6		)
Income from Continuing Operations before Income Taxes	57.4			77.4			604.5			517.1			426.2			429.1
Income Taxes	25.9			27.9			228.1			179.2			150.9			162.7
Income from Continuing Operations	31.5			49.5			376.4			337.9			275.3			266.4
(Loss) Income from Discontinued Operations - net of taxes	(0.1		)	0.1			(0.6		)	7.5
(Loss) Gain on Disposition of Discontinued Operations - net of taxes	—			(1.5		)	—			34.9
Loss from Discontinued Operations - net of taxes													—			(0.2		)
Net Income	$	31.4		$	48.1		$	375.8		$	380.3		275.3			266.2
Less: Net income attributable to noncontrolling interest													6.9			—
Net Income attributable to NiSource													$	268.4		$	266.2
Amounts attributable to NiSource:
Income from continuing operations													$	268.4		$	266.4
Loss from discontinued operations													—			(0.2		)
Net Income attributable to NiSource													$	268.4		$	266.2
Basic Earnings Per Share
Continuing operations	$	0.10		$	0.16		$	1.19		$	1.08		$	0.85		$	0.85
Discontinued operations	—			—			—			0.14			—			—
Basic Earnings Per Share	$	0.10		$	0.16		$	1.19		$	1.22		$	0.85		$	0.85
Diluted Earnings Per Share
Continuing operations	$	0.10		$	0.16		$	1.19		$	1.08		$	0.85		$	0.85
Discontinued operations	—			—			—			0.14			—			—
Diluted Earnings Per Share	$	0.10		$	0.16		$	1.19		$	1.22		$	0.85		$	0.85
Dividends Declared Per Common Share	$	0.26		$	0.25		$	1.02		$	0.98		$	0.52		$	0.50
Basic Average Common Shares Outstanding	315.4			312.8			314.9			312.1			316.6			314.2
Diluted Average Common Shares	316.6			313.8			316.0			313.0			317.4			315.1

The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Condensed Statements of Consolidated Comprehensive Income (unaudited)

Three Months Ended
September 30, Nine Months Ended September 30,
(in millions, net of taxes) 2014 2013 2014 2013
Net Income $ 31.4
$ 48.1
$ 375.8
$ 380.3
Other comprehensive income (loss)
Net unrealized (loss) gain on available-for-sale securities⁽¹⁾
(0.6 ) 0.9
0.2
(2.4 )
Net unrealized gain on cash flow hedges⁽²⁾
0.6
0.6
1.9
2.0
Unrecognized pension and OPEB (cost) benefit⁽³⁾
(0.2 ) 0.1
(0.1 ) 5.5
Total other comprehensive (loss) income (0.2 ) 1.6
2.0
5.1
Total Comprehensive Income $ 31.2
$ 49.7
$ 377.8
$ 385.4



	Three Months Ended March 31,
(in millions, net of taxes)	2015		2014
Net Income	$	275.3	$	266.2
Other comprehensive income
Net unrealized gain on available-for-sale securities⁽¹⁾	0.9		0.3
Net unrealized gain on cash flow hedges⁽²⁾	0.9		0.6
Unrecognized pension and OPEB benefit⁽³⁾	0.2		0.2
Total other comprehensive income	2.0		1.1
Comprehensive Income	$	277.3	$	267.3
Less: Comprehensive income attributable to noncontrolling interest	6.9		—
Comprehensive Income attributable to NiSource	$	270.4	$	267.3

⁽¹⁾ Net unrealized ~~(loss)~~ gain on available-for-sale securities, net of $~~0.3~~0.5 million ~~tax benefit~~ and $~~0.5~~0.2 million tax expense in the ~~third~~first quarter of ~~2014~~2015 and ~~2013, respectively, and $0.1 million tax expense and $1.3 million tax benefit for the nine months ended~~ 2014 ~~and~~ ~~2013~~, respectively.

⁽²⁾Net unrealized gains on derivatives qualifying as cash flow hedges, net of $0.4 million and $0.4 million tax expense in the ~~third~~first quarter of ~~2014~~2015 and ~~2013, and $1.2 million and $1.3 million tax expense for the nine months ended~~ 2014 ~~and~~ ~~2013~~, respectively.

⁽³⁾Unrecognized pension and OPEB ~~(cost)~~ benefit, net of ~~zero~~$0.1 million ~~tax benefit~~ and zero tax expense in the ~~third~~first quarter of ~~2014~~2015 and ~~2013, respectively, and $0.7 million tax benefit and $3.5 million tax expense for the nine months ended~~ 2014 ~~and~~ ~~2013~~, respectively.

The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc. Condensed Consolidated Balance Sheets (unaudited)	NiSource Inc. Condensed Consolidated Balance Sheets (unaudited)						NiSource Inc. Condensed Consolidated Balance Sheets (unaudited)

(in millions)	September 30, 2014			December 31, 2013			March 31, 2015			December 31, 2014
ASSETS
Property, Plant and Equipment
Utility plant	$	24,775.7		$	23,303.7		$	25,593.9		$	25,234.8
Accumulated depreciation and amortization	(9,533.2		)	(9,256.5		)	(9,686.7		)	(9,578.6		)
Net utility plant	15,242.5			14,047.2			15,907.2			15,656.2
Other property, at cost, less accumulated depreciation	344.0			317.9			376.2			360.9
Net Property, Plant and Equipment	15,586.5			14,365.1			16,283.4			16,017.1
Investments and Other Assets
Unconsolidated affiliates	443.5			373.7			447.9			452.6
Other investments	211.7			204.0			208.7			210.4
Total Investments and Other Assets	655.2			577.7			656.6			663.0
Current Assets
Cash and cash equivalents	17.7			26.8			42.0			25.4
Restricted cash	16.0			8.0			21.6			24.9
Accounts receivable (less reserve of $18.4 and $23.5, respectively)	639.3			1,005.8
Accounts receivable (less reserve of $40.3 and $25.2, respectively)							1,152.0			1,070.1
Gas inventory	513.0			354.6			134.4			445.1
Underrecovered gas and fuel costs	54.7			46.4			25.5			32.0
Materials and supplies, at average cost	106.4			101.2			109.0			106.0
Electric production fuel, at average cost	48.2			44.6			75.5			64.8
Exchange gas receivable	80.9			70.6			77.0			63.1
Regulatory assets	200.1			142.8			159.5			193.5
Deferred income taxes	231.7			175.3			277.2			272.1
Prepayments and other	103.6			183.1			187.3			169.5
Total Current Assets	2,011.6			2,159.2			2,261.0			2,466.5
Other Assets
Regulatory assets	1,440.9			1,522.2			1,683.2			1,696.4
Goodwill	3,666.2			3,666.2			3,666.2			3,666.2
Intangible assets	267.4			275.7			261.9			264.7
Deferred charges and other	82.3			87.8			86.6			92.4
Total Other Assets	5,456.8			5,551.9			5,697.9			5,719.7
Total Assets	$	23,710.1		$	22,653.9		$	24,898.9		$	24,866.3

The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc. Condensed Consolidated Balance Sheets (unaudited) (continued)	NiSource Inc. Condensed Consolidated Balance Sheets (unaudited) (continued)						NiSource Inc. Condensed Consolidated Balance Sheets (unaudited) (continued)

(in millions, except share amounts)	September 30, 2014			December 31, 2013			March 31, 2015			December 31, 2014
CAPITALIZATION AND LIABILITIES
Capitalization
Common Stockholders’ Equity
Common stock - $0.01 par value, 400,000,000 shares authorized; 315,597,089 and 313,675,911 shares outstanding, respectively	$	3.2		$	3.2
NiSource Common Stockholders’ Equity
Common stock - $0.01 par value, 400,000,000 shares authorized; 317,281,405 and 316,037,421 shares outstanding, respectively							$	3.2		$	3.2
Additional paid-in capital	4,764.7			4,690.1			5,048.4			4,787.6
Retained earnings	1,339.9			1,285.5			1,597.5			1,494.0
Accumulated other comprehensive loss	(41.6		)	(43.6		)	(46.6		)	(50.6		)
Treasury stock	(58.9		)	(48.6		)	(79.0		)	(58.9		)
Total Common Stockholders’ Equity	6,007.3			5,886.6
Total NiSource Common Stockholders’ Equity							6,523.5			6,175.3
Noncontrolling interest in consolidated subsidiaries							946.2			—
Total Equity							7,469.7			6,175.3
Long-term debt, excluding amounts due within one year	8,397.4			7,593.2			7,957.9			8,155.9
Total Capitalization	14,404.7			13,479.8			15,427.6			14,331.2
Current Liabilities
Current portion of long-term debt	18.7			542.1			462.7			266.6
Short-term borrowings	1,311.1			698.7			314.0			1,576.9
Accounts payable	427.7			619.0			563.9			670.6
Dividends payable	82.1			—			82.4			—
Customer deposits and credits	257.1			262.6			172.6			294.3
Taxes accrued	189.3			254.8			287.1			266.7
Interest accrued	81.7			136.4			81.4			140.7
Overrecovered gas and fuel costs	21.2			32.2			172.3			45.6
Exchange gas payable	143.1			186.4			65.8			136.2
Deferred revenue	6.5			18.5			25.5			25.6
Regulatory liabilities	79.9			60.2			102.0			62.4
Accrued capital expenditures							80.3			61.1
Accrued liability for postretirement and postemployment benefits	6.2			6.2			5.9			5.9
Legal and environmental	15.3			32.3			25.4			24.2
Other accruals	408.6			329.0			317.1			378.1
Total Current Liabilities	3,048.5			3,178.4			2,758.4			3,954.9
Other Liabilities and Deferred Credits
Deferred income taxes	3,540.8			3,277.8			3,803.5			3,661.6
Deferred investment tax credits	18.2			20.9			16.7			17.3
Deferred credits	102.7			91.9			105.5			101.1
Deferred revenue	20.9			17.1
Accrued liability for postretirement and postemployment benefits	425.6			527.5			653.7			675.9
Regulatory liabilities	1,675.8			1,669.8			1,678.6			1,673.8
Asset retirement obligations	175.2			174.4			160.9			159.4
Other noncurrent liabilities	297.7			216.3			294.0			291.1
Total Other Liabilities and Deferred Credits	6,256.9			5,995.7			6,712.9			6,580.2
Commitments and Contingencies (Refer to Note 16)	—			—			—			—
Total Capitalization and Liabilities	$	23,710.1		$	22,653.9		$	24,898.9		$	24,866.3

The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc. Condensed Statements of Consolidated Cash Flows (unaudited)	NiSource Inc. Condensed Statements of Consolidated Cash Flows (unaudited)						NiSource Inc. Condensed Statements of Consolidated Cash Flows (unaudited)

Nine Months Ended September 30, (in millions)	2014			2013
Three Months Ended March 31, (in millions)							2015			2014
Operating Activities
Net Income	$	375.8		$	380.3		$	275.3		$	266.2
Adjustments to Reconcile Net Income to Net Cash from Continuing Operations:
Depreciation and amortization	450.8			431.4			157.5			148.7
Net changes in price risk management assets and liabilities	1.9			1.9			(0.5		)	0.8
Deferred income taxes and investment tax credits	220.8			199.1			135.1			148.9
Deferred revenue	1.9			1.6			5.3			1.8
Stock compensation expense and 401(k) profit sharing contribution	54.6			39.7			19.4			13.9
Gain on sale of assets	(19.3		)	(10.2		)	(5.0		)	(15.7		)
Income from unconsolidated affiliates	(32.3		)	(25.5		)	(14.5		)	(9.6		)
Gain on disposition of discontinued operations - net of taxes	—			(34.9		)
Loss (Income) from discontinued operations - net of taxes	0.6			(7.5		)
Loss from discontinued operations - net of taxes							—			0.2
Amortization of debt related costs	7.5			7.0			2.5			2.4
AFUDC equity	(15.6		)	(12.7		)	(6.0		)	(4.0		)
Distributions of earnings received from equity investees	27.6			19.0			18.3			7.6
Changes in Assets and Liabilities
Accounts receivable	362.6			318.4			(93.8		)	(265.1		)
Income tax receivable	2.1			124.6			—			0.9
Inventories	(170.8		)	(103.7		)	297.2			274.0
Accounts payable	(218.1		)	(177.7		)	(84.2		)	126.5
Customer deposits and credits	70.2			(20.4		)	(121.7		)	(23.1		)
Taxes accrued	(67.7		)	(68.0		)	22.0			19.3
Interest accrued	(54.6		)	(62.1		)	(59.3		)	(61.1		)
(Under) Overrecovered gas and fuel costs	(19.2		)	38.1
Over (Under) recovered gas and fuel costs							133.2			(74.2		)
Exchange gas receivable/payable	(53.6		)	28.1			(84.3		)	(134.2		)
Other accruals	(29.7		)	(36.5		)	(60.3		)	(30.1		)
Prepayments and other current assets	56.1			45.5			(16.2		)	4.5
Regulatory assets/liabilities	17.1			71.5			90.6			2.9
Postretirement and postemployment benefits	(102.5		)	(95.9		)	(21.6		)	(19.3		)
Deferred credits	13.8			11.1			5.8			8.4
Deferred charges and other noncurrent assets	1.5			11.8			5.2			(0.2		)
Other noncurrent liabilities	6.3			(6.3		)	4.3			4.0
Net Operating Activities from Continuing Operations	887.8			1,067.7			604.3			394.4
Net Operating Activities (used for) from Discontinued Operations	(1.3		)	10.9
Net Operating Activities from (used for) Discontinued Operations							—			(0.4		)
Net Cash Flows from Operating Activities	886.5			1,078.6			604.3			394.0
Investing Activities
Capital expenditures	(1,441.7		)	(1,297.3		)	(407.5		)	(386.3		)
Insurance recoveries	6.8			6.4
Proceeds from disposition of assets	7.6			17.9			11.7			5.3
Restricted cash (deposits) withdrawals	(8.1		)	28.5
Contributions to equity investees	(63.8		)	(77.1		)
Restricted cash withdrawals (deposits)							3.3			(2.9		)
Distributions from (contributions to) equity investees							1.2			(31.0		)
Other investing activities	(13.0		)	(48.4		)	2.4			7.0
Net Investing Activities used for Continuing Operations	(1,512.2		)	(1,370.0		)
Net Investing Activities from Discontinued Operations	—			118.7
Net Cash Flows used for Investing Activities	(1,512.2		)	(1,251.3		)	(388.9		)	(407.9		)
Financing Activities
Issuance of long-term debt	748.4			815.3
Issuance of common units of CPPL, net of issuance costs							1,168.4			—
Repayments of long-term debt and capital lease obligations	(517.1		)	(505.2		)	(8.0		)	(9.1		)
Premiums and other debt related costs	—			(3.2		)
Change in short-term borrowings, net	612.4			43.9			(1,262.9		)	113.8
Issuance of common stock	22.4			36.1			5.9			8.9
Acquisition of treasury stock	(10.3		)	(8.0		)	(20.1		)	(10.0		)
Dividends paid - common stock	(239.2		)	(227.6		)	(82.1		)	(78.5		)
Net Cash Flows from Financing Activities	616.6			151.3
Change in cash and cash equivalents used for continuing operations	(7.8		)	(151.0		)
Cash contributions (to) from discontinued operations	(1.3		)	129.6
Net Cash Flows (used for) from Financing Activities							(198.8		)	25.1
Change in cash and cash equivalents from continuing operations							16.6			11.6
Change in cash and cash equivalents from (used for) discontinued operations							—			(0.4		)
Cash and cash equivalents at beginning of period	26.8			36.3			25.4			26.8
Cash and Cash Equivalents at End of Period	$	17.7		$	14.9		$	42.0		$	38.0

The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Condensed Statement of Consolidated ~~Common Stockholders'~~ Equity (unaudited)


(in millions)	Common Stock		Treasury Stock			Additional Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Income/(Loss)			Total			Common Stock		Treasury Stock			Additional Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Income/(Loss)			Noncontrolling Interest in Consolidated Subsidiaries			Total
Balance as of January 1, 2014	$	3.2	$	(48.6	)	$	4,690.1	$	1,285.5		$	(43.6	)	$	5,886.6
Balance as of January 1, 2015																	$	3.2	$	(58.9	)	$	4,787.6	$	1,494.0		$	(50.6	)	$	—		$	6,175.3
Comprehensive Income:
Net Income	—		—			—		375.8			—			375.8			—		—			—		268.4			—			6.9			275.3
Other comprehensive income, net of tax	—		—			—		—			2.0			2.0			—		—			—		—			2.0			—			2.0
Common stock dividends	—		—			—		(321.4		)	—			(321.4		)
Allocation of AOCI to noncontrolling interest																	—		—			—		—			2.0			(2.0		)	—
Common stock dividends ($0.52 per share)																	—		—			—		(164.9		)	—			—			(164.9		)
Treasury stock acquired	—		(10.3		)	—		—			—			(10.3		)	—		(20.1		)	—		—			—			—			(20.1		)
Issued:
Common units of CPPL																	—		—			—		—			—			1,168.4			1,168.4
Employee stock purchase plan	—		—			3.0		—			—			3.0			—		—			1.2		—			—			—			1.2
Long-term incentive plan	—		—			31.9		—			—			31.9			—		—			11.0		—			—			—			11.0
401(k) and profit sharing issuance	—		—			33.8		—			—			33.8			—		—			19.6		—			—			—			19.6
Dividend reinvestment plan	—		—			5.9		—			—			5.9			—		—			1.9		—			—			—			1.9
Balance as of September 30, 2014	$	3.2	$	(58.9	)	$	4,764.7	$	1,339.9		$	(41.6	)	$	6,007.3
Sale of interest in Columbia OpCo to CPPL⁽¹⁾																	—		—			227.1		—			—			(227.1		)	—
Balance as of March 31, 2015																	$	3.2	$	(79.0	)	$	5,048.4	$	1,597.5		$	(46.6	)	$	946.2		$	7,469.7

⁽¹⁾ Represents the purchase of an additional 8.4% limited partner interest in Columbia OpCo, recorded at the historical carrying value of Columbia OpCo's net assets after giving effect to the $1,168.4 million equity contribution.

The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited)

1. Basis of Accounting Presentation

The accompanying Condensed Consolidated Financial Statements (unaudited) for NiSource (the “Company”) reflect all normal recurring adjustments that are necessary, in the opinion of management, to present fairly the results of operations in accordance with GAAP in the United States of America. The accompanying financial statements contain the accounts of the Company and its majority-owned or controlled subsidiaries, including CPPL (see Note 3).

The accompanying financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in NiSource’s Annual Report on Form 10-K for the fiscal year ended December 31, ~~2013~~2014. Income for interim periods may not be indicative of results for the calendar year due to weather variations and other factors.

The Condensed Consolidated Financial Statements (unaudited) have been prepared pursuant to the rules and regulations of the SEC. Certain information and note disclosures normally included in annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to those rules and regulations, although NiSource believes that the disclosures made are adequate to make the information not misleading.

Planned Separation of Columbia Pipeline Group ~~and Initial Public Offering of Columbia Pipeline Partners LP~~

On September 28, 2014, NiSource announced that its Board of Directors had approved in principle plans to separate its natural gas pipeline and related businesses into a stand-alone publicly traded company (the “Proposed Separation”). If completed, the Proposed Separation will result in two energy infrastructure companies: NiSource Inc., a fully regulated natural gas and electric utilities company, and Columbia Pipeline Group Inc., a natural gas pipeline, midstream and storage company (“CPG”). The Proposed Separation is expected to occur ~~in mid-2015.~~on July 1, 2015.

Under the plan for the Proposed Separation, NiSource shareholders would retain their current shares of NiSource stock and receive a pro rata distribution of shares of CPG stock in a transaction that is expected to be tax-free to NiSource and its shareholders.

~~On September 29, 2014, Columbia Pipeline Partners LP,~~2. Recent Accounting Pronouncements

In April 2015, the FASB issued ASU 2015-05, Intangibles - Goodwill and Other-Internal-Use Software (Subtopic 350-40):Customer's Accounting for Fees Paid in a ~~wholly owned subsidiary (“CPPL”), filed~~Cloud Computing Arrangement. ASU 2015-05 clarifies guidance on determining whether a cloud computing arrangement contains a software license that should be accounted for as internal-use software. NiSource is required to adopt ASU 2015-05 for periods beginning after December 15, 2015, including interim periods, and the guidance is permitted to be applied either (1) prospectively to all agreements entered into or materially modified after the effective date or (2) retrospectively, with early adoption permitted. NiSource is currently evaluating the ~~Securities~~impact the adoption of ASU 2015-05 will have on the Condensed Consolidated Financial Statements (unaudited) or Notes to Condensed Consolidated Financial Statements (unaudited).

In April 2015, the FASB issued ASU 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. ASU 2015-03 changes the way entities present debt issuance costs in financial statements by presenting issuance costs on the balance sheet as a direct deduction from the related debt liability rather than as a deferred charge. Amortization of these costs will continue to be reported as interest expense. NiSource is required to adopt ASU 2015-03 for periods beginning after December 15, 2015, including interim periods, and ~~Exchange Commission~~the guidance is to be applied retrospectively with early adoption permitted. NiSource is currently evaluating the impact the adoption of ASU 2015-03 will have on the Condensed Consolidated Financial Statements (unaudited) or Notes to Condensed Consolidated Financial Statements (unaudited).

In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis. ASU 2015-02 amends consolidation guidance by including changes to the variable and voting interest models used by entities to evaluate whether an entity should be consolidated. NiSource is required to adopt ASU 2015-02 for periods beginning after December 15, 2015, including interim periods, and the guidance is to be applied retrospectively or using a ~~Registration Statement~~modified retrospective approach, with early adoption permitted. NiSource is currently evaluating the impact the adoption of ASU 2015-02 will have on ~~Form S-1 related~~the Condensed Consolidated Financial Statements (unaudited) and Notes to CPPL’s proposed initial public offering of common units representing limited partner interests in CPPL. We expect that CPPL will sell a minority share of its total limited partner interests in the offering, which is expected to occur in the first quarter of 2015. If the proposed offering closes, CPPL’s initial asset would consist of an approximate 14.6% ownership interest in CPG OpCo LP (“Columbia OpCo”), which is the entity that will own substantially all of NiSource’s natural gas transmission, midstream and storage assets. In addition, NiSource, through its ownership of CPG, would indirectly own (a) the remaining ownership interest in Columbia OpCo, (b) the general partner of CPPL, (c) the remaining CPPL limited partner interests that are not sold in the offering and (d) all the incentive distribution rights in CPPL.Condensed Consolidated Financial Statements (unaudited).

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

~~2. Recent Accounting Pronouncements~~3. Columbia Pipeline Partners LP (CPPL)

~~In June 2014,~~On December 5, 2007, NiSource formed CPPL (the "Partnership") (NYSE: CPPL) to own, operate and develop a portfolio of pipelines, storage and related assets.

On February 11, 2015, CPPL completed its IPO of 53.8 million common units representing limited partnership interests, constituting 53.5% of the ~~FASB issued ASU 2014-12,~~ ~~Compensation - Stock Compensation(Topic 718): Accounting for Share-Based Payments When~~Partnership's outstanding limited partnership interests. The Partnership received $1,168.4 million of net proceeds from the ~~Terms~~IPO. NiSource, through CPG, owns the general partner of ~~an Award Provide That a Performance Target Could Be Achieved after~~ the ~~Requisite Service Period. ASU 2014-12 clarifies that entities should treat performance targets that can be met after~~Partnership, all of the ~~requisite service period~~Partnership's subordinated units and the incentive distribution rights. The assets of the Partnership consist of a share-based payment award as performance conditions that affect vesting. NiSource is required to adopt ASU 2014-12 for periods beginning after December 15, 2015, including interim periods, and the guidance is to be applied prospectively, with early adoption permitted. Retroactive application would apply to awards with performance targets outstanding after the beginning15.7 percent limited partner interest in Columbia OpCo, which consists of substantially all of the ~~first annual period presented.~~Columbia Pipeline Group Operations segment. The ~~adoption~~operations of ~~this guidance~~the Partnership will ~~not have~~be consolidated in NiSource's results as long as the Partnership remains a ~~material impact on~~subsidiary. If the Proposed Separation occurs, CPG would no longer be a subsidiary of NiSource and, thus, NiSource would cease to own (a) any interest in Columbia OpCo, (b) the general partner of the Partnership, (c) any of the limited partner interests in the Partnership or (d) any of the incentive distribution rights in the Partnership. As of March 31, 2015, the portion of CPPL owned by the public is reflected as a noncontrolling interest in the Condensed Consolidated Financial Statements (unaudited) ~~or Notes to Condensed Consolidated Financial Statements (unaudited)~~.

~~In May 2014,~~The table below summarizes the ~~FASB issued ASU 2014-09,~~ ~~Revenue from Contracts with Customers (Topic 606)~~. ASU 2014-09 outlines a single, comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance. The core principleeffects of the ~~new standard~~changes in NiSource's ownership interest in Columbia OpCo on equity:



(in millions)	Three Months Ended March 31, 2015
Net income attributable to NiSource	268.4
Increase in NiSource's paid-in capital for the sale of 8.4% of Columbia OpCo	227.1
Change from net income attributable to NiSource and transfers to noncontrolling interest	495.5

The Partnership maintains a $500.0 million revolving credit facility, of which $50.0 million is ~~that an entity should recognize revenue~~available for issuance of letters of credit. The purpose of the facility is to ~~depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange~~provide cash for ~~those goods or services. NiSource is required to adopt ASU 2014-09 for periods beginning after December 15, 2016,~~general partnership purposes, including ~~interim periods,~~working capital, capital expenditures and the ~~new standard is to be applied retrospectively with early adoption not permitted. NiSource is currently evaluating the impact the adoption~~funding of ~~ASU 2014-09 will have on its Condensed Consolidated Financial Statements (unaudited) and Notes to Condensed Consolidated Financial Statements (unaudited).~~

~~In April 2014, the FASB issued ASU 2014-08,~~ ~~Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.~~ ASU 2014-08 changes the criteria for reporting a discontinued operation. Under the new pronouncement, a disposal of a part of an organization that has a major effect on its operations and financial results is a discontinued operation. NiSource is required to adopt ASU 2014-08 prospectively for all disposals or components of its business classified as held for sale during fiscal periods beginning after December 15, 2014. NiSource is currently evaluating what impact, if any, adoption of ASU 2014-08 will have on its Condensed Consolidated Financial Statements (unaudited) and Notes to Condensed Consolidated Financial Statements (unaudited).capital calls. At March 31, 2015, CPPL had no outstanding borrowings under this facility.

3.4. Earnings Per Share

Basic EPS is computed by dividing net income ~~available~~attributable to ~~common stockholders~~NiSource by the weighted-average number of shares of common stock outstanding for the period. The weighted average shares outstanding for diluted EPS includes the incremental effects of the various long-term incentive compensation plans. The numerator in calculating both basic and diluted EPS for each period is reported net ~~income.~~income attributable to NiSource. The computation of diluted average common shares follows:


	Three Months Ended September 30,		Nine Months Ended September 30,		Three Months Ended March 31,
(in thousands)	2014	2013	2014	2013	2015	2014
Denominator
Basic average common shares outstanding	315,418	312,842	314,889	312,053	316,587	314,222
Dilutive potential common shares:
Stock options	32	112	30	102	—	59
Shares contingently issuable under employee stock plans	725	369	649	327	335	399
Shares restricted under stock plans	451	490	438	477	468	442
Diluted Average Common Shares	316,626	313,813	316,006	312,959	317,390	315,122

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

~~4. Discontinued~~5. Gas in Storage

Both the LIFO inventory methodology and the weighted average cost methodology are used to value natural gas in storage. Gas Distribution Operations price natural gas storage injections at the average of the costs of natural gas supply purchased during the year. For interim periods, the difference between current projected replacement cost and ~~Assets~~the LIFO cost for quantities of gas temporarily withdrawn from storage is recorded as a temporary LIFO liquidation credit or debit within the Condensed Consolidated Balance Sheets (unaudited). Due to seasonality requirements, NiSource expects interim variances in LIFO layers to be replenished by year-end. NiSource had a temporary LIFO liquidation debit of $25.3 million and ~~Liabilities Held~~zero as of March 31, 2015 and December 31, 2014, respectively, for ~~Sale~~

~~There were no assets~~certain gas distribution companies recorded within “Prepayments and ~~liabilities of discontinued operations and held for sale~~other,” on the Condensed Consolidated Balance Sheets (unaudited) at ~~September 30, 2014~~ ~~and~~ ~~December 31, 2013~~.

Results from discontinued operations are provided in the following table. These results are primarily from a settlement at NiSource's former exploration and production subsidiary, CER, NiSource's Retail Services business, and NiSource's unregulated natural gas marketing business.

Three Months Ended
September 30, Nine Months Ended September 30,
(in millions) 2014 2013 2014 2013
Net Revenues from Discontinued Operations $ —
$ 0.4
$ —
$ 1.3
(Loss) Income from discontinued operations (0.2 ) 0.1
(1.0 ) 12.2
Income tax (benefit) expense (0.1 ) —
(0.4 ) 4.7
(Loss) Income from Discontinued Operations - net of taxes $ (0.1 ) $ 0.1
$ (0.6 ) $ 7.5
(Loss) Gain on Disposition of Discontinued Operations - net of taxes $ —
$ (1.5 ) $ —
$ 34.9

5.6. Asset Retirement Obligations

Certain costs of removal that have been, and continue to be, included in depreciation rates and collected in the service rates of the rate-regulated subsidiaries are classified as “Regulatory liabilities” on the Condensed Consolidated Balance Sheets (unaudited).

Changes in NiSource’s liability for asset retirement obligations for the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014 are presented in the table below:

(in millions) 2014 2013
Balance as of January 1, $ 174.4
$ 160.4
Accretion expense 1.2
0.9
Accretion recorded as a regulatory asset/liability 6.3
6.5
Additions 2.3
9.7
Settlements (1.4 ) (1.3 )
Change in estimated cash flows⁽¹⁾
(7.6 ) (0.7 )
Balance as of September 30, $ 175.2
$ 175.5

⁽¹⁾~~The change in estimated cash flows for 2014 is primarily attributed to changes in estimated costs to retire pipeline.~~



(in millions)	2015			2014
Balance as of January 1,	$	159.4		$	174.4
Accretion expense	0.4			0.4
Accretion recorded as a regulatory asset/liability	1.9			2.1
Additions	—			0.1
Settlements	(0.7		)	(0.5		)
Change in estimated cash flows	(0.1		)	—
Balance as of March 31,	$	160.9		$	176.5

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

6.7. Regulatory Matters

Gas Distribution Operations Regulatory Matters

Significant Rate Developments. On April 30, 2013, Indiana Governor Pence signed Senate Enrolled Act 560 into law. Among other provisions, this legislation provides for cost recovery outside of a base rate proceeding for new or replacement electric and gas transmission, distribution, and storage projects that a public utility undertakes for the purposes of safety, reliability, system modernization, or economic development. Provisions of the TDSIC statute require that, among other things, requests for recovery include a seven-year plan of eligible investments. Once the plan is approved by the IURC, 80 percent of eligible costs can be recovered using a periodic rate adjustment mechanism. The cost recovery mechanism is referred to as a TDSIC mechanism. Recoverable costs include a return on, and of, the investment, including AFUDC, post in service carrying charges, operation and maintenance expenses, depreciation, and property taxes. The remaining 20 percent of recoverable costs are to be deferred for future recovery in the public utility’s next general rate case. The periodic rate adjustment mechanism is capped at an annual increase of no more than two percent of total retail revenues. On October 3, 2013, NIPSCO filed its gas TDSIC seven-year plan of eligible investments for a total of approximately $710 million with the IURC. On April 30, 2014, the IURC issued an order approving NIPSCO's gas TDSIC seven-year plan. On May 29, 2014, the NIPSCO Industrial Group filed a Notice of Appeal with the Indiana Court of Appeals in response to the IURC's April 30, 2014 ruling. Subsequently, the NIPSCO Industrial Group filed a Voluntary Notice of Dismissal, which was granted with prejudice.

On September 12, 2014, Columbia of Ohio filed an application that seeks authority to establish a regulatory asset and defer, for accounting and financial reporting purposes, the expenditures to be incurred in implementing Columbia of Ohio’s Pipeline Safety Program. Columbia of Ohio is requesting authority to defer Pipeline Safety Program costs of up to $15 million annually. Comments are due November 17, 2014, and Reply Comments are due December 2, 2014.

On November 25, ~~2013,~~2014, Columbia of Ohio filed a Notice of Intent to file an application to adjust rates associated with its IRP and DSM Riders. Columbia of Ohio filed its Application on February ~~28, 2014, requesting~~27, 2015, and requested authority to increase revenues by ~~approximately $25.5 million. The parties have settled all issues, and on April 7, 2014 filed a stipulation providing for a revenue increase of approximately $25.5~~$24.7 million. On ~~April 23, 2014,~~March 26, 2015, PUCO Staff filed Comments recommending that the PUCO approve Columbia of ~~Ohioreceived approval~~Ohio’s application in full. On April 22, 2015, the PUCO issued an Order that approved Columbia of ~~its annual infrastructure replacement and demand-side management rider request from the PUCO. New rates became effective April 30, 2014.~~Ohio's application.

On September 16, 2013, Columbia of Massachusetts filed its Peak Period GAF for the period November 1, 2013 through April 30, 2014, and its Peak Period 2012-2013 GAF Reconciliation. On January 17, 2014, Columbia of Massachusetts filed a revision to the GAF effective February 1, 2014, and on February 18, 2014, Columbia of Massachusetts filed its second revision to the GAF effective March 1, 2014, to eliminate Columbia of Massachusetts’s projected Peak Period under-collection of $50.0 million. On February 28, 2014, the Massachusetts DPU approved a revised GAF subject to further review and reconciliation to recover approximately $25 million of the anticipated under-collection and defer recovery of the remaining $25 million to November 2014 through April19, 2015, ~~and thus, this deferred amount has been incorporated into the proposed GAF as filed on September 16, 2014, in Columbia of Massachusetts’s 2014-2015 Peak Period GAF filing.~~

On August 4, 2014, Columbia of Massachusetts filed its 2014-2015 Peak Period LDAF and on September 16, 2014, Columbia of Massachusetts filed its 2014 PEF and its 2014 RAAF, each with a proposed effective date of November 1, 2014. Columbia of Massachusetts expects approval of the 2014-2015 LDAF by October 31, 2014. Columbia of Massachusetts also expects approval of the 2014 PEF and 2014 RAAF by October 31, 2014, subject to further investigation and reconciliation.

On April 16, 2013, Columbia of Massachusetts submitted a filing with the Massachusetts DPU requesting an annual revenue requirement increase of $30.1 million. Pursuant to the procedural schedule for this case, on September 3, 2013, Columbia of Massachusetts filed its updated revenue requirement of $29.5 million and on October 16, 2013, filed an updated cost of service for $30 million. A final revenue requirement update of $29.9 million was filed on December 16, 2013. On February 28, 2014, the Massachusetts DPU issued an order granting an annual revenue requirement increase of $19.3 million effective March 1, 2014, and the compliance filing associated with the order has been approved.

~~On March 21, 2014,~~ Columbia of Pennsylvania filed a base rate case with the Pennsylvania PUC, seeking a revenue increase of ~~approximately~~ ~~$54.1~~$46.2 million annually. The case is driven by Columbia of Pennsylvania’s capital investment program which exceeds ~~$180~~$197.0 million in ~~both 2014~~2015 and ~~2015~~$211.0 million in 2016 as well as ~~new~~costs to train and comply with pipeline safety-related operation and maintenance expenditures. Columbia of ~~Pennsylvania seeks Pennsylvania PUC approval to implement additional rates to recover~~Pennsylvania's request for rate relief includes the recovery of costs that are projected to be incurred after the implementation of ~~those~~ new rates, as authorized by the Pennsylvania General Assembly with the passage of Act 11 of

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes~~ 2012. New rates are expected to ~~Condensed Consolidated Financial Statements (unaudited) (continued)~~

2012. Columbia of Pennsylvania's filing seeks to implement rates in December 2014 under which Columbia of Pennsylvania would immediately begin to recover costs that are projected for the twelve-month period ending December 31, 2015. On September 5, 2014, the parties to the rate case filed a joint petition which seeks approval of a full settlement. If the settlement is approved, Columbia of Pennsylvania will be authorized to increase its annual base revenues by $32.5 million. The administrative law judge assigned to the case issued a Recommended Decision on October 17, 2014, in which he recommended that the settlement be approved, without modification. A final order from the Pennsylvania PUC is expected ingo into effect during the fourth quarter of ~~2014.~~2015.

On April 16, 2015, Columbia of Massachusetts filed a base rate case with the Massachusetts DPU. The case, which seeks increased annual revenues of approximately $49.0 million, is designed to support the company's continued focus on providing safe and reliable service in compliance with increasing state and federal regulations and oversight, and recovery of associated increased operations and maintenance costs. An order in the proceeding is expected on February 29, 2016 with new rates effective March 1, 2016.

On April 30, 2014, Columbia of Virginia filed a base rate case with the VSCC seeking an annual revenue increase of $31.8 million, which includes $6.9 million in annual revenues currently collected as a separate infrastructure replacement rider on customers’ bills under the Virginia SAVE Plan Act. On December 10, 2014, Columbia of Virginia presented at hearing a Stipulation and Proposed Recommendation (“Stipulation”) executed by certain parties to the rate proceeding, including the Staff of the VSCC and the Division of Consumer Counsel of the Office of the Attorney General of the Commonwealth of Virginia. The ~~SAVE rider will be reset~~Stipulation includes

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to ~~zero and these revenues will be moved into non-gas~~Condensed Consolidated Financial Statements (unaudited) (continued)

a base ~~rates, resulting in a proposed net~~ revenue increase of ~~$24.9~~$25.2 million, ~~per year. Columbia~~recovery of ~~Virginia also seeks to recover~~ costs related to ~~its~~the implementation of pipeline safety programs, and ~~forward looking adjustments to its capital investments and changes in operating costs projected to occur during~~ the ~~rate year ending September 30, 2015. In addition, Columbia of Virginia is proposing a~~proposed change ~~from volumetric based (Mcf) billing~~ to thermal ~~based (Btu)~~ billing. ~~The~~On January 13, 2015, the Hearing Examiner issued a report that recommended that the VSCC approve the Stipulation. On March 30, 2015, the VSCC issued ~~a procedural order~~an Order Remanding for Further Action. In the Order, the VSCC found the revenue increase of $25.2 million and apportionment of that increase between rate classes contained in the ~~case on May 28, 2014~~Stipulation reasonable. However, the VSCC remanded back to the Hearing Examiner for further proceedings the manner in which ~~scheduled~~fixed costs are to be assigned to the ~~case for hearing on December 9, 2014. New rates are subject to refund and became effective October 1, 2014.~~fixed customer charges of each rate class.

Cost Recovery and Trackers. A significant portion of the distribution companies' revenue is related to the recovery of gas costs, the review and recovery of which occurs via standard regulatory proceedings. All states require periodic review of actual gas procurement activity to determine prudence and to permit the recovery of prudently incurred costs related to the supply of gas for customers. NiSource distribution companies have historically been found prudent in the procurement of gas supplies to serve customers.

Certain operating costs of the NiSource distribution companies are significant, recurring in nature, and generally outside the control of the distribution companies. Some states allow the recovery of such costs via cost tracking mechanisms. Such tracking mechanisms allow for abbreviated regulatory proceedings in order for the distribution companies to implement charges and recover appropriate costs. Tracking mechanisms allow for more timely recovery of such costs as compared with more traditional cost recovery mechanisms. Examples of such tracking mechanisms include GCR adjustment mechanisms, tax riders, ~~gas energy efficiency programs,~~ and bad debt recovery mechanisms.

Comparability of Gas Distribution Operations line item operating results is impacted by regulatory trackers that allow for the recovery in rates of certain costs such as bad debt ~~expenses.~~expense. Increases in the expenses that are the subject toof trackers, result in a corresponding increase in net revenues and therefore have essentially no impact on total operating income results.

Certain of the NiSource distribution companies have completed rate proceedings involving infrastructure replacement or are embarking upon regulatory initiatives to replace significant portions of their operating systems that are nearing the end of their useful lives. Each LDC's approach to cost recovery may be unique, given the different laws, regulations and precedent that exist in each jurisdiction.

~~As further discussed above,~~ NIPSCO has approval from the IURC to recover certain costs for gas transmission, distribution and storage system improvements. On ~~August 28, 2014,~~February 27, 2015, NIPSCO filed ~~its~~ gas ~~TDSIC-1 with the IURC for ratemaking and accounting relief associated with the eligible investments,~~TDSIC-2 which included ~~$4.4~~$43.3 million of net capital expenditures for the period ended ~~June 30,~~December 31, 2014. This filing includes changes to the revenue requirement mechanism to be consistent with the IURC order in the electric TDSIC case and revised seven-year plan eligible investment projections. An order is expected in the first quarter of 2015.

Columbia Pipeline Group Operations Regulatory Matters

~~Significant Rate Developments.~~ ~~On January 30, 2014,~~ Columbia Transmission ~~received FERC approval of its December 2013 filing to recover costs associated with~~Customer Settlement. In January 2015, Columbia Pipeline Group Operations commenced the ~~first~~third year of ~~its comprehensive~~the Columbia Transmission long-term system modernization program. ~~During 2013,~~The Columbia Transmission completed more than 30 individual projects representing a total investment of about $300 million. The program includes replacement of aging pipeline and compressor facilities, enhancementsPipeline Group Operations segment expects to ~~system inspection capabilities, and improvements~~invest approximately $300.0 million in ~~real-time analytics and control systems.~~modernization investments during 2015. Recovery of ~~the 2013~~approximately $320.0 million of investments made in 2014 began on February 1, ~~2014.~~2015.

~~The second year of the program includes planned modernization investments of approximately~~ ~~$330 million. Columbia Transmission and its customers have agreed to the initial five years of the comprehensive modernization program, with an opportunity to mutually extend the agreement.~~

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

Cost Recovery Trackers. A significant portion of the ~~regulated~~ transmission and storage regulated companies' revenue is related to the recovery of their operating costs, the review and recovery of which occurs via standard regulatory proceedings with the FERC under section 4 of the Natural Gas Act. However, certain operating costs of the NiSource regulated transmission and storage companies are significant and recurring in nature, such as fuel for compression and lost and unaccounted for ~~gas, which is settled in-kind and reflected net of recoveries in operating expenses.~~gas. The FERC allows for the recovery of such costs via cost tracking mechanisms. These tracking mechanisms allow the transmission and storage companies' rates to fluctuate in response to changes in certain operating costs or conditions as they occur to facilitate the timely recovery of its costs incurred. The tracking mechanisms involve a rate adjustment that is filed at a predetermined frequency, typically annually, with the FERC and is subject to regulatory review before new rates go into effect. Other such costs under regulatory tracking mechanisms include ~~third-party~~upstream pipeline ~~transportation,~~transmission, electric compression, ~~certain environmental related expenses, and certain~~ operational purchases and sales of natural ~~gas.~~gas, and the revenue requirement for capital investments made under Columbia Transmission's long-term plan to modernize its interstate transmission system as discussed above.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

Electric Operations Regulatory Matters

Significant Rate Developments. On July 19, 2012 and December 19, 2012, the FERC issued orders approving construction work in progress in rate base and abandoned plant cost recovery requested by NIPSCO for a 100-mile, 345 kV transmission project and its right to develop 50 percent of the 66-mile, 765 kV project. NIPSCO began recording revenue in the first quarter of 2013 using a forward looking rate, based on an average construction work in progress balance. For the three months ended March 31, 2015 and 2014, revenue of $5.3 million and $2.1 million, respectively, was recorded.

On July 19, 2013, NIPSCO filed its electric TDSIC ~~further discussed above,~~ with the IURC. The filing included the seven-year plan of eligible investments for a total of approximately $1.1 billion with the majority of the spend occurring in years 2016 through 2020. On February 17, 2014, the IURC issued an order approving NIPSCO’s seven-year plan of eligible investments. The Order also granted NIPSCO ratemaking relief associated with the eligible investments through a rate adjustment mechanism. ~~On March 10, 2014, the OUCC filed a Petition for Reconsideration with the IURC, and the IURC denied that Petition for Reconsideration on May 7, 2014. In addition, the~~The NIPSCO Industrial Group and the OUCC have filed Notices of Appeal with the Indiana Court of Appeals in response to the IURC's ~~ruling, which are still pending.~~

ruling. On November ~~12, 2013, several industrial customers, including INDIEC, filed a complaint at~~25, 2014, NIPSCO’s requested TDSIC factors were approved on an interim basis and subject to refund, pending the ~~FERC regarding~~outcome of the ~~12.38% base ROE used to set~~appeals of the ~~MISO Transmission Owners' transmission rates and requested a reduction in~~IURC’s February 17, 2014 Orders. On April 8, 2015, the ~~base ROE to 9.15%. The complaint requested that FERC limit the capital structure~~Court of ~~MISO Transmission Owners to no more than 50% common equity for ratemaking purposes and that FERC eliminate incentive adders for membership in a RTO. On October 16, 2014, FERC~~Appeals issued an Order concluding that ~~dismissed~~ the ~~portions~~IURC erred in approving NIPSCO’s seven-year plan given its lack of detail regarding the projects for years two through seven. The Court then remanded the decision to the IURC. The April 8, 2015 Order is final after the expiration of 30 days if no parties petition for transfer to the Supreme Court. However, if a party petitions for transfer to the Supreme Court, the Order is not final until completion of the ~~complaint that challenged Transmission Owner capital structures~~appellate process. NIPSCO is reviewing this decision and ~~incentive adders; set~~evaluating its options and does not believe the ~~base ROE for hearing and suspended to allow for settlement; set a refund effective date of November 12, 2013; and directed the parties~~impact is material to the new two-step discounted cash flow methodology established by FERC in Opinion No. 531 in Docket No. EL11-77-001. NIPSCO is unable to estimate the impact of this complaint or the timing of any potential impact at this time.Condensed Consolidated Financial Statements (unaudited).

Cost Recovery and Trackers. A significant portion of NIPSCO's revenue is related to the recovery of fuel costs to generate power and the fuel costs related to purchased power. These costs are recovered through a FAC, a standard, quarterly, “summary” regulatory proceeding in Indiana.

Certain operating costs of the Electric Operations are significant, recurring in nature, and generally outside the control of NIPSCO. The IURC allows for recovery of such costs via cost tracking mechanisms. Such tracking mechanisms allow for abbreviated regulatory proceedings in order for NIPSCO to implement charges and recover appropriate costs. Tracking mechanisms allow for more timely recovery of such costs as compared with more traditional cost recovery mechanisms. Examples of such mechanisms include electric energy efficiency programs, MISO non-fuel costs and revenues, ~~federally mandated costs,~~ resource capacity charges, and environmental related costs.

NIPSCO has approval from the IURC to recover certain environmental related costs through an ECT. Under the ECT, NIPSCO is permitted to recover (1) AFUDC and a return on the capital investment expended by NIPSCO to implement environmental compliance plan projects through an ECRM and (2) related operation and maintenance and depreciation expenses once the environmental facilities become operational through an EERM.

On ~~August 1, 2014, NIPSCO filed ECR-24 which included $658.4~~April 22, 2015, the IURC issued an order on ECR-25 approving NIPSCO's request to begin earning a return on $734.1 million of net capital expenditures for the period ended ~~June 30,~~December 31, 2014. AnThe order ~~is expected in~~also approved a revised capital cost estimate of $264.8 million for its Phase III multi-pollutant compliance plan projects related to the ~~fourth quarter~~Unit 12 FGD, an increase from the previous IURC approved cost estimate of ~~2014.~~$246.3 million.

~~As further discussed above,~~ NIPSCO has approval from the IURC to recover certain costs for transmission and distribution system ~~improvements.~~improvements through the electric TDSIC. On ~~August 28,~~November 25, 2014, ~~NIPSCO filed its electric TDSIC-1 with~~ the IURC ~~for ratemaking~~approved, on an interim basis and ~~accounting relief~~subject to refund pending the outcome of appeals, NIPSCO’s requested TDSIC factors associated with the eligible investments, which included $19.4 million of net capital expenditures for the period ended June 30, 2014. ~~An order is expected in~~On February 26, 2015, NIPSCO filed electric TDSIC-2 which included $62.3 million of net capital expenditures for the ~~fourth quarter of~~period ended December 31, 2014.

See further discussion regarding the electric TDSIC above.

1716

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ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

7.8. Fair Value

A. Fair Value Measurements

Recurring Fair Value Measurements. The following tables present financial assets and liabilities measured and recorded at fair value on NiSource’s Condensed Consolidated Balance Sheets (unaudited) on a recurring basis and their level within the fair value hierarchy as of ~~September 30, 2014~~March 31, 2015 and December 31, ~~2013~~2014:


Recurring Fair Value Measurements September 30, 2014 (in millions)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Balance as of September 30, 2014
Recurring Fair Value Measurements March 31, 2015 (in millions)									Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Balance as of March 31, 2015
Assets
Price risk management assets:
Commodity financial price risk programs	$	0.7	$	—	$	—	$	0.7	$	—	$	—	$	0.2	$	0.2
Available-for-sale securities	31.6		103.6		—		135.2		30.5		100.9		—		131.4
Total	$	32.3	$	103.6	$	—	$	135.9	$	30.5	$	100.9	$	0.2	$	131.6
Liabilities
Price risk management liabilities:
Commodity financial price risk programs	$	3.5	$	—	$	0.9	$	4.4	$	9.3	$	—	$	—	$	9.3
Total	$	3.5	$	—	$	0.9	$	4.4	$	9.3	$	—	$	—	$	9.3


Recurring Fair Value Measurements December 31, 2013 (in millions)	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Balance as of December 31, 2013
Recurring Fair Value Measurements December 31, 2014 (in millions)									Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Balance as of December 31, 2014
Assets
Price risk management assets:
Commodity financial price risk programs	$	2.1	$	—	$	—	$	2.1	$	0.1	$	—	$	—	$	0.1
Interest rate risk activities	—		21.1		—		21.1
Available-for-sale securities	25.3		96.1		—		121.4		28.4		103.5		—		131.9
Total	$	27.4	$	117.2	$	—	$	144.6	$	28.5	$	103.5	$	—	$	132.0
Liabilities
Price risk management liabilities:
Commodity Financial price risk programs	$	1.6	$	—	$	0.1	$	1.7
Commodity financial price risk programs									$	14.2	$	—	$	0.1	$	14.3
Total	$	1.6	$	—	$	0.1	$	1.7	$	14.2	$	—	$	0.1	$	14.3

Price risk management assets and liabilities primarily include NYMEX futures and NYMEX options which are commodity exchange-traded and non-exchange-based derivative contracts. Exchange-traded derivative contracts are based on unadjusted quoted prices in active markets and are classified within Level 1. These financial assets and liabilities are secured with cash on deposit with the exchange; therefore nonperformance risk has not been incorporated into these valuations. Certain non-exchange-traded derivatives are valued using broker or over-the-counter, on-line exchanges. In such cases, these non-exchange-traded derivatives are classified within Level 2. Non-exchange-based derivative instruments include swaps, forwards, and options. In certain instances, these instruments may utilize models to measure fair value. NiSource uses a similar model to value similar instruments. Valuation models utilize various inputs that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, other observable inputs for the asset or liability, and market-corroborated inputs, i.e., inputs derived principally from or corroborated by observable market data by correlation or other means. Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. Certain derivatives trade in less active markets with a lower availability of pricing information and models may be utilized in the valuation. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized in Level 3. Credit risk is considered in the fair value calculation of derivative instruments that are not exchange-traded. Credit exposures are adjusted to reflect collateral agreements which reduce exposures. As ofMarch 31, 2015 and December

1817

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

~~September 30, 2014~~ ~~and December~~ 31, ~~2013~~2014, there were no material transfers between fair value hierarchies. Additionally, there were no changes in the method or significant assumptions used to estimate the fair value of NiSource’s financial instruments.

~~At December 31, 2013,~~Commodity price risk ~~management assets also include fixed-to-floating interest rate swaps, which are designated as fair value hedges, as a means to achieve~~resulting from derivative activities at NiSource’s ~~targeted level~~rate-regulated subsidiaries is limited, since regulations allow recovery of ~~variable-rate debt as a percent of total debt. NiSource used a calculation of future cash inflows~~prudently incurred purchased power, fuel and ~~estimated future outflows related to~~gas costs through the ~~swap agreements, which we discounted and netted to determine~~ratemaking process, including gains or losses on these derivative instruments. If states should explore additional regulatory reform, these subsidiaries may begin providing services without the current fair value. Additional inputs to the present value calculation include the contract terms, as well as market parameters such as current and projected interest rates and volatility. As they are based on observable data and valuations of similar instruments, the interest rate swaps are categorized in Level 2 in the fair value hierarchy. Credit risk is considered in the fair value calculationbenefit of the ~~interest rate swap. On July 15, 2014, $500.0 million~~traditional ratemaking process and may be more exposed to commodity price risk. Some of ~~fixed-to-variable interest rate swaps expired, whereby NiSource Finance received payments based upon a fixed 5.40% interest rate~~NiSource’s rate-regulated utility subsidiaries offer commodity price risk products to its customers for which derivatives are used to hedge forecasted customer usage under such products. These subsidiaries do not have regulatory recovery orders for these products and ~~paid a floating interest rate amount based on U.S. 6-month BBA LIBOR plus an average of 0.78% per annum.~~are subject to gains and losses recognized in earnings due to hedge ineffectiveness.

Available-for-sale securities are investments pledged as collateral for trust accounts related to NiSource’s wholly-owned insurance company. Available-for-sale securities are included within “Other investments” in the Condensed Consolidated Balance Sheets (unaudited). Securities classified within Level 1 include U.S. Treasury debt securities which are highly liquid and are actively traded in over-the-counter markets. NiSource values corporate and mortgage-backed debt securities using a matrix pricing model that incorporates market-based information. These securities trade less frequently and are classified within Level 2. Total unrealized gains and losses from available-for-sale securities are included in other comprehensive income (loss). The amortized cost, gross unrealized gains and losses, and fair value of available-for-sale debt securities at ~~September 30, 2014~~March 31, 2015 and December 31, ~~2013~~2014 were:

September 30, 2014 (in millions)
Amortized
Cost
Gross Unrealized Gains Gross Unrealized Losses
Fair
Value
Available-for-sale debt securities
U.S. Treasury $ 34.3
$ 0.2
$ (0.3 ) $ 34.2
Corporate/Other 101.0
0.9
(0.9 ) 101.0
Total Available-for-sale debt securities $ 135.3
$ 1.1
$ (1.2 ) $ 135.2
December 31, 2013 (in millions)
Amortized
Cost
Gross Unrealized Gains Gross Unrealized Losses
Fair
Value
Available-for-sale debt securities
U.S. Treasury $ 30.3
$ 0.3
$ (0.5 ) $ 30.1
Corporate/Other 91.5
1.1
(1.3 ) 91.3
Total Available-for-sale debt securities $ 121.8
$ 1.4
$ (1.8 ) $ 121.4



March 31, 2015 (in millions)	Amortized Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
Available-for-sale debt securities
U.S. Treasury securities	$	32.5	$	0.6	$	—		$	33.1
Corporate/Other bonds	97.0		1.5		(0.2		)	98.3
Total Available-for-sale debt securities	$	129.5	$	2.1	$	(0.2	)	$	131.4
December 31, 2014 (in millions)	Amortized Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
Available-for-sale debt securities
U.S. Treasury securities	$	30.8	$	0.3	$	(0.2	)	$	30.9
Corporate/Other bonds	100.6		1.0		(0.6		)	101.0
Total Available-for-sale debt securities	$	131.4	$	1.3	$	(0.8	)	$	131.9

For the three months ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014, the net realized gain on the sale of available-for-sale U.S. Treasury debt securities was zero and $0.1 million, respectively. For the three months ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014, the net realized gain on the sale of available-for-sale Corporate/Other bond debt securities was ~~$0.1 million~~zero and ~~zero, respectively.~~

~~For the nine months ended~~ ~~September 30, 2014~~ ~~and~~ ~~2013, the net realized gain on the sale of available-for-sale U.S. Treasury debt securities was~~ $0.1 million, ~~and $0.5 million,~~ respectively. ~~For the nine months ended~~ ~~September 30, 2014~~ ~~and~~ ~~2013, the net realized gain on the sale of available-for-sale Corporate/Other bond debt securities was $0.3 million.~~

The cost of maturities sold is based upon specific identification. At ~~September 30, 2014~~March 31, 2015, approximately $~~4.9~~4.5 million of U.S. Treasury debt securities have maturities of less than a year while the remaining securities have maturities of greater than one year. At ~~September 30, 2014~~March 31, 2015, approximately $~~6.2~~5.0 million of Corporate/Other bonds have maturities of less than a year while the remaining securities have maturities of greater than one year.

There are no material items in the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the three ~~and nine~~ months ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014.

Non-recurring Fair Value Measurements. There were no significant non-recurring fair value measurements recorded during the ~~nine~~three months ended ~~September 30, 2014.~~March 31, 2015.

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

B. Other Fair Value Disclosures for Financial Instruments. The carrying amount of cash and cash equivalents, restricted cash, notes receivable, customer deposits and short-term borrowings is a reasonable estimate of fair value due to their liquid or short-term nature. NiSource’s long-term borrowings are recorded at historical amounts.

The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate fair value.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

Long-term Debt. The fair values of these securities are estimated based on the quoted market prices for the same or similar issues or on the rates offered for securities of the same remaining maturities. Certain premium costs associated with the early settlement of long-term debt are not taken into consideration in determining fair value. These fair value measurements are classified as Level 2 within the fair value hierarchy. For the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014, there were no changes in the method or significant assumptions used to estimate the fair value of the financial instruments.

The carrying amount and estimated fair values of financial instruments were as follows:


(in millions)	Carrying Amount as of September 30, 2014		Estimated Fair Value as of September 30, 2014		Carrying Amount as of Dec. 31, 2013		Estimated Fair Value as of Dec. 31, 2013		Carrying Amount as of March 31, 2015		Estimated Fair Value as of March 31, 2015		Carrying Amount as of Dec. 31, 2014		Estimated Fair Value as of Dec. 31, 2014
Long-term debt (including current portion)	$	8,416.1	$	9,338.2	$	8,135.3	$	8,697.3	$	8,420.6	$	9,637.7	$	8,422.5	$	9,505.7

8.9. Transfers of Financial Assets

Transfers of accounts receivable are accounted for as secured borrowings resulting in the recognition of short-term borrowings on the Condensed Consolidated Balance Sheets (unaudited). The maximum amount of debt that can be recognized related to NiSource’s accounts receivable programs is $515 million.

All accounts receivables sold to the ~~commercial paper conduits~~purchasers are valued at face value, which approximates fair value due to their short-term nature. The amount of the undivided percentage ownership interest in the accounts receivables sold is determined in part by required loss reserves under the agreements. Below is information about the accounts receivable securitization agreements entered into by NiSource’s ~~subsidiaries.~~subsidiaries

Columbia of Ohio is under an agreement to sell, without recourse, substantially all of its trade receivables, as they originate, to CGORC, a wholly-owned subsidiary of Columbia of Ohio. CGORC, in turn, is party to an agreement with BTMU and BNS, under the terms of which it sells an undivided percentage ownership interest in its accounts receivable to commercial paper conduits sponsored by BTMU and BNS. ~~This~~This agreement was last renewed on October 17, ~~2014. The maximum seasonal program limit under~~2014; the ~~terms of the current agreement is~~ ~~$240 million. The~~ current agreement expires on October 16, 2015 and can be further renewed if mutually agreed to by all parties. The maximum seasonal program limit under the terms of the current agreement is $240 million. As of ~~September 30, 2014~~, ~~$70.8 million~~ ofMarch 31, 2015, no accounts receivable had been transferred by CGORC. CGORC is a separate corporate entity from NiSource and Columbia of Ohio, with its own separate obligations, and upon a liquidation of CGORC, CGORC’s obligations must be satisfied out of CGORC’s assets prior to any value becoming available to CGORC’s stockholder.

NIPSCO is under an agreement to sell, without recourse, substantially all of its trade receivables, as they originate, to NARC, a wholly-owned subsidiary of NIPSCO. NARC, in turn, is party to an agreement with PNC and Mizuho under the terms of which it sells an undivided percentage ownership interest in its accounts receivable to PNC and a commercial paper ~~conduits~~conduit sponsored by ~~PNC and~~ Mizuho. This agreement was last renewed on August 27, ~~2014. The maximum seasonal program limit under~~2014; the ~~terms of the current agreement is~~ ~~$200 million. The~~ current agreement expires on August 26, 2015 and can be further renewed if mutually agreed to by all parties. The maximum seasonal program limit under the terms of the current agreement is $200 million. As of ~~September 30, 2014~~, ~~$125.0~~March 31, 2015, $200.0 million of accounts receivable had been transferred by NARC. NARC is a separate corporate entity from NiSource and NIPSCO, with its own separate obligations, and upon a liquidation of NARC, NARC’s obligations must be satisfied out of NARC’s assets prior to any value becoming available to NARC’s stockholder.

Columbia of Pennsylvania is under an agreement to sell, without recourse, substantially all of its trade receivables, as they originate, to CPRC, a wholly-owned subsidiary of Columbia of Pennsylvania. CPRC, in turn, is party to an agreement with BTMU under the terms of which it sells an undivided percentage ownership interest in its accounts receivable to a commercial paper conduit sponsored by BTMU. The ~~maximum seasonal program limit under the terms of the agreement is~~ ~~$75 million. The~~ agreement with BTMU was last renewed on March ~~11, 2014,~~10, 2015, having a current scheduled termination date of March ~~10, 2015,~~9, 2016 and can be further renewed if mutually agreed to by both parties. The maximum seasonal program limit under the terms of the agreement is $75 million. As of ~~September 30, 2014~~, ~~$10.0~~March 31, 2015, $75.0 million of accounts receivable had been transferred

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

by CPRC. CPRC is a separate corporate entity from NiSource and Columbia of Pennsylvania, with its own separate obligations, and upon a liquidation of CPRC, CPRC’s obligations must be satisfied out of CPRC’s assets prior to any value becoming available to CPRC’s stockholder.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

The following table reflects the gross and net receivables transferred as well as short-term borrowings related to the securitization transactions as of ~~September 30, 2014~~March 31, 2015 and December 31, ~~2013~~2014 for Columbia of Ohio, NIPSCO and Columbia of Pennsylvania:


(in millions)	September 30, 2014		December 31, 2013		March 31, 2015		December 31, 2014
Gross Receivables	$	374.0	$	610.9	$	755.1	$	611.7
Less: Receivables not transferred	168.2		345.8		480.1		327.4
Net receivables transferred	$	205.8	$	265.1	$	275.0	$	284.3
Short-term debt due to asset securitization	$	205.8	$	265.1	$	275.0	$	284.3

Columbia of Ohio, NIPSCO and Columbia of Pennsylvania remain responsible for collecting on the receivables securitized and the receivables cannot be sold to another party.

9.10. Goodwill

NiSource tests its goodwill for impairment annually as of May 1 unless indicators, events, or circumstances would require an immediate review. Goodwill is tested for impairment using financial information at the reporting unit level, which is consistent with the level of discrete financial information reviewed by operating segment management. NiSource's three reporting units are Columbia Distribution Operations, Columbia Transmission Operations and NIPSCO Gas Distribution Operations.

NiSource's goodwill assets as of September 30, 2014 were $3.7 billion pertaining primarily to the acquisition of Columbia on November 1, 2000. Of this amount, approximately $2.0 billion is allocated to Columbia Transmission Operations and $1.7 billion is allocated to Columbia Distribution Operations. In addition, NIPSCO Gas Distribution Operations' goodwill assets of $17.8 million at September 30, 2014 relate to the purchase of Northern Indiana Fuel and Light in March 1993 and Kokomo Gas in February 1992.

NiSource completed a quantitative ("step 1") fair value measurement of its reporting units during the May 1, 2012 goodwill test. The test indicated that the fair value of each of the reporting units that carry or are allocated goodwill substantially exceeded their carrying values, indicating that no impairment existed.

ASU 2011-08 allows entities testing goodwill for impairment the option of performing a qualitative ("step 0") assessment before calculating the fair value of a reporting unit for the goodwill impairment test. If a step 0 assessment is performed, an entity is no longer required to calculate the fair value of a reporting unit unless the entity determines that, based on that assessment, it is more likely than not that its fair value is less than its carrying amount.

NiSource applied the qualitative step 0 analysis to its reporting units for the annual impairment test performed as of May 1, 2014. For the current year test, NiSource assessed various assumptions, events and circumstances that would have affected the estimated fair value of the reporting units as compared to its base line May 1, 2012 step 1 fair value measurement. The results of this assessment indicated that it is not more likely than not that its reporting unit fair values are less than the reporting unit carrying values.

NiSource considered whether there were any events or changes in circumstances subsequent to the annual test that would reduce the fair value of any of the reporting units below their carrying amounts and necessitate another goodwill impairment test. No such indicators were noted that would require a subsequent goodwill impairment testing during the ~~third quarter.~~first quarter of 2015.

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

~~10.~~11. Income Taxes

NiSource’s interim effective tax rates reflect the estimated annual effective tax rates for ~~2014~~2015 and ~~2013~~2014, adjusted for tax expense associated with certain discrete items. The effective tax rates for the three months ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014 were ~~45.1%~~35.4% and ~~36.0%~~37.9%~~, respectively. The effective tax rate for the nine months ended September 30, 2014 and 2013 were 37.7% and 34.7%~~, respectively. These effective tax rates differ from the Federal tax rate of 35% primarily due to the effects of tax credits, state income taxes, utility ratemaking, and other permanent book-to-tax differences.

The ~~increase~~decrease in the three month effective tax rate of ~~9.1%~~2.5% in ~~2014~~2015 versus 2013 is primarily due to a change in the estimated annual effective tax rate due to a revision in estimated nontaxable income during the third quarter of 2014. The increase in the year-to-date effective tax rate of 3.0%2014 is primarily due to the impact of the Indiana ~~tax~~ rate change ~~see below for further information, and deferred tax adjustments recorded~~ in ~~2013 related to state apportionment changes.~~

On March 25, 2014, the governor of Indiana signed into law Senate Bill 1, which among other things, lowers the corporate income tax rate from 6.5% to 4.9% over six years beginning on July 1, 2015. The reduction in the tax rate will impact deferred income taxes and tax related regulatory assets and liabilities recoverable in the ratemaking process. In addition, other deferred tax assets and liabilities, primarily deferred tax assets related to the Indiana net operating loss carry forward, will be reduced to reflect the lower rate at which these temporary differences and tax benefits will be realized. In the first quarter of 2014, NiSource recorded tax expense of $7.1 million to reflect the effect of this rate change. This expense is largely attributable to the remeasurement of the Indiana net operating loss at the 4.9% rate. The majority of NiSource's tax temporary differences are related to NIPSCO's utility plant. The remeasurement of these temporary differences at 4.9% was recorded as a reduction of a regulatory asset.2014.

There were no material changes recorded in ~~2014~~2015 to NiSource's uncertain tax positions as of December 31, ~~2013.~~2014.

~~11.~~12. Pension and Other Postretirement Benefits

NiSource provides defined contribution plans and noncontributory defined benefit retirement plans that cover its employees. Benefits under the defined benefit retirement plans reflect the employees’ compensation, years of service and age at retirement. Additionally, NiSource provides health care and life insurance benefits for certain retired employees. The majority of employees may become eligible for these benefits if they reach retirement age while working for NiSource. The expected cost of such benefits is accrued during the employees’ years of service. Current rates of rate-regulated companies include postretirement benefit costs, including amortization of the regulatory assets that arose prior to inclusion of these costs in rates. For most plans, cash contributions are remitted to grantor trusts.

For the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015, NiSource has contributed $~~35.3~~0.7 million to its pension plans and $~~29.3~~8.7 million to its other postretirement benefit plans.

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ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

The following tables provide the components of the plans’ net periodic benefits cost for the three ~~and nine~~ months ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014:


	Pension Benefits						Other Postretirement Benefits						Pension Benefits						Other Postretirement Benefits
Three Months Ended September 30, (in millions)	2014			2013			2014			2013
Three Months Ended March 31, (in millions)													2015			2014			2015			2014
Components of Net Periodic Benefit Cost
Service cost	$	8.7		$	9.0		$	2.0		$	3.0		$	9.5		$	8.7		$	1.8		$	2.3
Interest cost	27.2			24.9			7.0			8.0			25.2			27.3			6.8			8.2
Expected return on assets	(45.3		)	(42.0		)	(9.3		)	(7.6		)	(46.2		)	(45.3		)	(9.3		)	(9.1		)
Amortization of transition obligation	—			—			—			0.2
Amortization of prior service cost (credit)	0.1			—			(1.4		)	(0.2		)
Amortization of prior service credit													(0.1		)	—			(1.4		)	(0.6		)
Recognized actuarial loss	11.9			18.9			0.2			2.8			15.9			11.9			1.1			—
Settlement loss	—			4.0			—			—
Total Net Periodic Benefit Cost (Credit)	$	2.6		$	14.8		$	(1.5	)	$	6.2		$	4.3		$	2.6		$	(1.0	)	$	0.8

Pension Benefits
Other Postretirement
Benefits
Nine Months Ended September 30, (in millions)
2014 2013 2014 2013
Components of Net Periodic Benefit Cost
Service cost $ 26.1
$ 27.7
$ 6.5
$ 9.0
Interest cost 81.8
73.5
23.0
24.2
Expected return on assets (135.9 ) (126.5 ) (27.5 ) (22.8 )
Amortization of transition obligation —
—
—
0.4
Amortization of prior service cost (credit) 0.1
0.2
(2.9 ) (0.6 )
Recognized actuarial loss 35.7
59.3
0.3
8.4
Settlement loss —
28.3
—
—
Total Net Periodic Benefit Cost (Credit) $ 7.8
$ 62.5
$ (0.6 ) $ 18.6

~~In 2013, NiSource pension plans had lump sum payouts exceeding the plans' 2013 service cost plus interest cost and, therefore, settlement accounting was required.~~

~~12.~~13. Variable Interests and Variable Interest Entities

In general, a VIE is an entity that (1) has an insufficient amount of at-risk equity to permit the entity to finance its activities without additional financial subordinated support provided by any parties, (2) whose at-risk equity owners, as a group, do not have power, through voting rights or similar rights, to direct activities of the entity that most significantly impact the entity’s economic performance or (3) whose at-risk owners do not absorb the entity’s losses or receive the entity’s residual return. A VIE is required to be consolidated by a company if that company is determined to be the primary beneficiary of the VIE.

NiSource consolidates those VIEs for which it is the primary beneficiary. NiSource considers quantitative and qualitative elements in determining the primary beneficiary. Qualitative measures include the ability to control an entity and the obligation to absorb losses or the right to receive benefits.

NiSource’s analysis includes an assessment of guarantees, operating leases, purchase agreements, and other contracts, as well as its investments and joint ventures. For items that have been identified as variable interests, or where there is involvement with an identified VIE, an in-depth review of the relationship between the relevant entities and NiSource is made to evaluate qualitative and quantitative factors to determine the primary beneficiary, if any, and whether additional disclosures would be required under the current standard.

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

NIPSCO has a service agreement with Pure Air, a general partnership between Air Products and Chemicals, Inc. and First Air Partners LP, under which Pure Air provides scrubber services to reduce sulfur dioxide emissions for Units 7 and 8 at the Bailly Generating Station. NiSource has made an exhaustive effort to obtain information needed from Pure Air to determine the status of Pure Air as a VIE. However, NIPSCO has not been able to obtain this information and, as a result, it is unclear whether Pure Air is a VIE and if NIPSCO is the primary beneficiary. NIPSCO will continue to request the information required to determine whether Pure Air is a VIE. NIPSCO has no exposure to loss related to the service agreement with Pure Air and payments under this agreement were ~~$17.0~~$5.6 million and ~~$17.1~~$5.4 million for the ~~nine~~three months ended ~~September 30,~~March 31, 2015 and 2014, ~~and 2013,~~ respectively.

~~13. Long-Term Debt~~

~~On August 20, 2014, NiSource Finance negotiated a $750.0 million three-year bank term loan with a syndicate of banks which carries a floating interest rate of BBA LIBOR plus 100 basis points.~~

~~On July 15, 2014, NiSource Finance redeemed $500.0 million of 5.40% senior unsecured notes at maturity.~~

14. Short-Term Borrowings

NiSource Finance maintains a $2.0 billion revolving credit facility with a syndicate of banks led by Barclays Capital with a termination date of September 28, 2018. The purpose of the facility is to fund ongoing working capital requirements including the provision of liquidity support for NiSource’s $1.5 billion commercial paper program, provide for issuance of letters of credit, and also for general corporate purposes. At ~~September 30, 2014~~March 31, 2015, NiSource had no outstanding borrowings under this facility.

NiSource Finance's commercial paper program has a program limit of up to $1.5 billion with a dealer group comprised of Barclays, Citigroup, Credit Suisse, RBS and Wells Fargo. Commercial paper issuances are supported by available capacity under NiSource’s $2.0 billion unsecured revolving credit facility. At ~~September 30, 2014~~March 31, 2015, NiSource had $~~1,105.3~~39.0 million of commercial paper outstanding.

As of ~~September 30,~~March 31, 2015 and December 31, 2014,, NiSource had $~~31.2~~30.9 million of stand-by letters of credit outstanding of which $~~15.0~~14.7 million were under the revolving credit facility. At ~~December 31, 2013~~,

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource ~~had~~ ~~$31.6~~Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

CPPL maintains a $500.0 million revolving credit facility, of ~~stand-by~~which $50.0 million is available for issuance of letters of ~~credit~~credit. The purpose of the facility is to provide cash for general partnership purposes, including working capital, capital expenditures and the funding of capital calls. At March 31, 2015, CPPL had no outstanding ~~of which $14.3 million~~ ~~were~~borrowings under ~~the revolving credit~~this facility.

Transfers of accounts receivable are accounted for as secured borrowings resulting in the recognition of short-term ~~debt~~borrowings on the Condensed Consolidated Balance Sheets (unaudited) in the amount of $~~205.8~~275.0 million and $~~265.1~~284.3 million as of ~~September 30, 2014~~March 31, 2015 and December 31, ~~2013~~2014, respectively. Refer to Note ~~8, “Transfers of Financial Assets,”~~9 for additional information.


(in millions)	September 30, 2014		December 31, 2013		March 31, 2015		December 31, 2014
Commercial Paper weighted average interest rate of 0.67% and 0.70% at September 30, 2014 and December 31, 2013, respectively.	$	1,105.3	$	433.6
Commercial Paper weighted average interest rate of 0.96% and 0.82% at March 31, 2015 and December 31, 2014, respectively					$	39.0	$	792.6
Credit facilities borrowings weighted average interest rate of 1.44% at December 31, 2014					—		500.0
Accounts receivable securitization facility borrowings	205.8		265.1		275.0		284.3
Total Short-Term Borrowings	$	1,311.1	$	698.7	$	314.0	$	1,576.9

Given their turnover is less than 90 days, cash flows related to the borrowings and repayments of the items listed above are presented net in the Condensed Statements of Consolidated Cash Flows (unaudited).

15. Share-Based Compensation

The stockholders approved and adopted the NiSource Inc. 2010 Omnibus Incentive Plan (the “Omnibus Plan”), at the Annual Meeting of Stockholders held on May 11, 2010. The Omnibus Plan provides for awards to employees and non-employee directors of incentive and nonqualified stock options, stock appreciation rights, restricted stock and restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. The Omnibus Plan provides that the number of shares of common stock of NiSource available for awards is 8,000,000 plus the number of shares subject to outstanding awards granted under either the long-term incentive plan approved by stockholders on April 13, 1994 ~~Plan (defined below)~~("1994 Plan") or the Director Stock Incentive Plan ("Director Plan"), that expire or terminate for any reason. No further awards are permitted to be granted under the 1994 Plan or the Director Plan. At ~~September 30, 2014~~,March 31, 2015, there were ~~6,260,962~~5,785,224 shares reserved for future awards ~~under the Omnibus Plan.~~

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

Prior to May 11, 2010, NiSource issued long-term equity incentive grants to key management employees under a long-term incentive plan approved by stockholders on April 13, 1994 (“1994 Plan”). The types of equity awards previously authorized under the 1994 Plan did not significantly differ from those permitted under the Omnibus Plan.

NiSource recognized stock-based employee compensation expense of $~~16.3~~11.2 million and $~~8.8~~5.3 million for the three months ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014, respectively, as well as related tax benefits of $~~5.4~~4.0 million and $~~3.2~~2.0 million, ~~respectively. For the nine months ended~~ ~~September 30, 2014~~ ~~and~~ ~~2013, stock-based employee compensation expense of $27.3 million and $17.5 million was recognized, respectively, as well as related tax benefit of $10.1 million and $6.1 million,~~ respectively.

As of ~~September 30, 2014~~March 31, 2015, the total remaining unrecognized compensation cost related to nonvested awards amounted to $~~26.8~~35.8 million, which will be amortized over the weighted-average remaining requisite service period of ~~2.2~~2.3 years.

~~Stock Options.~~ ~~As of~~ ~~September 30, 2014, approximately~~ ~~0.1 million~~ ~~options were outstanding and exercisable with a weighted average strike price of~~ ~~$22.62. No options were granted during the~~ ~~nine months endedSeptember 30, 2014~~ ~~and~~ ~~2013. As of~~ ~~September 30, 2014, the aggregate intrinsic value for the options outstanding and exercisable was~~ ~~$2.0 million. During the~~ ~~nine~~ ~~months ended~~ ~~September 30, 2014~~ ~~and~~ ~~2013, cash received from the exercise of options was~~ ~~$6.8 million~~ ~~and~~ ~~$22.6 million, respectively.~~

Restricted Stock Units and Restricted Stock. During the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015, NiSource granted ~~148,133~~486,523 restricted stock units and shares of restricted stock, subject to service conditions. The total grant date fair value of restricted stock units and shares of restricted stock was $~~4.8~~19.4 million, based on the average market price of NiSource’s common stock at the date of each grant less the present value of any dividends not received during the vesting period, which will be expensed, net of forfeitures, over the vesting period which is generally three years. As of ~~September 30, 2014~~March 31, 2015, ~~309,829~~723,406 nonvested (all of which are expected to vest) restricted stock units and shares of restricted stock ~~were granted and outstanding.~~

~~Performance Shares.~~ ~~During the~~ ~~nine months endedSeptember 30, 2014, NiSource granted~~ ~~535,037~~ ~~performance shares subject to service and performance conditions. The grant date fair value of the awards was~~ ~~$16.6 million~~, based on the average market price of NiSource’s common stock at the date of each grant less the present value of dividends not received during the vesting period which will be expensed, net of forfeitures, over the three year requisite service and performance period. As of ~~September 30, 2014~~, ~~1,735,551~~ ~~nonvested performance shares~~ were granted and outstanding.

401(k) Match, Profit Sharing and Company Contribution. NiSource has a voluntary 401(k) savings plan covering eligible employees that allows for periodic discretionary matches as a percentage of each participant’s contributions payable in shares of common stock. NiSource also has a retirement savings plan that provides for discretionary profit sharing contributions payable in shares of common stock to eligible employees based on earnings results; and eligible exempt employees hired after January 1, 2010, receive a non-elective company contribution of three percent of eligible pay payable in shares of common stock. For the quarters ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014, NiSource recognized 401(k) match, profit sharing and non-elective contribution expense of $~~10.5~~8.2 million and $~~7.9 million, respectively. For the nine months ended~~ ~~September 30, 2014~~ ~~and~~ ~~2013, NiSource recognized 401(k) match, profit sharing and non-elective contribution expenses of~~ ~~$27.4 million~~ ~~and~~ ~~$22.2~~8.5 million, respectively.

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ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

16. Other Commitments and Contingencies

A. Guarantees and Indemnities. As a part of normal business, NiSource and certain subsidiaries enter into various agreements providing financial or performance assurance to third parties on behalf of certain subsidiaries. Such agreements include guarantees and stand-by letters of credit. These agreements are entered into primarily to support or enhance the creditworthiness otherwise attributed to a subsidiary on a stand-alone basis, thereby facilitating the extension of sufficient credit to accomplish the subsidiaries’ intended commercial purposes. The total guarantees and indemnities in existence at ~~September 30, 2014~~March 31, 2015 and the years in which they expire were:


(in millions)	Total		2014		2015		2016		2017		2018		After		Total		2015		2016		2017		2018		2019		After
Guarantees of subsidiaries debt	$	7,960.5	$	—	$	230.0	$	616.5	$	1,257.0	$	800.0	$	5,057.0	$	7,960.5	$	230.0	$	616.5	$	1,257.0	$	800.0	$	500.0	$	4,557.0
Accounts receivable securitization	205.8		205.8		—		—		—		—		—		275.0		275.0		—		—		—		—		—
Lines of credit	1,105.3		1,105.3		—		—		—		—		—		39.0		39.0		—		—		—		—		—
Letters of credit	31.2		—		31.2		—		—		—		—		30.9		30.9		—		—		—		—		—
Other guarantees	142.4		7.4		29.5		—		—		—		105.5		146.8		26.1		3.4		—		—		1.7		115.6
Total commercial commitments	$	9,445.2	$	1,318.5	$	290.7	$	616.5	$	1,257.0	$	800.0	$	5,162.5	$	8,452.2	$	601.0	$	619.9	$	1,257.0	$	800.0	$	501.7	$	4,672.6

Guarantees of Subsidiaries Debt. NiSource has guaranteed the payment of $~~8.0 billion~~7,960.5 million of debt for various wholly-owned subsidiaries including NiSource Finance and Columbia of Massachusetts, and through a support agreement for Capital Markets, which is reflected on NiSource’s Condensed Consolidated Balance Sheets (unaudited). The subsidiaries are required to comply with certain covenants under the debt indenture and in the event of default, NiSource would be obligated to pay the debt’s principal and related interest. NiSource does not anticipate its subsidiaries will have any difficulty maintaining compliance. On October 3, 2011, NiSource executed a Second Supplemental Indenture to the original Columbia of Massachusetts Indenture dated April 1, 1991, for the specific purpose of guaranteeing Columbia of Massachusetts’ outstanding unregistered medium-term notes.

Lines and Letters of Credit and Accounts Receivable Advances. NiSource Finance maintains a $2.0 billion revolving credit facility with a syndicate of banks led by Barclays Capital with a termination date of September 28, 2018. The purpose of the facility is to fund ongoing working capital requirements including the provision of liquidity support for NiSource’s $1.5 billion commercial paper program, provide for ~~the~~ issuance of letters of credit, and also for general corporate purposes. At ~~September 30, 2014~~March 31, 2015, NiSource had no borrowings under its five-year revolving credit facility, $~~1,105.3~~39.0 million in commercial paper outstanding and $~~205.8~~275.0 million outstanding under its accounts receivable securitization agreements. At ~~September 30, 2014~~March 31, 2015, NiSource had issued stand-by letters of credit of approximately $~~31.2~~30.9 million for the benefit of third parties. See Note 14 ~~“Short-Term Borrowings,”~~ for additional information.

CPPL maintains a $500.0 million revolving credit facility, of which $50.0 million is available for issuance of letters of credit. The purpose of the facility is to provide cash for general partnership purposes, including working capital, capital expenditures and the funding of capital calls. At March 31, 2015, CPPL had no outstanding borrowings under this facility.

Other Guarantees or Obligations. NiSource has ~~additional~~ purchase and sales agreement guarantees totaling $25.6 million, which guarantee purchaser performance ~~of the seller’s~~or seller performance under covenants, ~~agreements,~~ obligations, liabilities, representations ~~and~~or warranties under the agreements. No amounts related to the purchase and ~~sales~~sale agreement guarantees are reflected in the Condensed Consolidated Balance Sheets (unaudited). Management believes that the likelihood NiSource would be required to perform or otherwise incur any significant losses associated with any of the aforementioned guarantees is remote.

NiSource has on deposit a letter of credit with Union Bank, N.A., Collateral Agent, in a debt service reserve account in association with Millennium's notes as required under the Deposit and Disbursement Agreement that governs the Millennium notes. This account is to be drawn upon by the note holders in the event that Millennium is delinquent on its principal and interest payments. The value of NiSource’s letter of credit represents 47.5% (NiSource’s ownership ~~percentage~~interest in Millennium) of the debt service reserve account requirement, or ~~$16.2 million~~.$16.2 million. The total exposure for NiSource is ~~$16.2 million~~.$16.2 million. NiSource has an accrued liability of ~~$1.5~~$1.5 million related to the inception date fair value of this guarantee as of ~~September 30, 2014~~.

NiSource has issued other guarantees supporting derivative related payments associated with operating leases for many of its subsidiaries and for other agreements entered into by its current and former subsidiaries.March 31, 2015.

B. Other Legal Proceedings. In the normal course of its business, NiSource and its subsidiaries have been named as defendants in various legal proceedings. In the opinion of management, the ultimate disposition of these currently asserted claims will not have a material impact on NiSource’s consolidated financial statements.

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ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

C. Environmental Matters. NiSource operations are subject to environmental statutes and regulations related to air quality, water quality, hazardous waste and solid waste. NiSource believes that it is in substantial compliance with those environmental regulations currently applicable to its operations and believes that it has all necessary permits to conduct its operations.

It is ~~management’s~~management's continued intent to address environmental issues in cooperation with regulatory authorities in such a manner as to achieve mutually acceptable compliance plans. However, there can be no assurance that fines and penalties will not be incurred. Management expects a significant portion of environmental assessment and remediation costs to be recoverable through rates for certain NiSource companies.

As of ~~September 30, 2014~~March 31, 2015 and December 31, ~~2013~~2014, NiSource had recorded an accrual of approximately $~~130.9~~128.3 million and $~~143.9~~128.4 million, respectively, to cover environmental remediation at various sites. The current portion of this accrual is included in "Legal and environmental" in the Condensed Consolidated Balance Sheets (unaudited). The noncurrent portion is included in "Other noncurrent liabilities" in the Condensed Consolidated Balance Sheets (unaudited). NiSource accrues for costs associated with environmental remediation obligations when the incurrence of such costs is probable and the amounts can be reasonably estimated. The original estimates for cleanup can differ materially from the amount ultimately expended. The actual future expenditures depend on many factors, including currently enacted laws and regulations, the nature and extent of contamination, the method of cleanup, and the availability of cost recovery from customers. These expenditures are not currently estimable at some sites. NiSource periodically adjusts its accrual as information is collected and estimates become more refined.

Air

The actions listed below could require further reductions in emissions from various emission sources. NiSource will continue to closely monitor developments in these matters.

Climate Change. Future legislative and regulatory programs could significantly restrict emissions of GHGs or could impose a cost or tax on GHG emissions.

On June 2, 2014, the EPA proposed a GHG performance standard for existing fossil-fuel fired electric utility generating units under section 111(d) of the Clean Air Act. The proposed rule establishes state-specific ~~CO2~~CO₂ emission rate goals, applied to the state's fleet of fossil-fuel fired electric generating units, and requires each state to submit a plan indicating how the ~~generating units within the~~ state will meet the EPA's emission rate ~~goal.~~goal, including possibly imposing reduction obligations on specific units. Final ~~CO2~~CO₂ emission rate standards are expected to be set by the EPA ~~in June~~by midsummer 2015, and state plans are required to be submitted to the EPA as early as June 2016. The cost to comply with this rule will depend on a number of factors, including the requirements of the final federal regulation and the level of NIPSCO's required GHG reductions. It is possible that this new rule, comprehensive federal or state GHG legislation, or other GHG regulation could result in additional expense or compliance costs that could materially impact NiSource's financial results. NiSource will continue to monitor this matter and cannot estimate its impact at this time.

National Ambient Air Quality Standards. The CAA requires the EPA to set NAAQS for particulate matter and five other pollutants considered harmful to public health and the environment. Periodically the EPA imposes new or modifies existing NAAQS. States that contain areas that do not meet the new or revised standards must take steps to maintain or achieve compliance with the standards. These steps could include additional pollution controls on boilers, engines, turbines, and other facilities owned by electric generation, gas distribution, and gas transmission operations.

The following NAAQS were recently added or modified:

~~Particulate Matter:~~Ozone: ~~In December 2009,~~On November 25, 2014, the EPA ~~issued area~~proposed to lower the 8-hour ozone standard from 75 ppb to within a range of 65-70 ppb. If the standard is finalized and the EPA proceeds with designations, ~~for the 2006 24-hour PM~~_2.5 ~~standard, and several counties in which~~areas where NiSource operates ~~were~~currently designated as ~~non-attainment. In addition, a final rule was promulgated in December 2012 that lowered the annual PM~~_2.5 ~~standard from 15 to 12 µg/m~~³~~. NiSource will continue to monitor these matters and cannot estimate their impact at this time.~~

~~Ozone (eight hour):~~ On September 2, 2011, the EPA announced it would implement its 2008 eight-hour ozone NAAQS rather than tightening the standard in 2012. The EPA will review, and possibly propose a new standard in 2014. In addition, the EPA has designated the Chicago metropolitan area, including the area in which NIPSCO operates one of its electric generation facilities,attainment may be re-classified as ~~non-attainment for ozone.~~non-attainment. NiSource will continue to monitor this matter and cannot estimate ~~the~~its impact ~~of any new rules~~ at this time.

Nitrogen Dioxide ~~(NO2):~~ (NO₂):The EPA revised the NO₂ NAAQS by adding a one-hour standard while retaining the annual standard. The new standard could impact some NiSource combustion sources. The EPA designated all areas of the country as unclassifiable/attainment in January 2012. After the establishment of a new monitoring network and possible modeling implementation, areas will potentially be re-designated sometime in 2016. States with areas that do not meet the standard will be required to develop rules to bring areas into compliance within five years of designation. Additionally, under certain permitting circumstances, emissions

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

from some existing NiSource combustion sources may need to be assessed and mitigated. NiSource will continue to monitor this matter and cannot estimate the impact of these rules at this time.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

Waste

NiSource subsidiaries are potentially responsible parties at waste disposal sites under the CERCLA (commonly known as Superfund) and similar state laws. Additionally, aNiSource affiliates have retained environmental liabilities, including cleanup liabilities, associated with certain former operations.

A program has been instituted to identify and investigate former MGP sites where Gas Distribution Operations subsidiaries or predecessors may have liability. The program has identified 66 such sites where liability is probable. Remedial actions at many of these sites are being overseen by state or federal environmental agencies through consent agreements or voluntary remediation agreements.

NiSource utilizes a probabilistic model to estimate its future remediation costs related to its MGP sites. The model was prepared with the assistance of a third party and incorporates NiSource and general industry experience with remediating MGP sites. NiSource completes an annual refresh of the model in the second quarter of each fiscal year. No material changes to the estimated liability were noted as a result of the refresh completed as of June 30, 2014. The total estimated liability at NiSource related to the facilities subject to remediation was ~~$122.8~~$120.3 million and ~~$129.5~~$121.5 million at ~~September 30, 2014~~March 31, 2015 and December 31, ~~2013~~,2014, respectively. The liability represents NiSource’s best estimate of the probable cost to remediate the facilities. NiSource believes that it is reasonably possible that remediation costs could vary by as much as ~~$25~~$25 million in addition to the costs noted above. Remediation costs are estimated based on the best available information, applicable remediation standards at the balance sheet date, and experience with similar facilities.

Additional Issues Related to Individual Business Segments

The sections below describe various regulatory actions that affect ~~Columbia Pipeline Group Operations and Electric Operations.~~

~~Columbia Pipeline Group Operations.~~

~~Air~~

~~In April 2014, the Pennsylvania DEP proposed~~individual business segments for which NiSource has retained a ~~rule,~~ ~~Additional RACT Requirements for Major Sources of NOx and VOCs~~, which may require emissions reductions from several Columbia Transmission turbines and reciprocating engines. The rule is expected to be finalized by the end of 2014 and would give facilities three years to bring emissions sources into compliance with the reductions required by this rule. Columbia Transmission will continue to monitor developments in this matter and cannot estimate costs at this time.

~~Waste~~

Columbia Transmission continues to conduct characterization and remediation activities at specific sites under a 1995 AOC (subsequently modified in 1996 and 2007). NiSource utilizes a probabilistic model to estimate its future remediation costs related to the 1995 AOC. The model was prepared with the assistance of a third party and incorporates NiSource and general industry experience with remediating sites. NiSource completes an annual refresh of the model in the second quarter of each fiscal year. No material changes to the liability were noted as a result of the refresh completed as of June 30, 2014. The total remaining liability at Columbia Transmission related to the facilities subject to remediation was ~~$2.8 million~~ ~~and~~ ~~$8.7 million~~ at ~~September 30, 2014~~ ~~and~~ ~~December 31, 2013~~, respectively. The liability represents Columbia Transmission’s best estimate of the cost to remediate the facilities or manage the sites. Remediation costs are estimated based on the information available, applicable remediation standards, and experience with similar facilities. Columbia Transmission expects that the remediation for these facilities will be substantially completed in 2015.liability.

Electric Operations.

Air

NIPSCO is subject to a number of ~~new~~ air-quality mandates in the next several years. These mandates ~~require~~required NIPSCO to make capital improvements to its electric generating stations. The cost of capital improvements is estimated to be ~~$860~~$870 million,, of which approximately ~~$155.8~~$107.3 million remains to be spent. This figure includes additional capital improvements associated with the New Source Review Consent Decree and the Utility Mercury and Air Toxics Standards Rule. NIPSCO believes that the capital costs will likely be recoverable from customers.

~~EPA Cross-State Air Pollution Rule / Clean Air Interstate Rule (CAIR) / Transport Rule:~~ On July 6, 2011, the EPA announced its replacement for the 2005 CAIR to reduce the interstate transport of fine particulate matter and ozone. The CSAPR reduces overall emissions of SO2 and NOx by setting state-wide caps on power plant emissions. Implementation of the CSAPR was delayed for

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

several years by litigation, but the EPA recently received permission from a court to begin enforcing CSAPR on January 1, 2015. The EPA’s implementation of CSAPR will not significantly impact NIPSCO's current emissions control plans. NIPSCO utilizes the inventory model in accounting for emission allowances issued under the CAIR program whereby these allowances were recognized at zero cost upon receipt from the EPA. NIPSCO believes its current multi-pollutant compliance plan and New Source Review Consent Decree capital investments will allow NIPSCO to meet the emission requirements of CSAPR.

Utility Mercury and Air Toxics Standards Rule: On December 16, 2011, the EPA finalized the MATS rule establishing new emissions limits for mercury and other air toxics. ~~Compliance for~~ NIPSCO’s affected units ~~is required by~~have completed projects to meet the April 2015 ~~or by April 2016 for those~~compliance deadline. For NIPSCO’s remaining affected units, ~~that have been approved for~~ a one year compliance extension granted by ~~IDEM.~~IDEM delays the compliance date until April 2016. NIPSCO ~~is implementing~~continues to implement an IURC-approved plan for the installation of additional environmental controls needed to comply with ~~MATS.~~

~~New Source Review:~~ ~~On September 29, 2004,~~ the EPA issued an NOV to NIPSCO for alleged violations of the CAA and the Indiana SIP. The NOV alleged that modifications were made to certain boiler units at three of NIPSCO's generating stations between the years 1985 and 1995 without obtaining appropriate air permits for the modifications. NIPSCO, the EPA, the Department of Justice, and IDEM have settled the matter through a consent decree, entered on July 22, 2011.MATS extension.

Water

On August 15, 2014, the EPA published the final Phase II Rule of the Clean Water Act Section 316(b), which requires all large existing steam electric generating stations to meet certain performance standards to reduce the effects on aquatic organisms at their cooling water intake structures. Under this rule, stations will have to either demonstrate that the performance of their existing fish protection systems meet the new standards or develop new systems, such as a closed-cycle cooling tower. The cost to comply will depend on a number of factors, including evaluation of the various compliance options available under the regulation and permitting-related ~~discussions with~~determinations by IDEM. NIPSCO is currently evaluating these options and cannot estimate the cost of compliance at this time.

On June 7, 2013, the EPA published a proposed rule to amend the effluent limitations guidelines and standards for the Steam Electric Power Generating category. These proposed regulations could impose new water treatment requirements on NIPSCO’s electric generating facilities. NIPSCO will continue to monitor developments in this matter and cannot estimate the cost of compliance at this time.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

Waste

On ~~June 21, 2010,~~April 17, 2015, the EPA ~~published~~released a ~~proposed~~final rule for regulation of CCRs. The ~~proposal outlines multiple regulatory approaches that~~rule regulates CCRs under the ~~EPA is considering. These proposed regulations could negatively affect NIPSCO’s ongoing byproduct reuse programs~~Resource Conservation and ~~would impose additional~~Recovery Act Subtitle D, which determines them to be non-hazardous. It will require increased groundwater monitoring, reporting, recordkeeping, and posting related information to the Internet. The rule also establishes requirements onrelated to CCR management, impoundments, landfills and storage. NIPSCO will have to modify its infrastructure and management of ~~coal combustion residuals.~~CCRs under this rule. The rule will allow NIPSCO ~~will~~to continue ~~to monitor developments in this matter~~its byproduct beneficial use program. NIPSCO is currently evaluating the rule and cannot estimate the cost of compliance at this time.

D. Other Matters.

Transmission Upgrade Agreements. On February 11, 2014, NIPSCO entered into two TUAs with upgrade sponsors to complete upgrades on NIPSCO’s transmission system on behalf of those sponsors. The upgrade sponsors have agreed to reimburse NIPSCO for the total cost to construct transmission upgrades and place them into service, ~~which is estimated at $50.3 million,~~ multiplied by a rate of 1.71 ("the multiplier").

On June 10, 2014, certain upgrade sponsors for both TUAs filed a complaint at the FERC against NIPSCO regarding the multiplier stated in the TUAs. On June 30, 2014, NIPSCO filed an answer defending the terms of the TUAs and the just and reasonable nature of the multiplier charged therein and moved for dismissal of the complaint. On December 8, 2014, the FERC issued an order in response to the complaint finding that it is appropriate for NIPSCO to recover, through the multiplier, substantiated costs of ownership related to the TUAs. The FERC set for hearing the issue of what constitutes the incremental costs NIPSCO will incur, but is holding that hearing in abeyance to allow for settlement. NIPSCO will continue to monitor developments in this matter ~~but cannot estimate~~and does not believe the impact ~~(if any) on~~is material to the Condensed Consolidated Financial Statements (unaudited) ~~the complaint will have at this time.~~.

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

Springfield, Massachusetts. On November 23, 2012, while Columbia of Massachusetts was investigating the source of an odor of gas at a service location in Springfield, Massachusetts, a gas service line was pierced and an explosion occurred. While this explosion impacted multiple buildings and resulted in several injuries, no life threatening injuries or fatalities have been reported. Columbia of Massachusetts is fully cooperating with both the Massachusetts DPU and the Occupational Safety & Health Administration in their investigations of this incident. Columbia of Massachusetts believes any costs associated with damages, injuries, and other losses related to this incident are substantially covered by insurance. Any amounts not covered by insurance are not expected to have a material impact on NiSource's consolidated financial statements. In accordance with GAAP, NiSource recorded any accruals and the related insurance recoveries resulting from this incident on a gross basis within the Condensed Consolidated Balance Sheets (unaudited).

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ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

17. Accumulated Other Comprehensive Loss

The following tables display the components of Accumulated Other Comprehensive Loss for the three ~~and nine~~ months ended ~~September 30, 2014~~March 31, 2015 and ~~2013:~~2014:

Three Months Ended September 30, 2014 (in millions)
Gains and Losses on Securities⁽¹⁾

Gains and Losses on Cash Flow Hedges⁽¹⁾

Pension and OPEB Items⁽¹⁾

Accumulated
Other
Comprehensive
Loss⁽¹⁾
Balance as of July 1, 2014 $ 0.5
$ (24.5 ) $ (17.4 ) $ (41.4 )
Other comprehensive income before reclassifications (0.5 ) —
(0.1 ) (0.6 )
Amounts reclassified from accumulated other comprehensive income (0.1 ) 0.6
(0.1 ) 0.4
Net current-period other comprehensive (loss) income (0.6 ) 0.6
(0.2 ) (0.2 )
Balance as of September 30, 2014 $ (0.1 ) $ (23.9 ) $ (17.6 ) $ (41.6 )

Nine Months Ended September 30, 2014 (in millions)
Gains and Losses on Securities⁽¹⁾

Gains and Losses on Cash Flow Hedges⁽¹⁾

Pension and OPEB Items⁽¹⁾

Accumulated
Other
Comprehensive
Loss⁽¹⁾
Balance as of January 1, 2014 $ (0.3 ) $ (25.8 ) $ (17.5 ) $ (43.6 )
Other comprehensive income before reclassifications 0.5
0.1
(0.4 ) 0.2
Amounts reclassified from accumulated other comprehensive income (0.3 ) 1.8
0.3
1.8
Net current-period other comprehensive income (loss) 0.2
1.9
(0.1 ) 2.0
Balance as of September 30, 2014 $ (0.1 ) $ (23.9 ) $ (17.6 ) $ (41.6 )

Three Months Ended September 30, 2013 (in millions)
Gains and Losses on Securities⁽¹⁾

Gains and Losses on Cash Flow Hedges⁽¹⁾

Pension and OPEB Items⁽¹⁾

Accumulated
Other
Comprehensive
Loss⁽¹⁾
Balance as of July 1, 2013 $ (0.7 ) $ (27.2 ) $ (34.1 ) $ (62.0 )
Other comprehensive income before reclassifications 1.0
(0.1 ) (0.6 ) 0.3
Amounts reclassified from accumulated other comprehensive income (0.1 ) 0.7
0.7
1.3
Net current-period other comprehensive income 0.9
0.6
0.1
1.6
Balance as of September 30, 2013 $ 0.2
$ (26.6 ) $ (34.0 ) $ (60.4 )

Nine Months Ended September 30, 2013 (in millions)
Gains and Losses on Securities⁽¹⁾

Gains and Losses on Cash Flow Hedges⁽¹⁾

Pension and OPEB Items⁽¹⁾

Accumulated
Other
Comprehensive
Loss⁽¹⁾
Balance as of January 1, 2013 $ 2.6
$ (28.6 ) $ (39.5 ) $ (65.5 )
Other comprehensive income before reclassifications (1.9 ) (0.1 ) 2.6
0.6
Amounts reclassified from accumulated other comprehensive income (0.5 ) 2.1
2.9
4.5
Net current-period other comprehensive (loss) income (2.4 ) 2.0
5.5
5.1
Balance as of September 30, 2013 $ 0.2
$ (26.6 ) $ (34.0 ) $ (60.4 )



Three Months Ended March 31, 2015 (in millions)	Gains and Losses on Securities⁽¹⁾			Gains and Losses on Cash Flow Hedges⁽¹⁾			Pension and OPEB Items⁽¹⁾			Accumulated Other Comprehensive Loss⁽¹⁾
Balance as of January 1, 2015	$	0.3		$	(23.6	)	$	(27.3	)	$	(50.6	)
Other comprehensive income before reclassifications	1.0			—			—			1.0
Amounts reclassified from accumulated other comprehensive income	(0.1		)	0.9			0.2			1.0
Net current-period other comprehensive income	0.9			0.9			0.2			2.0
Allocation of AOCI to noncontrolling interest	$	—		$	2.0		$	—		$	2.0
Balance as of March 31, 2015	$	1.2		$	(20.7	)	$	(27.1	)	$	(46.6	)

Three Months Ended March 31, 2014 (in millions)	Gains and Losses on Securities⁽¹⁾			Gains and Losses on Cash Flow Hedges⁽¹⁾			Pension and OPEB Items⁽¹⁾			Accumulated Other Comprehensive Loss⁽¹⁾
Balance as of January 1, 2014	$	(0.3	)	$	(25.8	)	$	(17.5	)	$	(43.6	)
Other comprehensive income before reclassifications	0.5			0.1			—			0.6
Amounts reclassified from accumulated other comprehensive income	(0.2		)	0.5			0.2			0.5
Net current-period other comprehensive income	0.3			0.6			0.2			1.1
Balance as of March 31, 2014	$	—		$	(25.2	)	$	(17.3	)	$	(42.5	)

⁽¹⁾All amounts are net of tax. Amounts in parentheses indicate debits.

Equity Investment

As Millennium is an equity method investment, NiSource is required to recognize a proportional share of Millennium’s OCI. The remaining unrecognized loss at ~~September 30, 2014~~March 31, 2015 of $~~16.9~~14.2 million, net of tax, related to terminated interest rate swaps is being amortized over the period ending June 2025 into earnings using the effective interest method through interest expense as interest payments are made by Millennium. The unrecognized loss of $~~16.9~~14.2 million and $~~17.7~~16.6 million at ~~September 30, 2014~~March 31, 2015 and December 31, ~~2013~~2014, respectively, is included in gains and losses on cash flow hedges above.

~~Table of Contents~~

~~ITEM 1. FINANCIAL STATEMENTS (continued)~~

~~NiSource Inc.~~

~~Notes to Condensed Consolidated Financial Statements (unaudited) (continued)~~

18. Business Segment Information

Operating segments are components of an enterprise for which separate financial information is available and evaluated regularly by the chief operating decision maker in deciding how to allocate resources and assess performance. NiSource's Chief Executive Officer is the chief operating decision maker.

At ~~September 30, 2014~~March 31, 2015, NiSource’s operations are divided into three primary business segments. The Gas Distribution Operations segment provides natural gas service and transportation for residential, commercial and industrial customers in Ohio, Pennsylvania, Virginia, Kentucky, Maryland, Indiana and Massachusetts. The Columbia Pipeline Group Operations segment offers gas transportation and storage services for LDCs, marketers and industrial and commercial customers located in northeastern, mid-Atlantic, ~~midwestern~~Midwestern and southern states and the District of Columbia along with unregulated businesses that include midstream services and development of mineral rights positions. The Electric Operations segment provides electric service in 20 counties in the northern part of Indiana.

Table of Contents

ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

The following table provides information about business segments. NiSource uses operating income as its primary measurement for each of the reported segments and makes decisions on finance, dividends and taxes at the corporate level on a consolidated basis. Segment revenues include intersegment sales to affiliated subsidiaries, which are eliminated in consolidation. Affiliated sales are recognized on the basis of prevailing market, regulated prices or at levels provided for under contractual agreements. Operating income is derived from revenues and expenses directly associated with each segment.


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
(in millions)	2014			2013			2014			2013			2015			2014
Revenues
Gas Distribution Operations
Unaffiliated	$	411.9		$	409.5		$	2,593.8		$	2,126.8		$	1,456.2		$	1,565.4
Intersegment	—			—			0.3			0.2			0.1			0.2
Total	411.9			409.5			2,594.1			2,127.0			1,456.3			1,565.6
Columbia Pipeline Group Operations
Unaffiliated	285.7			251.3			900.2			752.0			297.4			303.2
Intersegment	31.9			31.4			106.5			105.9			42.4			42.4
Total	317.6			282.7			1,006.7			857.9			339.8			345.6
Electric Operations
Unaffiliated	424.4			413.6			1,279.9			1,175.9			395.6			450.2
Intersegment	0.3			0.1			0.6			0.5			0.2			0.2
Total	424.7			413.7			1,280.5			1,176.4			395.8			450.4
Corporate and Other
Unaffiliated	1.9			2.4			5.6			5.8			0.5			1.7
Intersegment	138.1			119.6			393.8			351.3			129.9			126.8
Total	140.0			122.0			399.4			357.1			130.4			128.5
Eliminations	(170.3		)	(151.1		)	(501.2		)	(457.9		)	(172.6		)	(169.6		)
Consolidated Gross Revenues	$	1,123.9		$	1,076.8		$	4,779.5		$	4,060.5		$	2,149.7		$	2,320.5
Operating Income (Loss)
Gas Distribution Operations	$	0.8		$	(5.0	)	$	362.4		$	279.1		$	325.2		$	301.8
Columbia Pipeline Group Operations	94.4			98.7			357.0			321.0			163.0			158.9
Electric Operations	76.9			87.5			218.7			212.2			70.0			78.9
Corporate and Other(1)	(14.3		)	(4.8		)	(27.0		)	(13.0		)	(28.1		)	(5.9		)
Consolidated Operating Income	$	157.8		$	176.4		$	911.1		$	799.3		$	530.1		$	533.7

⁽¹⁾Primarily comprised of costs associated with the Proposed Separation.

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ITEM 1. FINANCIAL STATEMENTS (continued)

NiSource Inc.

Notes to Condensed Consolidated Financial Statements (unaudited) (continued)

19. Supplemental Cash Flow Information

The following table provides additional information regarding NiSource’s Condensed Statements of Consolidated Cash Flows (unaudited) for the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014:


	Nine Months Ended September 30,				Three Months Ended March 31,
(in millions)	2014		2013		2015		2014
Supplemental Disclosures of Cash Flow Information
Non-cash transactions:
Capital expenditures included in current liabilities	$	213.9	$	202.7	$	189.3	$	131.4
Assets acquired under a capital lease	69.9		5.7		4.8		51.6
Schedule of interest and income taxes paid:
Cash paid for interest, net of interest capitalized amounts	$	375.0	$	359.4	$	167.7	$	167.7
Cash paid for income taxes	12.2		8.5		4.3		6.8

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

NiSource Inc.

Note regarding forward-looking statements

The Management’s Discussion and Analysis, including statements regarding market risk sensitive instruments, contains “forward-looking statements,” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Investors and prospective investors should understand that many factors govern whether any forward-looking statement contained herein will be or can be realized. Any one of those factors could cause actual results to differ materially from those projected. These forward-looking statements include, but are not limited to, statements concerning NiSource’s plans, objectives, expected performance, expenditures, recovery of expenditures through rates, stated on either a consolidated or segment basis, the Proposed Separation ~~the Columbia Pipeline Partners LP initial public offering~~ and any and all underlying assumptions and other statements that are other than statements of historical fact. From time to time, NiSource may publish or otherwise make available forward-looking statements of this nature. All such subsequent forward-looking statements, whether written or oral and whether made by or on behalf of NiSource, are also expressly qualified by these cautionary statements. All forward-looking statements are based on assumptions that management believes to be reasonable; however, there can be no assurance that actual results will not differ materially.

Factors that could cause actual results to differ materially from the projections, forecasts, estimates and expectations discussed in this Quarterly Report on Form 10-Q include, among other things, weather, fluctuations in supply and demand for energy commodities, growth opportunities for NiSource’s businesses, increased competition in deregulated energy markets, the success of regulatory and commercial initiatives, dealings with third parties over whom NiSource has no control, actual operating experience of NiSource’s assets, the regulatory process, regulatory and legislative changes, the impact of potential new environmental laws or regulations, the results of material litigation, changes in pension funding requirements, changes in general economic, capital and commodity market conditions, counterparty credit risk, the timing to consummate the Proposed ~~Separation and the Columbia Pipeline Partners LP initial public offering (collectively, the “Proposed Transactions”),~~Separation; the risk that a condition to ~~consummation of a proposed transaction~~the Proposed Separation is not ~~satisfied,~~satisfied; disruption to operations as a result of the Proposed ~~Transactions,~~Separation, the inability of one or more of the businesses to operate independently following the completion of the Proposed Separation and the matters set forth in the “Risk Factors” section of NiSource’s ~~2013~~2014 Form 10-K and this Form 10-Q, many of which are beyond the control of NiSource. In addition, the relative contributions to profitability by each segment, and the assumptions underlying the forward-looking statements relating thereto, may change over time. NiSource expressly disclaims aany duty to update any of the forward-looking statements contained in this report.

The following Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with NiSource’s Annual Report on Form 10-K for the fiscal year ended December 31, ~~2013~~2014.

CONSOLIDATED REVIEW

Planned Separation of Columbia Pipeline Group and Initial Public Offering of Columbia Pipeline Partners LP

On September 28, 2014, NiSource (the “Company”) announced that its Board of Directors had approved in principle plans to separate its natural gas pipeline and related businesses into a stand-alone publicly traded company (the “Proposed Separation”). If completed, the Proposed Separation will result in two energy infrastructure companies: NiSource Inc., a fully regulated natural gas and electric utilities company, and Columbia Pipeline Group Inc., a natural gas pipeline, midstream and storage company (“CPG”). The Proposed Separation is expected to occur ~~in mid-2015.~~on July 1, 2015.

Under the plan for the Proposed Separation, NiSource ~~shareholders~~stockholders would retain their current shares of NiSource stock and receive a pro rata distribution of shares of CPG stock in a transaction that is expected to be tax-free to NiSource and its ~~shareholders.~~stockholders for U.S. federal income tax purposes.

The Proposed Separation is subject to various conditions, including, without limitation, the receipt by NiSource of a legal opinion on the tax-free nature of the distribution and final approval of the NiSource Board of Directors. NiSource shareholder approval of the transaction is not required. There is no assurance that the transaction will be completed ~~in mid-2015~~on July 1, 2015 or at all.

In addition, prior to the Proposed Separation, CPG expects to issue its own long-term notes and use the proceeds from that offering to repay intercompany debt and pay a special dividend to NiSource, which plans to use the special dividend to reduce its net debt prior to the Proposed Separation.

On September 29, 2014, Columbia Pipeline Partners LP, a wholly owned subsidiary (“CPPL”), filed with the Securities and Exchange Commission a Registration Statement on Form S-1 related to CPPL’s proposed initial public offeringFebruary 11, 2015, CPPL completed its IPO of 53.8 million common units representing limited ~~partner~~partnership interests, ~~in CPPL. We expect that CPPL will sell a minority share~~constituting 53.5% of ~~its total~~the Partnership's outstanding limited ~~partner interests in the offering, which is expected to occur in the first quarter~~partnership interests. The Partnership received $1,168.4 million of ~~2015. If the proposed offering closes, CPPL’s initial asset would consist of an approximate 14.6% ownership interest in CPG OpCo LP (“Columbia OpCo”), which is the entity that will own~~net proceeds

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)

NiSource Inc.

~~substantially~~from the IPO. NiSource, through CPG, owns the general partner of the Partnership, all of ~~NiSource’s natural gas transmission, midstream~~the Partnership's subordinated units and ~~storage assets. In addition, NiSource, through its ownership~~the incentive distribution rights. The assets of ~~CPG, would indirectly own (a)~~ the ~~remaining ownership~~Partnership consist of a 15.7 percent limited partner interest in Columbia OpCo, ~~(b)~~which consists of substantially all of the ~~general partner~~Columbia Pipeline Group Operations segment. The operations of ~~CPPL, (c)~~ the ~~remaining CPPL limited partner interests that are not sold~~Partnership will be consolidated in NiSource's results as long as the ~~offering and (d) all the incentive distribution rights in CPPL.~~

Partnership remains a subsidiary. If the Proposed Separation occurs, CPG would no longer be a subsidiary of NiSource and, thus, NiSource would cease to own (a) any interest in Columbia OpCo, (b) the general partner of ~~CPPL,~~the Partnership, (c) any of the limited partner interests in ~~CPPL~~the Partnership or (d) any of the incentive distribution rights in ~~CPPL.~~the Partnership.

Executive Summary

NiSource ~~(the “Company”)~~ is an energy holding company under the Public Utility Holding Company Act of 2005 whose subsidiaries are engaged in the transmission, storage and distribution of natural gas in the high-demand energy corridor stretching from the Gulf Coast through the Midwest to New England and the generation, transmission and distribution of electricity in Indiana. NiSource generates ~~virtually 100%~~substantially all of its operating income through these rate-regulated businesses. A significant portion of NiSource’s operations is subject to seasonal fluctuations in sales. During the heating season, which is primarily from November through March, net revenues from gas sales are more significant, and during the cooling season, which is primarily from June through September, net revenues from electric sales and transportation services are more significant, than in other months.

For the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015, net income attributable to NiSource ~~reported income from continuing operations of $376.4~~was $268.4 million, or ~~$1.19~~$0.85 per basic share, compared to ~~$337.9~~$266.2 million, or ~~$1.08~~$0.85 per basic share reported for the same period in ~~2013.~~2014.

The increase in net income ~~from continuing operations~~attributable to NiSource was due primarily to the following items:

Regulatory and service programs at Gas Distribution Operations increased net revenues by ~~$69.9~~$33.2 million primarily due to the impacts of the rate ~~settlement in 2013~~cases at Columbia of Pennsylvania, Columbia of Virginia and Columbia of Massachusetts, as well as the implementation of rates under Columbia of Ohio's approved infrastructure replacement program. Refer to Note 8,7, “Regulatory Matters,” in the Notes to ~~the~~ Consolidated Financial Statements included in ~~NiSource’s~~NiSource's Annual Report on Form 10-K for the fiscal year ended December 31, ~~2013~~2014 for more information.

Demand margin revenue increased by ~~$34.1~~$30.7 million at Columbia Pipeline Group Operations primarily as a result of growth projects placed in service. Refer to the Columbia Pipeline Group Operations' segment discussion for further information on growth projects.

The Company recognized previously deferred gains of $20.8 million from the conveyances of mineral interests at Columbia Pipeline Group Operations. As of September 30, 2014, remaining gains of approximately $21.0 million recorded in "Deferred revenue" on the Condensed Consolidated Balance Sheets (unaudited) will be recognized in earnings upon performance of future obligations.

Net revenues increased by $20.6 million as a result of higher industrial usage at Electric Operations primarily due to large industrial customers expanding plant operations and using less internal generation. Refer to the Electric Operations' segment discussion for further information.

Increased third party drilling activity resulted in an increase in mineral rights royalty revenue at Columbia Pipeline Group Operations of $20.5 million. The Company expects to invest in excess of $20 million a year in its mineral rights positions.

These increases in net income attributable to ~~income from continuing operations~~NiSource were partially offset by the following:

Employee and administrative expense increased by $55.2 million due primarily to outages and maintenance, greater labor expense due to a growing workforce and reduced payroll capitalization, and IT support and enhancement projects.

Interest expense increased by $23.5 million resulting from the issuance of $500.0 million of long-term debt in October 2013 and the issuance of $750.0 million of long-term debt in April 2013. These increases were partially offset by the maturity of $500 million of long-term debt in July 2014 and the maturity of $420.3 million of long-term debt in March 2013.

Outside service costs increased by ~~$22.7~~$26.2 million primarily due to costs associated with the Proposed ~~Separation~~Separation.

Employee and ~~Columbia of Pennsylvania's pipeline safety initiatives.~~

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~~Depreciation and amortization~~administrative expense increased ~~$21.2~~by $20.4 million due primarily to greater labor expense due to ~~higher capital expenditures. NiSource projects 2014 capital expenditures to be approximately $2.2 billion.~~a growing workforce.

These factors and other impacts to the financial results are discussed in more detail within the following discussions of “Results of Operations” and “Results and Discussion of Segment Operations.”

Platform for Growth

NiSource’s business plan will continue to center on commercial and regulatory ~~initiatives;~~initiatives, commercial growth and expansion of the gas transmission and storage ~~business;~~business, and financial management of the balance ~~sheet; and cost and process excellence.~~sheet.

Commercial and Regulatory Initiatives

NiSource is moving forward on regulatory initiatives across several distribution company markets. Whether through full rate case filings or other approaches, NiSource’s goal is to develop strategies that benefit all stakeholders as it addresses changing customer conservation patterns, develops more contemporary pricing structures, and embarks on long-term investment programs to enhance its infrastructure.

NIPSCO continued to focus on customer service, reliability and long-term growth and modernization initiatives during the ~~third~~first quarter, while executing on significant environmental investments.

On April 30, 2014, the IURC approved NIPSCO's seven-year, $710 million, natural gas modernization program, referred to as TDSIC. The program complements the in-progress $1.1 billion electric TDSIC approved in February 2014, and is addressing system modernization as well as system expansion in certain areas.

Progress also continued on two major NIPSCO electric transmission projects designed to enhance system flexibility and reliability. Right-of-way acquisition and permitting are underway for both projects. The Greentown-Reynolds project is a 70-mile, 765-kV line being constructed in a joint development agreement with Pioneer Transmission, and the Reynolds-Topeka project is a 100-mile, 345-kV line. The projects involve a NIPSCO investment of approximately $500 million and are anticipated to be in service by the end of 2018.

Two remaining FGD projects at NIPSCO’s coal-fired electric generating facilities remain on schedule. The FGD investments are part of approximately $860 million in environmental investments, including water quality and emission-control projects, recently completed and planned at NIPSCO’s electric generating facilities. One project is expected to be completed by the end of 2014 and the other by the end of 2015.

~~NiSource's Gas Distribution companies continue to execute their strategy of long-term infrastructure replacement and enhancement and advance their regulatory agenda.~~

On April 30, 2014, Columbia of Virginia filed a rate case with the VSCC to recover investments with a multi-year gas distribution system modernization program. If approved as filed, the case would increase annual revenues by approximately $24.9 million. The VSCC issued a procedural order in the case on May 28, 2014 which scheduled the case for hearing on December 9, 2014. New rates are subject to refund and became effective October 1, 2014.

On March 21, 2014, Columbia of Pennsylvania filed a rate case with the Pennsylvania PUC seeking an annual revenue increase of approximately $54.1 million to support continuation of Columbia of Pennsylvania’s ongoing infrastructure modernization program. On September 5, 2014, the parties to the rate case filed a joint petition which seeks approval of a full settlement which features an annual increase of $32.5 million. On October 17, 2014, the administrative law judge assigned to the case issued a Recommended Decision in which he recommended that the settlement be approved, without modification. A final order from the Pennsylvania PUC is expected in the fourth quarter of 2014.

On June 26, 2014, Massachusetts Governor Deval Patrick signed into law House Bill 4164, an Act relative to natural gas leaks. The centerpiece of the Bill significantly reduces the lag in recovery associated with priority pipe replacement under Columbia of Massachusetts’ current Targeted Infrastructure Reinvestment Factor. Columbia of Massachusetts will make its first filing under the new law on October 31, 2014. Recovery of infrastructure investments made under this program are expected to begin May 1, 2015.

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NIPSCO remains on schedule and on budget with its FGD unit at its Michigan City Generating Station. The approximately $264.8 million project is expected to be placed in service by the end of 2015 along with an additional $80 million in environmental investments at NIPSCO’s coal-fired generating facilities. These investments, supported with cost recovery, help improve air quality and ensure NIPSCO’s generation fleet remains in compliance with current environmental regulations. These investments also help ensure that NIPSCO can continue offering low-cost, reliable and efficient generating capacity for its customers.

Progress also continued on two major NIPSCO electric transmission projects designed to enhance system flexibility and reliability. The Greentown-Reynolds project is a 70-mile, 765-kV line being constructed in a joint development agreement with Pioneer Transmission, and the Reynolds-Topeka project is a 100-mile, 345-kV line. Right-of-way acquisition and permitting are under way for both projects and construction has begun on the Reynolds-Topeka line. The projects involve a NIPSCO investment of approximately $500 million and are anticipated to be in service by the end of 2018.

NiSource's Gas Distribution companies continue to execute their strategy of long-term infrastructure replacement and enhancement and advance their regulatory agenda.

On March 19, 2015, Columbia of Pennsylvania filed a base rate case with the Pennsylvania PUC to support continuation of Columbia of Pennsylvania’s infrastructure modernization and safety programs. If approved as filed, the case would increase annual revenues by $46.2 million. New rates are expected to go into effect during the fourth quarter of 2015.

On April 16, 2015, Columbia of Massachusetts filed a base rate case with the Massachusetts DPU. The case, which seeks increased annual revenues of approximately $49.0 million, is designed to support the company's continued focus on providing safe and reliable service in compliance with increasing state and federal regulations and oversight and recovery of associated increased operations and maintenance costs. An order in the proceeding is expected on February 29, 2016 with new rates effective March 1, 2016.

Columbia of Virginia’s base rate case remains pending with the VSCC. The case is expected to provide a base rate increase of $25.2 million, including recovery of pipeline safety program costs.

Refer to Note 6,7, “Regulatory Matters,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for a complete discussion of regulatory and commercial matters.

Modernization, Commercial Growth and Expansion of the Columbia Pipeline Group Operations

Columbia Pipeline Group Operations continues to make progress on its long-term infrastructure modernization program, as well as a series of midstream and core growth initiatives tied to NiSource's asset position in the Utica and Marcellus Shale production regions.

In January 2015, Columbia ~~Transmission is on track with~~Pipeline Group Operations commenced the ~~second~~third year of ~~its~~the Columbia Transmission long-term system modernization program. The second year of the program includes planned modernization investments of approximately $330 million. Columbia Transmission and its customers have agreed to the initial five years of the comprehensive modernization program, with an opportunity to mutually extend the agreement. The overall program is expected to last 10 years or more and involves an aggregate investment in excess of $4 billion.

In August 2014, Columbia Pipeline Group confirmed details of its planned $1.75 billion investment in the Leach XPress and Rayne XPress projects. The projects will create a new pathway for delivering natural gas supplies to market, providing transportation capacity of approximately 1.5 Bcf per day for Marcellus and Utica shale gas on the Columbia Transmission system and 1.0 Bcf per day on the Columbia Gulf system. The projects, expected to be placed into service by the end of 2017, include approximately150 miles of new transmission pipeline and new compression facilities at multiple sites in Ohio and West Virginia.

The Columbia Pipeline Group Operations segment ~~will~~expects to invest approximately ~~$870~~$300 million in ~~its WB XPress project. This~~modernization investments during 2015. Recovery of approximately $320 million of investments made in 2014 began on February 1, 2015. A settlement with the company's customers, approved in early 2013, addresses the initial five years of an expected 10 to 15 year program that is expected to exceed $4 billion in investment.

Columbia Pipeline Group Operations segment’s East Side Expansion project will transport approximately 1.3 Bcf of Marcellus Shale production on the Columbia Transmission system to pipeline interconnects and East Coast markets, which includes access to the Cove Point LNG terminal. Resolution of conditions precedent is anticipatedbe placed in service in the fourth quarter of ~~2014.~~2015. The $275 million project ~~is expected~~will provide up to ~~be placed in service during the fourth quarter~~312,000 Dth/d of ~~2018.~~additional capacity for Marcellus Shale supplies to reach growing and capacity constrained northeastern and mid-Atlantic markets.

~~NiSource Midstream began work~~Progress continues on ~~its $120~~several other major growth projects, including Columbia Pipeline Group Operations' approximately $1.8 billion combined investment in the Leach and Rayne XPress projects, the approximate $850 million ~~Washington County Gathering~~WB XPress project, the $310 million Cameron Access project, the $50 million Utica Access project, the $33 million Chesapeake LNG project, and the $24 million Kentucky Power Plant project. ~~The project, anchored by a long-term agreement with a subsidiary~~Together these projects will entail approximately 4 billion cubic feet of ~~Range Resources Corporation, will consist of gathering pipelines and compression~~new capacity commitments across the Columbia Pipeline Group Operations' system, including access to LNG export facilities in western Pennsylvania to transport production into a nearby Columbia Transmission pipeline. The project is expected to be in service during the fourth quarter of 2015, with additional expansion expected as gas production grows.

~~NiSource Midstream is expanding~~Louisiana and optimizing its Big Pine Gathering System to support Marcellus Shale production in Western Pennsylvania by investing $65 million in facility enhancements to make a connection to the Big Pine pipeline and add compression facilities that will add incremental capacity. The project is expected to be in service during the third quarter of 2015.

~~Financial Management of the Balance Sheet~~

~~On August 20, 2014, NiSource Finance negotiated a $750.0 million million three-year bank term loan with a syndicate of banks which carries a floating interest rate of BBA LIBOR plus 100 basis points.~~

~~On July 15, 2014, NiSource Finance redeemed $500.0 million million of 5.40% senior unsecured notes at maturity.~~

Additionally on July 15, 2014, $500.0 million of fixed-to-variable interest rate swaps expired, whereby NiSource Finance received payments based upon a fixed 5.40% interest rate and paid a floating interest rate amount based on U.S. 6-month BBA LIBOR plus an average of 0.78% per annum.Maryland.

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NiSource Midstream also is on budget and schedule with the first phase of its $120 million Washington County Gathering project and its approximately $65 million Big Pine Expansion project. Both are expected to be in service in the third quarter of 2015.

Financial Management of the Balance Sheet

On September 28, 2014, NiSource announced that its Board of Directors has approved in principle plans to separate its natural gas pipeline and related businesses into a stand-alone publicly traded company whereby NiSource will continue as a fully regulated natural gas and electric utilities company. The separation announcement triggered ratings reviews by Standard & Poor’s, Moody’s, and Fitch. On September 29, 2014,March 30, 2015, Standard & Poor's affirmed the senior unsecured ratings for NiSource and ~~the existing ratings of~~ its ~~other rated~~ subsidiaries at BBB- and the ~~NiSource Finance~~ commercial paper rating of A-3, placing the company’s ratings on watch positive. On September 29, 2014, Moody's Investors Service affirmed the NiSource senior unsecured rating of Baa2 and commercial paper rating of P-2, with a stable outlook. Additionally, Moody's affirmed NIPSCO’s Baa1 rating and affirmed the Baa2 rating for Columbia of Massachusetts. On September 29, 2014, Fitch affirmed the senior unsecured ratings for NiSource at BBB-, and the existing ratings of all other subsidiaries. Fitch'sA-3. Standard & Poor's outlook for NiSource and all of its subsidiaries is ~~stable.~~Watch Positive.

On February 11, 2015, CPPL completed its IPO of 53.8 million common units representing limited partnership interests. See additional information at the beginning of this section.

In preparation for the Planned Separation, the debt recapitalization process is expected to begin during the second quarter of 2015 and will include CPG issuing its own long-term debt prior to the separation to fund a one-time cash distribution to NiSource, which is to be used, in large part, to reduce NiSource’s net debt.

Ethics and Controls

NiSource has had a long-term commitment to providing accurate and complete financial reporting as well as high standards for ethical behavior by its employees. NiSource’s senior management takes an active role in the development of this Form 10-Q and the monitoring of the company’s internal control structure and performance. In addition, NiSource will continue its mandatory ethics training program for all employees.

~~Refer~~For additional information refer to Item 4, “Controls and ~~Procedures” included in Item 4.~~Procedures.”

Results of Operations

Quarter Ended ~~September 30, 2014~~March 31, 2015

Net Income Attributable to NiSource

NiSource reported net income of ~~$31.4~~$268.4 million,, or ~~$0.10~~$0.85 per basic share, for the three months ended ~~September 30, 2014~~,March 31, 2015, compared to net income of ~~$48.1~~$266.2 million,, or ~~$0.16~~$0.85 per basic share, for the ~~third~~first quarter of ~~2013~~.2014. Income from continuing operations was ~~$31.5~~$268.4 million,, or ~~$0.10~~$0.85 per basic share, for the three months ended ~~September 30, 2014~~,March 31, 2015, compared to income from continuing operations of ~~$49.5~~$266.4 million,, or ~~$0.16~~$0.85 per basic share, for the ~~third~~first quarter of ~~2013~~.2014. Operating income was ~~$157.8~~$530.1 million,, a decrease of ~~$18.6~~$3.6 million from the same period in ~~2013~~.2014. All per share amounts are basic earnings per share. Basic average shares of common stock outstanding at ~~September 30, 2014~~March 31, 2015 were ~~315.4~~316.6 million compared to ~~312.8~~314.2 million at ~~September 30, 2013~~.March 31, 2014.

Comparability of line item operating results between quarterly periods is impacted by regulatory and tax trackers that allow for the recovery in rates of certain costs such as bad debt ~~expenses.~~expense. Therefore, increases in these tracked operating expenses are offset by increases in net revenues and have essentially no impact on income from continuing operations.

Net Revenues

Total consolidated net revenues (gross revenues less cost of sales) for the quarter ended ~~September 30, 2014~~,March 31, 2015, were ~~$893.4~~$1,343.7 million,~~, a~~ ~~$59.6~~ an $84.5 millionincrease from the same period last year. This increase in net revenues was primarily due to increased Gas Distribution Operations' net revenues of $91.1 million, offset by a decrease in Columbia Pipeline Group Operations' net revenues of ~~$35.0 million, higher Gas Distribution Operations' net revenues of $19.5 million and increased Electric Operations' net revenues of $5.7 million.~~

Columbia Pipeline Group Operations’ net revenues increased primarily due to higher regulatory trackers, which are offset in expense, of $15.6 million, increased demand margin revenue of $11.8 million primarily as a result of growth projects placed in service, higher mineral rights royalty revenue of $5.9 million and increased condensate revenue of $2.6$5.8 million.

Gas Distribution Operations’ net revenues increased due primarily ~~due~~ to an increase in regulatory and tax trackers, which are offset in expense, of ~~$10.2~~$50.6 million and an increase of $33.2 million for regulatory and service programs, including the impacts of rate cases at Columbia of Pennsylvania, Columbia of Virginia and Columbia of Massachusetts, as well as the implementation of rates under Columbia of Ohio's approved infrastructure replacement ~~program and the impacts of the rate case at Columbia of Massachusetts.~~program. Additionally, there was ~~an increase in net revenues as result of a settlement of $3.2 million at Columbia of Massachusetts in 2013, increased industrial and commercial usage of $1.4 million,~~ higher ~~net revenues due to increased margins of $1.4 million and higher large customer~~ revenue of ~~$1.3 million.~~

~~Electric Operations’ net revenues increased primarily due to higher industrial and residential usage of $7.4~~$5.3 million ~~increased trackers, which are offset~~resulting from the prior year reduction in expense, of $4.4 million and an increase in the return on the environmental capital investment recovery of $4.2 million due to an increased plant balance eligible for recovery. These increases were partially offset by the effects of weather of $10.3 million.revenue from NIPSCO's GCIM.

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These increases to net revenues were partially offset by the following:

Columbia Pipeline Group Operations’ net revenues decreased due primarily to lower regulatory trackers, which are offset in expense, of $27.4 million and other miscellaneous decreases of $9.1 million. These decreases were partially offset by increased demand margin revenue of $30.7 million as a result of growth projects placed in service and new firm contracts.

Operating Expenses

Operating expenses for the ~~third~~first quarter of ~~2014~~2015 were ~~$747.6~~$829.0 million,, an increase of ~~$79.7~~$93.7 million from the ~~2013~~2014 period. This increase was primarily due to higher operation and maintenance expenses of ~~$60.6~~$72.9 million, increased depreciation and amortization of ~~$8.5 million~~$8.8 and a decrease in the gain on the sale of assets of ~~$6.9~~$10.7 million. The increase in operation and maintenance expenses was primarily due to increased ~~employee and administrative~~outside service costs of ~~$31.7~~$26.2 million, higher regulatory trackers, which are offset in net revenues, of ~~$18.6 million, increased outside service costs of $13.4 million, higher electric generation costs of $3.4~~$24.7 million and increased ~~storm damage~~employee and administrative costs of ~~$3.3 million. These increases were partially offset by a decrease in software data conversion costs of $7.5 million and lower environmental costs of $3.7~~$20.4 million. The increase in depreciation and amortization is primarily due to higher capital expenditures placed in service. The decrease in the gain on the sale of assets primarily resulted from ~~the sale~~lower gains on conveyance of ~~storage base gas in 2013.~~mineral interests of $12.2 million.

Equity Earnings in Unconsolidated Affiliates

Equity Earnings in Unconsolidated Affiliates were ~~$12.0~~$15.4 million during the ~~third~~first quarter of ~~2014~~2015 compared to ~~$10.5~~$9.8 million for the ~~third~~first quarter of ~~2013~~.2014. Equity Earnings in Unconsolidated Affiliates includes earnings from investments in Millennium, Hardy Storage and Pennant, which are integral to the Columbia Pipeline Group Operations’ business. Equity earnings increased primarily from increased earnings at Millennium attributable to growth projects placed in ~~service.~~

~~Other Income (Deductions)~~

~~Other Income (Deductions)~~ ~~reduced~~ ~~income by~~ ~~$100.4 million~~ ~~in the~~ ~~third~~ ~~quarter of~~ ~~2014~~ ~~compared to a~~ ~~reduction~~ ~~in income of~~ ~~$99.0 million~~ ~~in the prior year. The increase in deductions is primarily due to an increase in interest expense of $5.9 million resulting from the issuance of $500.0 million of long-term debt in October 2013~~service and the expiration of $500.0 million of interest rate swaps in July 2014. These increases were partially offset by the maturity of $500.0 million of long-term debt in July 2014. Other, net of $9.2 million was recorded in 2014 compared to $4.7 million in the prior year. This increase is primarily attributable to current period transmission upgrade agreement income.

~~Income Taxes~~

~~Income tax expense for the quarter ended~~ ~~September 30, 2014~~ ~~was~~ ~~$25.9 million~~ ~~compared to~~ ~~$27.9 million~~ in the prior year. NiSource’s interim effective tax rates reflect the estimated annual effective tax rates for 2014 and 2013, adjusted for tax expense associated with certain discrete items. The effective tax rates for the quarters ended ~~September 30, 2014~~ ~~and~~ ~~2013~~ ~~were~~ ~~45.1%~~ ~~and~~ ~~36.0%, respectively. These effective tax rates differ from the Federal tax rate of~~ ~~35%~~ primarily due to the effects of tax credits, state income taxes, utility ratemaking, and other permanent book-to-tax differences. The increase in the three month effective tax rate of 9.1% in 2014 versus 2013 is primarily due to a change in the estimated annual effective tax rate due to a revision in estimated nontaxable income during the third quarter of 2014. Refer to Note 10, "Income Taxes," in the Notes to Condensed Consolidated Financial Statements (unaudited) for further discussion of income taxes.

~~Results of Operations~~

~~Nine Months Ended~~ ~~September 30, 2014~~

~~Net Income~~

~~NiSource reported net income of $375.8 million, or $1.19 per basic share, for the nine months ended~~ ~~September 30, 2014, compared to net income of $380.3 million, or $1.22 per basic share, for the nine months ended~~ ~~2013. Income from continuing operations was $376.4 million, or~~ ~~$1.19~~ ~~per basic share, for the nine months ended~~ ~~September 30, 2014, compared to income from continuing operations of $337.9 million, or $1.08 per basic share, for the nine months ended~~ ~~2013. Operating income was $911.1 million, an increase of $111.8 million from the same period in~~ ~~2013. All per share amounts are basic~~higher earnings ~~per share. Basic average shares of common stock outstanding~~ at ~~September 30, 2014~~ ~~were 314.9 million compared to 312.1 million at~~ ~~September 30, 2013~~.

Comparability of line item operating results between quarterly periods is impacted by regulatory and tax trackers that allow for the recovery in rates of certain costs such as bad debt expenses. Therefore, increases in these tracked operating expenses are offset by increases in net revenues and have essentially no impact on income from continuing operations.

~~Net Revenues~~

~~Total consolidated net revenues (gross revenues less cost of sales) for the nine months ended~~ ~~September 30, 2014~~, were $3,116.0 million, a $323.8 million increase from the same period last year. This increase in net revenues was primarily due to increased Columbia Pipeline Group Operations' net revenues of $148.9 million, higher Gas Distribution Operations' net revenues of $136.9 million, and increased Electric Operations' net revenues of $38.3 million.

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Columbia Pipeline Group Operations’ net revenues increased primarily due to higher regulatory trackers, which are offset in expense, of $87.6 million, increased demand margin revenue of $34.1 million primarilyPennant as a result of ~~growth~~the joint venture projects ~~placed in service, higher mineral rights royalty revenue of $20.5 million due to increased third party drilling activity and higher condensate revenue of $3.7 million.~~

Gas Distribution Operations’ net revenues increased primarily due to an increase of $69.9 million for regulatory and service programs, including the impacts of the rate settlement in 2013 at Columbia of Pennsylvania and the implementation of rates under Columbia of Ohio's approved infrastructure replacement program, the effects of colder weather of $19.7 million and increased regulatory and tax trackers, which are offset in expense, of $17.0 million. Additionally, there was higher residential, commercial and industrial usage of $8.8 million, an increase in off-system sales of $5.1 million, higher revenue of $4.9 million due to increased customer count and an increase in large customer revenue of $4.6 million. Also, there were higher net revenues due to increased margins of $3.9 million, higher net revenues from the recovery of storage inventory costs of $3.6 million and a settlement of $3.2 million at Columbia of Massachusetts in 2013. These increases were partially offset by a decrease of $5.8 million resulting from NIPSCO’s GCIM.

Electric Operations’ net revenues increased primarily due to higher industrial and residential usage of $21.9 million, an increase in the return on the environmental capital investment recovery of $17.3 million due to an increased plant balance eligible for recovery. Additionally, there were increased net revenues of $4.1 million as a result of two electric transmission projects authorized by the MISO and higher off-system sales of $3.9 million. These increases were partially offset by a decrease in transmission upgrade revenue of $6.5 million and the effects of weather of $3.8 million.

~~Operating Expenses~~

~~Operating expenses for the nine months ended~~ ~~September 30, 2014~~ ~~were $2,237.8 million, an increase of $219.3 million from the~~ ~~2013~~ period. This increase was primarily due to higher operation and maintenance expenses of $188.2 million, increased other taxes of $20.8 million and higher depreciation and amortization of $19.4 million. These increases were partially offset by an increase in the gain on sale of assets of $9.1 million. The increase in operation and maintenance expenses was primarily due to increased regulatory trackers, which are offset in net revenues, of $99.9 million, higher employee and administrative costs of $55.2 million, increased outside service costs of $22.7 million, higher electric generation costs of $14.3 million and an increase of uncollectibles of $4.5 million. These increases were partially offset by lower software data conversion costs of $7.5 million and a decrease in environmental costs of $5.5 million. The increase in other taxes is primarily due to higher property and other taxes of $13.9 million and increased tax trackers, which are offset in net revenues, of $6.9 million. The increase in depreciation and amortization is primarily due to higher capital expenditures placed in service. The increase in the gain on sale of assets primarily results from conveyances of mineral interests of $20.8 million, offset by the sale of storage base gas in 2013 of $11.1 million at Columbia Pipeline Group Operations.

~~Equity Earnings in Unconsolidated Affiliates~~

~~Equity Earnings in Unconsolidated Affiliates were $32.9 million during the nine months ended~~ ~~September 30, 2014, compared to $25.6 million from the~~ ~~2013~~ period. Equity Earnings in Unconsolidated Affiliates includes investments in Millennium, Hardy Storage and Pennant, which are integral to the Columbia Pipeline Group Operations’ business. Equity earnings increased primarily from increased earnings at Millennium attributable to growth projects placed in service.going fully in-service.

Other Income (Deductions)

Other Income (Deductions) reduced income by ~~$306.6~~$103.9 million ~~for~~in the ~~nine months ended September 30, 2014,~~first quarter of 2015 compared to a reduction in income of ~~$282.2~~$104.6 million in the prior year. The increase in deductions is primarily due to an increase in interest expense of $23.5 million resulting from the issuance of $500.0 million of long-term debt in October 2013 and the issuance of $750.0 million of long-term debt in April 2013. These increases were partially offset by the maturity of $500 million of long-term debt in July 2014 and the maturity of $420.3 million of long-term debt in March 2013.

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~~NiSource Inc.~~

Income Taxes

Income tax expense for the ~~nine months~~quarter ended ~~September 30, 2014~~March 31, 2015 was ~~$228.1~~$150.9 million compared to ~~$179.2~~$162.7 million in the prior year. NiSource’s interim effective tax rates reflect the estimated annual effective tax rates for ~~2014~~2015 and ~~2013,~~2014, adjusted for tax expense associated with certain discrete items. The effective tax rates for the ~~nine months~~quarters ended ~~September 30,~~March 31, 2015 and 2014 were 35.4% and ~~2013~~ ~~were 37.7% and 34.7%~~37.9%, respectively. These effective tax rates differ from the Federal tax rate of 35% primarily due to the effects of tax credits, state income taxes, utility ~~rate-making,~~ratemaking, and other permanent book-to-tax differences. The ~~increase~~decrease in the ~~year-to-date~~three month effective tax rate of ~~3.0%~~2.5% in 2015 versus 2014 is primarily due to the impact of the Indiana ~~tax~~ rate change ~~and deferred tax adjustments recorded~~ in ~~2013 related to state apportionment changes.~~2014. Refer to Note ~~10,~~11, "Income Taxes," in the Notes to Condensed Consolidated Financial Statements (unaudited) for further discussion of income taxes.

~~Discontinued Operations~~

~~There was a net loss of $0.6 million in the nine months ended~~ ~~September 30, 2014~~ ~~from discontinued operations compared to net income of $7.5 million in~~ ~~2013~~. The net income in 2013 relates primarily to a settlement at NiSource's former exploration and production subsidiary, CER. A gain on the disposition of discontinued operations of $36.4 million was recorded in the first quarter of 2013 as a result of a gain on the sale of the service plan and leasing business lines of NiSource's Retail Services business.

Liquidity and Capital Resources

A significant portion of NiSource’s operations, most notably in the gas distribution, gas transportation and electric businesses, are subject to seasonal fluctuations in cash flow. During the heating season, which is primarily from November through March, cash receipts from gas sales and transportation services typically exceed cash requirements. During the summer months, cash on hand, together with the seasonal increase in cash flows from the electric business during the summer cooling season and external short-term and long-term financing, is used to purchase gas to place in storage for heating season deliveries and perform necessary maintenance of facilities. NiSource believes that through income generated from operating activities, amounts available under its short-term revolver, commercial paper program, ~~and~~ long-term debt agreements and NiSource’s ability to access the capital markets, there is adequate capital available to fund its operating activities and capital expenditures in ~~2014~~2015.

Operating Activities

Net cash from operating activities for the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015 was ~~$886.5~~$604.3 million, ~~a decrease~~an increase of ~~$192.1~~$210.3 million compared to the ~~nine~~three months ended ~~September 30, 2013.~~March 31, 2014. The ~~decrease~~increase in net cash from operating activities was primarily ~~attributable~~due to an ~~income tax refund received~~increase in ~~2013.~~overrecovered gas and fuel costs and accounts receivable working capital accounts as a result of lower gas prices and warmer weather in the first quarter of 2015 compared to the same period in 2014.

Pension and Other Postretirement Plan Funding. NiSource expects to make contributions of approximately ~~$38.3~~$3.5 million to its pension plans and approximately ~~$39.1~~$34.8 million to its other postretirement benefit plans in ~~2014~~,2015, which could change depending on market conditions. For the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015, NiSource has contributed $~~35.3~~0.7 million to its pension plans and $~~29.3~~8.7 million to its other postretirement benefit plans.

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Investing Activities

NiSource’s capital expenditures for the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015 were ~~$1,441.7~~$407.5 million, compared to ~~$1,297.3~~$386.3 million for the comparable period in ~~2013.~~2014. This increased spending is mainly due to ~~continued spending on infrastructure replacement programs in the Gas Distributions Operations segment,~~ higher spending in the Columbia Pipeline Group Operations segment ~~for~~on various growth projects primarily in the Marcellus and Utica Shale areas and for expenditures under ~~its~~the modernization ~~program and increased expenditures in the Electric Operations segment primarily due to TDSIC spend.~~program. NiSource projects ~~2014~~2015 capital expenditures to be approximately ~~$2.2~~$2.4 billion.

Restricted cash was $~~16.0~~21.6 million and $~~8.0~~24.9 million as of ~~September 30, 2014~~March 31, 2015 and December 31, ~~2013~~2014, respectively.

Contributions to equity investees decreased ~~$13.3~~$32.2 million primarily due to ~~lower~~no contributions being made ~~by Columbia Transmission~~ to ~~Millennium and NiSource Midstream to Pennant. Refer to~~Pennant during the ~~Columbia Pipeline Group Operations segment discussion in~~first quarter of 2015 as a result of the ~~Management's Discussion and Analysis of Financial Condition and Results of Operations for information on these contributions.~~joint venture projects going fully in-service.

Financing Activities

Columbia Pipeline Partners LP. CPPL received net proceeds of $1,168.4 million from its IPO completed on February 11, 2015.

Credit Facilities. N~~iSource~~NiSource Finance currently maintains a $2.0 billion revolving credit facility with a syndicate of banks led by Barclays Capital with a termination date of September 28, 2018. The purpose of the facility is to fund ongoing working capital requirements

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~~NiSource Inc.~~

including the provision of liquidity support for ~~NiSource Finance’s~~NiSource’s $1.5 billion commercial paper program, provide for issuance of letters of credit, and also for general corporate purposes. In December 2014, with an effective date pending the Proposed Separation of NiSource and CPG, NiSource Finance revised the $2.0 billion revolver to $1.5 billion and extended the termination date to the fifth anniversary of the effective date. Contemporaneous with the revision to NiSource Finance’s revolving credit facility, revolving credit facilities were established for CPG and CPPL in the amount of $1.5 billion and $500 million, respectively.

As of March 31, 2015, NiSource has deferred $8.8 million of debt issuance costs related to the establishment of the CPG and CPPL credit facilities and the revision of the NiSource Finance facility.

The $1.5 billion CPG credit facility will be effective with the Proposed Separation.

CPPL's $500 million revolving credit facility, of which $50 million will be available for issuance of letters of credit, became effective upon the closing of the IPO. The purpose of the facility is to provide cash for general partnership purposes, including working capital, capital expenditures and the funding of capital calls.

NiSource Finance's commercial paper program has a program limit of up to $1.5 billion with a dealer group comprised of Barclays, Citigroup, Credit Suisse, RBS and Wells Fargo. Commercial paper issuances are supported by available capacity under ~~NiSource Finance’s~~NiSource’s $2.0 billion unsecured revolving credit ~~facility.~~facility, which expires in September 2018. The aforementioned pending revolver amendment for NiSource Finance and pending revolver for CPG are expected to support commercial paper borrowings of $1.5 billion each. CPPL is not expected to issue commercial paper.

NiSource Finance had no borrowings outstanding under its revolving credit facility at ~~September 30, 2014~~March 31, 2015 and $500.0 million at December 31, ~~2013. In addition, NiSource Finance had $1,105.3 million in commercial paper outstanding at~~ ~~September 30,~~ 2014, at a weighted average interest rate of ~~0.67%~~ ~~and~~ ~~$433.6~~1.44%. In addition, NiSource Finance had $39.0 million in commercial paper outstanding at ~~December~~March 31, ~~2013~~,2015, at a weighted average interest rate of ~~0.70%~~0.96% and $792.6 million in commercial paper outstanding at December 31, 2014, at a weighted average interest rate of 0.82%.

As of ~~September 30, 2014~~March 31, 2015 and December 31, ~~2013,~~2014, NiSource had ~~$205.8~~$275.0 million and ~~$265.1~~$284.3 million, respectively, of short-term borrowings recorded on the Condensed Consolidated Balance Sheets (unaudited) ~~and cash from financing activities in the same amount~~ relating to its accounts receivable securitization facilities. See Note 8,9, “Transfers of Financial Assets,” in the Notes to ~~the~~ Condensed Consolidated Financial Statements (unaudited).

As of ~~September 30,~~March 31, 2015 and December 31, 2014,, NiSource had ~~$31.2~~$30.9 million of stand-by letters of credit outstanding of which ~~$15.0~~$14.7 million were under the revolving credit facility. At ~~December 31, 2013, NiSource had~~ ~~$31.6 million~~ ~~of stand-by letters of credit outstanding of which $14.3 million~~ ~~were under the revolving credit facility.~~

As of ~~September 30, 2014~~March 31, 2015, an aggregate of ~~$879.7~~$1,946.3 million of credit was available under the credit facility.

Debt Covenants. NiSource is subject to a financial covenant under its revolving credit facility and its three-year term loans, which ~~requires~~require NiSource to maintain a debt to capitalization ratio that does not exceed 70%. A similar covenant in a 2005 private placement note purchase agreement requires NiSource to maintain a debt to capitalization ratio that does not exceed 75%. As of ~~September 30, 2014~~,March 31, 2015, the ratio was ~~61.8%~~53.9%.

NiSource is also subject to certain other non-financial covenants under the revolving credit ~~facility and the term loans.~~facility. Such covenants include a limitation on the creation or existence of new liens on NiSource’s assets, generally exempting liens on utility assets, purchase

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NiSource Inc.

money security interests, preexisting security interests and an additional subset of assets equal to $150 million. An asset sale covenant generally restricts the sale, lease and/or transfer of NiSource’s assets to no more than 10% of its consolidated total assets and dispositions for a price not materially less than the fair market value of the assets disposed of that do not impair the ability of NiSource and NiSource Finance to perform obligations under the revolving credit facility, and that, together with all other such dispositions, would not have a material adverse effect. The revolving credit facility ~~and the term loans~~ also ~~include~~includes a cross-default provision, which triggers an event of default under the credit facility in the event of an uncured payment default relating to any indebtedness of NiSource or any of its subsidiaries in a principal amount of $50 million or more.

NiSource’s indentures generally do not contain any financial maintenance covenants. However, NiSource’s indentures are generally subject to cross-default provisions ranging from uncured payment defaults of $5 million to $50 million, and limitations on the incurrence of liens on NiSource’s assets, generally exempting liens on utility assets, purchase money security interests, preexisting security interests and an additional subset of assets capped at 10% of NiSource’s consolidated net tangible assets.

CPPL's revolving credit facility contains various covenants and restrictive provisions which, among other things, limit CPPL’s and its restricted subsidiaries’ ability to incur additional indebtedness, guarantees and/or liens; consolidate, merge or transfer all or substantially all of their assets; make certain investments or restricted payments; modify certain material agreements; engage in certain types of transactions with affiliates; dispose of assets; and prepay certain indebtedness, each of which is subject to customary and usual exceptions and baskets, including an exception to the limitation on restricted payments for distributions of available cash, as permitted by CPPL's organizational documents. If CPPL fails to perform its obligations under these and other covenants, the revolving credit commitment could be terminated and any outstanding borrowings, together with accrued interest, under the revolving credit facility could be declared immediately due and payable. The CPPL revolving credit facility also contains customary events of default, including cross default provisions that apply to any other indebtedness CPPL may have with an outstanding principal amount in excess of $50 million.

CPPL's revolving credit facility also contains certain negative financial covenants that will require CPPL (a) to maintain a consolidated total leverage ratio that does not exceed (i) 5.75 to 1.00 for the test period ending December 31, 2015, (ii) 5.50 to 1.00 for any test period ending after December 31, 2015 and on or before December 31, 2017, and (iii) 5.00 to 1.00 for any test period ending after December 31, 2017, provided that after December 31, 2017 and during a Specified Acquisition Period (as defined in CPPL's revolving credit facility), then the leverage ratio may not exceed 5.50 to 1.00 and (b) until CPG has received an investment grade rating, to maintain a Consolidated Interest Coverage Ratio (as defined in the MLP revolving credit facility) of no less than 3.00 to 1.00.

A breach by CPPL of any of these covenants could result in a default in respect of the related debt. If a default occurred, the relevant lenders could elect to declare the debt, together with accrued interest and other fees, to be immediately due and payable and proceed against CPPL or any guarantor, including NiSource.

Sale of Trade Accounts Receivables. Refer to Note 8,9, “Transfers of Financial Assets,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on the sale of trade accounts receivable.

All accounts receivable sold to the ~~commercial paper conduits~~purchasers are valued at face value, which approximates fair value due to their short-term nature. The amount of the undivided percentage ownership interest in the accounts receivables sold is determined, in part, by required loss reserves under the agreements.

Credit Ratings. On September 28, 2014, NiSource announced that its Board of Directors has approved in principle plans to separate its natural gas pipeline and related businesses into a stand-alone publicly traded company whereby NiSource will continue as a fully regulated natural gas and electric utilities company. The separation announcement triggered ratings reviews by Standard & Poor’s, Moody’s, and Fitch. On September 29, 2014,March 30, 2015, Standard & Poor's affirmed the senior unsecured ratings for NiSource and ~~the existing ratings of~~ its ~~other rated~~ subsidiaries at BBB- and the ~~NiSource Finance~~ commercial paper rating of ~~A-3, placing the company’s ratings on watch positive.~~A-3. Standard & Poor's outlook for NiSource and all of its subsidiaries is Watch Positive. On September 29, 2014, Moody's ~~Investors Service~~ affirmed the NiSource senior unsecured rating of Baa2 and commercial paper rating of P-2, with a stable outlook. Additionally, Moody's affirmed NIPSCO’s Baa1 rating and affirmed the Baa2 rating for Columbia of Massachusetts. On September 29, 2014, Fitch affirmed the senior

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~~NiSource Inc.~~

unsecured ratings for NiSource at BBB-, and the existing ratings of its other rated subsidiaries. Fitch's outlook for NiSource and its subsidiaries is stable. Although all ratings continue to be investment grade, a downgrade by either Standard & Poor's or Fitch would result in a rating that is below investment grade.

Certain NiSource affiliates have agreements that contain “ratings triggers” that require increased collateral if the credit ratings of NiSource or certain of its subsidiaries are rated below BBB- by Standard & ~~Poor’s~~Poor's or Baa3 by ~~Moody’s.~~Moody's. These agreements are primarily for insurance purposes and for the physical purchase or sale of power. The collateral requirement that would be required in the event of a downgrade below the ratings trigger levels would amount to approximately ~~$38.9 million.~~$39.7 million as of March 31, 2015. In addition to agreements with ratings triggers, there are other agreements that contain “adequate assurance” or “material adverse change” provisions that could necessitate additional credit support such as letters of credit and cash collateral to transact business.

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NiSource Inc.

Contractual Obligations. There were no material changes recorded during the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015 to NiSource’s contractual obligations as of December 31, ~~2013.~~2014.

Market Risk Disclosures

Risk is an inherent part of NiSource’s energy businesses. The extent to which NiSource properly and effectively identifies, assesses, monitors and manages each of the various types of risk involved in its businesses is critical to its profitability. NiSource seeks to identify, assess, monitor and manage, in accordance with defined policies and procedures, the following principal market risks that are involved in NiSource’s energy businesses: commodity price risk, interest rate risk and credit risk. Risk management at NiSource is a multi-faceted process with oversight by the Risk Management Committee that requires constant communication, judgment and knowledge of specialized products and markets. NiSource’s senior management takes an active role in the risk management process and has developed policies and procedures that require specific administrative and business functions to assist in the identification, assessment and control of various risks. These include but are not limited to market, operational, financial, compliance and strategic risk types. In recognition of the increasingly varied and complex nature of the energy business, NiSource’s risk management process, policies and procedures continue to evolve and are subject to ongoing review and modification.

Commodity Price Risk

NiSource is exposed to commodity price risk as a result of its subsidiaries’ operations involving natural gas and power. To manage this market risk, NiSource’s subsidiaries use derivatives, including commodity futures contracts, swaps and options. NiSource is not involved in speculative energy trading activity.

Commodity price risk resulting from derivative activities at NiSource’s rate-regulated subsidiaries is limited, since regulations allow recovery of prudently incurred purchased power, fuel and gas costs through the ratemaking process, including gains or losses on these derivative instruments. If states should explore additional regulatory reform, these subsidiaries may begin providing services without the benefit of the traditional ratemaking process and may be more exposed to commodity price risk. Some of NiSource’s rate-regulated utility subsidiaries offer commodity price risk products to its customers for which derivatives are used to hedge forecasted customer usage under such products. These subsidiaries do not have regulatory recovery orders for these products and are subject to gains and losses recognized in earnings due to hedge ineffectiveness.

There are no material commodity price risk assets or liabilities as of ~~September 30, 2014~~March 31, 2015 and December 31, ~~2013.~~2014.

Interest Rate Risk

NiSource is exposed to interest rate risk as a result of changes in interest rates on borrowings under its revolving credit agreement, term loans, commercial paper program and accounts receivable programs, which have interest rates that are indexed to short-term market interest rates. Based upon average borrowings and debt obligations subject to fluctuations in short-term market interest rates, an increase (or decrease) in short-term interest rates of 100 basis points (1%) would have increased (or decreased) interest expense by $~~5.6~~4.9 million ~~and $13.6 million~~ for the three ~~and nine~~ months ended~~September 30, 2014, respectively,~~March 31, 2015 and $~~3.6~~3.7 million ~~and $10.7 million~~ for the three ~~and nine~~ months ended~~September 30, 2013, respectively.~~March 31, 2014.

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~~NiSource Inc.~~

Credit Risk

Due to the nature of the industry, credit risk is embedded in many of NiSource’s business activities. NiSource’s extension of credit is governed by a Corporate Credit Risk Policy. In addition, Risk Management Committee guidelines are in place which document management approval levels for credit limits, evaluation of creditworthiness, and credit risk mitigation efforts. Exposures to credit risks are monitored by the Corporate Credit Risk function which is independent of commercial operations. Credit risk arises due to the possibility that a customer, supplier or counterparty will not be able or willing to fulfill its obligations on a transaction on or before the settlement date. For derivative related contracts, credit risk arises when counterparties are obligated to deliver or purchase defined commodity units of gas or power to NiSource at a future date per execution of contractual terms and conditions. Exposure to credit risk is measured in terms of both current obligations and the market value of forward positions net of any posted collateral such as cash and letters of ~~credit and qualified guarantees of support.~~credit.

NiSource closely monitors the financial status of its banking credit providers. NiSource evaluates the financial status of its banking partners through the use of market-based metrics such as credit default swap pricing levels, and also through traditional credit ratings provided by major credit rating agencies.

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NiSource Inc.

Fair Value Measurement

NiSource measures certain financial assets and liabilities at fair value. The level of the fair value hierarchy disclosed is based on the lowest level of input that is significant to the fair value measurement. NiSource’s financial assets and liabilities include price risk assets and liabilities, available-for-sale securities and a deferred compensation plan obligation.

Exchange-traded derivative contracts are generally based on unadjusted quoted prices in active markets and are classified within Level 1. These financial assets and liabilities are secured with cash on deposit with the exchange; therefore nonperformance risk has not been incorporated into these valuations. Certain non-exchange-traded derivatives are valued using broker or over-the-counter, on-line exchanges. In such cases, these non-exchange-traded derivatives are classified within Level 2. Non-exchange-based derivative instruments include swaps, forwards, and options. In certain instances, NiSource may utilize models to measure fair value. Valuation models utilize various inputs that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, other observable inputs for the asset or liability, and market-corroborated inputs, i.e., inputs derived principally from or corroborated by observable market data by correlation or other means. Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. Certain derivatives trade in less active markets with a lower availability of pricing information and models may be utilized in the valuation. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized in Level 3. Credit risk is considered in the fair value calculation of derivative instruments that are not exchange-traded. Credit exposures are adjusted to reflect collateral agreements which reduce exposures.

Refer to Note 7,8, “Fair Value” in the Notes to the Condensed Consolidated Financial Statements (unaudited) for additional information on NiSource’s fair value measurements.

Off Balance Sheet Arrangements

As a part of normal business, NiSource and certain subsidiaries enter into various agreements providing financial or performance assurance to third parties on behalf of certain subsidiaries. Such agreements include guarantees and stand-by letters of credit.

NiSource has purchase and sales agreement guarantees totaling $25.6 million, which guarantee purchaser performance ~~of the seller’s~~or seller performance under covenants, ~~agreements,~~ obligations, liabilities, representations ~~and~~or warranties under the agreements. No amounts related to the purchase and sales agreement guarantees are reflected in the Condensed Consolidated Balance Sheets (unaudited). Management believes that the likelihood NiSource would be required to perform or otherwise incur any significant losses associated with any of the aforementioned guarantees is remote.

NiSource has other guarantees outstanding. Refer to Note 16-A, ~~“Guarantees~~“Other Commitments and Guarantees - Guarantees and Indemnities,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information about NiSource’s off balance sheet arrangements.

Other Information

Critical Accounting Policies

There were no significant changes to critical accounting policies for the period ended March 31, 2015.

Recently Issued Accounting Pronouncements

In April 2015, the FASB issued ASU 2015-05, Intangibles - Goodwill and Other-Internal-Use Software (Subtopic 350-40):Customer's Accounting for Fees Paid in a Cloud Computing Arrangement. ASU 2015-05 clarifies guidance on determining whether a cloud computing arrangement contains a software license that should be accounted for as internal-use software. NiSource is required to adopt ASU 2015-05 for periods beginning after December 15, 2015, including interim periods, and the guidance is permitted to be applied either (1) prospectively to all agreements entered into or materially modified after the effective date or (2) retrospectively, with early adoption permitted. NiSource is currently evaluating the impact the adoption of ASU 2015-05 will have on the Condensed Consolidated Financial Statements (unaudited) or Notes to Condensed Consolidated Financial Statements (unaudited).

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~~Other Information~~

~~Critical Accounting Policies~~

~~There were no significant changes to critical accounting policies for the period ended~~ ~~September 30, 2014~~.

~~Recently Issued Accounting Pronouncements~~

~~In May 2014, the FASB issued ASU 2014-09,~~ ~~Revenue from Contracts with Customers (Topic 606)~~. ASU 2014-09 outlines a single, comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance. The core principle of the new standard is that an entity should recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. NiSource is required to adopt ASU 2014-09 for periods beginning after December 15, ~~2016,~~2015, including interim periods, and the ~~new standard~~guidance is to be applied retrospectively with early adoption ~~not~~ permitted. NiSource is currently evaluating the impact the adoption of ASU ~~2014-09~~2015-03 will have on ~~its~~the Condensed Consolidated Financial Statements (unaudited) or Notes to Condensed Consolidated Financial Statements (unaudited).

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NiSource Inc.

RESULTS AND DISCUSSION OF SEGMENT OPERATIONS

Presentation of Segment Information

NiSource’s operations are divided into three primary business segments: Gas Distribution Operations, Columbia Pipeline Group Operations and Electric Operations.

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Gas Distribution Operations


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
(in millions)	2014			2013			2014			2013			2015			2014
Net Revenues
Sales revenues	$	411.9		$	409.5		$	2,594.1		$	2,127.0		$	1,456.3		$	1,565.6
Less: Cost of gas sold (excluding depreciation and amortization)	114.6			131.7			1,294.8			964.6			722.6			923.0
Net Revenues	297.3			277.8			1,299.3			1,162.4			733.7			642.6
Operating Expenses
Operation and maintenance	208.8			199.1			644.4			614.6			291.8			228.8
Depreciation and amortization	55.4			51.1			161.7			149.7			56.1			52.2
Loss (Gain) on sale of assets	—			1.3			(0.2		)	1.2
Other taxes	32.3			31.3			131.0			117.8			60.6			59.8
Total Operating Expenses	296.5			282.8			936.9			883.3			408.5			340.8
Operating Income (Loss)	$	0.8		$	(5.0	)	$	362.4		$	279.1
Operating Income													$	325.2		$	301.8
Revenues ($ in millions)
Residential	$	249.1		$	235.3		$	1,646.0		$	1,331.2		$	1,014.9		$	1,005.8
Commercial	77.0			68.7			572.7			452.2			369.4			366.3
Industrial	36.9			32.0			169.3			140.6			88.0			84.3
Off System	28.5			54.8			166.3			210.4			38.8			71.9
Other	20.4			18.7			39.8			(7.4		)	(54.8		)	37.3
Total	$	411.9		$	409.5		$	2,594.1		$	2,127.0		$	1,456.3		$	1,565.6
Sales and Transportation (MMDth)
Residential	15.4			15.2			206.9			182.0			153.1			156.5
Commercial	17.5			16.2			135.0			118.5			88.7			90.1
Industrial	126.2			120.7			384.7			367.4			146.8			136.8
Off System	7.1			15.6			35.6			55.7			13.5			14.3
Other	—			—			(0.1		)	0.4			—			0.2
Total	166.2			167.7			762.1			724.0			402.1			397.9
Heating Degree Days	100			94			4,092			3,576			3,404			3,437
Normal Heating Degree Days	85			85			3,576			3,576			2,892			2,892
% Colder than Normal	18		%	11		%	14		%	—		%	18		%	19		%
Customers
Residential							3,035,401			3,022,289			3,111,880			3,094,353
Commercial							276,923			276,219			284,081			283,000
Industrial							7,512			7,488			7,641			7,570
Other							15			22			15			20
Total							3,319,851			3,306,018			3,403,617			3,384,943

NiSource’s Gas Distribution Operations serve approximately ~~3.3~~3.4 million customers in seven states: Ohio, Indiana, Pennsylvania, Massachusetts, Virginia, Kentucky and Maryland. The regulated subsidiaries offer both traditional bundled services as well as transportation only for customers that purchase gas from alternative suppliers. The operating results reflect the temperature-sensitive nature of customer demand with ~~74%~~73% of annual residential and commercial throughput affected by seasonality. As a result, segment operating income is higher in the first and fourth quarters reflecting the heating demand during the winter season.

Regulatory Matters

Refer to Note 6,7, “Regulatory Matters,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on significant rate developments and cost recovery and trackers for the Gas Distribution Operations segment.

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~~NiSource Inc.~~

~~Gas Distribution Operations~~

Customer Usage. Increased efficiency of natural gas appliances and improvements in home building codes and standards has contributed to a long-term trend of declining average use per customer. ~~Usage~~Residential and commercial usage for the three months

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Gas Distribution Operations

ended March 31, 2015 ~~months ended~~ ~~September 30, 2014~~ ~~increased~~decreased from the same period last year primarily due to ~~colder~~warmer weather compared to the prior year. While historically, rate design at the distribution level has been structured such that a large portion of cost recovery is based upon throughput, rather than in a fixed charge, operating costs are largely incurred on a fixed basis, and do not fluctuate due to changes in customer usage. As a result, the NiSource LDCs have pursued changes in rate design to more effectively match recoveries with costs incurred. Each of the states in which the NiSource LDCs operate has different requirements regarding the procedure for establishing changes to rate design. Columbia of Ohio restructured its rate design through a base rate proceeding and has adopted a “de-coupled” rate design which more closely links the recovery of fixed costs with fixed charges. Columbia of Massachusetts and Columbia of Virginia received regulatory approval of decoupling mechanisms which adjust revenues to an approved benchmark level through a volumetric adjustment factor. Columbia of Maryland has received regulatory approval to implement a residential class revenue normalization adjustment, a decoupling mechanism whereby monthly revenues that exceed or fall short of approved levels are reconciled in subsequent months. In a prior base rate proceeding, Columbia of Pennsylvania implemented a residential weather normalization adjustment charge. In a prior base rate proceeding, NIPSCO implemented a higher fixed customer charge for residential and small customer classes moving toward full straight fixed variable rate design.

Environmental Matters

~~Various~~Currently, various environmental matters ~~occasionally~~ impact the Gas Distribution Operations segment. As of ~~September 30, 2014, a reserve has~~March 31, 2015, reserves have been recorded to cover probable ~~and estimable~~ environmental response actions. Refer to Note 16-C, ~~“Environmental~~“Other Commitments and Guarantees - Environmental Matters,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information regarding environmental matters for the Gas Distribution Operations segment.

Weather

In general, NiSource calculates the weather related revenue variance based on changing customer demand driven by weather variance from normal heating degree-days. Normal is evaluated using heating degree days across the NiSource distribution region. While the temperature base for measuring heating degree days (i.e. the estimated average daily temperature at which heating load begins) varies slightly across the region, the NiSource composite measurement is based on 65 degrees. NiSource composite heating degree days reported do not directly correlate to the weather related dollar impact on the results of Gas Distribution Operations. Heating degree days experienced during different times of the year or in different operating locations may have more or less impact on volume and dollars depending on when and where they occur. When the detailed results are combined for reporting, there may be weather related dollar impacts on operations when there is not an apparent or significant change in the aggregated NiSource composite heating degree-day comparison.

Weather in the Gas Distribution Operations’ territories for the ~~third~~first quarter of ~~2014~~2015 was 18% colder than normal and ~~6% colder~~1% warmer than the ~~third~~first quarter in ~~2013~~.

~~Weather in the Gas Distribution Operations’ territories for the~~ ~~nine~~ ~~months ended~~ ~~September 30, 2014~~ ~~was 14% colder than normal and 14% colder than the same period in~~ ~~2013~~.2014.

Throughput

Total volumes sold and transported of ~~166.2~~402.1 million MMDth for the ~~third~~first quarter of ~~2014 decreased~~2015 increased by ~~1.5~~4.2 MMDth from the same period last year. This ~~0.9% decrease~~1.1% increase in volumes was primarily attributable to ~~a decrease in off-system sales partially offset by~~ higher industrial throughput.

~~Total volumes sold and transported of 762.1 MMDth for the~~ ~~nine~~ ~~months ended~~ ~~September 30, 2014~~ ~~increased by 38.1 MMDth from the same period last year. This 5.3% increase in volume was primarily attributable to colder weather.~~

Net Revenues

Net revenues for the ~~third~~first quarter of ~~2014~~2015 were ~~$297.3~~$733.7 million, an increase of ~~$19.5~~$91.1 million from the same period in ~~2013~~.2014. The increase in net revenues is due primarily to an increase in regulatory and tax trackers, which are offset in expense, of ~~$10.2~~$50.6 million and an increase of $33.2 million for regulatory and service programs, including the impacts of rate cases at Columbia of Pennsylvania, Columbia of Virginia and Columbia of Massachusetts, as well as the implementation of rates under Columbia of Ohio's approved infrastructure replacement program and the impacts of the rate case at Columbia of Massachusetts. Additionally, there was an increase in net revenues as result of a settlement of $3.2 million at Columbia of Massachusetts in 2013, increased industrial and commercial usage of $1.4 million, higher net revenues due to increased margins of $1.4 million and higher large customer revenue of $1.3 million.

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~~ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)~~

~~NiSource Inc.~~

~~Gas Distribution Operations~~

Net revenues for the nine months ended September 30, 2014 were $1,299.3 million, an increase of $136.9 million from the same period in 2013. The increase in net revenues is due primarily to an increase of $69.9 million for regulatory and service programs, including the impacts of the rate settlement in 2013 at Columbia of Pennsylvania and the implementation of rates under Columbia of Ohio's approved infrastructure replacement program, the effects of colder weather of $19.7 million and increased regulatory and tax trackers, which are offset in expense, of $17.0 million.program. Additionally, there was higher ~~residential, commercial and industrial usage of $8.8 million, an increase in off-system sales of $5.1 million, higher~~ revenue of $4.9 million due to increased customer count and an increase in large customer revenue of $4.6 million. Also, there were higher net revenues due to increased margins of $3.9 million, higher net revenues from the recovery of storage inventory costs of $3.6 million and a settlement of $3.2 million at Columbia of Massachusetts in 2013. These increases were partially offset by a decrease of $5.8$5.3 million resulting from ~~NIPSCO’s~~the prior year reduction in revenue from NIPSCO's GCIM.

At NIPSCO, sales revenues and customer billings are adjusted for amounts related to under and over-recovered purchased gas costs from prior periods per regulatory order. These amounts are primarily reflected in the “Other” gross revenues statistic provided at the beginning of this segment discussion. The adjustment to Other gross revenues for the three ~~and nine~~ months ended ~~September 30, 2014~~March 31, 2015 was a revenue decrease of $63.6 million compared to a revenue increase of ~~$10.0 million and $9.7 million, respectively, compared to an increase of $8.1 million and a decrease of $42.4~~$31.5 million for the three ~~and nine~~ months ended ~~September 30, 2013, respectively.~~March 31, 2014.

~~Operating Income~~

~~For the~~ ~~third~~ ~~quarter of~~ ~~2014, Gas Distribution Operations reported operating income of $0.8 million, an increase of $5.8 million from the comparable~~ ~~2013~~ period. Operating income increased as a result of higher net revenues, as described above, partially offset by increased operating expenses. Operating expenses were $13.7 million higher than the comparable period reflecting increased employee and administrative expenses of $12.9 million and higher depreciation of $4.3 million due to increased capital expenditures. These increases were partially offset by a decrease in environmental costs of $3.7 million.

For the nine months ended September 30, 2014, Gas Distribution Operations reported operating income of $362.4 million, an increase of $83.3 million from the comparable 2013 period. Operating income increased as a result of higher net revenues, as described above, partially offset by increased operating expenses. Operating expenses were $53.6 million higher than the comparable period reflecting higher employee and administrative expenses of $17.7 million, increased regulatory and tax trackers, which are offset in net revenues, of $17.0 million and higher depreciation of $12.0 million due to increased capital expenditures. Additionally, there was increased other taxes of $6.3 million, higher outside service costs of $4.0 million and increased uncollectibles of $3.7 million. These increases were partially offset by a decrease in environmental costs of $5.8 million.

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NiSource Inc.

~~Columbia Pipeline Group~~Gas Distribution Operations

Three Months Ended
September 30, Nine Months Ended September 30,
(in millions) 2014 2013 2014 2013
Net Revenues
Transportation revenues $ 194.0
$ 176.4
$ 597.8
$ 558.9
Storage revenues 49.1
48.6
148.3
147.8
Other revenues 74.5
57.7
260.6
151.2
Total Sales Revenues 317.6
282.7
1,006.7
857.9
Less: Cost of sales (excluding depreciation and amortization) —
0.1
0.2
0.3
Net Revenues 317.6
282.6
1,006.5
857.6
Operating Expenses
Operation and maintenance 194.4
165.3
565.2
448.0
Depreciation and amortization 29.2
26.7
87.7
78.9
Gain on sale of assets (3.0 ) (11.1 ) (20.8 ) (11.3 )
Other taxes 14.6
13.5
50.3
46.6
Total Operating Expenses 235.2
194.4
682.4
562.2
Equity Earnings in Unconsolidated Affiliates 12.0
10.5
32.9
25.6
Operating Income $ 94.4
$ 98.7
$ 357.0
$ 321.0
Throughput (MMDth)
Columbia Transmission 160.9
158.4
814.6
790.8
Columbia Gulf 143.0
134.0
473.3
494.0
Crossroads Pipeline 3.2
4.1
12.4
12.4
Intrasegment eliminations (22.1 ) (36.5 ) (105.3 ) (211.8 )
Total 285.0
260.0
1,195.0
1,085.4
Operating Income

For the first quarter of 2015, Gas Distribution Operations reported operating income of $325.2 million, an increase of $23.4 million from the comparable 2014 period. Operating income increased as a result of higher net revenues, as described above, partially offset by increased operating expenses. Operating expenses were $67.7 million higher than the comparable period reflecting increased regulatory and tax trackers, which are offset in net revenues, of $50.6 million, higher employee and administrative expenses of $6.6 million, increased depreciation of $3.9 million, and higher outside service costs of $3.8 million.

NiSource’s Columbia Pipeline Group Operations segment primarily consists of the operations of Columbia Transmission, Columbia Gulf, NiSource Midstream, NEVCO, Crossroads Pipeline, and the equity investments in Pennant, Millennium and Hardy Storage. In total, NiSource owns a pipeline network of approximately 15,000 miles extending from the Gulf of Mexico to New York and the eastern seaboard. The pipeline network serves customers in 16 northeastern, mid-Atlantic, midwestern and southern states, as well as the District of Columbia. In addition, the Columbia Pipeline Group Operations segment operates one of the nation’s largest underground natural gas storage systems.

~~Columbia Pipeline Group Operations’ most significant projects are as follows:~~

~~Warren County.~~ The Columbia Pipeline Group Operations segment invested approximately $37 million on an expansion project, which included 2.5 miles of 24-inch new pipeline and modifications to existing compression assets, with Virginia Power Services Energy Corporation, Inc., the energy manager for Virginia Electric and Power Company. This project expanded the Columbia Transmission system in order to provide up to nearly 250,000 Dth per day of transportation capacity under a long-term, firm contract. The project went into service in the second quarter of 2014.

~~West Side Expansion.~~ The Columbia Pipeline Group Operations segment invested approximately $200 million in new pipeline and compression to increase supply origination from the Smithfield and Waynesburg areas on the Columbia Transmission system and provide transportation to Gulf Coast markets on the Columbia Gulf system. This investment will increase capacity up to 444,000 Dth per day from the Smithfield and Waynesburg areas and up to 540,000 Dth per day from Leach to Rayne transporting Marcellus production under long-term, firm contracts. Limited interim service was provided throughout 2014 with the project fully in service in October 2014.

~~Giles County.~~ The Columbia Pipeline Group Operations segment spent approximately $25 million to construct nearly 13 miles of 8-inch pipeline to provide 46,000 Dth per day of firm service to a third party off of its Line VA system into Columbia of Virginia's system. Columbia of Virginia expanded pipeline facilities and an existing direct connection with the third party's plant in Giles County, Virginia. The project was placed into service in October 2014.

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Columbia Pipeline Group Operations



	Three Months Ended March 31,
(in millions)	2015			2014
Net Revenues
Transportation revenues	$	251.1		$	222.3
Storage revenues	50.0			49.9
Other revenues	38.7			73.4
Total Sales Revenues	339.8			345.6
Less: Cost of sales (excluding depreciation and amortization)	0.1			0.1
Net Revenues	339.7			345.5
Operating Expenses
Operation and maintenance	145.8			165.7
Depreciation and amortization	32.5			29.7
Gain on sale of assets	(5.3		)	(17.5		)
Other taxes	19.1			18.5
Total Operating Expenses	192.1			196.4
Equity Earnings in Unconsolidated Affiliates	15.4			9.8
Operating Income	$	163.0		$	158.9
Throughput (MMDth)
Columbia Transmission	497.3			459.5
Columbia Gulf	145.7			184.9
Crossroads Pipeline	5.1			5.7
Intrasegment eliminations	(28.7		)	(61.6		)
Total	619.4			588.5

NiSource’s Columbia Pipeline Group Operations subsidiaries own and operate approximately 15,000 miles of interstate pipelines and operate one of the nation’s largest underground natural gas storage systems, capable of operationally storing approximately 622 Bcf of natural gas. Through its subsidiaries, Columbia Transmission, Columbia Gulf, Columbia Midstream and Crossroads Pipeline, NiSource owns and operates an interstate pipeline network extending from the Gulf of Mexico to New York and the eastern seaboard. Together, these companies serve customers in 16 northeastern, mid-Atlantic, Midwestern and southern states and the District of Columbia.

Columbia Pipeline Group Operations’ most significant projects are as follows:

~~Line 1570~~West Side Expansion (Columbia Gulf-Bi-Directional). The Columbia Pipeline Group Operations segment ~~is replacing~~invested approximately ~~19 miles of 20-inch bare steel pipe~~$113 million in system modifications and horsepower to provide a firm backhaul transportation path from the Leach, Kentucky interconnect with ~~24-inch pipe from Waynesburg, Pennsylvania~~Columbia Transmission to ~~Redd Farm, Pennsylvania at an approximate cost of $20 million. The project also includes~~Gulf Coast markets on the ~~installation of two compressors at Redd Farm and an uprate~~Columbia Gulf system. This investment will increase capacity up to 540,000 Dth/d to transport Marcellus production originating in ~~horsepower at Waynesburg, increasing capacity by nearly 99,000 Dth per day.~~West Virginia. The project is ~~expected to be~~supported by long-term firm contracts and was placed in service in the fourth quarter of 2014. The Alexandria Compression portion of Columbia Gulf’s West Side Expansion (approximately $75 million in capital costs) will be placed in service in the third quarter of 2015.

Chesapeake LNG. The project involves the investment of approximately $33 million to replace 120,000 Dth/d of existing LNG peak shaving facilities nearing the end of their useful lives. This project is expected to be placed in service in the second quarter of 2015.

Big Pine ~~Expansion.~~ Expansion. The Columbia Pipeline Group Operations segment is investing approximately $65 million to make a connection to the Big Pine pipeline and add compression facilities that will add incremental capacity. The additional ~~9 mile~~approximately 10-mile, 20-inch pipeline and compression facilities will support Marcellus shale production in western Pennsylvania. Approximately ~~half~~50% of the increased capacity generated by the project is ~~expected to be~~ supported by a long-term, fee-based agreement with a regional producer, with the remaining capacity expected to be sold to other area producers in the near term. ~~The~~This project is expected to be placed in service by the third quarter of 2015.

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Columbia Pipeline Group Operations

East Side ~~Expansion.~~ Expansion. The Columbia Pipeline Group Operations segment has received FERC authorization to construct facilities for this project, which will provide access for production from the Marcellus shale to the northeastern and mid-Atlantic markets. Supported by long-term firm contracts, the project will add up to 312,000 Dth/d of capacity and is expected to be placed in service in the fourth quarter of 2015. The Columbia Pipeline Group Operations segment plans to invest up to approximately $275 million in developing its East Side Expansion project, which will provide access for Marcellus supplies to the northeastern and mid-Atlantic markets. Backed by binding precedent agreements, the project will add up to 312,000 Dth per day of capacity, which is expected to be placed in service by the end of the third quarter of 2015.this project.

~~Chesapeake, Virginia LNG Facility Modernization.~~Washington County Gathering. A large producer has contracted with the Columbia Pipeline Group Operations segment to build an approximately 20-mile dry gas gathering system consisting of 8-inch, 12-inch, and 16-inch pipelines, a 20-inch lateral, as well as compression, measurement and dehydration facilities. The Columbia Pipeline Group Operations segment ~~is investing~~expects to invest approximately ~~$33~~$120 million beginning in 2014 through 2018 and expects to ~~upgrade the facility and extend its associated customer contracts for 15 years.~~commence construction in early 2015. The ~~project's first phase was completed~~initial wells are expected to come on-line in the ~~fourth~~third quarter of ~~2013.~~2015. The ~~remainder of the~~ project is ~~expected to be placed into service in the second quarter of 2015.~~supported with minimum volume commitments and further enhances Columbia Midstream’s relationship with a producer that has a large Marcellus acreage position.

~~Washington County Gathering.~~ Kentucky Power Plant Project. The Columbia Pipeline Group Operations segment ~~is constructing a field gathering system in Pennsylvania that will gather well pad production of primarily dry gas from a third party producer. Pipeline laterals will be built~~expects to ~~connect well pads as drilling is developed. The approximate $120~~invest approximately $24 million ~~investment will include about 20 miles of gathering pipelines of varying diameter, a compressor station and dehydration unit. The gas gathering agreement has an initial 15-year term with the option~~ to ~~extend. The project is expected to be in service during the fourth quarter of 2015, with additional expansion expected as gas production grows.~~

~~Kentucky Power Plant.~~ ~~The Columbia Pipeline Group Operations segment is constructing nearly 3~~construct 2.7 miles of 16-inch greenfield pipeline and other facilities to a third-party power plant from Columbia ~~Transmission's~~Transmission’s Line ~~P that will serve a third-party natural gas-fired electric generation plant in Kentucky. The~~P. This project will ~~cost approximately $24 million~~provide up to 72,000 Dth/d of new firm service, is supported by a long-term firm contract, and will ~~provide 72,000 Dth per day of capacity to the plant under an executed binding precedent agreement. The project is expected to~~ be placed in service ~~by the end of~~in the second quarter of 2016.

Utica ~~Access.~~Access Project. The Columbia Pipeline Group Operations segment ~~is investing~~intends to invest approximately ~~$51~~$50 million to construct ~~nearly 5~~4.7 miles of ~~20-inch~~24-inch greenfield pipeline to provide 205,000 ~~Dth per day~~Dth/d of new firm service to allow Utica production access to liquid trading points on ~~its~~our system. This project is expected to be in service ~~by the end of~~in the fourth quarter of 2016.

~~Leach XPress.~~ The Columbia Pipeline Group Operations segment ~~will invest approximately $1.4 billion in this project.~~has secured firm contracts for the full delivery volume.

Leach XPress. The ~~project involves~~Columbia Pipeline Group Operations segment finalized agreements for the installation of approximately 124 miles of 36-inch pipeline from Majorsville to the Crawford compressor station ~~(Crawford)~~(“Crawford CS”) located on the Columbia Transmission system, ~~and~~ 27 miles of 36-inch pipeline from Crawford CS to the McArthur compressor station located on the Columbia Transmission system, and approximately 101,700 hphorsepower across multiple ~~sites. The project will~~sites to provide approximately 1.5 ~~Bcf per day~~MMDth/d of capacity out of the Marcellus and Utica production regions to the Leach compressor station ~~(Leach)~~(“Leach CS”) located on the Columbia Gulf system, TCO Pool, and other markets on the Columbia Transmission system. Virtually all of the project’s capacity has been secured with long-term firm contracts. The ~~project is expected to go in service during the fourth quarter of 2017.~~

~~Rayne XPress.~~ ~~The~~ Columbia Pipeline Group Operations segment expects the project to go in service in the fourth quarter of 2017 and will invest approximately ~~$330 million to modify existing facilities and to add new compression.~~ $1.4 billion in this project.

Rayne XPress. This project would transport approximately 1 ~~Bcf per day~~MMDth/d of growing southwest Marcellus and Utica production away from constrained production areas to markets and liquid transaction points. Capable of receiving gas from Columbia Transmission’s Leach XPress project, gas would be transported from the Leach, Kentucky interconnect with Columbia Transmission in a southerly direction towards the Rayne compressor station in southern Louisiana to reach various Gulf Coast markets. ~~Definitive~~The project also includes the creation of a new compressor station. The Columbia Pipeline Group Operations segment has secured definitive agreements for firm service ~~have been secured~~ for the project’s ~~capacity. The~~capacity and expects the project ~~is expected~~ to be placed in service ~~by the end of~~in the fourth quarter of 2017. The Columbia Pipeline Group Operations segment expects to invest approximately $383 million on the Rayne XPress project to modify existing facilities and to add new compression.

Cameron Access Project. The Columbia Pipeline Group Operations segment is investing approximately $310 million in an 800,000 Dth/d expansion of the Columbia Gulf system through improvements to existing pipeline and compression facilities, a new state-of-the-art compressor station near Lake Arthur, Louisiana, and the installation of a new 26-mile pipeline in Cameron Parish to provide for a direct connection to the Cameron LNG Terminal. The Columbia Pipeline Group Operations segment expects the project to be placed in service in the first quarter of 2018 and has secured long-term firm contracts for approximately 90% of the increased volumes.

WB XPress. The Columbia Pipeline Group Operations segment expects to invest approximately $850 million in this project to expand the WB system through looping and added compression in order to transport approximately 1.3 MMDth/d of Marcellus Shale production on the Columbia Transmission system to pipeline interconnects and East Coast markets, which includes access to the Cove Point LNG terminal. The Columbia Pipeline Group Operations segment expects this project to be placed in service in the fourth quarter of 2018.

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Columbia Pipeline Group Operations

~~WB XPress.~~ The Columbia Pipeline Group Operations segment will invest approximately $870 million in this project that will transport approximately 1.3 Bcf of Marcellus Shale production on the Columbia Transmission system to pipeline interconnects and East Coast markets, which includes access to the Cove Point LNG terminal. Resolution of conditions precedent is anticipated in the fourth quarter of 2014. The project is expected to be placed in service during the fourth quarter of 2018.

~~Cameron Access.~~ The Columbia Pipeline Group Operations segment has entered into binding precedent agreements for the improvement to existing pipeline and the construction of new pipeline and compression facilities along the Columbia Gulf system to connect with the Cameron LNG Terminal in southern Louisiana. The approximately $310 million project will transport supplies from numerous supply basins to the planned LNG export facility, which received Department of Energy approval late in 2013. The project will offer an initial capacity of up to 800,000 Dth per day and is expected to be placed into service by the first quarter of 2018.

Equity Investments

Pennant. ~~NiSource~~Columbia Midstream entered into a 50:50 joint venture in 2012 with affiliates of Hilcorp to construct new wet natural gas gathering pipeline infrastructure and NGL processing facilities to support natural gas production in the Utica Shale region of northeastern Ohio and western Pennsylvania. ~~NiSource~~Columbia Midstream and Hilcorp jointly own Pennant with ~~NiSource~~Columbia Midstream serving as the operator of Pennant and the facilities. NiSource accounts for the joint venture under the equity method of accounting.

~~Pennant invested in~~During the construction of 20-24 inch wet gas gathering pipeline facilities with a capacity of approximately 500 MMcf per day. In addition, Pennant constructed a gas processing facility in New Middletown, Ohio that will have an initial capacity of 200 MMcf per day and is constructing a NGL pipeline with an initial capacity of 45,000 barrels per day that can be expanded to 90,000 barrels per day. Consistent with the terms of the joint venture, NiSource Midstream operates the gas processing facility, NGL pipeline and associated wet gas gathering system. The joint venture is designed and anticipated to serve other producers with significant acreage development in the area with an interest in obtaining capacity on the system. The facilities allow Pennant to be a full-service solution for providers in the northern Utica Shale region, offering access to wet gas gathering and processing as well as residue gas and NGL takeaway to attractive market destinations. NiSource Midstream's initial investment in this area, including the gathering pipeline, related laterals, NGL pipeline and the processing plant, is approximately $195 million. Portions of the facilities were placed in service in the fourthfirst quarter of ~~2013~~2015 and ~~the second quarter of~~ 2014, ~~with the remainder placed in service in October 2014.~~

~~During the third quarter of 2014, NiSource~~Columbia Midstream made ~~cash contributions to Pennant totaling $9.0 million. Cash~~ contributions of ~~$41.9~~zero and $28.4 million, ~~were made~~respectively, to Pennant. Pennant distributed $1.2 million of earnings and returned $1.3 million of capital to Columbia Midstream during the ~~same period last year. For the nine~~three months ended ~~September 30, 2014 and 2013, NiSource Midstream made cash contributions to~~March 31, 2015. No distributions were received from Pennant ~~of $61.2 million and of $68.0 million, respectively.~~

~~In a separate agreement with Hilcorp, test wells were drilled in 2012 and continued in 2013 to support~~during the development of the hydrocarbon potential on more than 100,000 combined acres in the Utica/Point Pleasant Shale formation. Production wells were drilled in 2013 and 2014, with the full production program in development. NiSource is investing alongside Hilcorp in the development of the acreage, with NiSource owning both a working and overriding royalty interest. All of the Hilcorp/NiSource acreage is dedicated to Pennant.three months ended March 31, 2014.

Millennium. The Millennium ~~operates~~system is a FERC-regulated interstate natural gas transportation pipeline system, which consists of approximately 253 miles of natural gas transmission pipeline and three compressor stations with approximately 43,000 hp of installed ~~capacity under the jurisdictional authority~~capacity. Millennium transports an average of ~~the FERC. The Millennium pipeline has the capability to transport~~1 Bcf/d of natural gas sourced from the Marcellus shale to markets ~~along its route, which lies between Corning,~~across New ~~York~~York's Southern Tier and ~~Ramapo, New York,~~lower Hudson Valley, as well as to the New York City ~~market~~markets through its pipeline interconnections. Columbia Transmission owns a 47.5% interest in Millennium and acts as operator for the pipeline in partnership with DTE Millennium Company and National Grid Millennium LLC, which each own an equal remaining share of the company.

During the ~~third~~first quarter of ~~2014~~2015 and ~~2013,~~2014, Columbia Transmission made contributions of zero and ~~$2.4~~$2.6 million, respectively, to Millennium. For the nine months ended September 30, 2014 and 2013, Columbia Transmission made contributions of $2.6 million and $9.0 million, respectively, to fund its share of capital projects. During the third quarter of 2014 and 2013, Columbia Transmission received distributions of earnings of ~~$14.2~~$16.6 million and ~~$6.2~~$7.1 million ~~respectively. For~~for the ~~nine~~three months ended ~~September 30,~~March 31, 2015 and 2014, ~~and 2013, Columbia transmission received distributions of earnings of $26.1 million and $17.1 million,~~ respectively.

Millennium began two projects in 2012 that added approximately 30,000 hp of compression to its system. The first project went into service in June 2013 and increased capacity at its interconnections with Algonquin Gas Transmission, with a total investment

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~~ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)~~

~~NiSource Inc.~~

~~Columbia Pipeline Group Operations~~

of approximately $50 million. The second project included a total investment of approximately $40 million that increased capacity with interconnections to other third-party facilities. The second project was placed into service in March 2014. Columbia Transmission's share of the above investments is limited to its 47.5% interest in Millennium.

Hardy Storage.The Hardy Storage facility is a ~~50:50 joint venture between subsidiaries of Columbia Transmission and Piedmont that~~FERC-regulated interstate natural gas storage system, which consists of 29 storage wells in a depleted gas production field in Hampshire and Hardy counties, West Virginia, 36.7 miles of pipeline and ~~Hampshire counties in West Virginia. Columbia Transmission serves as operator~~7,100 hp of ~~the company, which is regulated by the FERC. Hardy Storage facilities interconnect~~installed capacity. The facility interconnects with Columbia Transmission and ~~include~~has approximately ~~37 miles~~12 MMDth of ~~pipeline~~working gas capacity and ~~nearly 7,200 hp~~176,000 Dth/d of ~~installed capacity with~~withdrawal capacity. Columbia Transmission owns a ~~working storage capacity of 12 Bcf~~50% interest in Hardy Storage and acts as operator for the ~~ability to deliver 176,000 Dth of natural gas per day.~~system. A third party, Piedmont Natural Gas Company, Inc., owns the remaining 50% interest in Hardy Storage.

During both the ~~third~~first quarter of ~~2014~~2015 and ~~2013,~~2014, NiSource received distributions of earnings of $0.5 million ~~of available accumulated earnings. For the nine months ended September 30, 2014 and 2013, NiSource received $1.5 million and $1.9 million of available accumulated earnings, respectively.~~from Hardy Storage. NiSource made no contributions during ~~2014~~the first quarter of 2015 or ~~2013.~~2014.

Nature of Sales

Columbia Transmission and Columbia Gulf compete for transportation customers based on the type of service a customer needs, operating flexibility, available capacity and price. Columbia Gulf and Columbia Transmission provide a significant portion of total transportation services under firm contracts and derive a smaller portion of revenues through interruptible contracts, with management seeking to maximize the portion of physical capacity sold under firm contracts.

Firm service contracts require pipeline capacity to be reserved for a given customer between certain receipt and delivery points. Firm customers generally pay a “capacity reservation” fee based on the amount of capacity being reserved regardless of whether the capacity is used, plus an incremental usage fee when the capacity is used. Annual capacity reservation revenues derived from firm service contracts generally remain constant over the life of the contract because the revenues are based upon capacity reserved and not whether the capacity is actually used. The high percentage of revenue derived from capacity reservation fees mitigates the risk of revenue fluctuations within the ~~Columbia~~Gas Pipeline Group Operations segment due to changes in near-term supply and demand conditions. The following percentages exclude the impact of intrasegment revenues and tracker-related revenues. For the quarter ended ~~September 30, 2014,~~March 31, 2015, approximately ~~94.6%~~93.9% of the transportation revenues were derived from capacity reservation fees paid under firm contracts and ~~3.6%~~4.5% of the transportation revenues were derived from usage fees under firm contracts compared to approximately ~~93.7%~~92.6% and ~~4.1%~~5.2%, respectively, for the quarter ended September 30, 2013. For the nine months ended September 30, 2014, approximately 93.8% of the transportation revenues were derived from capacity reservation fees paid under firm contracts and 4.3% of the transportation revenues were derived from usage fees under firm contracts compared to approximately 92.9% and 5.3% respectively, for the nine months ended September 30, 2013.March 31, 2014.

Interruptible transportation service is typically short term in nature and is generally used by customers that either do not need firm service or have been unable to contract for firm service. These customers pay a usage fee only for the volume of gas actually transported. The ability to provide this service is limited to available capacity not otherwise used by firm customers, and customers receiving services under interruptible contracts are not assured capacity in the pipeline facilities. Columbia Pipeline Group Operations provides interruptible service at competitive prices in order to capture short term market opportunities as they occur and interruptible service is viewed by management as an important strategy to optimize revenues from the gas transmission assets.

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Columbia Pipeline Group Operations

For the quarters ended ~~September 30,~~March 31, 2015 and 2014, ~~and 2013,~~ approximately ~~1.8%~~1.6% and 2.2%~~, respectively, of the transportation revenues were derived from interruptible contracts. For the nine months ended September 30, 2014 and 2013, approximately 2.0% and 1.8%~~, respectively, of the transportation revenues were derived from interruptible contracts.

Regulatory Matters

Refer to Note 6,7, “Regulatory Matters,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on regulatory matters for the Columbia Pipeline Group Operations segment.

Environmental Matters

~~Various~~Currently, various environmental matters ~~occasionally~~ impact the Columbia Pipeline Group Operations segment. As of ~~September 30, 2014~~,March 31, 2015, a reserve has been recorded to cover probable and estimable environmental response actions. Refer to Note 16-C, ~~“Environmental~~“Other Commitments and Guarantees - Environmental Matters,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information regarding environmental matters for the Columbia Pipeline Group Operations segment.

Throughput

Columbia Transmission's throughput consists of gas transportation service deliveries to LDC city gates, to gas fired power plants,

other industrial customers, or other interstate pipelines in its market area. Columbia Transmission's market area covers portions

of northeastern, mid-Atlantic, Midwestern, and southern states as well as the District of Columbia. Throughput for Columbia Gulf

reflects transportation services for gas delivered through its mainline and laterals. Crossroads Pipeline’s throughput comes from

deliveries it makes to its customers and other pipelines that are located in northern Indiana and Ohio. Intersegment eliminations

represent gas delivered to affiliated pipelines within the segment.

Throughput for the Columbia Pipeline Group Operations segment totaled 619.4 MMDth for the first quarter of 2015, compared to 588.5 MMDth for the same period in 2014. The increase of 30.9 MMDth primarily reflected increased Marcellus and Utica natural gas production.

Net Revenues

Net revenues were $339.7 million for the first quarter of 2015, a decrease of $5.8 million from the same period in 2014. The decrease in net revenues is due primarily to lower regulatory trackers, which are offset in expense, of $27.4 million and other miscellaneous decreases of $9.1 million. This decrease was partially offset by increased demand margin revenue of $30.7 million as a result of growth projects placed in service and new firm contracts.

Operating Income

Operating income was $163.0 million for the first quarter of 2015, an increase of $4.1 million from the first quarter of 2014. Operating income increased as a result of decreased operating expenses and higher equity earnings, partially offset by lower net revenues, as described above. Operating expenses were $4.3 million lower due to decreased regulatory trackers, which are offset in net revenues, of $27.4 million. This decrease in operating expenses was partially offset by lower gains on the sale of assets of $12.2 million primarily resulting from decreased gains on conveyances of mineral interests, higher employee and administrative expenses of $7.5 million and increased depreciation of $2.8 million. Equity Earnings increased $5.6 million due to increased earnings at Millennium attributable to growth projects placed in service and higher earnings at Pennant as a result of the joint venture projects going fully in-service.

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~~Columbia Pipeline Group Operations~~

~~Throughput~~

Columbia Transmission's throughput consists of gas transportation service deliveries to LDC city gates, to gas fired power plants, other industrial customers, or other interstate pipelines in its market area. Columbia Transmission's market area covers portions of northeastern, mid-Atlantic, midwestern, and southern states as well as the District of Columbia. Gas delivered via transportation services to storage is not accounted for as throughput until it is withdrawn from storage and delivered to one of the aforementioned locations via a transportation service. Throughput for Columbia Gulf traditionally consists of gas delivered to Columbia Transmission at Leach, Kentucky as well as gas delivered south of Leach to other interstate pipelines or to an LDC's city gate. Market conditions on Columbia Gulf continue to support greater use of backhaul transportation services from supplies originating near Leach, Kentucky and its Louisiana interconnects to markets in the southeastern United States. Crossroads Pipeline serves customers in northern Indiana and Ohio via gas flowing west to east originating from outside the Chicago area to Cygnet, Ohio where it interconnects with Columbia Transmission. Intra-segment eliminations represent gas delivered to an affiliated pipeline within the segment.

~~Throughput for the Columbia Pipeline Group Operations segment totaled~~ ~~285.0~~ ~~MMDth for the~~ ~~third~~ ~~quarter of~~ ~~2014, compared to~~ ~~260.0~~ ~~MMDth for the same period in~~ ~~2013. The increase of 25.0 MMDth reflected increased Marcellus natural gas production and favorable pricing conditions to third party interconnects in the Southeast region of the United States.~~

~~Throughput for the Columbia Pipeline Group Operations segment totaled 1,195.0 MMDth for the nine months ended September 30, 2014, compared to 1,085.4 MMDth for the same period in~~ ~~2013~~. The increase of 109.6 MMDth was primarily attributable to increased natural gas production on the Columbia Pipeline Group system and the transportation of volumes to third party interconnects mentioned above.

~~Net Revenues~~

~~Net revenues were $317.6 million for the~~ ~~third~~ ~~quarter of~~ ~~2014, an increase of $35.0 million from the same period in~~ ~~2013~~. The increase in net revenues is due primarily to higher regulatory trackers, which are offset in expense, of $15.6 million, increased demand margin revenue of $11.8 million primarily as a result of growth projects placed in service, higher mineral rights royalty revenue of $5.9 million and increased condensate revenue of $2.6 million.

Net revenues were $1,006.5 million for the nine months ended September 30, 2014, an increase of $148.9 million from the same period in 2013. The increase in net revenues is due primarily to higher regulatory trackers, which are offset in expense, of $87.6 million, increased demand margin revenue of $34.1 million primarily as a result of growth projects placed in service, higher mineral rights royalty revenue of $20.5 million due to increased third party drilling activity and higher condensate revenue of $3.7 million.

~~Operating Income~~

~~Operating income was $94.4 million for the~~ ~~third~~ ~~quarter of~~ ~~2014, a decrease of $4.3 million from the~~ ~~third~~ ~~quarter of~~ ~~2013~~. Operating income decreased as a result of increased operating expenses, partially offset by higher net revenues, as described above, and higher equity earnings. Operating expenses were $40.8 million higher than the comparable period primarily as a result of increased regulatory trackers, which are offset in net revenues, of $15.6 million, higher employee and administrative expenses of $13.5 million, a decrease in gains on the sale of assets of $8.1 million primarily resulting from the sale of storage base gas in 2013, higher outside service costs of $5.8 million, and increased depreciation of $2.5 million. These increases were partially offset by a decrease in software data conversion costs of $7.5 million. Equity earnings increased $1.5 million due to higher earnings at Millennium.

Operating income was $357.0 million for the nine months ended September 30, 2014, an increase of $36.0 million from the comparable 2013 period. Operating income increased as a result of higher net revenues, as described above, and higher equity earnings partially offset by increased operating expenses. Operating expenses were $120.2 million higher than the comparable period primarily as a result of increased regulatory trackers, which are offset in net revenues, of $87.6 million, higher employee and administrative expenses of $24.4 million, increased depreciation of $8.8 million, higher outside service costs of $7.5 million and increased property taxes of $3.1 million. These increases were partially offset by an increase in the gain on the sale of assets of $9.5 million primarily resulting from conveyances of mineral interests of $20.8 million, offset by the sale of storage base gas in 2013 of $11.1 million and lower software data conversion costs of $7.5 million. Equity earnings increased $7.3 million due to higher earnings at Millennium attributable to growth projects placed in service.

~~Table of Contents~~

~~ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)~~

NiSource Inc.

Electric Operations


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
(in millions)	2014			2013			2014			2013			2015			2014
Net Revenues
Sales revenues	$	424.7		$	413.7		$	1,280.5		$	1,176.4		$	395.8		$	450.4
Less: Cost of sales (excluding depreciation and amortization)	147.5			142.2			474.2			408.4			125.7			180.4
Net Revenues	277.2			271.5			806.3			768.0			270.1			270.0
Operating Expenses
Operation and maintenance	120.5			107.1			355.2			323.7			120.2			112.5
Depreciation and amortization	62.4			60.6			182.9			184.2			62.2			60.4
Gain on sale of assets	—			—			(0.1		)	—
Other taxes	17.4			16.3			49.6			47.9			17.7			18.2
Total Operating Expenses	200.3			184.0			587.6			555.8			200.1			191.1
Operating Income	$	76.9		$	87.5		$	218.7		$	212.2		$	70.0		$	78.9
Revenues ($ in millions)
Residential	$	122.3		$	122.1		$	335.7		$	326.1		$	113.6		$	113.2
Commercial	122.4			116.8			337.3			324.8			110.5			106.2
Industrial	185.3			155.3			537.0			467.0			175.0			179.7
Wholesale	4.9			3.1			26.6			20.8			6.3			21.4
Other	(10.2		)	16.4			43.9			37.7			(9.6		)	29.9
Total	$	424.7		$	413.7		$	1,280.5		$	1,176.4		$	395.8		$	450.4
Sales (Gigawatt Hours)
Residential	915.2			1,000.5			2,604.6			2,633.7			865.8			896.2
Commercial	1,031.6			1,066.1			2,932.0			2,929.9			940.0			935.5
Industrial	2,504.7			2,337.2			7,567.6			6,913.1			2,425.4			2,607.1
Wholesale	161.4			108.6			485.3			664.6			116.9			311.8
Other	36.4			31.3			104.7			91.5			34.6			33.4
Total	4,649.3			4,543.7			13,694.2			13,232.8			4,382.7			4,784.0
Cooling Degree Days	381			531			657			781
Normal Cooling Degree Days	570			570			799			799
% Colder than Normal	(33		)%	(7		)%	(18		)%	(2		)%
Electric Customers
Residential							401,683			401,174			403,409			402,676
Commercial							54,383			54,267			54,695			54,378
Industrial							2,364			2,371			2,354			2,370
Wholesale							751			728			747			724
Other							4			6			5			5
Total							459,185			458,546			461,210			460,153

NiSource generates and distributes electricity, through its subsidiary NIPSCO, to approximately ~~459~~461 thousand customers in 20 counties in the northern part of Indiana. The operating results reflect the temperature-sensitive nature of customer demand with annual sales affected by temperatures in the northern part of Indiana. As a result, segment operating income is generally higher in the second and third quarters, reflecting cooling demand during the summer season.

~~Table of Contents~~

~~ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)~~

~~NiSource Inc.~~

~~Electric Operations~~

Electric Supply

On October ~~28, 2011,~~31, 2014, NIPSCO ~~filed~~submitted its ~~2011~~2014 Integrated Resource Plan with the IURC. The plan evaluates demand-side and supply-side resource alternatives to reliably and cost-effectively meet NIPSCO customers' future energy requirements over the next twenty years. Existing resources are expected to be sufficient, assuming favorable outcomes for environmental upgrades, to meet customers' needs ~~for~~into the next decade. NIPSCO continues to monitor and assess economic, regulatory and legislative activity, and will update its resource plan as appropriate.

Regulatory Matters

Table of Contents

ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)

NiSource Inc.

Electric Operations

Environmental Matters

~~Various~~Currently, various environmental matters ~~occasionally~~ impact the Electric Operations segment. As of ~~September 30, 2014~~,March 31, 2015, a reserve has been recorded to cover probable and estimable environmental response actions. Refer to Note 16-C, ~~“Environmental~~“Other Commitments and Guarantees - Environmental Matters,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information regarding environmental matters for the Electric Operations segment.

Transmission Upgrade Agreements

On February 11, 2014, NIPSCO entered into two TUAs with upgrade sponsors to complete upgrades on NIPSCO’s transmission system on behalf of those sponsors. The upgrade sponsors have agreed to reimburse NIPSCO for the total cost to construct transmission upgrades and place them into service, ~~which is estimated at $50.3 million,~~ multiplied by a rate of 1.71 ("the multiplier").

On June 10, 2014, certain upgrade sponsors for both TUAs, filed a complaint at the FERC against NIPSCO regarding the multiplier stated in the TUAs. On June 30, 2014, NIPSCO filed an answer defending the terms of the TUAs and the just and reasonable nature of the multiplier charged therein and moved for dismissal of the complaint. On December 8, 2014, the FERC issued an order in response to the complaint finding that it is appropriate for NIPSCO to recover, through the multiplier, substantiated costs of ownership related to the TUAs. The FERC set for hearing the issue of what constitutes the incremental costs NIPSCO will incur, but is holding that hearing in abeyance to allow for settlement. NIPSCO will continue to monitor developments in this matter ~~but cannot estimate~~and does not believe the impact ~~(if any) on~~is material to the Condensed Consolidated Financial Statements (unaudited) ~~the complaint will have at this time.~~.

Sales

Electric Operations sales quantities for the ~~third~~first quarter of ~~2014~~2015 were ~~4,649.3~~4,382.7 gwh, ~~an increase~~a decrease of ~~105.6~~401.3 gwh compared to the ~~third~~first quarter of ~~2013~~.2014. The ~~2.3% increase~~8.4% decrease is primarily attributable to ~~an increase~~decreases in sales for resale and industrial usage. The decrease in sales for resale was primarily attributable to increased opportunities for off-system sales during the first quarter of 2014 due to the cold weather. The decrease in industrial usage ~~due~~was primarily attributable to higher internal generation from large industrial customers ~~expanding plant operations and using less internal generation.~~

~~Electric Operations sales quantities for~~during the ~~nine months ended September 30, 2014 were~~ ~~13,694.2~~ ~~gwh, an increase~~first quarter of 461.4 gwh compared to the same period in 2013. The 3.5% increase is primarily attributable to an increase in industrial usage due to large industrial customers expanding plant operations and using less internal generation.2015.

Net Revenues

Net revenues were ~~$277.2~~$270.1 million for the ~~third~~first quarter of ~~2014~~,2015, an increase of ~~$5.7~~$0.1 million from the same period in ~~2013~~.2014. The increase in net revenues is due primarily to lower fuel handling costs of $3.5 million and higher ~~industrial and residential usage~~net revenues of ~~$7.4~~$3.2 million as a result of two electric transmission projects authorized by the MISO. Additionally, there were increased trackers, which are offset in expense, of ~~$4.4~~$2.2 million and ~~an increase in the~~a higher return on the environmental capital investment recovery of ~~$4.2~~$1.6 million due to an increased plant balance eligible for recovery. These increases were partially offset by ~~the effects of weather of $10.3 million.~~

Net revenues were $806.3 million for the nine months ended September 30, 2014, an increase of $38.3 million from the same period in 2013. The increase in net revenues is due primarily to higher industrial and residential usage of $21.9 million, an increase in the return on the environmental capital investment recovery of $17.3 million due to an increased plant balance eligible for recovery. Additionally, there was increased net revenues of $4.1 million as a result of two electric transmission projects authorized by the MISO and higherlower off-system sales of ~~$3.9 million. These increases were partially offset by a decrease in transmission upgrade revenue of $6.5 million and the effects of weather of $3.8~~$8.6 million.

At NIPSCO, sales revenues and customer billings are adjusted for amounts related to under and over-recovered purchased fuel costs from prior periods per regulatory order. These amounts are primarily reflected in the “Other” gross revenues statistic provided at the beginning of this segment discussion. The adjustment to Other gross revenues for the three ~~and nine~~ months ended March 31, 2015 was a revenue decrease of $22.7 million compared to a revenue increase of $20.3 million for the three months ended March 31, 2014.

Operating Income

For the first quarter of 2015, Electric Operations reported operating income of $70.0 million, a decrease of $8.9 million from the comparable 2014 period. Operating income decreased as a result of higher operating expenses of $9.0 million due primarily to increased employee and administrative expenses of $3.0 million, higher environmental expenses of $2.3 million and increased trackers, which are offset in net revenues, of $2.2 million.

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~~ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)~~

~~NiSource Inc.~~

~~Electric Operations~~

September 30, 2014 was a revenue decrease of $22.2 million and an increase of $8.6 million, respectively, compared to a revenue increase of $6.9 million and $6.6 million for the three and nine months ended September 30, 2013, respectively.

~~Operating Income~~

~~For the~~ ~~third~~ ~~quarter of~~ ~~2014, Electric Operations reported operating income of $76.9 million, a decrease of $10.6 million from the comparable~~ ~~2013~~ period. Operating income decreased as a result of increased operating expenses, partially offset by higher net revenues, as described above. Operating expenses increased $16.3 million due primarily to higher employee and administrative expenses of $5.3 million, an increase in trackers, which are offset in net revenues, of $4.4 million, higher electric generation costs of $3.4 million and increased storm damage costs of $3.3 million.

For the nine months ended September 30, 2014, Electric Operations reported operating income of $218.7 million, an increase of $6.5 million from the comparable 2013 period. Operating income increased as a result of higher net revenues, as described above, partially offset by increased operating expenses. Operating expenses increased $31.8 million due primarily to higher employee and administrative expenses of $15.3 million, increased electric generation costs of $14.3 million as a result of maintenance related outages and higher storm damage costs of $2.6 million.

~~Table of Contents~~

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

NiSource Inc.

For a discussion regarding quantitative and qualitative disclosures about market risk see “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Market Risk Disclosures.”

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

NiSource’s ~~Chief Executive Officer~~chief executive officer and its ~~Principal Financial Officer, after~~principal financial officer, are responsible for evaluating the effectiveness of ~~NiSource’s~~our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e))~~, have concluded based on~~. NiSource's disclosure controls and procedures are designed to provide reasonable assurance that the ~~evaluation~~information required to be disclosed by ~~paragraph (b) of~~us in reports that we file or submit under the Exchange Act ~~Rules 13a-15~~is accumulated and ~~15d-15~~communicated to our management, including NiSource's chief executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based upon that evaluation, NiSource's chief executive officer and principal financial officer concluded that, as of the end of the period covered by this report, ~~NiSource’s~~our disclosure controls and procedures ~~are considered effective.~~were effective to provide reasonable assurance that financial information was processed, recorded and reported accurately.

Changes in Internal Controls

There have been no changes in NiSource's internal control over financial reporting during the fiscal quarter covered by this report that has materially affected, or is reasonably likely to materially affect, NiSource's internal control over financial reporting.

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PART II

ITEM 1. LEGAL PROCEEDINGS

NiSource Inc.

On ~~August 29, 2014,~~March 6, 2015, Columbia Transmission and Pike County Conservation District executed a Consent Assessment of Civil Penalty to resolve the NOV issued ~~an NOV to Columbia Transmission~~on August 29, 2014 alleging violations of the Pennsylvania Clean Streams Law and Columbia Transmission’s Erosion and Sediment Control General Permit in connection with Columbia Transmission’s Line 1278 Replacement Project. ~~Discussions are ongoing with the Pike County Conservation District~~Columbia Transmission paid $171,500 on March 13, 2015 to resolve ~~this~~the allegations of the NOV.

ITEM 1A. RISK FACTORS

There ~~have been~~were no material changes tofrom the risk factors ~~previously~~ disclosed in ~~our~~NiSource's 2014 Annual Report on Form 10-K for the fiscal year ended December 31, 2013 (“Form 10-K”), except for the addition of the risk factors set forth below. The risks and uncertainties described below should be read in conjunction with the risk factors and other information disclosed in our Form 10-K.

~~The Proposed Separation may not be completed~~filed on ~~the currently contemplated timeline or terms, or at all, and may not achieve the intended benefits~~.

The Proposed Separation is subject to conditions, including, without limitation, final NiSource Board of Directors approval and the receipt by NiSource of a legal opinion to the effect that the distribution of CPG shares to NiSource shareholders will qualify as tax-free under Section 355 of the U.S. Internal Revenue Code. Unanticipated developments or changes in market conditions may delay the Proposed Separation, and the Proposed Separation may not occur on the currently contemplated timeline or at all.

NiSource cannot predict with certainty when the benefits expected from the Proposed Separation will occur or the extent to which they will be achieved, if at all. Furthermore, there are various uncertainties and risks relating to the process of the Proposed Separation that could have a negative impact on our financial condition, results of operations and cash flows, including disruption of our operations and impairment of our relationship with regulators, key personnel, customers and vendors.

If the Proposed Separation is successfully completed, NiSource will face new and unique risks, including the possibility of reduced financial resources and less diversification of revenue sources, which may adversely impact NiSource’s financial condition, results of operations and cash flows. In addition, the changes in our operational and financial profile may not meet some or all of our shareholders’ investment strategies, which could cause investors to sell their NiSource shares and otherwise decrease demand for shares of NiSource common stock. Excess selling will cause the relative market price of NiSource common stock to decrease, and the market price of NiSource common stock may be subject to greater volatility following the completion of the Proposed Separation.

A condition to the Proposed Separation is the receipt by NiSource of a legal opinion to the effect that the distribution of CPG shares to NiSource shareholders will qualify as tax-free under Section 355 of the U.S. Internal Revenue Code. However, even if we receive such an opinion, the Internal Revenue Service could determine on audit that the distribution is taxable. Both NiSource and our shareholders could incur significant U.S. federal income tax liabilities if taxing authorities conclude the distribution is taxable.

Following the Proposed Separation, both NiSource and CPG are expected to have investment grade credit ratings. However, there is no assurance that this will occur, and even if both NiSource and CPG have investment grade credit ratings at the time the Proposed Separation is completed, there is no assurance that they will continue to maintain such investment grade credit ratings in the future.

Inability to complete the planned initial public offering of Columbia Pipeline Partners LP on the currently contemplated timeline or terms may adversely impact our stock price and our ability to enhance our growth potential.

On September 29, 2014, a registration statement relating to the proposed initial public offering, or IPO, of common units representing limited partner interests in Columbia Pipeline Partners LP was filed with the Securities and Exchange Commission but has not yet become effective. Completion of the registration is subject to market conditions and numerous other risks beyond our control, including, but not limited to, the general economy, credit markets, equity markets and energy prices. Therefore, it is possible that the master limited partnership will not complete an offering of securities, will not raise the planned amount of capital even if an offering of securities is completed, and will not be able to complete its proposed actions on the timetable indicated. Furthermore,

~~ITEM 1A. RISK FACTORS (continued)~~

~~NiSource Inc.~~

the structure, nature, purpose, proposed assets and liabilities, and proposed manner of offering of the master limited partnership may change materially from those anticipated. If the IPO is not completed or is delayed, our stock price may decline and our growth potential may be negatively impacted.

A registration statement relating to common units of Columbia Pipeline Partners LP has been filed with the SEC but has not yet become effective. These securities may not be sold nor may offers to buy be accepted prior to the time the registration statement becomes effective. This quarterly report on Form 10-Q shall not constitute an offer to sell or the solicitation of an offer to buy any securities. Any offers, solicitations of offers to buy, or any sales of securities of Columbia Pipeline Partners LP will be made only in accordance with the registration requirements of the Securities Act of 1933 or an exemption therefrom.February 18, 2015.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

None.

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ITEM 6. EXHIBITS

NiSource Inc.



(10.1)	~~Term Loan~~Letter Agreement ~~(the "Agreement") with the lenders party thereto, CoBank, ACB, as Syndication Agent, JPMorgan Chase Bank, N.A., as Administrative Agent,~~between NiSource Inc. and ~~J.P. Morgan Securities LLC and CoBank, ACB, as Joint Lead Arrangers and Joint Bookrunners~~Donald Brown dated ~~August 20, 2014.~~March 17, 2015. **

(31.1)	Certification of ~~Robert C. Skaggs, Jr.,~~ Chief Executive Officer pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. **

(31.2)	Certification of ~~Stephen P. Smith,~~ Chief Financial Officer pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. **

(32.1)	Certification of ~~Robert C. Skaggs, Jr.,~~ Chief Executive Officer pursuant to 18. U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith). **

(32.2)	Certification of ~~Stephen P. Smith,~~ Chief Financial Officer pursuant to 18. U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith). **

(101.INS)	XBRL Instance Document

(101.SCH)	XBRL Schema Document

(101.CAL)	XBRL Calculation Linkbase Document

(101.LAB)	XBRL Labels Linkbase Document

(101.PRE)	XBRL Presentation Linkbase Document

(101.DEF)	XBRL Definition Linkbase Document



**	Exhibit filed herewith.

Pursuant to Item 601(b)(4)(iii) of Regulation S-K, NiSource hereby agrees to furnish the SEC, upon request, any instrument defining the rights of holders of long-term debt of NiSource not filed as an exhibit herein. No such instrument authorizes long-term debt securities in excess of 10% of the total assets of NiSource and its subsidiaries on a consolidated basis.

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SIGNATURE

NiSource Inc.

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.



			NiSource Inc.
			(Registrant)

Date:	~~October~~April 30, ~~2014~~2015	By:	/s/ Joseph W. Mulpas
			Joseph W. Mulpas
			Vice President and Chief Accounting Officer (Principal Accounting Officer and Duly Authorized Officer)

6253



September 30, 2014 (in millions)	Amortized Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
Available-for-sale debt securities
U.S. Treasury	$	34.3	$	0.2	$	(0.3	)	$	34.2
Corporate/Other	101.0		0.9		(0.9		)	101.0
Total Available-for-sale debt securities	$	135.3	$	1.1	$	(1.2	)	$	135.2
December 31, 2013 (in millions)	Amortized Cost		Gross Unrealized Gains		Gross Unrealized Losses			Fair Value
Available-for-sale debt securities
U.S. Treasury	$	30.3	$	0.3	$	(0.5	)	$	30.1
Corporate/Other	91.5		1.1		(1.3		)	91.3
Total Available-for-sale debt securities	$	121.8	$	1.4	$	(1.8	)	$	121.4