CPG OpCo 10-Q 2 Aug 16 2016 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares shares in Millions	6 Months Ended
	Jun. 30, 2016	Jul. 26, 2016
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q2
Entity Registrant Name	CPG OpCo LP/DE
Entity Central Index Key	1,667,154
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Units Outstanding		0

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions		Jun. 30, 2016	Dec. 31, 2015
Current Assets
Cash and cash equivalents		$ 52	$ 78.2
Accounts receivable (less reserve of $0.3 and $0.3, respectively)		161.1	145.9
Accounts receivable-affiliated		102	149.4
Materials and supplies, at average cost		26.5	32.8
Exchange gas receivable		11.2	18.8
Deferred property taxes		36.4	52
Prepayments and other		32.9	33.8
Total Current Assets		422.1	510.9
Investments
Unconsolidated affiliates		440.2	437.1
Other investments		1.8	1.8
Total Investments		442	438.9
Property, Plant and Equipment
Property, plant and equipment		9,670.9	8,930.9
Accumulated depreciation and amortization		(3,023.4)	(2,960.1)
Net Property, Plant and Equipment		6,647.5	5,970.8
Other Noncurrent Assets
Regulatory assets		129.9	134.1
Goodwill		1,975.5	1,975.5
Postretirement and postemployment benefits assets		124.2	120.5
Deferred charges and other		8.9	9
Total Other Noncurrent Assets		2,238.5	2,239.1
Total Assets		9,750.1	9,159.7
Current Liabilities
Short-term borrowings-affiliated		653.2	42.1
Accounts payable		105.4	49.9
Accounts payable-affiliated		26.7	85.9
Customer deposits		15.3	17.8
Taxes accrued		94.8	108.2
Exchange gas payable		11.2	18.2
Deferred revenue		6.6	15
Accrued capital expenditures		132.7	95.9
Accrued compensation and related costs		26	26.6
Other accruals		62	43.9
Total Current Liabilities		1,133.9	503.5
Noncurrent Liabilities
Long-term debt-affiliated		630.9	630.9
Deferred income taxes		1	1
Accrued liability for postretirement and postemployment benefits		33.5	36.1
Regulatory liabilities		284.4	309.7
Asset retirement obligations		23.9	25.3
Other noncurrent liabilities		65.3	63.5
Total Noncurrent Liabilities		1,039	1,066.5
Total Liabilities		2,172.9	1,570
Equity
Accumulated other comprehensive loss	[1]	(24.7)	(25.7)
Total Equity		7,577.2	7,589.7
Total Liabilities and Equity		9,750.1	9,159.7
Columbia Energy Group [Member]
Equity
Limited Partner Interest		6,288.8	6,300.1
Columbia Hardy Corporation [Member]
Equity
Limited Partner Interest		39.6	39.7
Columbia Pipeline Partners LP [Member]
Equity
Limited Partner Interest		$ 1,273.5	$ 1,275.6
[1]	Amounts in parentheses indicate debits.

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Accounts receivable less reserve	$ 0.3	$ 0.3

Statements Of Consolidated and

Statements Of Consolidated and Combined Operations - USD ($) $ in Millions	3 Months Ended		5 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Operating Revenues
Transportation revenues	$ 258.8	$ 237.3		$ 566.6	$ 485.2
Transportation revenues-affiliated	0	18.4		0	47.1
Storage revenues	48.9	36.2		98.8	72.8
Storage revenues-affiliated	0	12.9		0	26.2
Other revenues	5.5	10.8		11.3	23.5
Total Operating Revenues	313.2	315.6		676.7	654.8
Operating Expenses
Operation and maintenance	105.7	137.8		204.4	247.3
Operation and maintenance-affiliated	39.2	38.5		81.3	74.6
Depreciation and amortization	37.7	33		75.3	65.3
Gain on sale of assets	(3.4)	(8.3)		(6)	(13.6)
Property and other taxes	19.9	19.1		40.7	38.1
Total Operating Expenses	199.1	220.1		395.7	411.7
Equity Earnings in Unconsolidated Affiliates	16.3	14		32.1	28.9
Operating Income	130.4	109.5		313.1	272
Other Income (Deductions)
Interest expense	(0.2)	0		(0.4)	0
Interest expense-affiliated	(7)	(6.3)		(14.2)	(17.7)
Other, net	9.9	5.4		16	9.8
Total Other Income (Deductions), net	2.7	(0.9)		1.4	(7.9)
Income before Income Taxes	133.1	108.6		314.5	264.1
Income Taxes	0.1	0		0.1	23.7
Net Income	133	108.6	$ 197.7	314.4	$ 240.4
Net Income Attributable to the Partnership	$ 133	$ 108.6	197.7	$ 314.4
Parent
Other Income (Deductions)
Net Income			$ 0

Statements of Consolidated and5

Statements of Consolidated and Combined Comprehensive Income - USD ($) $ in Millions		1 Months Ended	3 Months Ended				5 Months Ended	6 Months Ended
		Feb. 11, 2015	Jun. 30, 2016		Jun. 30, 2015		Jun. 30, 2015	Jun. 30, 2016		Jun. 30, 2015
Net Income			$ 133		$ 108.6		$ 197.7	$ 314.4		$ 240.4
Net unrealized gain on cash flow hedges	[1]		0.5		0.5			1		0.6
Total other comprehensive income			0.5		0.5			1		0.6
Total other comprehensive income prior to CPPL's IPO			0.5	[2]	0.5	[2]	0.5	1	[2]	0.6	[2],[3]
Total comprehensive income			133.5		109.1			315.4		$ 241
Comprehensive Income (Loss), Net of Tax, Attributable to Limited Partners			$ 133.5		$ 109.1		$ 198.2	$ 315.4
Predecessor
Total other comprehensive income prior to CPPL's IPO		$ 0.1
Predecessor net income prior to CPPL's IPO		42.7
Total comprehensive income		$ 42.8
[1]	Net unrealized gains on derivatives qualifying as cash flow hedges, net of zero tax expense in the second quarter of 2016 and 2015, and zero and $0.1 million tax expense for the six months ended June 30, 2016 and 2015, respectively
[2]	Amounts in parentheses indicate debits.
[3]	All amounts prior to CPPL's IPO are net of tax.

Statements of Consolidated and6

Statements of Consolidated and Combined Comprehensive Income (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Net unrealized gains on derivatives qualifying as cash flow hedges	$ 0	$ 0	$ 0	$ 0.1

Statements Of Consolidated and7

Statements Of Consolidated and Combined Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Operating Activities
Net Income	$ 314.4	$ 240.4
Adjustments to Reconcile Net Income to Net Cash from Operating Activities:
Depreciation and amortization	75.3	65.3
Deferred income taxes and investment tax credits	0	10.5
Deferred revenue	(2.4)	(0.1)
Equity-based compensation expense and profit sharing contribution	1.8	3.5
Gain on sale of assets	(6)	(13.6)
Income from unconsolidated affiliates	(32.1)	(28.9)
AFUDC equity	(15.9)	(8.4)
Distributions of earnings received from equity investees	31	27.9
Changes in Assets and Liabilities:
Accounts receivable	(9.1)	13.9
Accounts receivable-affiliated	6.7	17.1
Accounts payable	2.7	1
Accounts payable-affiliated	(60.7)	(15)
Customer deposits	(2.5)	1
Taxes accrued	(13.5)	(10.2)
Exchange gas receivable/payable	0.6	0.3
Other accruals	2.3	(4.6)
Prepayments and other current assets	23.1	17
Regulatory assets/liabilities	(2.3)	25.5
Postretirement and postemployment benefits	(2.3)	(13.5)
Deferred charges and other noncurrent assets	(3.5)	0
Other noncurrent liabilities	3.7	(1.5)
Net Cash Flows from Operating Activities	311.3	327.6
Investing Activities
Capital expenditures	(656.6)	(430.6)
Insurance recoveries	0	2.1
Changes in short-term lendings-affiliated	40.7	(527.1)
Proceeds from disposition of assets	0.1	19
Contributions to equity investees	(1.9)	0
Distributions from equity investees	0.8	2.2
Other investing activities	(3.6)	(13.3)
Net Cash Flows used for Investing Activities	(620.5)	(947.7)
Financing Activities
Change in short-term borrowings-affiliated	610.9	(180.2)
Payments of long-term debt-affiliated, including current portion	0	(957.8)
Capital contribution from CEG	0	1,217.3
Capital contribution from Columbia Pipeline Partners LP for additional interest	0	1,170
Proceeds from capital contributions from Columbia Pipeline Partners LP distributed to CEG	0	(500)
Quarterly distributions to limited partners	(327.9)	0
Net Cash Flows from Financing Activities	283	749.3
Change in cash and cash equivalents	(26.2)	129.2
Cash and cash equivalents at beginning of period	78.2	0.5
Cash and Cash Equivalents at End of Period	$ 52	$ 129.7

Statements Of Consolidated and8

Statements Of Consolidated and Combined Equity - USD ($) $ in Millions		Total		Accumulated Other Comprehensive Loss	Parent	Columbia Energy Group [Member]Limited Partner [Member]	Columbia Hardy Corporation [Member]Limited Partner [Member]	Columbia Pipeline Partners LP [Member]Limited Partner [Member]
Beginning Balance (Predecessor) at Dec. 31, 2014		$ 4,171.3		$ (16.7)	$ 4,188	$ 0	$ 0	$ 0
Net Income (Loss) Attributable to Noncontrolling Interest | Predecessor		42.7		0	42.7	0	0	0
Other Comprehensive Income (Loss), Net of Tax | Predecessor		0.1		0.1	0	0	0	0
Contribution of capital from parent | Predecessor		1,217.3		0	1,217.3	0	0	0
Predecessor net tax liabilities not assumed by the Partnership | Predecessor	[1]	1,222.2		(10.3)	1,232.5	0	0	0
Contributed/Noncontributed Net Parent Investment Adjustments | Predecessor	[2]	(7.7)		0	(7.7)	0	0	0
Ending Balance (Predecessor) at Feb. 11, 2015		6,645.9		(26.9)	6,672.8	0	0	0
Beginning Balance (Predecessor) at Dec. 31, 2014		4,171.3		(16.7)	4,188	0	0	0
Net Income		240.4
Other Comprehensive Income (Loss), Net of Tax	[3],[4]	0.6
Predecessor net tax liabilities not assumed by the Partnership	[3],[4],[5]			(10.3)
Ending Balance at Jun. 30, 2015		7,515.3		(26.4)	0	6,238.6	39.1	1,264
Beginning Balance (Predecessor) at Feb. 11, 2015		6,645.9		(26.9)	6,672.8	0	0	0
Allocation of net investment to partners' capital		0		0	(6,672.8)	6,148.1	37.6	487.1
Capital contribution from CPPL for additional interest		1,170		0	0	0	0	1,170
CPPL's purchase of additional interest in the Partnership	[6]	0		0	0	424.4	0	(424.4)
Distributions to parent		(500)		0	0	(500)	0	0
Net Income		197.7		0	0	165.1	1.5	31.1
Other Comprehensive Income (Loss), Net of Tax		0.5		0.5	0	0	0	0
Net Transfers (To) From Parent		1.2		0	0	1	0	0.2
Ending Balance at Jun. 30, 2015		7,515.3		(26.4)	$ 0	6,238.6	39.1	1,264
Beginning Balance at Dec. 31, 2015		7,589.7		(25.7)		6,300.1	39.7	1,275.6
Net Income		314.4		0		262.6	2.4	49.4
Other Comprehensive Income (Loss), Net of Tax		1	[4]	1		0	0	0
Quarterly distributions		(327.9)		0		(273.9)	(2.5)	(51.5)
Ending Balance at Jun. 30, 2016		$ 7,577.2		$ (24.7)		$ 6,288.8	$ 39.6	$ 1,273.5
[1]	Reflects the non-cash elimination of all historical current and deferred income taxes other than Tennessee state income taxes that continue to be borne by the Partnership post-CPPL IPO, as well as associated regulatory assets and liabilities.
[2]	Reflects the removal of amounts related to Crossroads Pipeline Company, CPGSC, Central Kentucky Transmission Company and 1% of the 50% interest in Hardy Storage that were included in the Predecessor but were not contributed to the Partnership, as well as the inclusion of CNS Microwave, which was not part of the Predecessor.
[3]	All amounts prior to CPPL's IPO are net of tax.
[4]	Amounts in parentheses indicate debits.
[5]	Reflects the non-cash elimination of all historical current and deferred income taxes other than Tennessee state income taxes that will continue to be borne by the Partnership post-IPO.
[6]	Represents the purchase of an additional 8.4% limited partner interest in the Partnership, recorded at the historical carrying value of the Partnership's net assets after giving effect to the $1,170.0 million equity contribution. This decreases CPPL's limited partner interest equity by the same amount it increases CEG's limited partner interest because the CPPL's purchase price for its additional 8.4% interest in the Partnership exceeded book value.

Statement of Consolidated and C

Statement of Consolidated and Combined Equity (Parenthetical) $ in Millions	Jun. 30, 2016
Hardy Storage
Equity Method Investment, Percent Not Contributed to Partnership	1.00%
Equity Method Investment, Ownership Percentage	50.00%

Basis of Accounting Presentatio

Basis of Accounting Presentation	6 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Accounting Presentation	Basis of Accounting Presentation CPG OpCo LP (the "Partnership") was formed in Delaware on September 26, 2014, as a subsidiary of NiSource. The general partner of the Partnership, OpCo GP, is 100.0% owned by its sole member CPPL. At or prior to the closing of CPPL's IPO the following transactions occurred: • CEG contributed $1,217.3 million of capital to certain subsidiaries of the Predecessor to repay intercompany debt owed to NiSource Finance. CEG entered into new intercompany debt agreements with NiSource Finance for $1,217.3 million ; • CEG and Columbia Hardy contributed substantially all of the subsidiaries in the Predecessor to the Partnership; • CEG assumed responsibility for all historical current and deferred income taxes other than Tennessee state income taxes that continue to be borne by the Partnership post-IPO, as well as associated regulatory assets and liabilities; • CEG contributed to CPPL a 7.3% limited partner interest in the Partnership in exchange for 46,811,398 subordinated units in CPPL and all of CPPL's incentive distribution rights; • CPPL purchased from the Partnership an additional 8.4% limited partner interest in exchange for $1,170.0 million from the net proceeds of CPPL's IPO, resulting in CPPL owning a 15.7% limited partner interest in the Partnership; • The Partnership distributed $ 500.0 million to CEG as a reimbursement of preformation capital expenditures with respect to the assets contributed to the Partnership; • Following CPPL's IPO, CPPL owns a 15.7% limited partner interest in the Partnership, Columbia Hardy owns a 0.77% limited partner interest and CEG owns the remaining 83.53% limited partner interest. On February 11, 2015, concurrent with the completion of CPPL's IPO, NiSource contributed its subsidiary, CEG, to CPG. Following this contribution, CPG owns and operates, through its subsidiaries, approximately 15,000 miles of strategically located interstate gas pipelines extending from New York to the Gulf of Mexico and one of the nation’s largest underground natural gas storage systems, with approximately 300 MMDth of working gas capacity, as well as related gathering and processing assets. CEG owns and operates, through its subsidiaries, substantially all of the natural gas transmission and storage assets of CPG. Prior to July 1, 2015, CPG was a wholly owned subsidiary of NiSource. On July 1, 2015, all the shares of CPG were distributed by NiSource to holders of NiSource common stock completing CPG's separation from NiSource (the "Separation"). As a result of the Separation, CPG became an independent publicly traded company. CPG OpCo LP Predecessor (the “Predecessor”) is comprised of NiSource’s Columbia Pipeline Group Operations reportable segment. The Partnership entered into an omnibus agreement with CEG and its affiliates (together with a services agreement with CPGSC) at the closing of CPPL's IPO that addresses (1) centralized corporate, general and administrative services to be provided by CEG for the Partnership and the reimbursement by the Partnership for the Partnership's portion of these services, (2) CPPL's right of first offer for CEG's 84.3% interest in the Partnership, (3) the indemnification of the Partnership for certain potential environmental and toxic tort claims losses and expenses associated with the operation of the assets and occurring before the closing date of the IPO and (4) the Partnership's requirement to guarantee future indebtedness that CPG incurs. The Partnership is engaged in regulated interstate gas transportation and storage services for LDCs, marketers, producers and industrial and commercial customers located in northeastern, mid-Atlantic, midwestern and southern states and the District of Columbia along with unregulated businesses that include midstream services, including gathering, treating, conditioning, processing, compression and liquids handling, and development of mineral rights positions. The regulated services are performed under tariffs at rates subject to FERC approval. For periods subsequent to the closing of CPPL's IPO, the financial statements included in this current report are the financial statements and accounting records of the Partnership. For periods prior to the closing of CPPL's IPO, the financial statements included in this quarterly report are the financial statements and accounting records of the Predecessor. The consolidated and combined financial statements were prepared as follows: • The Condensed Consolidated Balance Sheets (unaudited) consist of the consolidated balance sheet of the Partnership as of June 30, 2016 and December 31, 2015 . • The Condensed Statements of Consolidated and Combined Operations (unaudited) consist of consolidated results of the Partnership for the three months ended June 30, 2016 and 2015. • The Condensed Statements of Consolidated and Combined Operations (unaudited) consist of consolidated results of the Partnership for the six months ended June 30, 2016 and for the period from February 11, 2015 through June 30, 2015 and the combined results of the Predecessor for the period from January 1, 2015 through February 10, 2015. • The Condensed Statements of Consolidated and Combined Comprehensive Income (unaudited) consist of consolidated results of the Partnership for the three months ended June 30, 2016 and 2015. • The Condensed Statements of Consolidated and Combined Comprehensive Income (unaudited) consist of consolidated results of the Partnership for six months ended June 30, 2016 and for the period from February 11, 2015 through June 30, 2015 and the combined results of the Predecessor for the period from January 1, 2015 through February 10, 2015. • The Condensed Statements of Consolidated and Combined Cash Flows (unaudited) consist of consolidated results of the Partnership for the six months ended June 30, 2016 and for the period from February 11, 2015 through June 30, 2015 and the combined results of the Predecessor for the period from January 1, 2015 through February 10, 2015. • The Condensed Statements of Consolidated and Combined Equity (unaudited) consist of consolidated activity of the Partnership for the six months ended June 30, 2016 and for the period from February 11, 2015 through June 30, 2015 and the combined results of the Predecessor for the period from January 1, 2015 through February 10, 2015. Merger. On March 17, 2016, CPG entered into an Agreement and Plan of Merger (the “Merger Agreement”), among CPG, TransCanada PipeLines Limited, a Canadian corporation (“Parent”), TransCanada PipeLine USA Ltd., a Nevada corporation and a wholly owned subsidiary of Parent (“US Parent”), Taurus Merger Sub Inc., a Delaware corporation and a wholly owned subsidiary of US Parent (“Merger Sub”), and, solely for purposes of Section 3.02, Section 5.02, Section 5.09 and Article VIII of the Merger Agreement, TransCanada Corporation, a Canadian corporation and the direct parent company of Parent (“TransCanada”). Upon the terms and subject to the conditions set forth in the Merger Agreement, effective July 1, 2016, Merger Sub was merged with and into CPG (the “Merger”) with CPG surviving the Merger as an indirect, wholly owned subsidiary of TransCanada. The Merger did not affect the ownership of the Partnership's general partner or limited partner interests, but the Partnership is indirectly managed by TransCanada after the Merger. Subsequent to June 30, 2016, approximately $ 100 million of employee related costs were accrued upon consummation of the Merger. The Partnership's Condensed Consolidated and Combined 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 the Partnership believes that the disclosures made are adequate to make the information not misleading. These financial statements should be read in conjunction with the Partnership’s audited consolidated and combined financial statements for the year ended December 31, 2015 . These financial statements reflect all normal recurring adjustments that are, in the opinion of management, necessary to fairly present the Partnership’s results of operations and financial position in accordance with GAAP in the United States of America. Amounts reported in the Condensed Statements of Consolidated and Combined Operations (unaudited) are not necessarily indicative of amounts expected for the respective annual periods. All intercompany transactions and balances have been eliminated.

Recent Accounting Pronouncement

Recent Accounting Pronouncements	6 Months Ended
	Jun. 30, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Pronouncements	Recent 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. In August 2015, the FASB issued ASU 2015-14 to extend the adoption date for ASU 2014-09 to periods beginning after December 15, 2017, including interim periods, and the new standard is to be applied retrospectively, with early adoption permitted on the original effective date of ASU 2014-09 on a limited basis. In March 2016, the FASB issued ASU 2016-08, which amends the principal-versus-agent implementation guidance and illustrations in ASU 2014-09. Among other things, ASU 2016-08 clarifies that an entity should evaluate whether it is the principal or the agent for each specified good or service promised in a contract with a customer. In April 2016, the FASB issued ASU 2016-10, which clarifies guidance related to identifying performance obligations and licensing implementation guidance contained in ASU 2014-09. In May 2016, the FASB issued ASU 2016-12, which contains narrow scope improvements for certain aspects of ASU 2014-09 including collectability, presentation of sales tax and other similar taxes collected from customers, noncash consideration, contract modifications and completed contracts at transition and transition technical correction. The Partnership is currently evaluating the impact the adoption of ASU 2014-09, and the related ASUs, will have on the Condensed Consolidated and Combined Financial Statements (unaudited) or Notes to Condensed Consolidated and Combined Financial Statements (unaudited). In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) . ASU 2016-02 introduces a lessee model that brings most leases on the balance sheet. The new standard also aligns many of the underlying principles of the new lessor model with those in ASC 606, the FASB's new revenue recognition standard (e.g., those related to evaluating when profit can be recognized). Furthermore, ASU 2016-02 addresses other concerns related to the current leases model. For example, ASU 2016-02 eliminates the requirement in current U.S. GAAP for an entity to use bright-line tests in determining lease classification. The standard also requires lessors to increase the transparency of their exposure to changes in value of their residual assets and how they manage that exposure. The Partnership is required to adopt ASU 2016-02 for periods beginning after December 15, 2018, including interim periods, with early adoption permitted. The Partnership is currently evaluating the impact the adoption of ASU 2016-02 will have on the Condensed Consolidated and Combined Financial Statements (unaudited) or Notes to Condensed Consolidated and Combined 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 liability rather than as a deferred charge. Amortization of these costs will continue to be reported as interest expense. In August 2015, the FASB issued ASU 2015-15 to clarify the SEC staff's position on these costs in relation to line-of-credit agreements stating that the SEC staff would not object to an entity deferring and presenting debt issuance costs related to a line-of-credit arrangement as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of such arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit. The Partnership retrospectively adopted ASU 2015-03 and ASU 2015-15 as of January 1, 2016. The adoption of this guidance did not have a material impact on the Condensed Consolidated and Combined Financial Statements (unaudited) or Notes to Condensed Consolidated and Combined 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. The Partnership retrospectively adopted ASU 2015-02 as of January 1, 2016. The adoption of this guidance did not have a material impact on the Condensed Consolidated and Combined Financial Statements (unaudited) or Notes to Condensed Consolidated and Combined Financial Statements (unaudited).

Transactions With Affiliates

Transactions With Affiliates	6 Months Ended
	Jun. 30, 2016
Related Party Transactions [Abstract]
Transactions With Affiliates	Transactions with Affiliates Prior to CPG's separation from NiSource, the Partnership engaged in transactions with subsidiaries of NiSource, which were deemed to be affiliates of the Partnership. The Partnership continues to engage in transactions with subsidiaries of CPG subsequent to the Separation. These affiliate transactions are summarized in the tables below: Statement of Operations Three Months Ended Six Months Ended (in millions) 2016 2015 2016 2015 Transportation revenues $ — $ 18.4 $ — $ 47.1 Storage revenues — 12.9 — 26.2 Other revenues — 0.1 — 0.2 Operation and maintenance expense 39.2 38.5 81.3 74.6 Interest expense 7.0 6.3 14.2 17.7 Interest income 0.2 1.1 0.3 2.1 Balance Sheet (in millions) June 30, December 31, 2015 Accounts receivable $ 102.0 $ 149.4 Short-term borrowings 653.2 42.1 Accounts payable 26.7 85.9 Long-term debt 630.9 630.9 Transportation, Storage and Other Revenues . Prior to the Separation, the Partnership provided natural gas transportation, storage and other services to subsidiaries of NiSource, the Partnership's former affiliates. Prior to CPPL's IPO, the Predecessor provided similar services to subsidiaries of NiSource. Operation and Maintenance Expense . The Partnership receives executive, financial, legal, information technology and other administrative and general services from CPGSC. Prior to CPPL's IPO, the Predecessor received similar services from NiSource Corporate Services. Expenses incurred as a result of these services consist of employee compensation and benefits, outside services and other expenses. The expenses are charged directly or allocated using various allocation methodologies based on a combination of gross fixed assets, total operating expense, number of employees and other measures. Management believes the allocation methodologies are reasonable. However, these allocations and estimates may not represent the amounts that would have been incurred had the services been provided by an outside entity. Interest Expense and Income . The Partnership was charged interest for long-term debt of $7.5 million and $7.5 million for the three months ended June 30, 2016 and 2015 , respectively, offset by associated AFUDC of $1.2 million and $1.4 million for the three months ended June 30, 2016 and 2015 , respectively. The Partnership was charged interest for long-term debt of $15.2 million and $19.7 million for the six months ended June 30, 2016 and 2015 , respectively, offset by associated AFUDC of $1.9 million and $2.4 million for the six months ended June 30, 2016 and 2015 , respectively. The Partnership and its subsidiaries entered into an intercompany money pool agreement with NiSource Finance, which became effective on the date of CPPL's IPO. Following the Separation, the agreement is with CPG. The money pool is available for the Partnership and its subsidiaries' general purposes, including capital expenditures and working capital. This intercompany money pool agreement is discussed in connection with Short-term Borrowings below. Prior to CPPL's IPO, the subsidiaries of the Predecessor participated in a similar money pool agreement with NiSource Finance. CPGSC administers the current money pool agreement. The cash accounts maintained by the subsidiaries of the Partnership and the Predecessor were, prior to the Separation, swept into a NiSource corporate account on a daily basis, creating an affiliated receivable or decreasing an affiliated payable, as appropriate, between NiSource and the subsidiary. Subsequent to the Separation, cash accounts maintained by subsidiaries of the Partnership were swept into a CPG corporate account on a daily basis, creating an affiliated receivable or decreasing an affiliated payable, as appropriate, between CPG and the subsidiary. The amount of interest expense and income for short-term borrowings was determined by the net position of each subsidiary in the money pool. The money pool weighted-average interest rate at June 30, 2016 and 2015 was 0.53% and 1.21% , respectively. For the three months ended June 30, 2016 and 2015 , the interest expense for short-term borrowings charged was $0.7 million and $0.2 million , respectively. For the six months ended June 30, 2016 and 2015 , the interest expense for short-term borrowings charged was $ 0.9 million and $ 0.4 million , respectively. Accounts Receivable . The Partnership includes in accounts receivable amounts due from the money pool discussed above of $99.7 million at June 30, 2016 for subsidiaries of the Partnership in a net deposit position. The Partnership includes in accounts receivable amounts due from the money pool discussed above of $ 140.5 million at December 31, 2015 for subsidiaries in a net deposit position. Also included in the balance at June 30, 2016 and December 31, 2015 are amounts due from subsidiaries of CPG for transportation and storage services of $2.2 million and $8.9 million , respectively. Net cash flows related to the money pool receivables are included as Investing Activities on the Condensed Statements of Consolidated and Combined Cash Flows (unaudited). All other affiliated receivables are included as Operating Activities. Short-term Borrowings . In connection with the closing of CPPL's IPO, the subsidiaries of the Partnership entered into an intercompany money pool agreement with NiSource Finance with $750.0 million of reserved borrowing capacity. Following the Separation, the agreement was with CPG. In furtherance of the money pool agreement, CPG entered into a $1,500.0 million revolving credit agreement on December 5, 2014. Effective July 1, 2016, in connection with the Merger, the $1,500.0 million CPG revolving credit facility was terminated and replaced by a $2,000.0 million revolving credit facility with US Parent. The balance of Short-term Borrowings at June 30, 2016 and December 31, 2015 of $653.2 million and $42.1 million , respectively, includes those subsidiaries of the Partnership in a net borrower position of the money pool discussed above. Net cash flows related to Short-term Borrowings are included as Financing Activities on the Condensed Statements of Consolidated and Combined Cash Flows (unaudited). Accounts Payable . The affiliated accounts payable balance primarily includes amounts due for services received from CPGSC, and interest payable to CPG. Long-term Debt . In May 2015, the Partnership's outstanding intercompany debt transferred from NiSource Finance to CPG. The Partnership's long-term financing requirements are satisfied through borrowings from CPG. On January 31, 2016, the Partnership amended its intercompany credit agreement with CPG to extend the maturity date of the note originating on December 9, 2013 from December 31, 2016 to December 31, 2020. The Partnership may borrow at any time from the origination date to December 31, 2016 not to exceed $2.6 billion . From January 1, 2017 to December 31, 2020, the Partnership may borrow at any time not to exceed $2.3 billion . As of the January 2016 amendment, the note carries a fixed interest rate of 4.70% for the outstanding borrowings as of June 30, 2016 . Details of the long-term debt balance are summarized in the table below: Origination Date Interest Rate Maturity Date June 30, 2016 December 31, 2015 (in millions) December 9, 2013 4.70 % December 31, 2020 $ 630.9 $ 630.9 Dividends . During the six months ended June 30, 2016 , the Partnership distributed $ 327.9 million to the limited partners. During the six months ended June 30, 2015 , the Partnership distributed $ 500.0 million to the limited partners as a reimbursement of preformation capital expenditures with respect to the assets contributed to the Partnership. There were no restrictions on the payment of distributions by the Partnership.

Gain On Sale Of Assets

Gain On Sale Of Assets	6 Months Ended
	Jun. 30, 2016
Gain On Sale of Assets [Abstract]
Gain On Sale Of Assets	Gain on Sale of Assets The Partnership recognizes gains on conveyances of mineral rights positions into earnings as any obligation associated with conveyance is satisfied. For the three months ended June 30, 2016 and 2015 , gains on conveyances amounted to $3.4 million and $8.3 million , respectively, and are included in "Gain on sale of assets" on the Condensed Statements of Consolidated and Combined Operations (unaudited). For the six months ended June 30, 2016 and 2015 , gains on conveyances amounted to $ 6.0 million and $ 13.6 million , respectively, and are included in "Gain on sale of assets" on the Condensed Statements of Consolidated and Combined Operations (unaudited). As of June 30, 2016 and December 31, 2015 , deferred gains of approximately $2.0 million and $8.1 million , respectively, were deferred pending performance of future obligations and recorded within "Deferred revenue," on the Condensed Consolidated Balance Sheets (unaudited).

Goodwill

Goodwill	6 Months Ended
	Jun. 30, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Goodwill The Partnership 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, referred to as the Columbia Gas Transmission Operations reporting unit, which is consistent with the level of discrete financial information reviewed by management. The Columbia Gas Transmission Operations reporting unit includes the following entities: Columbia Gas Transmission (including its equity method investment in the Millennium Pipeline joint venture), Columbia Gulf and the equity method investment in Hardy Storage. All of the Partnership's goodwill relates to NiSource's acquisition of CEG in 2000, which was contributed to the Partnership prior to CPPL's IPO. The Partnership’s goodwill assets at June 30, 2016 were $1,975.5 million . The Predecessor completed a quantitative (“step 1”) fair value measurement of the reporting unit during the May 1, 2012 goodwill test. The test indicated that the fair value of the reporting unit substantially exceeded the carrying value, indicating that no impairment existed. GAAP 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. The Partnership applied the qualitative step 0 analysis to its reporting unit for the annual impairment test performed as of May 1, 2016 . For the current year test, the Partnership assessed various assumptions, events and circumstances that would have affected the estimated fair value of the reporting unit as compared to its base line May 1, 2012 step 1 fair value measurement. The recent Merger Agreement and proposed acquisition price were incorporated into the current year testing. The results of this assessment indicated that it is not more likely than not that its reporting unit fair value is less than the reporting unit carrying value. The Partnership considered whether there were any events or changes in circumstances subsequent to the annual test that would reduce the fair value of the reporting unit below its carrying amount and necessitate another goodwill impairment test. In consideration of all relevant factors, there were no indicators that would require a subsequent goodwill impairment test during the second quarter of 2016 .

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2016
Asset Retirement Obligation [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations Changes in the Partnership’s liability for asset retirement obligations for the six months ended June 30, 2016 and 2015 are presented in the table below: (in millions) 2016 2015 Balance as of January 1, $ 25.3 $ 23.2 Noncontributed net parent investment adjustments (1) — (0.4 ) Accretion expense 0.5 0.6 Additions — 0.4 Settlements — — Change in estimated cash flows (1.9 ) — Balance as of June 30, $ 23.9 $ 23.8 (1) Reflects the removal of amounts related to Crossroads Pipeline Company, which was included in the Predecessor but was not contributed to the Partnership. The asset retirement obligations above relate to the modernization program of pipelines and transmission facilities, the retiring of offshore facilities, polychlorinated biphenyl ("PCB") remediation and asbestos removal at several compressor and measuring stations. The Partnership recognizes that certain assets, which include gas pipelines and natural gas storage wells, will operate for an indeterminate future period when properly maintained. A liability for these asset retirement obligations will be recorded only if and when a future retirement obligation with a determinable life is identified.

Regulatory Matters

Regulatory Matters	6 Months Ended
	Jun. 30, 2016
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Matters	Regulatory Matters Columbia Gas Transmission Customer Settlement. In November 2015, Columbia Gas Transmission commenced the fourth year of the Columbia Gas Transmission long-term system modernization program. Columbia Gas Transmission expects to place approximately $ 300.0 million in modernization investments into service during the year. Recovery of the revenue requirement on approximately $ 320.0 million of investments made in 2015 began on February 1, 2016. In December 2015, Columbia Gas Transmission filed an extension of this settlement and received the FERC's approval of the customer agreement in March 2016. This extension will allow Columbia Gas Transmission to invest an additional $1.1 billion over an additional three-year period through 2020. This agreement also expands the scope of facility investments covered by the program. Columbia Gulf. On January 21, 2016, the FERC issued an Order (the "January 21 Order") initiating an investigation pursuant to Section 5 of the NGA to determine whether Columbia Gulf’s existing rates for jurisdictional services are unjust and unreasonable. Columbia Gulf filed a cost and revenue study with the FERC on April 5, 2016, as required by the January 21 Order. The January 21 Order directed that a hearing be conducted pursuant to an accelerated timeline and that an initial decision be issued by February 28, 2017. On June 13, 2016, the FERC trial staff, Columbia Gulf, and all of the active parties filed a Joint Motion to Suspend the Procedural Schedule and Waive Answer Period (the "Motion"). The Motion represents that the parties unanimously support the Motion and requested waiver of the answer period, which was granted. The parties reached an agreement in principle during a June 2, 2016 settlement conference that would fully resolve all matters set for hearing by the FERC. The Motion represents that the parties expect to file an offer of settlement memorializing the agreement in principle no later than July 29, 2016, and suspension of the procedural schedule will promote an efficient and speedy resolution of this matter by allowing the participants to focus their efforts on drafting the necessary settlement documents. Columbia Gulf filed the offer of settlement with the FERC in accordance with the agreement noted above. Cost Recovery Trackers and other similar mechanisms. A significant portion of the 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 NGA. However, certain operating costs of the Columbia OpCo regulated transmission and storage companies are significant and recurring in nature, such as fuel for compression and lost and unaccounted for 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 upstream pipeline transmission, electric compression, operational purchases and sales of natural gas, and the revenue requirement for capital investments made under Columbia Gas Transmission's long-term plan to modernize its interstate transmission system as discussed above.

Equity Method Investments

Equity Method Investments	6 Months Ended
	Jun. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Equity Method Investments Certain investments of the Partnership are accounted for under the equity method of accounting. These investments are recorded within "Unconsolidated affiliates" on the Condensed Consolidated Balance Sheets (unaudited) and the Partnership's portion of the results is reflected in "Equity Earnings in Unconsolidated Affiliates" on the Condensed Statements of Consolidated and Combined Operations (unaudited). In the normal course of business, the Partnership engages in various transactions with these unconsolidated affiliates. Contributions are made to these equity investees to fund the Partnership’s share of capital projects. The following table contains contribution and distribution data representing the Partnership's portion based on the Partnership's ownership percentage of each investment: Three Months Ended Six Months Ended (in millions) 2016 2015 2016 2015 Millennium Pipeline Contributions to Millennium Pipeline $ — $ — $ 1.9 $ — Distributions of earnings from Millennium Pipeline 8.6 7.6 23.8 24.2 Hardy Storage Contributions to Hardy Storage — — — — Distributions of earnings from Hardy Storage 0.7 0.5 1.4 1.0 Pennant Contributions to Pennant — — — — Distributions of earnings from Pennant 3.0 1.5 6.0 2.7 Return of capital from Pennant 0.6 0.9 0.8 2.2

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Partnership is a limited partnership and is treated as a partnership for U.S. federal income tax purposes and, therefore, is not liable for entity-level federal income taxes. Amounts presented for 2015 in the combined financial statements relate to income taxes that have been determined on a separate tax return basis for the period prior to CPPL's IPO. The effective tax rates for the six months ended June 30, 2016 and 2015 were zero and 9.0% , respectively. The effective tax rate for 2015 differs from the Federal tax rate of 35% primarily due to post-IPO income that is not subject to income tax at the partnership level.

Pension And Other Postretiremen

Pension And Other Postretirement Benefits	6 Months Ended
	Jun. 30, 2016
Pension and Other Postretirement Benefit Expense [Abstract]
Pension And Other Postretirement Benefits	Pension and Other Postretirement Benefits CPG provides defined contribution plans and noncontributory defined benefit retirement plans that cover employees of subsidiaries of the Partnership. Prior to the Separation, employees of subsidiaries of the Partnership were covered by defined contribution plans and noncontributory defined benefit retirement plans provided by NiSource. Benefits under the defined benefit retirement plans reflect the employees' compensation, years of service and age at retirement. Additionally, CPG provides health care and life insurance benefits for certain retired employees of subsidiaries of the Partnership. The majority of employees may become eligible for these benefits if they reach retirement age while working for subsidiaries of the Partnership. The expected cost of such benefits is accrued during the employees' years of service. Current rates charged to customers of subsidiaries of the Partnership include postretirement benefit costs. Cash contributions are remitted to trusts, including a grantor trust used to fund benefits of the CPG non-qualified defined benefit plan. Subsidiaries of the Partnership are participants in the consolidated CPG defined benefit retirement plans (the Plans) and, therefore, subsidiaries of the Partnership are allocated a ratable portion of CPG's trusts for the Plans in which its employees and retirees participate. As a result, the Partnership follows multiple employer accounting under the provisions of GAAP. The following table provides the components of the subsidiaries of the Partnership's allocation of net periodic benefits cost for the three and six months ended June 30, 2016 and 2015 : Pension Benefits Other Postretirement Benefits Three Months Ended June 30, (in millions) 2016 2015 2016 2015 Components of Net Periodic Benefit Cost (Income) Service cost $ 1.4 $ 1.3 $ 0.2 $ 0.3 Interest cost 3.1 3.0 0.9 1.0 Expected return on assets (5.5 ) (6.1 ) (3.8 ) (4.3 ) Amortization of prior service (credit) cost (0.3 ) (0.2 ) 0.1 — Recognized actuarial loss 2.6 2.1 0.1 — Total Net Periodic Benefit Cost (Income) $ 1.3 $ 0.1 $ (2.5 ) $ (3.0 ) Pension Benefits Other Postretirement Benefits Six Months Ended June 30, (in millions) 2016 2015 2016 2015 Components of Net Periodic Benefit Cost (Income) Service cost $ 2.7 $ 2.6 $ 0.4 $ 0.6 Interest cost 6.3 6.1 1.9 2.0 Expected return on assets (11.0 ) (12.2 ) (7.6 ) (8.6 ) Amortization of prior service (credit) cost (0.5 ) (0.4 ) 0.1 — Recognized actuarial loss 5.1 4.1 0.1 — Total Net Periodic Benefit Cost (Income) $ 2.6 $ 0.2 $ (5.1 ) $ (6.0 )

Fair Value

Fair Value	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value	Fair Value The Partnership has certain financial instruments that are not measured at fair value on a recurring basis but nevertheless are recorded at amounts that approximate fair value due to their liquid or short-term nature, including cash and cash equivalents, customer deposits and short-term borrowings-affiliated. The Partnership's long-term debt-affiliated is 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. Long-term debt-affiliated. The fair value of these securities is estimated based on the quoted market prices for similar issues or on the rates offered for securities of the same remaining maturities. On January 31, 2016, the Partnership amended its intercompany credit agreement to extend the maturity date and apply a fixed interest rate. Prior to this amendment, the fair value approximated carrying value as these securities bore interest at variable rates. These fair value measurements are classified as Level 2 within the fair value hierarchy. For the six months ended June 30, 2016 and for the year ended December 31, 2015 , 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 June 30, 2016 Estimated Fair Value as of June 30, 2016 Carrying Amount as of Dec. 31, 2015 Estimated Fair Value as of Dec. 31, 2015 Long-term debt-affiliated $ 630.9 $ 671.9 $ 630.9 $ 630.9

Other Commitments And Contingen

Other Commitments And Contingencies	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Other Commitments and Contingencies A. Guarantees and Indemnities. In the normal course of its business, the Partnership and certain subsidiaries enter into various agreements providing financial or performance assurance to third parties on behalf of the parent or 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 the parent or a subsidiary on a stand-alone basis, thereby facilitating the extension of sufficient credit to accomplish the parent or the subsidiaries' intended commercial purposes. The total guarantees and indemnities in existence at June 30, 2016 and the years in which they expire were: (in millions) Total 2016 2017 2018 2019 2020 After Guarantees of debt $ 2,750.0 $ — $ — $ 500.0 $ — $ 750.0 $ 1,500.0 Letters of credit 18.1 18.1 — — — — — Total commercial commitments $ 2,768.1 $ 18.1 $ — $ 500.0 $ — $ 750.0 $ 1,500.0 Guarantees of Debt. The Partnership, together with CEG and OpCo GP (the "Guarantors") have guaranteed payment of $2,750.0 million in aggregated principal amount of CPG's senior notes. Each Guarantor is required to comply with covenants under the debt indenture and in the event of default the Guarantors would be obligated to pay the debt's principal and related interest. The Partnership does not anticipate that it will have any difficulty maintaining compliance. The guarantees of any Guarantor may be released under certain circumstances. Lines and Letters of Credit. CPPL maintained a $500.0 million senior revolving credit facility, of which $50.0 million was available for issuance of letters of credit. The Partnership, together with CPG, CEG and OpCo GP, each fully guaranteed the CPPL credit facility. On June 29, 2016, in anticipation of the Merger, all outstanding borrowings, facility fees and interest were paid in full and the revolving credit facility was terminated. CPG maintains a $1,500.0 million senior revolving credit facility, of which $250.0 million in letters of credit is available. The Partnership, together with CEG and OpCo GP, have each fully guaranteed the CPG credit facility. As of June 30, 2016 , CPG had no borrowings outstanding and $18.1 million in letters of credit outstanding under its revolving credit facility. On July 1, 2016, in connection with the Merger, all existing letters of credit were migrated to a TransCanada credit facility and the CPG revolving credit facility was terminated. CPG's commercial paper program (the “Program”) had a Program limit of up to $1,000.0 million . The Partnership, together with CEG and OpCo GP, each agreed, jointly and severally, unconditionally and irrevocably to guarantee payment in full of the principal of and interest (if any) on the promissory notes. On June 30, 2016, in anticipation of the Merger, the Program was terminated. CPG had no promissory notes outstanding under the Program at the time of termination. B. Other Legal Proceedings. In the normal course of its business, the Partnership has been named as a defendant in various legal proceedings. In the opinion of management, the ultimate disposition of these currently asserted claims will not have a material impact on the Partnership’s consolidated and combined financial statements. C. Environmental Matters. The Partnership's operations are subject to environmental statutes and regulations related to air quality, water quality, hazardous waste and solid waste. The Partnership believes that it is in substantial compliance with those environmental regulations currently applicable to its operations and believes that it has all necessary material permits to conduct its operations. It is the Partnership'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. The Partnership records accruals to cover environmental remediation at various sites. The current portion of this accrual is included in “Other accruals” in the Condensed Consolidated Balance Sheets (unaudited). The noncurrent portion is included in “Other noncurrent liabilities” in the Condensed Consolidated Balance Sheets (unaudited). Air The CAA and comparable state laws regulate emissions of air pollutants from various industrial sources, including compressor stations, and also impose various monitoring and reporting requirements. Such laws and regulations may require pre-approval for the construction or modification of certain projects or facilities expected to produce air emissions or result in an increase of existing air emissions; application for, and strict compliance with, air permits containing various emissions and operational limitations; or the utilization of specific emission control technologies to limit emissions. The actions listed below could require further reductions in emissions from various emission sources. The Partnership will continue to closely monitor developments in these matters. National Ambient Air Quality Standards. The federal 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 gas transmission operations. The following NAAQS were recently added or modified: Ozone : On October 1, 2015, the EPA issued a final rule lowering the NAAQS for ground-level ozone to 70 ppb under both the primary and secondary standards to provide requisite protection of public health and welfare, respectively. The EPA is required to include an adequate margin of safety in establishing the primary ozone standard for protection of public health, whereas the secondary ozone standard is intended to improve protection for trees, plants and ecosystems. The final rule becomes effective sixty days after the rule is published in the Federal Register. The EPA is required to make attainment and non-attainment designations for specific geographic locations under the revised standards by October 1, 2017 and, depending on the severity of the ozone present, non-attainment areas will have until between 2020 and 2037 to meet the health standard. With the EPA lowering the ground-level ozone standard, states may be required to implement more stringent regulations. Based on the current version of the rule, the Partnership does not expect a material impact on its operations. Nitrogen Dioxide (NO2) : The EPA revised the NO2 NAAQS by adding a one-hour standard while retaining the annual standard. The new standard could impact some Partnership 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 from some existing Partnership combustion sources may need to be assessed and mitigated. The Partnership will continue to monitor this matter and cannot estimate the impact of these rules at this time. Climate Change. Future legislative and regulatory programs could significantly restrict emissions of greenhouse gases including methane. New Source Performance Standards : On May 12, 2016, the EPA finalized the rule to regulate fugitive methane emissions for compressor stations in the natural gas transmission and storage sector. The final rule was subsequently published in the Federal Register on June 3, 2016. Semiannual leak detection and repair requirements using optical gas imaging are required for all components at new or existing compressor stations. Existing compressor stations trigger leak detection and repair requirements if any unit at the facility is modified. The EPA established additional requirements for any new or modified centrifugal or reciprocating compressors. Replacement of wet seals with dry seals or demonstrating a 95% reduction of methane emissions from wet seals is required for centrifugal compressors and rod packing replacement for reciprocating compressors is required every 26,000 hours of operation or every three years. The Partnership is working with industry groups to clarify ambiguities within the rule and to develop an assessment of the impacts to the Partnership and cannot estimate the impact of these rules at this time. Pipeline Safety On March 17, 2016, the federal Pipeline and Hazardous Materials Safety Administration (“PHMSA”) announced a proposed rulemaking that would, if adopted, impose more stringent requirements for certain gas lines and gathering lines under varying circumstances. Among other things, the proposed rulemaking would extend certain of PHMSA’s current regulatory safety programs for gas pipelines beyond “high consequence areas” to cover gas pipelines found in newly defined “moderate consequence areas” that contain as few as 5 dwellings within the potential impact area; require gas pipelines installed before 1970 that are currently exempted from certain pressure testing obligations to be tested to determine their maximum allowable operating pressures (“MAOP”); and require gathering lines in Class I areas, both onshore and offshore, to comply with standards regarding damage prevention, corrosion control (for metallic pipe), public education, MAOP limits, line markers and emergency planning if such gathering lines’ nominal design is 8 inches or more. In order to provide clarity and greater certainty on what may constitute a “gathering line,” PHMSA is proposing a new definition of that term under the rulemaking, which term would now encompass “a pipeline, or a connected series of pipelines, and equipment used to collect gas from the endpoint of a production facility/operation and transport it to the furthermost point downstream of the following endpoints” including the “inlet of 1 st gas processing plant;” the “outlet of” a gas treatment facility (not associated with a processing plant or compressor station); the “[o]utlet of the furthermost downstream compressor” leading to a pipeline, or the “point where separate production fields are commingled.” Other new requirements proposed by PHMSA under the rulemaking would require pipeline operators to: report to PHMSA in the event of certain MAOP exceedances; strengthen PHMSA integrity management requirements; consider seismicity in evaluating threats to a pipeline; conduct hydrostatic testing for all pipeline segments manufactured using longitudinal seam welds; and use more detailed guidance from PHMSA in the selection of assessment methods to inspect pipelines. The Partnership will continue to monitor this matter and cannot estimate the impact of these rules at this time. On June 22, 2016, President Obama signed new pipeline safety legislation, the “Protecting our Infrastructure of Pipelines and Enhancing Safety Act of 2016" (the “PIPES Act”). Extending PHMSA’s statutory mandate through 2019, the PIPES Act establishes or continues the development of stringent requirements affecting pipeline safety including: (i) providing PHMSA with additional authority to address imminent hazards by imposing emergency restrictions, prohibitions and safety measures on owners and operators of gas or hazardous liquid pipeline facilities without prior notice or an opportunity for a hearing; (ii) having pipeline operators that experience a spill from a liquids pipeline provide safety data sheets for the spilled liquid to the on-scene coordinator predesignated by the EPA and state and local officials within six hours of a telephonic notice; (iii) obligating PHMSA to develop safety standards for natural gas storage facilities by June 22, 2018; (iv) obligating PHMSA to provide feedback to pipeline operators after an inspection, including a briefing within thirty days and a written report with written preliminary findings within ninety days to the extent practicable; (v) requiring annual internal inspection of certain underwater hazardous liquid pipeline facilities in high consequence areas located at depths greater than 150 feet under the surface of the water; and (vi) requiring PHMSA to complete certain of the outstanding mandates under existing legislation and to report to Congress on the status of overdue rulemakings. The Partnership will continue to monitor this matter and cannot estimate the impact of these rules at this time.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	6 Months Ended
	Jun. 30, 2016
Other Comprehensive Income (Loss), Tax [Abstract]
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss The following tables display the components of Accumulated Other Comprehensive Loss for the three and six months ended June 30, 2016 and 2015 : Three Months Ended June 30, 2016 (in millions) Gains and Losses on Cash Flow Hedges (1) Pension and OPEB Items (1) Accumulated (1) Balance as of April 1, 2016 $ (24.8 ) $ (0.4 ) $ (25.2 ) Other comprehensive income before reclassifications — — — Amounts reclassified from accumulated other comprehensive income 0.5 — 0.5 Net current-period other comprehensive income 0.5 — 0.5 Balance as of June 30, 2016 $ (24.3 ) $ (0.4 ) $ (24.7 ) (1) Amounts in parentheses indicate debits. Six Months Ended June 30, 2016 (in millions) Gains and Losses on Cash Flow Hedges (1) Pension and OPEB Items (1) Accumulated Other Comprehensive Loss (1) Balance as of January 1, 2016 $ (25.3 ) $ (0.4 ) $ (25.7 ) Other comprehensive income before reclassifications — — — Amounts reclassified from accumulated other comprehensive income 1.0 — 1.0 Net current-period other comprehensive income 1.0 — 1.0 Balance as of June 30, 2016 $ (24.3 ) $ (0.4 ) $ (24.7 ) (1) Amounts in parentheses indicate debits. Three Months Ended June 30, 2015 (in millions) Gains and Losses on Cash Flow Hedges (1) Pension and OPEB Items (1) Accumulated (1) Balance as of April 1, 2015 $ (26.7 ) $ (0.2 ) $ (26.9 ) Other comprehensive income before reclassifications — — — Amounts reclassified from accumulated other comprehensive income 0.5 — 0.5 Net current-period other comprehensive income 0.5 — 0.5 Balance as of June 30, 2015 $ (26.2 ) $ (0.2 ) $ (26.4 ) (1) Amounts in parentheses indicate debits. Six Months Ended June 30, 2015 (in millions) Gains and Losses on Cash Flow Hedges (1)(2) Pension and OPEB Items (1)(2) Accumulated Other Comprehensive Loss (1)(2) Balance as of January 1, 2015 $ (16.6 ) $ (0.1 ) $ (16.7 ) Predecessor net tax liabilities not assumed by the Partnership (3) (10.2 ) (0.1 ) (10.3 ) Other comprehensive income before reclassifications — — — Amounts reclassified from accumulated other comprehensive income 0.6 — 0.6 Net current-period other comprehensive income 0.6 — 0.6 Balance as of June 30, 2015 $ (26.2 ) $ (0.2 ) $ (26.4 ) (1) Amounts in parentheses indicate debits. (2) All amounts prior to CPPL's IPO are net of tax. (3) Reflects the non-cash elimination of all historical current and deferred income taxes other than Tennessee state income taxes that will continue to be borne by the Partnership post-IPO. Equity Investment Millennium Pipeline is an equity method investment and, therefore, the Partnership is required to recognize a proportional share of Millennium Pipeline’s OCI. The remaining unrecognized loss at June 30, 2016 of $24.3 million , before tax, related to terminated interest rate swaps is being amortized over a 15 year period ending June 2025 into earnings using the effective interest method through interest expense as interest payments are made by Millennium Pipeline. The unrecognized loss of $24.3 million and $25.0 million , before tax, at June 30, 2016 and December 31, 2015 , respectively, is included in gains and losses on cash flow hedges above.

Other, Net

Other, Net	6 Months Ended
	Jun. 30, 2016
Other Income and Expenses [Abstract]
Other, Net	Other, Net Three Months Ended Six Months Ended (in millions) 2016 2015 2016 2015 AFUDC Equity $ 9.8 $ 4.9 $ 15.9 $ 8.4 Miscellaneous 0.1 0.5 0.1 1.4 Total Other, net $ 9.9 $ 5.4 $ 16.0 $ 9.8

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	6 Months Ended
	Jun. 30, 2016
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Supplemental Cash Flow Information The following table provides additional information regarding the Partnership’s Condensed Statements of Consolidated and Combined Cash Flows (unaudited) for the six months ended June 30, 2016 and 2015 : (in millions) 2016 2015 Supplemental Disclosures of Cash Flow Information Non-cash transactions: Capital expenditures included in current liabilities (1) $ 212.8 $ 184.5 Schedule of interest paid: Cash paid for interest, net of interest capitalized amounts $ 14.3 $ 21.3 (1) Capital expenditures included in current liabilities is comprised of "Accrued capital expenditures" and certain other amounts included within "Accounts payable" on the Condensed Consolidated Balance Sheets (unaudited).

Concentration Of Credit Risk

Concentration Of Credit Risk	6 Months Ended
	Jun. 30, 2016
Risks and Uncertainties [Abstract]
Concentration Risk Disclosure	Concentration of Credit Risk Columbia Gas of Ohio, an affiliated party prior to the Separation, accounted for greater than 10% of total operating revenues for the three and six months ended June 30, 2016 and 2015 . The following tables provide this customer's operating revenues and percentage of total operating revenues for the three and six months ended June 30, 2016 and 2015 : Three Months Ended June 30, 2016 2015 (in millions) Total Operating Revenues Percentage of Total Operating Revenues Total Operating Revenues Percentage of Total Operating Revenues Columbia Gas of Ohio (1) $ 35.1 11.2 % $ 36.2 11.5 % Six Months Ended June 30, 2016 2015 (in millions) Total Operating Revenues Percentage of Total Operating Revenues Total Operating Revenues Percentage of Total Operating Revenues Columbia Gas of Ohio (1) $ 85.5 12.6 % $ 85.1 13.0 % (1) Represents the gross amount of revenue contracted for with Columbia Gas of Ohio and, therefore, subject to risk at the loss of this customer. Columbia Gas of Ohio has entered into certain capacity release arrangements with third parties which ultimately can decrease the net revenue amount the Partnership receives from Columbia Gas of Ohio in any given period. The loss of a significant portion of operating revenues from this customer could have a material adverse effect on the business of the Partnership.

Transactions With Affiliates (T

Transactions With Affiliates (Tables)	6 Months Ended
	Jun. 30, 2016
Related Party Transactions [Abstract]
Schedule of Transactions With Affiliates	Statement of Operations Three Months Ended Six Months Ended (in millions) 2016 2015 2016 2015 Transportation revenues $ — $ 18.4 $ — $ 47.1 Storage revenues — 12.9 — 26.2 Other revenues — 0.1 — 0.2 Operation and maintenance expense 39.2 38.5 81.3 74.6 Interest expense 7.0 6.3 14.2 17.7 Interest income 0.2 1.1 0.3 2.1 Balance Sheet (in millions) June 30, December 31, 2015 Accounts receivable $ 102.0 $ 149.4 Short-term borrowings 653.2 42.1 Accounts payable 26.7 85.9 Long-term debt 630.9 630.9
Schedule of Related Party Transactions, Long-Term Debt	Origination Date Interest Rate Maturity Date June 30, 2016 December 31, 2015 (in millions) December 9, 2013 4.70 % December 31, 2020 $ 630.9 $ 630.9

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2016
Asset Retirement Obligation [Abstract]
Changes In Company's Liability For Asset Retirement Obligations	(in millions) 2016 2015 Balance as of January 1, $ 25.3 $ 23.2 Noncontributed net parent investment adjustments (1) — (0.4 ) Accretion expense 0.5 0.6 Additions — 0.4 Settlements — — Change in estimated cash flows (1.9 ) — Balance as of June 30, $ 23.9 $ 23.8 (1) Reflects the removal of amounts related to Crossroads Pipeline Company, which was included in the Predecessor but was not contributed to the Partnership.

Equity Method Investments (Tabl

Equity Method Investments (Tables)	6 Months Ended
	Jun. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	The following table contains contribution and distribution data representing the Partnership's portion based on the Partnership's ownership percentage of each investment: Three Months Ended Six Months Ended (in millions) 2016 2015 2016 2015 Millennium Pipeline Contributions to Millennium Pipeline $ — $ — $ 1.9 $ — Distributions of earnings from Millennium Pipeline 8.6 7.6 23.8 24.2 Hardy Storage Contributions to Hardy Storage — — — — Distributions of earnings from Hardy Storage 0.7 0.5 1.4 1.0 Pennant Contributions to Pennant — — — — Distributions of earnings from Pennant 3.0 1.5 6.0 2.7 Return of capital from Pennant 0.6 0.9 0.8 2.2

Pension And Other Postretirem29

Pension And Other Postretirement Benefits (Tables)	6 Months Ended
	Jun. 30, 2016
Pension and Other Postretirement Benefit Expense [Abstract]
Components Of The Plans' Net Periodic Benefits Cost	Pension Benefits Other Postretirement Benefits Three Months Ended June 30, (in millions) 2016 2015 2016 2015 Components of Net Periodic Benefit Cost (Income) Service cost $ 1.4 $ 1.3 $ 0.2 $ 0.3 Interest cost 3.1 3.0 0.9 1.0 Expected return on assets (5.5 ) (6.1 ) (3.8 ) (4.3 ) Amortization of prior service (credit) cost (0.3 ) (0.2 ) 0.1 — Recognized actuarial loss 2.6 2.1 0.1 — Total Net Periodic Benefit Cost (Income) $ 1.3 $ 0.1 $ (2.5 ) $ (3.0 ) Pension Benefits Other Postretirement Benefits Six Months Ended June 30, (in millions) 2016 2015 2016 2015 Components of Net Periodic Benefit Cost (Income) Service cost $ 2.7 $ 2.6 $ 0.4 $ 0.6 Interest cost 6.3 6.1 1.9 2.0 Expected return on assets (11.0 ) (12.2 ) (7.6 ) (8.6 ) Amortization of prior service (credit) cost (0.5 ) (0.4 ) 0.1 — Recognized actuarial loss 5.1 4.1 0.1 — Total Net Periodic Benefit Cost (Income) $ 2.6 $ 0.2 $ (5.1 ) $ (6.0 )

Fair Value (Tables)

Fair Value (Tables)	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Carrying Amount And Estimated Fair Values Of Financial Instruments	The carrying amount and estimated fair values of financial instruments were as follows: (in millions) Carrying Amount as of June 30, 2016 Estimated Fair Value as of June 30, 2016 Carrying Amount as of Dec. 31, 2015 Estimated Fair Value as of Dec. 31, 2015 Long-term debt-affiliated $ 630.9 $ 671.9 $ 630.9 $ 630.9

Other Commitments And Conting31

Other Commitments And Contingencies (Tables)	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Schedule of Guarantee Obligations	The total guarantees and indemnities in existence at June 30, 2016 and the years in which they expire were: (in millions) Total 2016 2017 2018 2019 2020 After Guarantees of debt $ 2,750.0 $ — $ — $ 500.0 $ — $ 750.0 $ 1,500.0 Letters of credit 18.1 18.1 — — — — — Total commercial commitments $ 2,768.1 $ 18.1 $ — $ 500.0 $ — $ 750.0 $ 1,500.0

Accumulated Other Comprehensi32

Accumulated Other Comprehensive Loss (Tables)	6 Months Ended
	Jun. 30, 2016
Other Comprehensive Income (Loss), Tax [Abstract]
Components Of Accumulated Other Comprehensive Loss	Three Months Ended June 30, 2016 (in millions) Gains and Losses on Cash Flow Hedges (1) Pension and OPEB Items (1) Accumulated (1) Balance as of April 1, 2016 $ (24.8 ) $ (0.4 ) $ (25.2 ) Other comprehensive income before reclassifications — — — Amounts reclassified from accumulated other comprehensive income 0.5 — 0.5 Net current-period other comprehensive income 0.5 — 0.5 Balance as of June 30, 2016 $ (24.3 ) $ (0.4 ) $ (24.7 ) (1) Amounts in parentheses indicate debits. Six Months Ended June 30, 2016 (in millions) Gains and Losses on Cash Flow Hedges (1) Pension and OPEB Items (1) Accumulated Other Comprehensive Loss (1) Balance as of January 1, 2016 $ (25.3 ) $ (0.4 ) $ (25.7 ) Other comprehensive income before reclassifications — — — Amounts reclassified from accumulated other comprehensive income 1.0 — 1.0 Net current-period other comprehensive income 1.0 — 1.0 Balance as of June 30, 2016 $ (24.3 ) $ (0.4 ) $ (24.7 ) (1) Amounts in parentheses indicate debits. Three Months Ended June 30, 2015 (in millions) Gains and Losses on Cash Flow Hedges (1) Pension and OPEB Items (1) Accumulated (1) Balance as of April 1, 2015 $ (26.7 ) $ (0.2 ) $ (26.9 ) Other comprehensive income before reclassifications — — — Amounts reclassified from accumulated other comprehensive income 0.5 — 0.5 Net current-period other comprehensive income 0.5 — 0.5 Balance as of June 30, 2015 $ (26.2 ) $ (0.2 ) $ (26.4 ) (1) Amounts in parentheses indicate debits. Six Months Ended June 30, 2015 (in millions) Gains and Losses on Cash Flow Hedges (1)(2) Pension and OPEB Items (1)(2) Accumulated Other Comprehensive Loss (1)(2) Balance as of January 1, 2015 $ (16.6 ) $ (0.1 ) $ (16.7 ) Predecessor net tax liabilities not assumed by the Partnership (3) (10.2 ) (0.1 ) (10.3 ) Other comprehensive income before reclassifications — — — Amounts reclassified from accumulated other comprehensive income 0.6 — 0.6 Net current-period other comprehensive income 0.6 — 0.6 Balance as of June 30, 2015 $ (26.2 ) $ (0.2 ) $ (26.4 ) (1) Amounts in parentheses indicate debits. (2) All amounts prior to CPPL's IPO are net of tax. (3) Reflects the non-cash elimination of all historical current and deferred income taxes other than Tennessee state income taxes that will continue to be borne by the Partnership post-IPO.

Other, Net (Tables)

Other, Net (Tables)	6 Months Ended
	Jun. 30, 2016
Other Income and Expenses [Abstract]
Schedule Of Other, Net	Three Months Ended Six Months Ended (in millions) 2016 2015 2016 2015 AFUDC Equity $ 9.8 $ 4.9 $ 15.9 $ 8.4 Miscellaneous 0.1 0.5 0.1 1.4 Total Other, net $ 9.9 $ 5.4 $ 16.0 $ 9.8

Supplemental Cash Flow Inform34

Supplemental Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2016
Supplemental Cash Flow Information [Abstract]
Additional Information Regarding Condensed Statements Of Consolidated Cash Flows	(in millions) 2016 2015 Supplemental Disclosures of Cash Flow Information Non-cash transactions: Capital expenditures included in current liabilities (1) $ 212.8 $ 184.5 Schedule of interest paid: Cash paid for interest, net of interest capitalized amounts $ 14.3 $ 21.3 (1) Capital expenditures included in current liabilities is comprised of "Accrued capital expenditures" and certain other amounts included within "Accounts payable" on the Condensed Consolidated Balance Sheets (unaudited).

Concentration Of Credit Risk (T

Concentration Of Credit Risk (Tables)	6 Months Ended
	Jun. 30, 2016
Risks and Uncertainties [Abstract]
Schedule of Concentration Of Credit Risk	Three Months Ended June 30, 2016 2015 (in millions) Total Operating Revenues Percentage of Total Operating Revenues Total Operating Revenues Percentage of Total Operating Revenues Columbia Gas of Ohio (1) $ 35.1 11.2 % $ 36.2 11.5 % Six Months Ended June 30, 2016 2015 (in millions) Total Operating Revenues Percentage of Total Operating Revenues Total Operating Revenues Percentage of Total Operating Revenues Columbia Gas of Ohio (1) $ 85.5 12.6 % $ 85.1 13.0 % (1) Represents the gross amount of revenue contracted for with Columbia Gas of Ohio and, therefore, subject to risk at the loss of this customer. Columbia Gas of Ohio has entered into certain capacity release arrangements with third parties which ultimately can decrease the net revenue amount the Partnership receives from Columbia Gas of Ohio in any given period.

Basis of Accounting Presentat36

Basis of Accounting Presentation (Narrative) (Details) $ in Millions	Jul. 01, 2016USD ($)	Feb. 11, 2015USD ($)	Jun. 30, 2015USD ($)shares	Jun. 30, 2016mi
Basis Of Accounting Presentation [Line Items]
Pipeline Miles | mi				15,000
Reimbursement of Preformation Capital			$ 500
Net proceeds from IPO			$ 1,170
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest				100.00%
Columbia Pipeline Partners LP [Member]
Basis Of Accounting Presentation [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				15.70%
Columbia Hardy Corporation [Member]
Basis Of Accounting Presentation [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				0.77%
Columbia Energy Group [Member]
Basis Of Accounting Presentation [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest			84.30%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest				83.53%
Columbia Pipeline Partners LP [Member]
Basis Of Accounting Presentation [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest Additional Ownership Interest			8.40%
Columbia Energy Group [Member]
Basis Of Accounting Presentation [Line Items]
Contribution of capital from parent		$ 1,217.3
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest			7.30%
Subordinated Units [Member] | Columbia Energy Group [Member]
Basis Of Accounting Presentation [Line Items]
Partners' Capital Account, Units, Sold in Public Offering | shares			46,811,398
Subsequent Event [Member]
Basis Of Accounting Presentation [Line Items]
Employee related Merger transaction costs	$ 100

Transactions With Affiliates (N

Transactions With Affiliates (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		5 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Jul. 01, 2016	Dec. 31, 2015	Dec. 05, 2014
Related Party Transaction [Line Items]
Interest Expense, Long-term Debt	$ 7.5	$ 7.5		$ 15.2	$ 19.7
Allowance for Funds Used During Construction, Capitalized Interest	1.2	1.4		1.9	2.4
Interest Expense, Short-term Borrowings	0.7	$ 0.2		0.9	$ 0.4
Accounts receivable-affiliated	102			102			$ 149.4
Line of Credit Facility, Maximum Borrowing Capacity	2,600			2,600
Short-term borrowings-affiliated	653.2			653.2			42.1
Distribution Made to Limited Partner, Cash Distributions Paid				327.9
Reimbursement of Preformation Capital			$ 500
Transportation and Storage Services
Related Party Transaction [Line Items]
Accounts receivable-affiliated	$ 2.2			$ 2.2			8.9
Money Pool
Related Party Transaction [Line Items]
Short-term Debt, Weighted Average Interest Rate	0.53%	1.21%	1.21%	0.53%	1.21%
Accounts receivable-affiliated	$ 99.7			$ 99.7			$ 140.5
Line of Credit Facility, Maximum Borrowing Capacity	750			750
Revolving Credit Facility [Member]
Related Party Transaction [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity								$ 1,500
Notes Due 2020 [Member]
Related Party Transaction [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 2,300			$ 2,300
Debt Instrument, Interest Rate, Stated Percentage	4.70%			4.70%
Debt Instrument, Maturity Date				Dec. 31, 2020
TransCanada PipeLine USA Ltd. [Member] | Subsequent Event [Member] | Revolving Credit Facility [Member]
Related Party Transaction [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity						$ 2,000

Transactions With Affiliates (S

Transactions With Affiliates (Schedule of Affiliated Transactions) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Related Party Transaction [Line Items]
Transportation revenues	$ 0	$ 18.4	$ 0	$ 47.1
Storage revenues	0	12.9	0	26.2
Other revenues	0	0.1	0	0.2
Operation and maintenance expense	39.2	38.5	81.3	74.6
Interest expense	7	6.3	14.2	17.7
Interest income	0.2	$ 1.1	0.3	$ 2.1
Accounts receivable	102		102		$ 149.4
Short-term borrowings	653.2		653.2		42.1
Accounts payable	26.7		26.7		85.9
Long-term debt	$ 630.9		$ 630.9		$ 630.9

Transactions With Affiliates 39

Transactions With Affiliates (Schedule of Long-term Debt) (Details) - Notes Due 2020 [Member] - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Schedule of Related Party Transactions, Long-Term Debt [Line Items]
Debt Instrument, Issuance Date	Dec. 9, 2013
Debt Instrument, Interest Rate, Stated Percentage	4.70%
Debt Instrument, Maturity Date	Dec. 31, 2020
Long-term Debt	$ 630.9	$ 630.9

Gain On Sale Of Assets (Narrati

Gain On Sale Of Assets (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Gain On Sale of Assets [Abstract]
Gain on Conveyances	$ 3.4	$ 8.3	$ 6	$ 13.6
Deferred Gains On Conveyances	$ 2		$ 2		$ 8.1

Goodwill (Narrative) (Details)

Goodwill (Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	$ 1,975.5	$ 1,975.5

Asset Retirement Obligations (C

Asset Retirement Obligations (Changes In Company's Liability For Asset Retirement Obligations) (Details) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance		$ 25.3	$ 23.2
Noncontributed net parent investment adjustments	[1]	0	(0.4)
Accretion expense		0.5	0.6
Additions		0	0.4
Settlements		0	0
Change in estimated cash flows		(1.9)	0
Ending Balance		$ 23.9	$ 23.8
[1]	Reflects the removal of amounts related to Crossroads Pipeline Company, which was included in the Predecessor but was not contributed to the Partnership.

Regulatory Matters (Narrative)

Regulatory Matters (Narrative) (Details) - USD ($) $ in Millions	Jan. 01, 2016	Jun. 30, 2016	Feb. 01, 2016
Regulatory Assets and Liabilities Disclosure [Abstract]
Expected Modernization Investment	$ 300
Modernization Program Recovery			$ 320
Annual Capital Cost Recovery Mechanism Extension Limit		$ 1,100

Equity Method Investments (Sche

Equity Method Investments (Schedule of Equity Method Investments) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Millennium Pipeline
Schedule of Equity Method Investments [Line Items]
Contributions	$ 0	$ 0	$ 1.9	$ 0
Distributions of earnings	8.6	7.6	23.8	24.2
Hardy Storage
Schedule of Equity Method Investments [Line Items]
Contributions	0	0	0	0
Distributions of earnings	0.7	0.5	1.4	1
Pennant
Schedule of Equity Method Investments [Line Items]
Contributions	0	0	0	0
Distributions of earnings	3	1.5	6	2.7
Return of capital	$ 0.6	$ 0.9	$ 0.8	$ 2.2

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Income Tax Disclosure [Abstract]
Effective income tax rates	0.00%	9.00%
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	35.00%	35.00%

Pension And Other Postretirem46

Pension And Other Postretirement Benefits (Components Of The Plans' Net Periodic Benefits Cost) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service Cost	$ 1.4	$ 1.3	$ 2.7	$ 2.6
Interest cost	3.1	3	6.3	6.1
Expected return on assets	(5.5)	(6.1)	(11)	(12.2)
Amortization of prior service (credit) cost	(0.3)	(0.2)	(0.5)	(0.4)
Recognized actuarial loss	2.6	2.1	5.1	4.1
Total Net Periodic Benefits Cost (Income)	1.3	0.1	2.6	0.2
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service Cost	0.2	0.3	0.4	0.6
Interest cost	0.9	1	1.9	2
Expected return on assets	(3.8)	(4.3)	(7.6)	(8.6)
Amortization of prior service (credit) cost	0.1	0	0.1	0
Recognized actuarial loss	0.1	0	0.1	0
Total Net Periodic Benefits Cost (Income)	$ (2.5)	$ (3)	$ (5.1)	$ (6)

Fair Value (Carrying Amount And

Fair Value (Carrying Amount And Estimated Fair Values Of Financial Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term debt-affiliated, Carrying Amount	$ 630.9	$ 630.9
Long-term debt-affiliated, Estimated Fair Value	$ 671.9	$ 630.9

Other Commitments And Conting48

Other Commitments And Contingencies (Narrative) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)	Dec. 05, 2014USD ($)
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Guarantees	$ 2,768.1
Line of Credit Facility, Maximum Borrowing Capacity	$ 2,600
Ozone Level Maximum	70 ppb
Percentage Reduction in Methane Emissions	95.00%
Hours of Operation	26,000
Replacement Years	3 years
Revolving Credit Facility [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 1,500
Guarantees of debt
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Guarantees	$ 2,750
Lines and letters of Credit
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Guarantees	18.1
Columbia Pipeline Partners LP [Member] | Revolving Credit Facility [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	500
Columbia Pipeline Partners LP [Member] | Lines and letters of Credit
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	50
Columbia Pipeline Group | Revolving Credit Facility [Member]
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	1,500
Columbia Pipeline Group | Lines and letters of Credit
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	250
Lines and letters of Credit | Columbia Pipeline Group
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Letters of Credit, Outstanding Amount	18.1
Commercial Paper [Member] | Columbia Pipeline Group
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	1,000
Commercial Paper	0
Revolving Credit Facility [Member] | Columbia Pipeline Group
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Credit facilities borrowings	$ 0

Other Commitments And Conting49

Other Commitments And Contingencies (Existence and Expiration of Commercial Commitments) (Details) $ in Millions	Jun. 30, 2016USD ($)
Total commercial commitments [Line Items]
Total	$ 2,768.1
2,016	18.1
2,017	0
2,018	500
2,019	0
2,020	750
After	1,500
Guarantees of debt
Total commercial commitments [Line Items]
Total	2,750
2,016	0
2,017	0
2,018	500
2,019	0
2,020	750
After	1,500
Lines and letters of Credit
Total commercial commitments [Line Items]
Total	18.1
2,016	18.1
2,017	0
2,018	0
2,019	0
2,020	0
After	$ 0

Accumulated Other Comprehensi50

Accumulated Other Comprehensive Loss (Narrative) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Accumulated Other Comprehensive Loss [Line Items]
Other Comprehensive Income Unrecognized Gain Loss On Derivatives Arising During Period Before Tax	$ 24.3	$ 25
Millennium Pipeline
Accumulated Other Comprehensive Loss [Line Items]
Unrealized loss, amortization period	15 years
Debt Instrument, Maturity Date	Jun. 1, 2025

Accumulated Other Comprehensi51

Accumulated Other Comprehensive Loss (Components Of Accumulated Other Comprehensive Loss) (Details) - USD ($) $ in Millions		3 Months Ended				5 Months Ended		6 Months Ended
		Jun. 30, 2016		Jun. 30, 2015		Jun. 30, 2015		Jun. 30, 2016		Jun. 30, 2015
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning Balance	[1]	$ (25.2)		$ (26.9)				$ (25.7)		$ (16.7)	[2]
Other comprehensive income before reclassifications	[1]	0		0				0		0	[2]
Amounts reclassified from accumulated other comprehensive income	[1]	0.5		0.5				1		0.6	[2]
Other Comprehensive Income (Loss), Net of Tax		0.5	[1]	0.5	[1]	$ 0.5		1	[1]	0.6	[1],[2]
Ending Balance	[1]	(24.7)		(26.4)	[2]	(26.4)	[2]	(24.7)		(26.4)	[2]
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning Balance	[1]	(24.8)		(26.7)				(25.3)		(16.6)	[2]
Predecessor net tax liabilities not assumed by the Partnership	[1],[2],[3]									(10.2)
Other comprehensive income before reclassifications	[1]	0		0				0		0	[2]
Amounts reclassified from accumulated other comprehensive income	[1]	0.5		0.5				1		0.6	[2]
Other Comprehensive Income (Loss), Net of Tax	[1]	0.5		0.5				1		0.6	[2]
Ending Balance	[1]	(24.3)		(26.2)	[2]	(26.2)	[2]	(24.3)		(26.2)	[2]
Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning Balance	[1]	(0.4)		(0.2)				(0.4)		(0.1)	[2]
Predecessor net tax liabilities not assumed by the Partnership	[1],[2],[3]									(0.1)
Other comprehensive income before reclassifications	[1]	0		0				0		0	[2]
Amounts reclassified from accumulated other comprehensive income	[1]	0		0				0		0	[2]
Other Comprehensive Income (Loss), Net of Tax	[1]	0		0				0		0	[2]
Ending Balance	[1]	$ (0.4)		$ (0.2)	[2]	(0.2)	[2]	(0.4)		(0.2)	[2]
Accumulated Other Comprehensive Loss
Accumulated Other Comprehensive Income (Loss) [Line Items]
Predecessor net tax liabilities not assumed by the Partnership	[1],[2],[3]									$ (10.3)
Other Comprehensive Income (Loss), Net of Tax						$ 0.5		$ 1
[1]	Amounts in parentheses indicate debits.
[2]	All amounts prior to CPPL's IPO are net of tax.
[3]	Reflects the non-cash elimination of all historical current and deferred income taxes other than Tennessee state income taxes that will continue to be borne by the Partnership post-IPO.

Other, Net (Schedule of Other,

Other, Net (Schedule of Other, Net) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Other Income and Expenses [Abstract]
AFUDC Equity	$ 9.8	$ 4.9	$ 15.9	$ 8.4
Miscellaneous	0.1	0.5	0.1	1.4
Total Other, net	$ 9.9	$ 5.4	$ 16	$ 9.8

Supplemental Cash Flow Inform53

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015
Supplemental Cash Flow [Line Items]
Capital expenditures included in current liabilities	[1]	$ 212.8	$ 184.5
Cash paid for interest, net of interest capitalized amounts		$ 14.3	$ 21.3
[1]	Capital expenditures included in current liabilities is comprised of "Accrued capital expenditures" and certain other amounts included within "Accounts payable" on the Condensed Consolidated Balance Sheets (unaudited).

Concentration Of Credit Risk (N

Concentration Of Credit Risk (Narrative) (Details)	6 Months Ended
	Jun. 30, 2016
Concentration Risk [Line Items]
Concentration Risk, Benchmark Description	greater than 10% of total operating revenues

Concentration of Credit Risk (S

Concentration of Credit Risk (Schedule of Concentration Of Credit Risk) (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2016		Jun. 30, 2015		Jun. 30, 2016	Jun. 30, 2015
Concentration Risk [Line Items]
Revenues	$ 313.2		$ 315.6		$ 676.7	$ 654.8
Credit Concentration Risk
Concentration Risk [Line Items]
Revenues	$ 35.1	[1]	$ 36.2	[1]	$ 85.5	$ 85.1
Concentration Risk, Percentage	11.20%	[1]	11.50%	[1]	12.60%	13.00%
[1]	Represents the gross amount of revenue contracted for with Columbia Gas of Ohio and, therefore, subject to risk at the loss of this customer. Columbia Gas of Ohio has entered into certain capacity release arrangements with third parties which ultimately can decrease the net revenue amount the Partnership receives from Columbia Gas of Ohio in any given period.