Kinder Morgan (KMI) 10-Q 28 Apr 15 2015 Q1 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	3 Months Ended
	Mar. 31, 2015	Apr. 24, 2015	Jun. 30, 2014
Entity [Abstract]
Entity Registrant Name	KINDER MORGAN, INC.
Entity Central Index Key	1506307
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$24,279,037,627
Entity Common Stock, Shares Outstanding		2,168,154,800
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (Unaudited) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Revenues [Abstract]
Natural gas sales	$785	$1,097
Services	1,970	1,829
Product sales and other	842	1,121
Total Revenues	3,597	4,047
Operating Costs, Expenses and Other
Costs of sales	1,090	1,643
Operations and maintenance	505	483
Depreciation, depletion and amortization	538	496
General and administrative	216	172
Taxes, other than income taxes	115	110
Impairment of Long-Lived Assets Held-for-use	51	0
Other expense (income), net	4	-4
Total Operating Costs, Expenses and Other	2,519	2,900
Operating Income	1,078	1,147
Other Income (Expense)
Earnings from equity investments	102	99
Loss on impairments of equity investments	-26	0
Amortization of excess cost of equity investments	-12	-10
Interest, net	-512	-448
Other, net	13	13
Total Other Expense	-435	-346
Income Before Income Taxes	643	801
Income Tax Expense	-224	-200
Net Income	419	601
Net Loss (Income) Attributable to Noncontrolling Interests	10	-314
Net Income Attributable to Kinder Morgan, Inc.	$429	$287
Class P Shares
Diluted Earnings Per Common Share	$0.20	$0.28
Diluted Weighted-Average Number of Shares Outstanding	2,151	1,029
Class P [Member]
Class P Shares
Basic Earnings Per Common Share	$0.20	$0.28
Basic Weighted-Average Number of Shares Outstanding	2,141	1,029
Dividends Per Common Share Declared for the Period	$0.48	$0.42

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Total
Net income	$419	$601
Other comprehensive income (loss), net of tax
Change in fair value of derivatives utilized for hedging purposes (net of tax benefit of $1 and $14, respectively)	-2	-45
Reclassification of change in fair value of derivatives to net income (net of tax benefit (expense) of $41 and $(4), respectively)	-72	14
Foreign currency translation adjustments (net of tax benefit of $62 and $18, respectively)	-108	-62
Benefit plan adjustments (net of tax (expense) benefit of $(3) and $-, respectively)	6	-1
Total other comprehensive loss	-176	-94
Comprehensive income	243	507
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	10	-258
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$253	$249

CONSOLIDATED_STATEMENTS_OF_COM1

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Total
Change in fair value of derivatives utilized for hedging purposes, tax benefit total	$1	$14
Reclassification of change in fair value of derivatives to net income, tax expense total	41	-4
Foreign currency translation adjustments, tax expense total	62	18
Adjustments to pension and other postretirement benefit plan liabilities, tax benefit total	($3)	$0

CONSOLIDATED_BALANCE_SHEETS_Un

CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Current Assets
Cash and cash equivalents	$259	$315
Accounts receivable, net	1,420	1,641
Inventories	453	459
Fair value of derivative contracts	561	535
Deferred income taxes	56	56
Other current assets	540	746
Total current assets	3,289	3,752
Property, plant and equipment, net	40,289	38,564
Investments	6,011	6,036
Goodwill	24,907	24,654
Other intangibles, net	3,762	2,302
Deferred income taxes	5,545	5,651
Deferred charges and other assets	2,361	2,239
Total Assets	86,164	83,198
Current Liabilities
Current portion of debt	3,435	2,717
Accounts payable	1,393	1,588
Accrued interest	538	637
Accrued contingencies	399	383
Other current liabilities	1,019	1,037
Total current liabilities	6,784	6,362
Long-term debt
Outstanding	39,633	38,212
Preferred interest in general partner of KMP	100	100
Debt fair value adjustments	2,091	1,934
Total long-term debt	41,824	40,246
Other long-term liabilities and deferred credits	2,197	2,164
Total long-term liabilities and deferred credits	44,021	42,410
Total Liabilities	50,805	48,772
Stockholders’ Equity
Preferred stock, $0.01 par value, 10,000,000 shares authorized, none outstanding	0	0
Additional paid-in capital	37,839	36,178
Accumulated other comprehensive loss	-193	-17
Total Kinder Morgan, Inc.’s stockholders’ equity	35,029	34,076
Noncontrolling interests	330	350
Total Stockholders’ Equity	35,359	34,426
Total Liabilities and Stockholders’ Equity	86,164	83,198
Class P [Member]
Stockholders’ Equity
Class P shares, $0.01 par value, 4,000,000,000 shares authorized, 2,165,283,234 and 2,125,147,116 shares, respectively, issued and outstanding	22	21
Retained deficit	-2,639	-2,106
Kinder Morgan G.P., Inc. [Member] | KMI $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock [Member]
Long-term debt
Preferred interest in general partner of KMP	$100	$100

CONSOLIDATED_BALANCE_SHEETS_Un1

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
Stockholders' Equity
Preferred Stock, Par or Stated Value Per Share	$0.01	$0.01
Preferred Stock, Shares Authorized	10,000,000	10,000,000
Preferred Stock, Shares Outstanding	0	0
Class P [Member]
Stockholders' Equity
Common stock, par value (in dollars per share)	$0.01	$0.01
Common Stock, Shares Authorized	4,000,000,000	4,000,000,000
Common Stock, Shares, Issued	2,165,283,234	2,125,147,116
Common Stock, Shares, Outstanding	2,165,283,234	2,125,147,116

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash Flows From Operating Activities
Net income	$419	$601
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization	538	496
Deferred income taxes	221	111
Amortization of excess cost of equity investments	12	10
Loss on impairments of long-lived assets and equity investments	77	0
Earnings from equity investments	-102	-99
Distributions from equity investment earnings	92	77
Pension contributions and noncash pension benefit credits	-12	-59
Changes in components of working capital, net of the effects of acquisitions
Accounts receivable	216	178
Increase (Decrease) in Income Taxes Receivable	195	0
Inventories	6	10
Other current assets	25	19
Accounts payable	-241	-140
Accrued interest	-114	-154
Increase (Decrease) in Other Current Liabilities	-12	95
Rate reparations, refunds and other litigation reserve adjustments	60	0
Other, net	-124	-27
Net Cash Provided by Operating Activities	1,256	1,118
Cash flows from investing activities
Business acquisitions, net of cash acquired (Note 2)	-1,859	-960
Acquisitions of other assets and investments	5	30
Capital expenditures	-897	-845
Contributions to investments	-30	-36
Distributions from equity investments in excess of cumulative earnings	50	38
Other, net	-34	14
Net Cash Used in Investing Activities	-2,775	-1,819
Cash flows from financing activities
Issuance of debt	7,136	5,191
Payment of debt	-6,305	-4,184
Debt issue costs	-16	-12
Issuances of shares	1,626	0
Cash dividends	-962	-425
Repurchases of shares and warrants	0	-149
Contributions from noncontrolling interests	0	684
Distributions to noncontrolling interests	-10	-479
Other, net	-1	0
Net Cash Provided by Financing Activities	1,468	626
Effect of Exchange Rate Changes on Cash and Cash Equivalents	-5	-10
Net decrease in Cash and Cash Equivalents	-56	-85
Cash and Cash Equivalents, beginning of period	315	598
Cash and Cash Equivalents, end of period	259	513
Non-cash Investing and Financing Activities
Assets acquired by the assumption or incurrence of liabilities	1,606	0
Net assets contributed to equity investment	27	0
Supplemental Disclosures of Cash Flow Information
Cash paid during the period for interest (net of capitalized interest)	592	566
Cash refunded during the period for income taxes, net	($196)	($2)

CONSOLIDATED_STATEMENTS_OF_STO

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Unaudited) Statement (USD $)	Total	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	KMI [Member]	Noncontrolling Interest [Member]	KMP, EPB and KMR [Member]	KMP, EPB and KMR [Member]	KMP, EPB and KMR [Member]	KMP, EPB and KMR [Member]	EP Trust I Preferred [Member]	EP Trust I Preferred [Member]	EP Trust I Preferred [Member]	Class P [Member]	Class P [Member]	Class P [Member]	Class P [Member]	Class P [Member]
In Millions, except Share data, unless otherwise specified	USD ($)	USD ($)	USD ($)	USD ($)	USD ($)	USD ($)	USD ($)	Additional Paid-in Capital [Member]	KMI [Member]	Noncontrolling Interest [Member]	USD ($)	Additional Paid-in Capital [Member]	KMI [Member]		Common Stock [Member]	Additional Paid-in Capital [Member]	KMI [Member]	EP Trust I Preferred [Member]
								USD ($)	USD ($)	USD ($)		USD ($)	USD ($)		USD ($)	USD ($)	USD ($)
Noncontrolling interests at Dec. 31, 2013						$15,192
Total Stockholders' Equity at Dec. 31, 2013	28,285
Stockholders' Equity Attributable to KMI at Dec. 31, 2013		14,479	-1,372	-24	13,093										10
Shares, Outstanding at Dec. 31, 2013														1,031,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Repurchased and Retired During Period, Shares														3,000,000
Stock Repurchased During Period, Value	-94	-94			-94
Minority Interest Increase From Contributions From Noncontrolling Interest	684				0	684
Adjustments to Paid In Capital, Warrants Repurchased	-55	-55			-55
Amortization of restricted shares	14	14			14
Impact of subsidiary equity transactions							-8	13	13	-21
Net income attributable to KMI	287		287		287
Net Income Attributable to Noncontrolling Interests	-314					314
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	601
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	-479				0	-479
Dividends, Common Stock, Cash	-425		-425		-425
Stockholders' Equity, Other	5	5			5
Other comprehensive income (loss), net of tax, portion attributable to KMI				-38	-38
Other comprehensive income (loss), net of tax, portion attributable to noncontrolling interests						-56
Total other comprehensive loss	-94
Total Stockholders' Equity at Mar. 31, 2014	28,434
Noncontrolling interests at Mar. 31, 2014						15,634
Stockholders' Equity Attributable to KMI at Mar. 31, 2014		14,362	-1,510	-62	12,800										10
Shares, Outstanding at Mar. 31, 2014														1,028,000,000
Noncontrolling interests at Dec. 31, 2014	350					350
Total Stockholders' Equity at Dec. 31, 2014	34,426
Stockholders' Equity Attributable to KMI at Dec. 31, 2014	34,076	36,178	-2,106	-17	34,076										21
Shares, Outstanding at Dec. 31, 2014														2,125,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock Issued During Period, Shares, New Issues														39,000,000
Stock Issued During Period, Value, New Issues	1,626														1	1,625	1,626
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period																		1,000,000
Conversions of EP Trust I Preferred securities											19	19	19
Adjustments to Paid in Capital, Warrants Exercised	1	1			1
Amortization of restricted shares	16	16			16
Net income attributable to KMI	429		429		429
Net Income Attributable to Noncontrolling Interests	10					-10
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	419
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders	-10				0	-10
Dividends, Common Stock, Cash	-962		-962		-962
Other comprehensive income (loss), net of tax, portion attributable to KMI				-176	-176
Total other comprehensive loss	-176
Total Stockholders' Equity at Mar. 31, 2015	35,359
Noncontrolling interests at Mar. 31, 2015	330					330
Stockholders' Equity Attributable to KMI at Mar. 31, 2015	$35,029	$37,839	($2,639)	($193)	$35,029										$22
Shares, Outstanding at Mar. 31, 2015														2,165,000,000

General_Notes

General (Notes)	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	General
	Organization
	We are the largest energy infrastructure and the third largest energy company in North America with an enterprise value of more than $130 billion. We own an interest in or operate approximately 84,000 miles of pipelines and 180 terminals. Our pipelines transport natural gas, refined petroleum products, crude oil, condensate, CO2 and other products, and our terminals transload and store petroleum products, ethanol and chemicals, and handle such products as coal, petroleum coke and steel. We are also the leading producer and transporter of CO2, which is utilized for enhanced oil recovery projects in North America.
	On November 26, 2014, we completed our acquisition, pursuant to three separate merger agreements, of all of the outstanding common units of Kinder Morgan Energy Partners, L.P. and El Paso Pipeline Partners, L.P. and all of the outstanding shares of Kinder Morgan Management, LLC that we did not already own. The transactions, valued at approximately $77 billion, are referred to collectively as the “Merger Transactions.” On January 1, 2015, EPB and its subsidiary, EPPOC merged with and into KMP. References to EPB refer to EPB for periods prior to its merger into KMP.
	Prior to November 26, 2014, we owned an approximate 10% limited partner interest (including our interest in KMR) and the 2% general partner interest including incentive distribution rights in KMP, and an approximate 39% limited partner interest and the 2% general partner interest and incentive distribution rights in EPB. Effective with the Merger Transactions, the incentive distribution rights held by the general partner of KMP were eliminated.
	The earnings recorded by KMP, EPB and KMR that are attributed to their units and shares, respectively, held by the public prior to November 26, 2014 are reported as “Net loss (income) attributable to noncontrolling interests” in our accompanying consolidated statements of income.
	Basis of Presentation
	General
	Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars, except where stated otherwise. Our accompanying unaudited consolidated financial statements have been prepared under the rules and regulations of the United States Securities and Exchange Commission (SEC). These rules and regulations conform to the accounting principles contained in the FASB’s Accounting Standards Codification, the single source of GAAP. Under such rules and regulations, all significant intercompany items have been eliminated in consolidation. Additionally, certain amounts from prior years have been reclassified to conform to the current presentation.
	Interim results are not necessarily indicative of results for a full year; accordingly, you should read these consolidated financial statements in conjunction with our consolidated financial statements and related notes included in our 2014 Form 10-K.
	Impairments
	Due to the continued low commodity price environment and certain actions of our customers during the first quarter of 2015, we recorded a non-cash pre-tax impairment charge of $77 million related to certain of our gas gathering and processing assets in our Natural Gas Pipelines segment. The impairment comprised $51 million of long-lived assets and $26 million related to our investments in Fort Union Gas Gathering L.L.C. and Bighorn Gas Gathering L.L.C.
	As conditions warrant, management routinely evaluates its assets for potential triggering events that could impact the fair value of certain assets or our ability to recover the carrying value of long-lived assets. Such assets include accounts receivable, property plant and equipment, including oil and gas properties and in-process construction, equity investments, goodwill and other intangibles. Depending on the nature of the asset, these evaluations require the use of significant judgments including but not limited to customer credit worthiness, future cash flow estimates, future volume expectations, current and future commodity prices, as well as general economic conditions and the related demand for products handled or transported by our assets. In the current commodity price environment and to the extent conditions further deteriorate, we may identify additional triggering events that may necessitate further impairments to the carrying value of our assets. Such non-cash impairments could have a significant effect on our results of operations.
	Earnings per Share
	We calculate earnings per share using the two-class method. Earnings were allocated to Class P shares of common stock and participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions over earnings. Our unvested restricted stock awards do not participate in excess distributions over earnings.
	The following tables set forth the allocation of net income available to shareholders for Class P shares and for participating securities and the reconciliation of Basic Weighted-Average Number of Shares Outstanding to Diluted Weighted-Average Number of Shares Outstanding (in millions):
		Three Months Ended March 31,
		2015			2014
	Class P	$	426		$	284
	Participating securities(a)	3			3
	Net Income Attributable to Kinder Morgan, Inc.	$	429		$	287
		Three Months Ended March 31,
		2015		2014
	Basic Weighted-Average Number of Shares Outstanding	2,141		1,029
	Effect of dilutive securities:
	Warrants(b)	10		—
	Diluted Weighted-Average Number of Shares Outstanding	2,151		1,029
	________
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
	(b)	Each of our warrants entitles the holder to purchase one share of our common stock for an exercise price of $40 per share, payable in cash or by cashless exercise, at any time until May 25, 2017.
	The following potential common stock equivalents are antidilutive and, accordingly, are excluded from the determination of diluted earnings per share (in millions on a weighted-average basis):
		Three Months Ended March 31,
		2015		2014
	Unvested restricted stock awards	7		7
	Warrants to purchase our Class P shares	289		341
	Convertible trust preferred securities	9		10
	_______

Acquisitions_Notes

Acquisitions (Notes)	3 Months Ended
	Mar. 31, 2015
Acquisitions and Divestitures [Abstract]
Acquisitions	Acquisitions
	Hiland Partners, LP
	On February 13, 2015, we acquired Hiland Partners, LP, a privately held Delaware limited partnership (Hiland) for an aggregate consideration of $3,120 million, including assumed debt and other assumed liabilities. Approximately $368 million of the debt assumed was immediately paid down after closing. Hiland’s assets consist primarily of crude oil gathering and transportation pipelines and gas gathering and processing systems, primarily serving production from the Bakken Formation in North Dakota and Montana. The acquired gathering and processing assets are included in our Natural Gas Pipelines business segment while the acquired crude transport pipeline is included in our Products Pipelines business segment.
	Vopak Terminal Assets
	On February 27, 2015, we acquired three U.S. terminals and one undeveloped site from Royal Vopak (Vopak) for approximately $158 million. The acquisition covers (i) a 36-acre, 1,069,500-barrel storage facility at Galena Park, Texas that handles base oils, biodiesel and crude oil and is immediately adjacent to our Galena Park terminal facility; (ii) two terminals in North Carolina: one in North Wilmington that handles chemicals and black oil and the other in South Wilmington that is not currently operating; and (iii) an undeveloped site in Perth Amboy, New Jersey, with waterfront access that can be developed. We include the acquired assets as part of the Terminals business segment.
	Our preliminary allocation of the purchase price for each of our significant acquisitions during the three months ended March 31, 2015 (in millions) is detailed below. The evaluation of the assigned fair values is ongoing and subject to adjustment.
		Acquisitions
		Hiland			Vopak Terminal Assets
	Purchase Price Allocation:
	Current assets	$	44		$	3
	Property, plant and equipment	1,521			131
	Goodwill	238			29
	Other intangibles(a)	1,507			—
	Total assets acquired	3,310			163
	Current liabilities	(187		)	(2		)
	Debt	(1,411		)	—
	Other liabilities	(3		)	(3		)
	Cash consideration	$	1,709		$	158
	_______
	(a)	Relates to customer contracts and relationships with a weighted average amortization period of 16.4 years.
	After measuring all of the identifiable tangible and intangible assets acquired and liabilities assumed at fair value on the acquisition date, goodwill is an intangible asset representing the future economic benefits expected to be derived from an acquisition that are not assigned to other identifiable, separately recognizable assets.  We believe the primary items that generated our goodwill are both the value of the synergies created between the acquired assets and our pre-existing assets, and our expected ability to grow the business we acquired by leveraging our pre-existing business experience. We expect our recorded goodwill associated with the above acquisitions to be deductible for tax purposes.

Debt_Debt_Disclosure_Notes

Debt Debt Disclosure (Notes)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Debt Disclosure [Text Block]	Debt
	We classify our debt based on the contractual maturity dates of the underlying debt instruments.  We defer costs associated with debt issuance over the applicable term. These costs are then amortized as interest expense in our accompanying consolidated statements of income. The following table provides detail on the principal amount of our outstanding debt balances. The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions):
			March 31, 2015		31-Dec-14
	KMI and Subsidiaries
	Senior notes, 1.50% through 8.25%, due 2015 through 2098(a)		$	13,330	$	11,438
	Credit facility due November 26, 2019(b)		600		850
	Commercial paper borrowings(b)		296		386
	KMP
	Senior notes, 2.65% through 9.00%, due 2015 through 2044(c)		20,360		20,660
	TGP senior notes, 7.00% through 8.375%, due 2016 through 2037		1,790		1,790
	EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032		1,115		1,115
	Copano senior notes, 7.125%, due April 1, 2021		332		332
	CIG senior notes, 5.95% through 6.85%, due 2015 through 2037		440		475
	SNG notes, 4.40% through 8.00%, due 2017 through 2032		1,211		1,211
	Other Subsidiary Borrowings (as obligor)
	Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036		1,636		1,636
	Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022(d)		975		—
	EPC Building, LLC, promissory note, 3.967%, due 2015 through 2035		450		453
	Preferred securities, 4.75%, due March 31, 2028		232		280
	KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock		100		100
	Other miscellaneous debt		301		303
	Total debt – KMI and Subsidiaries		43,168		41,029
	Less: Current portion of debt(e)		3,435		2,717
	Total long-term debt – KMI and Subsidiaries(f)		$	39,733	$	38,312
	_______
	(a)	March 31, 2015 amount includes senior notes that are denominated in Euros and have been converted and are reported at the March 31, 2015 exchange rate of 1.0731 U.S. dollars per Euro. We also entered into cross-currency swap agreements associated with these senior notes (see Note 5).
	(b)	As of March 31, 2015 and December 31, 2014, the weighted average interest rates on our credit facility borrowings, including commercial paper borrowings, were 1.56% and 1.54%, respectively.
	(c)	On January 1, 2015, EPB and EPPOC merged with and into KMP. On that date, KMP succeeded EPPOC as the issuer of approximately $2.9 billion of EPPOC’s senior notes, which were guaranteed by EPB, and EPB and EPPOC ceased to be obligors for those senior notes.
	(d)	Represents the principal amount of senior notes assumed in the Hiland acquisition.
	(e)	Amounts include outstanding credit facility and commercial paper borrowings.
	(f)	As of March 31, 2015 and December 31, 2014, our “Debt fair value adjustments” increased our combined debt balances by $2,091 million and $1,934 million, respectively. In addition to all unamortized debt discount/premium amounts and purchase accounting on our debt balances, our debt fair value adjustments also include (i) amounts associated with the offsetting entry for hedged debt; and (ii) any unamortized portion of proceeds received from the early termination of interest rate swap agreements.
	Credit Facilities
	As of March 31, 2015, we had $600 million outstanding under our five-year $4.0 billion revolving credit facility, $296 million outstanding under our $4.0 billion commercial paper program and $128 million in letters of credit. Our availability under this facility as of March 31, 2015 was $2,976 million. Borrowings under our revolving credit facility can be used for working capital and other general corporate purposes and as a backup to our commercial paper program. Similarly, borrowings under our commercial paper program reduce the borrowings allowed under our credit facility.
	On February 13, 2015, in connection with the Hiland acquisition, we entered into and made borrowings of $1,641 million under a new six-month bridge credit facility with UBS AG, Stamford Branch. Interest under this bridge credit facility was charged at the same rate as our $4.0 billion revolving credit facility. Prior to March 31, 2015, we repaid outstanding borrowings and the facility was terminated on April 6, 2015.
	Hiland Debt Acquired
	As of the February 13, 2015 Hiland acquisition date, we assumed (i) $975 million in principal amount of senior notes (which were valued at $1,043 million as of the acquisition date) and (ii) $368 million of other borrowings that were immediately repaid after closing, primarily consisting of borrowings outstanding under a revolving credit facility. The senior notes are subject to our cross guarantee agreement discussed in Note 12.
	Long-term Debt Issuances and Repayments
	Apart from the assumption of the Hiland debt discussed above, following are significant long-term debt issuances and repayments made during the three months ended March 31, 2015:
	Issuances		$800 million 5.05% notes due 2046
			$815 million 1.50% notes due 2022(a)
			$543 million 2.25% notes due 2027(a)
	Repayments		$300 million 5.625% notes due 2015
			$250 million 5.15% notes due 2015
	_______
	(a)	Senior notes are denominated in Euros and are presented above in U.S. dollars at the exchange rate on the issuance date of 1.086 U.S. dollars per Euro. We also entered into cross-currency swap agreements associated with these senior notes (see Note 5).

Stockholders_Equity_Notes

Stockholders' Equity (Notes)	3 Months Ended
	Mar. 31, 2015
Stockholders' Equity Note [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Stockholders’ Equity
	Common Equity
	As of March 31, 2015, our common equity consisted of our Class P common stock. For additional information regarding our Class P common stock, see Note 10 to our consolidated financial statements included in our 2014 Form 10-K.
	On December 19, 2014, we entered into an equity distribution agreement authorizing us to issue and sell through or to the managers party thereto, as sales agents and/or principals, shares of our Class P common stock having an aggregate offering price of up to $5,000 million from time to time during the term of this agreement. During the three months ended March 31, 2015, we issued and sold 39,398,245 shares of our Class P common stock pursuant to the equity distribution agreement, and issued an additional 2,692,672 shares after March 31, 2015 to settle sales made on or before March 31, 2015, resulting in net proceeds of $1,738 million.
	Dividends
	Holders of our common stock share equally in any dividend declared by our board of directors, subject to the rights of the holders of any outstanding preferred stock. The following table provides information about our per share dividends:
		Three Months Ended March 31,
		2015		2014
	Per common share cash dividend declared for the period	$	0.48	$	0.42
	Per common share cash dividend paid in the period	$	0.45	$	0.41
	_______
	On April 15, 2015, our board of directors declared a cash dividend of $0.48 per share for the quarterly period ended March 31, 2015, which is payable on May 15, 2015 to shareholders of record as of April 30, 2015.

Risk_Management_Notes

Risk Management (Notes)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Risk Management	Risk Management
	Certain of our business activities expose us to risks associated with unfavorable changes in the market price of natural gas, NGL and crude oil.  We also have exposure to interest rate and foreign currency risk as a result of the issuance of our debt obligations.  Pursuant to our management’s approved risk management policy, we use derivative contracts to hedge or reduce our exposure to certain of these risks. In addition, we have legacy power forward and swap contracts for which we entered into offsetting positions that eliminate the price risks associated with these power contracts.
	As of December 31, 2014, we had discontinued hedge accounting on certain of our crude derivative contracts as we did not expect them to be highly effective, for accounting purposes, in offsetting the variability in cash flows. This was caused primarily by volatility in basis differentials. As the forecasted transactions are still probable, accumulated gains and losses remain in other comprehensive income until earnings are impacted by the forecasted transactions. Future changes in the derivative contracts’ fair value subsequent to the discontinuance of hedge accounting will be reported in earnings. We may re-designate certain of these hedging relationships if their expected effectiveness improves.
	Energy Commodity Price Risk Management
	As of March 31, 2015, we had entered into the following outstanding commodity forward contracts to hedge our forecasted energy commodity purchases and sales:
		Net open position long/(short)
	Derivatives designated as hedging contracts
	Crude oil fixed price	(12.8	)		MMBbl
	Crude oil basis	(12.1	)		MMBbl
	Natural gas fixed price	(50.7	)		Bcf
	Natural gas basis	(25.9	)		Bcf
	Derivatives not designated as hedging contracts
	Crude oil fixed price	(14.2	)		MMBbl
	Crude oil basis	(0.3	)		MMBbl
	Natural gas fixed price	(17.9	)		Bcf
	Natural gas basis	(16.5	)		Bcf
	NGL fixed price	(52.7	)		MMBbl
	_______
	As of March 31, 2015, the maximum length of time over which we have hedged, for accounting purposes, our exposure to the variability in future cash flows associated with energy commodity price risk is through December 2017. We have additional economic hedge contracts not designated as accounting hedges through December 2019.
	Interest Rate Risk Management
	As of March 31, 2015 and December 31, 2014, we had a combined notional principal amount of $9,700 million and $9,200 million, respectively, of fixed-to-variable interest rate swap agreements, effectively converting the interest expense associated with certain series of senior notes from fixed rates to variable rates based on an interest rate of London Interbank Offered Rate (LIBOR) plus a spread.  All of our swap agreements have termination dates that correspond to the maturity dates of the related series of senior notes and, as of March 31, 2015, the maximum length of time over which we have hedged a portion of our exposure to the variability in the value of this debt due to interest rate risk is through March 15, 2035.
	In March 2015, we entered into four separate fixed-to-variable interest rate swap agreements having a combined notional principal amount of $600 million. These agreements effectively convert a portion of the interest expense associated with our 5.625% senior notes due November 15, 2023, from a fixed rate to a variable rate based on an interest rate of LIBOR plus a spread.
	Foreign Currency Risk Management
	In connection with the issuance of our Euro denominated senior notes in March 2015 (see Note 3), we entered into cross-currency swap agreements to manage the related foreign currency risk by effectively converting all of the fixed-rate Euro denominated debt, including annual interest payments and the payment of principal at maturity, to U.S. dollar denominated debt at fixed rates equivalent to approximately 3.79% and 4.67% for the 7-year and 12-year senior notes, respectively. These cross-currency swaps are accounted for as cash flow hedges. The terms of the cross-currency swap agreements correspond to the related hedged senior notes, and such agreements have the same maturities as the hedged senior notes.
	Fair Value of Derivative Contracts
	The following table summarizes the fair values of our derivative contracts included in our accompanying consolidated balance sheets (in millions):
	Fair Value of Derivative Contracts
					Asset derivatives								Liability derivatives
					March 31,				December 31,				March 31,				December 31,
					2015				2014				2015				2014
			Balance sheet location		Fair value								Fair value
	Derivatives designated as hedging contracts
	Natural gas and crude derivative contracts		Fair value of derivative contracts/(Other current liabilities)		$	318			$	309			$	(63	)		$	(34	)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		44				6				(2		)		—
	Subtotal				362				315				(65		)		(34		)
	Interest rate swap agreements		Fair value of derivative contracts/(Other current liabilities)		171				143				—				—
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		329				260				(5		)		(53		)
	Subtotal				500				403				(5		)		(53		)
	Cross-currency swap agreements		Fair value of derivative contracts/(Other current liabilities)		—				—				(31		)		—
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		—				—				(23		)		—
	Subtotal				—				—				(54		)		—
	Total				862				718				(124		)		(87		)
	Derivatives not designated as hedging contracts
	Natural gas, crude and NGL derivative contracts		Fair value of derivative contracts/(Other current liabilities)		62				73				(1		)		(2		)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		174				196				(1		)		—
	Subtotal				236				269				(2		)		(2		)
	Power derivative contracts		Fair value of derivative contracts/(Other current liabilities)		10				10				(56		)		(57		)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		1				—				(4		)		(16		)
	Subtotal				11				10				(60		)		(73		)
	Total				247				279				(62		)		(75		)
	Total derivatives				$	1,109			$	997			$	(186	)		$	(162	)
	_______
	Effect of Derivative Contracts on the Income Statement
	The following tables summarize the impact of our derivative contracts on our accompanying consolidated statements of income (in millions):
	Derivatives in fair value hedging relationships		Location of gain/(loss) recognized in income on derivatives		Amount of gain/(loss) recognized in income
					on derivatives and related hedged item
					Three Months Ended March 31,
					2015				2014
	Interest rate swap agreements		Interest expense		$	145			$	55
	Hedged fixed rate debt		Interest expense		$	(139	)		$	(55	)
	Derivatives in cash flow hedging relationships		Amount of gain/(loss)								Location of gain/(loss) reclassified from Accumulated OCI into income (effective portion)		Amount of gain/(loss) reclassified from Accumulated OCI							Location of gain/(loss) recognized in income on	Amount of gain/(loss)
			recognized in OCI										into income (effective portion)(b)							derivative (ineffective portion and amount excluded from	recognized in income
			on derivative (effective portion)(a)																	effectiveness testing)	on derivative
																					(ineffective portion
															and amount
															excluded from
															effectiveness testing)
		Three Months Ended March 31,										Three Months Ended March 31,								Three Months Ended March 31,
		2015				2014						2015				2014				2015		2014
Energy commodity		$	35			$	(43	)		Revenues—Natural		$	24			$	(9	)	Revenues—Natural	$	—	$	—
derivative contracts										gas sales									gas sales
										Revenues—Product		64				(6		)	Revenues—Product	7		(5		)
										sales and other									sales and other
										Costs of sales		(5		)		1			Costs of sales	—		—
Interest rate swap		(3		)		(2		)		Interest expense		(1		)		—			Interest expense	—		—
agreements
Cross-currency swap		(34		)		—				Other, net		(10		)		—
Total		$	(2	)		$	(45	)		Total		$	72			$	(14	)	Total	$	7	$	(5	)
_______
(a)	We expect to reclassify an approximate $175 million gain associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balances as of March 31, 2015 into earnings during the next twelve months (when the associated forecasted sales and purchases are also expected to occur), however, actual amounts reclassified into earnings could vary materially as a result of changes in market prices.
(b)	Amounts reclassified were the result of the hedged forecasted transactions actually affecting earnings (i.e., when the forecasted sales and purchases actually occurred).
Derivatives not designated as accounting hedges		Location of gain/(loss) recognized in income on derivatives		Amount of gain/(loss) recognized in income on derivatives
				Three Months Ended March 31,
				2015				2014
Energy commodity derivative contracts		Revenues—Natural gas sales		$	4			$	(7	)
		Revenues—Product sales and other		45				(1		)
		Costs of sales		(3		)		10
		Other expense (income)		—				(2		)
Total(a)				$	46			$	—
_______
(a) As of March 31, 2015, includes an approximate $5 million loss associated with natural gas, crude and NGL derivative contract settlements.
Credit Risks
In conjunction with the purchase of exchange-traded derivative contracts or when the market value of our derivative contracts with specific counterparties exceeds established limits, we are required to provide collateral to our counterparties, which may include posting letters of credit or placing cash in margin accounts.  As of both March 31, 2015 and December 31, 2014, we had $20 million of outstanding letters of credit supporting our commodity price risk management program in addition to $44 million and $47 million, respectively, of cash margin on deposit posted as collateral.
We also have agreements with certain counterparties to our derivative contracts that contain provisions requiring the posting of additional collateral upon a decrease in our credit rating.  As of March 31, 2015, we estimate that if our credit rating was downgraded one notch, we would be required to post $1 million of additional collateral to our counterparties. If we were downgraded two notches, we would be required to post no additional collateral from the one notch downgrade.
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income
Cumulative revenues, expenses, gains and losses that under GAAP are included within our comprehensive income but excluded from our earnings are reported as “Accumulated other comprehensive loss” within “Stockholders’ Equity” in our consolidated balance sheets. Changes in the components of our “Accumulated other comprehensive loss” not including non-controlling interests are summarized as follows (in millions):
	Net unrealized				Foreign				Pension and				Total
	gains/(losses)				currency				other				accumulated other
	on cash flow				translation				postretirement				comprehensive income/(loss)
	hedge derivatives				adjustments				liability adjustments
Balance as of December 31, 2014	$	327			$	(108	)		$	(236	)		$	(17	)
Other comprehensive loss before reclassifications	(2		)		(108		)		6				(104		)
Amounts reclassified from accumulated other comprehensive loss	(72		)		—				—				(72		)
Net current-period other comprehensive loss	(74		)		(108		)		6				(176		)
Balance as of March 31, 2015	$	253			$	(216	)		$	(230	)		$	(193	)
	Net unrealized				Foreign				Pension and				Total
	gains/(losses)				currency				other				accumulated other
	on cash flow				translation				postretirement				comprehensive loss
	hedge derivatives				adjustments				liability adjustments
Balance as of December 31, 2013	$	(3	)		$	2			$	(23	)		$	(24	)
Other comprehensive loss before reclassifications	(19		)		(25		)		—				(44		)
Amounts reclassified from accumulated other comprehensive loss	6				—				—				6
Net current-period other comprehensive loss	(13		)		(25		)		—				(38		)
Balance as of March 31, 2014	$	(16	)		$	(23	)		$	(23	)		$	(62	)

Fair_Value_Notes

Fair Value (Notes)	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value	Fair Value
	The fair values of our financial instruments are separated into three broad levels (Levels 1, 2 and 3) based on our assessment of the availability of observable market data and the significance of non-observable data used to determine fair value. Each fair value measurement must be assigned to a level corresponding to the lowest level input that is significant to the fair value measurement in its entirety.
	The three broad levels of inputs defined by the fair value hierarchy are as follows:
	•	Level 1 Inputs—quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date;
	•	Level 2 Inputs—inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. If the asset or liability has a specified (contractual) term, a Level 2 input must be observable for substantially the full term of the asset or liability; and
	•	Level 3 Inputs—unobservable inputs for the asset or liability. These unobservable inputs reflect the entity’s own assumptions about the assumptions that market participants would use in pricing the asset or liability, and are developed based on the best information available in the circumstances (which might include the reporting entity’s own data).
	Fair Value of Derivative Contracts
	The following two tables summarize the fair value measurements of our (i) energy commodity derivative contracts; (ii) interest rate swap agreements; and (iii) cross-currency swap agreements, based on the three levels established by the Codification (in millions). The tables also identify the impact of derivative contracts which we have elected to present on our accompanying consolidated balance sheets on a gross basis that are eligible for netting under master netting agreements.
		Balance sheet asset																		Net amount
		fair value measurements by level
		Level 1			Level 2			Level 3			Gross amount			Contracts available for netting			Cash collateral held(b)
	As of March 31, 2015
	Energy commodity derivative contracts(a)	$	39		$	559		$	11		$	609		$	(70	)	$	—		$	539
	Interest rate swap agreements	$	—		$	500		$	—		$	500		$	(3	)	$	—		$	497
	As of December 31, 2014
	Energy commodity derivative contracts(a)	$	49		$	533		$	12		$	594		$	(46	)	$	(13	)	$	535
	Interest rate swap agreements	$	—		$	403		$	—		$	403		$	(44	)	$	—		$	359
		Balance sheet liability																		Net amount
		fair value measurements by level
		Level 1			Level 2			Level 3			Gross amount			Contracts available for netting			Collateral posted(c)
	As of March 31, 2015
	Energy commodity derivative contracts(a)	$	(26	)	$	(41	)	$	(60	)	$	(127	)	$	70		$	44		$	(13	)
	Interest rate swap agreements	$	—		$	(5	)	$	—		$	(5	)	$	3		$	—		$	(2	)
	Cross-currency swap agreements	$	—		$	(54	)	$	—		$	(54	)	$	—		$	—		$	(54	)
	As of December 31, 2014
	Energy commodity derivative contracts(a)	$	(25	)	$	(11	)	$	(73	)	$	(109	)	$	46		$	47		$	(16	)
	Interest rate swap agreements	$	—		$	(53	)	$	—		$	(53	)	$	44		$	—		$	(9	)
	_______
	(a)	Level 1 consists primarily of New York Mercantile Exchange (NYMEX) natural gas futures.  Level 2 consists primarily of OTC West Texas Intermediate (WTI) swaps and options.  Level 3 consists primarily of power derivative contracts.
	(b)	Cash margin deposits held by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current liabilities” on our accompanying consolidated balance sheets.
	(c)	Cash margin deposits posted by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current assets” on our accompanying consolidated balance sheets.
	The table below provides a summary of changes in the fair value of our Level 3 energy commodity derivative contracts (in millions):
	Significant unobservable inputs (Level 3)
		Three Months Ended March 31,
		2015			2014
	Derivatives-net asset (liability)
	Beginning of Period	$	(61	)	$	(110	)
	Total gains or (losses)
	Included in earnings	—			7
	Included in other comprehensive loss	—			(1		)
	Settlements	12			4
	End of Period	$	(49	)	$	(100	)
	The amount of total gains or (losses) for the period included in earnings attributable to the change in unrealized gains or (losses) relating to assets held at the reporting date	$	1		$	3
	_______
	As of March 31, 2015, our Level 3 derivative assets and liabilities consisted primarily of power derivative contracts, where a significant portion of fair value is calculated from underlying market data that is not readily observable. The derived values use industry standard methodologies that may consider the historical relationships among various commodities, modeled market prices, time value, volatility factors and other relevant economic measures. The use of these inputs results in management’s best estimate of fair value.
	Fair Value of Financial Instruments
	The estimated fair value of our outstanding debt balances (the carrying amounts below include both short-term and long-term and debt fair value adjustments), is disclosed below (in millions):
		March 31, 2015						December 31, 2014
		Carrying			Estimated			Carrying			Estimated
		value			fair value			value			fair value
	Total debt	$	45,259		$	46,480		$	42,963		$	43,582
	_______
	We used Level 2 input values to measure the estimated fair value of our outstanding debt balances as of both March 31, 2015 and December 31, 2014.

Reportable_Segments_Notes

Reportable Segments (Notes)	3 Months Ended
	Mar. 31, 2015
Segment Reporting [Abstract]
Reportable Segments	Reportable Segments
	Financial information by segment follows (in millions):
		Three Months Ended March 31,
		2015			2014
	Revenues
	Natural Gas Pipelines
	Revenues from external customers	$	2,177		$	2,557
	Intersegment revenues	3			4
	CO2	446			483
	Terminals	457			391
	Products Pipelines	444			534
	Kinder Morgan Canada	60			69
	Other	4			4
	Total segment revenues	3,591			4,042
	Other revenues	9			9
	Less: Total intersegment revenues	(3		)	(4		)
	Total consolidated revenues	$	3,597		$	4,047
		Three Months Ended March 30,
		2015			2014
	Segment Earnings Before DD&A(a)
	Natural Gas Pipelines	$	1,015		$	1,070
	CO2	336			363
	Terminals	270			210
	Products Pipelines	246			208
	Kinder Morgan Canada	41			48
	Other	(6		)	7
	Total segment earnings before DD&A	1,902			1,906
	DD&A expense	(538		)	(496		)
	Amortization of excess cost of investments	(12		)	(10		)
	Other revenues	9			9
	General and administrative expense	(216		)	(172		)
	Interest expense, net of unallocable interest income	(514		)	(450		)
	Unallocable income tax expense	(212		)	(186		)
	Total consolidated net income	$	419		$	601
		March 31,			December 31,
		2015			2014
	Assets
	Natural Gas Pipelines	$	54,539		$	52,523
	CO2	5,318			5,227
	Terminals	9,071			8,850
	Products Pipelines	8,364			7,179
	Kinder Morgan Canada	1,480			1,593
	Other	443			459
	Total segment assets	79,215			75,831
	Corporate assets(b)	6,920			7,311
	Assets held for sale	29			56
	Total consolidated assets	$	86,164		$	83,198
	_______
	(a)	We evaluate performance based on each segment’s earnings before DD&A. Amounts include revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income), net, and losses on impairments of long-lived assets and equity investments. Operating expenses include natural gas purchases and other costs of sales, operations and maintenance expenses, and taxes, other than income taxes.
	(b)	Includes cash and cash equivalents, margin and restricted deposits, unallocable interest receivable, prepaid assets and deferred charges, risk management assets related to debt fair value adjustments and miscellaneous corporate assets (such as information technology and telecommunications equipment) not allocated to individual segments.

Pension_and_Other_Postretireme

Pension and Other Postretirement Benefit Plans (Notes)	3 Months Ended
	Mar. 31, 2015
Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]
Pension and Other Postretirement Benefits Disclosure [Text Block]	Pension and Other Postretirement Benefit Plans
	The components of net benefit plan (credit) expense for our pension and other postretirement benefit (OPEB) plans are as follows (in millions):
		Pension Benefits						OPEB
		Three Months Ended March 31,						Three Months Ended March 31,
		2015			2014			2015			2014
	Service cost	$	6		$	7		$	—		$	—
	Interest cost	24			27			6			7
	Expected return on assets	(43		)	(43		)	(6		)	(6		)
	Amortization of prior service credits	—			—			(1		)	(1		)
	Amortization of net actuarial loss	1			—			—			—
	Net benefit plan credit	$	(12	)	$	(9	)	$	(1	)	$	—

Income_Taxes_Notes

Income Taxes (Notes)	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes
	Income tax expense included in our accompanying consolidated statements of income were as follows (in millions, except percentages):
		Three Months Ended March 31,
		2015			2014
	Income tax expense	$	224		$	200
	Effective tax rate	34.8		%	25		%
	Income tax expense for the three months ended March 31, 2015 is approximately $224 million resulting in an effective tax rate of 34.8%, as compared with $200 million income tax expense and an effective tax rate of 25.0%, for the same period of 2014. The effective tax rate for the three months ended March 31, 2015 is slightly lower than the statutory federal rate of 35% primarily due to (i) dividend-received deductions from our 50% interest in Florida Gas Transmission Company, L.L.C. (Florida Gas) (through our investment in Citrus Corporation) and Plantation Pipe Line Company and (ii) a change in our effective tax rate as a result of the Hiland acquisition, partially offset by state income taxes.
	The effective tax rate for the three months ended March 31, 2014 is lower than the statutory federal rate of 35% primarily due to (i) the net effect of consolidating KMP and EPB’s income tax provisions; and (ii) dividend-received deductions from our 50% investment in Florida Gas (through our investment in Citrus Corporation). These decreases are partially offset by (i) state income taxes; (ii) a decrease in our share of non-tax deductible goodwill associated with our investments in KMP; (iii) adjustments to our income tax reserve for uncertain tax positions; and (iv) the amortization of the deferred charge recorded as a result of the August 2012 and March 2013 drop-down transactions to KMP.

Litigation_Environmental_and_O

Litigation, Environmental and Other Contingencies (Notes)	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Litigation, Environmental and Other Contingencies	Litigation, Environmental and Other Contingencies
	We and our subsidiaries are parties to various legal, regulatory and other matters arising from the day-to-day operations of our businesses that may result in claims against the Company. Although no assurance can be given, we believe, based on our experiences to date and taking into account established reserves, that the ultimate resolution of such items will not have a material adverse impact on our business, financial position, results of operations or dividends to our shareholders. We believe we have meritorious defenses to the matters to which we are a party and intend to vigorously defend the Company. When we determine a loss is probable of occurring and is reasonably estimable, we accrue an undiscounted liability for such contingencies based on our best estimate using information available at that time. If the estimated loss is a range of potential outcomes and there is no better estimate within the range, we accrue the amount at the low end of the range. We disclose contingencies where an adverse outcome may be material, or in the judgment of management, we conclude the matter should otherwise be disclosed.
	Federal Energy Regulatory Commission Proceedings
	SFPP
	The tariffs and rates charged by SFPP are subject to a number of ongoing proceedings at the FERC, including the complaints and protests of various shippers. In general, these complaints and protests allege the rates and tariffs charged by SFPP are not just and reasonable under the Interstate Commerce Act (ICA). In late June of 2014, certain shippers filed additional complaints with the FERC (docketed at OR14-35 and OR14-36) challenging SFPP’s adjustments to its rates in 2012 and 2013 for inflation under the FERC’s indexing regulations. If the shippers are successful in proving these claims or other of their claims, they are entitled to seek reparations (which may reach back up to two years prior to the filing of their complaints) or refunds of any excess rates paid, and SFPP may be required to reduce its rates going forward. These proceedings tend to be protracted, with decisions of the FERC often appealed to the federal courts. The issues involved in these proceedings include, among others, whether indexed rate increases are justified, and the appropriate level of return and income tax allowance we may include in our rates. With respect to all of the SFPP proceedings at the FERC, we estimate that the shippers are seeking approximately $20 million in annual rate reductions and approximately $110 million in refunds. However, applying the principles of several recent FERC decisions in SFPP cases, as applicable, to pending cases would result in substantially lower rate reductions and refunds than those sought by the shippers. We do not expect refunds in these cases to have an impact on our dividends to our shareholders.
	EPNG
	The tariffs and rates charged by EPNG are subject to two ongoing FERC proceedings (the “2008 rate case” and the “2010 rate case”). With respect to the 2008 rate case, the FERC issued its decision (Opinion 517) in May 2012. EPNG implemented certain aspects of that decision and believes it has an appropriate reserve related to the findings in Opinion 517. EPNG has sought rehearing on Opinion 517. With respect to the 2010 rate case, the FERC issued its decision (Opinion 528) on October 17, 2013. EPNG sought rehearing on certain issues in Opinion 528. As required by Opinion 528, EPNG filed revised pro forma recalculated rates consistent with the terms of Opinion 528. The FERC also required an Administrative Law Judge (ALJ) to conduct an additional hearing concerning one of the issues in Opinion 528. On September 17, 2014, the ALJ issued an initial decision finding certain shippers qualify for lower rates under a prior settlement. EPNG has sought FERC review of the ALJ decision and believes it has an appropriate reserve related to the findings in Opinion 528.
	California Public Utilities Commission Proceedings
	We have previously reported ratemaking and complaint proceedings against SFPP pending with the CPUC. The ratemaking and complaint cases generally involve challenges to rates charged by SFPP for intrastate transportation of refined petroleum products through its pipeline system in the state of California and request prospective rate adjustments and refunds with respect to tariffed and previously untariffed charges for certain pipeline transportation and related services.
	On October 3, 2014, SFPP and its shippers executed a global settlement resolving all pending CPUC proceedings and submitted the proposed settlement to the CPUC for its consideration and approval. The settlement included refunds in the amount of $319 million which was consistent with our established reserve amounts. It also included a three year moratorium on new rate filings or complaints and established current rates consistent with the revenues recognized by SFPP in 2014. On December 18, 2014, the CPUC issued its Decision No. 14-12-057 approving and adopting the global settlement, thereby resolving and closing all previously pending SFPP rate proceedings. On December 29, 2014, SFPP certified to the CPUC that it made all required settlement payments. On March 16, 2015, the CPUC issued its decision eliminating its previously imposed CPUC requirement that SFPP maintain a letter of credit in the amount of $100 million to secure SFPP’s payment obligation for refunds related to the now-resolved CPUC rate proceedings.
	Other Commercial Matters
	Union Pacific Railroad Company Easements & Related Litigation
	SFPP and Union Pacific Railroad Company (UPRR) are engaged in a proceeding to determine the extent, if any, to which the rent payable by SFPP for the use of pipeline easements on rights-of-way held by UPRR should be adjusted pursuant to existing contractual arrangements for the ten-year period beginning January 1, 2004 (Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al., Superior Court of the State of California for the County of Los Angeles, filed July 28, 2004). In September 2011, the trial judge determined that the annual rent payable as of January 1, 2004 was $14 million, subject to annual consumer price index increases. Judgment was entered by the Superior Court on May 29, 2012 and SFPP appealed the judgment.
	On November 5, 2014, the Court of Appeals issued an opinion which reversed the judgment, including the award of prejudgment interest, and remanded the matter to the trial court for a determination of UPRR’s property interest in its right-of-way, including whether UPRR has sufficient interest to grant SFPP’s easements. UPRR filed a petition for rehearing with the Court of Appeals, which was denied on December 5, 2014. UPRR filed a petition for review to the California Supreme Court, which was denied on January 21, 2015.
	By notice dated October 25, 2013, UPRR demanded the payment of $22.3 million in rent for the first year of the next ten-year period beginning January 1, 2014. SFPP rejected the demand and the parties are pursuing the dispute resolution procedure in their contract to determine the rental adjustment, if any, for such period.
	On April 23, 2015, a purported class action suit was filed in the U.S. District Court for the Northern District of California (Case No. 01842) by private landowners in California who claim to be the lawful owners of subsurface real property allegedly used or occupied by UPRR or SFPP. The suit, which is brought purportedly as a class action on behalf of all landowners who own land in fee adjacent to and underlying the railroad easement under which the SFPP pipeline is located within the State of California, asserts claims against UPRR, SFPP, KMGP, and Kinder Morgan Operating L.P. “D” for declaratory judgment, trespass, ejectment, quiet title, unjust enrichment, accounting, and alleged unlawful business acts and practices under California law arising from defendants’ alleged improper use or occupation of subsurface real property.
	SFPP and UPRR are also engaged in multiple disputes over the circumstances under which SFPP must pay for a relocation of its pipeline within the UPRR right-of-way and the safety standards that govern relocations. In July 2006, a trial before a judge regarding the circumstances under which SFPP must pay for relocations concluded, and the judge determined that SFPP must pay for any relocations resulting from any legitimate business purpose of the UPRR. SFPP appealed this decision, and in December 2008, the appellate court affirmed the decision. In addition, UPRR contends that SFPP must comply with the more expensive American Railway Engineering and Maintenance-of-Way Association (AREMA) standards in determining when relocations are necessary and in completing relocations. Each party is seeking declaratory relief with respect to its positions regarding the application of these standards with respect to relocations. A trial occurred in the fourth quarter of 2011, with a verdict having been reached that SFPP was obligated to comply with AREMA standards in connection with a railroad project in Beaumont Hills, California. On June 13, 2014, the trial court issued a statement of decision addressing all of the causes of action and defenses and resolved those matters against SFPP, consistent with the jury’s verdict. The judgment was signed on July 15, 2014. SFPP filed a notice of appeal on October 30, 2014. If the judgment is affirmed on appeal, SFPP will be required to pay a judgment of $42.5 million plus any accrued post judgment interest.
	Since SFPP does not know UPRR’s plans for projects or other activities that would cause pipeline relocations, it is difficult to quantify the effects of the outcome of these cases on SFPP. Even if SFPP is successful in advancing its positions, significant relocations for which SFPP must nonetheless bear the cost (i.e., for railroad purposes, with the standards in the federal Pipeline Safety Act applying) could have an adverse effect on our financial position, results of operations, cash flows, and our dividends to our shareholders. These effects could be even greater in the event SFPP is unsuccessful in one or more of these lawsuits.
	We believe we have recorded a right-of-way liability sufficient to cover our potential liability for back rent.
	Plains Gas Solutions, LLC v. Tennessee Gas Pipeline Company, L.L.C. et al.
	On October 16, 2013, Plains Gas Solutions, LLC (Plains) filed a petition in the 151st Judicial District Court for Harris County, Texas (Case No. 62528) against TGP, Kinetica Partners, LLC and two other Kinetica entities. The suit arises from the sale by TGP of the Cameron System in Louisiana to Kinetica Partners, LLC on September 1, 2013. Plains alleges that defendants breached a straddle agreement requiring that gas on the Cameron System be committed to Plains’ Grand Chenier gas-processing facility, that requisite daily volume reports were not provided, that TGP improperly assigned its obligations under the straddle agreement to Kinetica, and that defendants interfered with Plains’ contracts with producers. The petition alleges damages of at least $100 million. Under the Amended and Restated Purchase and Sale Agreement with Kinetica, Kinetica is obligated to defend and indemnify TGP in connection with the gas commitment and reporting claims. After agreeing initially to defend and indemnify TGP against such claims, Kinetica withdrew its defense and disputed its indemnity obligation. We intend to vigorously defend the suit and pursue Kinetica, if necessary, for indemnity and costs of defense.
	Brinckerhoff v. El Paso Pipeline GP Company, LLC., et al.
	In December 2011 (Brinckerhoff I), March 2012, (Brinckerhoff II), May 2013 (Brinckerhoff III) and June 2014 (Brinckerhoff IV), derivative lawsuits were filed in Delaware Chancery Court against El Paso Corporation, El Paso Pipeline GP Company, L.L.C., the general partner of EPB, and the directors of the general partner at the time of the relevant transactions. EPB was named in these lawsuits as a “Nominal Defendant.” The lawsuits arise from the March 2010, November 2010, May 2012 and June 2011 drop-down transactions involving EPB’s purchase of SLNG, Elba Express, CPG and interests in SNG and CIG. The lawsuits allege various conflicts of interest and that the consideration paid by EPB was excessive. Brinckerhoff I and II were consolidated into one proceeding. Motions to dismiss were filed in Brinckerhoff III and Brinckerhoff IV, and such motions remain pending. On June 12, 2014, defendants’ motion for summary judgment was granted in Brinckerhoff I, dismissing the case in its entirety. Defendants’ motion for summary judgment in Brinckerhoff II was granted in part, dismissing certain claims and allowing the matter to go to trial in late 2014 on the remaining claims. On April 20, 2015, subsequent to the issuance of our 2015 first quarter earnings release furnished as Exhibit 99.1 on Form 8-K dated April 15, 2015 (2015 first quarter earnings release), the Court issued a post-trial memorandum opinion (Memorandum Opinion) in Brinckerhoff II entering judgment in favor of all of the defendants other than the general partner of EPB, but finding the general partner liable for breach of contract in connection with EPB’s purchase of 49% interests in Elba and SLNG and a 15% interest in SNG in a $1.13 billion drop-down transaction that closed on November 19, 2010 (Fall Dropdown), prior to our acquisition of El Paso Corporation in 2012. In its Memorandum Opinion, the Court determined that EPB suffered damages of $171 million from the Fall Dropdown, which the Court determined to be the amount which EPB overpaid for Elba. We are reviewing the decision and continue to believe that the transaction was appropriate and in the best interests of EPB. Furthermore, we believe the claim is derivative in nature and was extinguished by our acquisition on November 26, 2014, pursuant to a merger agreement, of all of the outstanding common units of EPB that we did not already own.  On December 2, 2014, we filed a motion to dismiss the remaining claims in Brinckerhoff II based upon our acquisition of all of the outstanding common units of EPB, which motion remains pending. On April 24, 2015, we filed post-trial motion for an order to establish a briefing schedule on our pending motion to dismiss and, if necessary, clarification of the Court’s Memorandum Opinion. On April 27, 2015, the Court denied our post-trial motion without prejudice, and established a briefing schedule to review the matters raised therein. As part of our review of the Court’s Memorandum Opinion, we are evaluating all options, including a possible appeal to the Delaware Supreme Court once a final decision is issued. At the present time, we do not believe that an ultimate award, if any, will have a material financial impact on our Company. We continue to believe these lawsuits are without merit and intend to defend against them vigorously.
	Allen v. El Paso Pipeline GP Company, L.L.C., et al.
	In May 2012, a unitholder of EPB filed a purported class action in Delaware Chancery Court, alleging both derivative and non-derivative claims, against EPB, and EPB’s general partner and its board. EPB was named in the lawsuit as both a “Class Defendant” and a “Derivative Nominal Defendant.” The complaint alleges a breach of the duty of good faith and fair dealing in connection with the March 2011 sale to EPB of a 25% ownership interest in SNG. On June 20, 2014, defendants’ motion for summary judgment was granted, dismissing the case in its entirety. On February 25, 2015, this ruling was affirmed by the Delaware Supreme Court, and the matter is now closed.
	Price Reporting Litigation
	Beginning in 2003, several lawsuits were filed by purchasers of natural gas against El Paso Corporation, El Paso Marketing L.P. and numerous other energy companies based on a claim under state antitrust law that such defendants conspired to manipulate the price of natural gas by providing false price information to industry trade publications that published gas indices. Several of the cases have been settled or dismissed. The remaining cases, which were pending in Nevada federal court, were dismissed, but the dismissal was reversed by the 9th Circuit Court of Appeals. The U.S. Supreme Court affirmed the 9th Circuit Court of Appeals in a decision dated April 21, 2015. The case will now be remanded to the Nevada federal court for its further consideration and trial, if necessary, of numerous remaining issues. Although damages in excess of $140 million have been alleged in total against all defendants in one of the remaining lawsuits where a damage number is provided, there remains significant uncertainty regarding the validity of the causes of action, the damages asserted and the level of damages, if any, that may be allocated to us. Therefore, our costs and legal exposure related to the remaining outstanding lawsuits and claims are not currently determinable.
	Kinder Morgan, Inc. Corporate Reorganization Litigation
	Certain unitholders of KMP and EPB filed five putative class action lawsuits in the Court of Chancery of the State of Delaware in connection with the Merger Transactions, which the Court consolidated under the caption In re Kinder Morgan, Inc. Corporate Reorganization Litigation (Consolidated Case No. 10093-VCL). The plaintiffs originally sought to enjoin one or more of the proposed Merger Transactions, which relief the Court denied on November 5, 2014. On December 12, 2014, the plaintiffs filed a Verified Second Consolidated Amended Class Action Complaint, which purports to assert claims on behalf of both the former EPB unitholders and the former KMP unitholders. The EPB plaintiff alleged that (i) El Paso Pipeline GP Company, L.L.C. (EPGP), the general partner of EPB, and the directors of EPGP breached duties under the EPB partnership agreement, including the implied covenant of good faith and fair dealing, by entering into the EPB Transaction; (ii) EPB, E Merger Sub LLC, KMI and individual defendants aided and abetted such breaches; and (iii) EPB, E Merger Sub LLC, KMI, and individual defendants tortiously interfered with the EPB partnership agreement by causing EPGP to breach its duties under the EPB partnership agreement.
	The KMP plaintiffs allege that (i) KMR, KMGP, and individual defendants breached duties under the KMP partnership agreement, including the implied duty of good faith and fair dealing, by entering into the KMP Transaction and by failing to adequately disclose material facts related to the transaction; (ii) KMI aided and abetted such breach; and (iii) KMI, KMP, KMR, P Merger Sub LLC, and individual defendants tortiously interfered with the rights of the plaintiffs and the putative class under the KMP partnership agreement by causing KMGP to breach its duties under the KMP partnership agreement. The complaint seeks declaratory relief that the transactions were unlawful and unenforceable, reformation, rescission, rescissory or compensatory damages, interest, and attorneys’ and experts’ fees and costs. On December 30, 2014, the defendants moved to dismiss the complaint. On April 2, 2015, the EPB plaintiff and the defendants submitted a stipulation and proposed order of dismissal, agreeing to dismiss all claims brought by the EPB plaintiff with prejudice as to the EPB lead plaintiff and without prejudice to all other members of the putative EPB class. The Court entered such order on April 2, 2015.
	The defendants believe the allegations against them lack merit, and they intend to vigorously defend these lawsuits.
	Kinder Morgan Energy Partners, L.P. Capex Litigation
	Putative class action and derivative complaints were filed in the Court of Chancery in the State of Delaware against defendants KMI, KMGP and nominal defendant KMEP on February 5, 2014 and March 27, 2014 captioned Slotoroff v. Kinder Morgan, Inc., Kinder Morgan G.P., Inc. et al (Case No. 9318) and Burns et al v. Kinder Morgan, Inc., Kinder Morgan G.P., Inc. et al (Case No. 9479) respectively. The cases were consolidated on April 8, 2014 (Consolidated Case No. 9318). The consolidated suit seeks to assert claims both individually and on behalf of a putative class consisting of all public holders of KMEP units during the period of February 5, 2011 through the date of the filing of the complaints. The suit alleges direct and derivative causes of action for breach of the partnership agreement, breach of the duty of good faith and fair dealing, aiding and abetting, and tortious interference. Among other things, the suit alleges that defendants made a bad faith allocation of capital expenditures to expansion capital expenditures rather than maintenance capital expenditures for the alleged purpose of “artificially” inflating KMEP’s distributions and growth rate. The suit seeks disgorgement of any distributions to KMGP, KMI and any related entities, beyond amounts that would have been distributed in accordance with a “good faith” allocation of maintenance capital expenses, together with other unspecified monetary damages including punitive damages and attorney fees. Defendants believe this suit is without merit and intend to defend it vigorously.
	Walker v. Kinder Morgan, Inc., Kinder Morgan G.P., Inc. et al.
	On March 6, 2014, a putative class action and derivative complaint was filed in the District Court of Harris County, Texas (Case No. 2014-11872 in the 215th Judicial District) against KMI, KMGP, KMR, Richard D. Kinder, Steven J. Kean, Ted A. Gardner, Gary L. Hultquist, Perry M. Waughtal and nominal defendant KMEP. The suit was filed by Kenneth Walker, a purported unit holder of KMEP, and alleges derivative causes of action for alleged violation of duties owed under the partnership agreement, breach of the implied covenant of good faith and fair dealing, “abuse of control” and “gross mismanagement” in connection with the calculation of distributions and allocation of capital expenditures to expansion capital expenditures and maintenance capital expenditures. The suit seeks unspecified money damages, interest, punitive damages, attorney and expert fees, costs and expenses, unspecified equitable relief, and demands a trial by jury. Defendants believe this suit is without merit and intend to defend it vigorously. By agreement of the parties, the case is stayed pending further resolution of the Kinder Morgan Energy Partners, L.P. Capex Litigation described above.
	Pipeline Integrity and Releases
	From time to time, despite our best efforts, our pipelines experience leaks and ruptures. These leaks and ruptures may cause explosions, fire, and damage to the environment, damage to property and/or personal injury or death. In connection with these incidents, we may be sued for damages caused by an alleged failure to properly mark the locations of our pipelines and/or to properly maintain our pipelines. Depending upon the facts and circumstances of a particular incident, state and federal regulatory authorities may seek civil and/or criminal fines and penalties.
	General
	As of March 31, 2015 and December 31, 2014, our total reserve for legal matters was $518 million and $400 million, respectively. The reserve primarily relates to various claims from regulatory rate and right-of-way proceedings arising in our products pipeline segment and natural gas pipeline segment’s regulatory rate proceedings as well as certain corporate matters. The overall increase in the reserve from December 31, 2014 related to certain legal developments during the quarter on corporate matters.
	Environmental Matters
	We and our subsidiaries are subject to environmental cleanup and enforcement actions from time to time. In particular, CERCLA generally imposes joint and several liability for cleanup and enforcement costs on current and predecessor owners and operators of a site, among others, without regard to fault or the legality of the original conduct, subject to the right of a liable party to establish a “reasonable basis” for apportionment of costs. Our operations are also subject to federal, state and local laws and regulations relating to protection of the environment. Although we believe our operations are in substantial compliance with applicable environmental law and regulations, risks of additional costs and liabilities are inherent in pipeline, terminal and CO2 field and oil field operations, and there can be no assurance that we will not incur significant costs and liabilities. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies under the terms of authority of those laws, and claims for damages to property or persons resulting from our operations, could result in substantial costs and liabilities to us.
	We are currently involved in several governmental proceedings involving alleged violations of environmental and safety regulations. As we receive notices of non-compliance, we attempt to negotiate and settle such matters where appropriate. We do not believe that these alleged violations will have a material adverse effect on our business, financial position, results of operations or dividends to our shareholders.
	We are also currently involved in several governmental proceedings involving groundwater and soil remediation efforts under administrative orders or related state remediation programs. We have established a reserve to address the costs associated with the cleanup.
	In addition, we are involved with and have been identified as a potentially responsible party in several federal and state superfund sites. Environmental reserves have been established for those sites where our contribution is probable and reasonably estimable. In addition, we are from time to time involved in civil proceedings relating to damages alleged to have occurred as a result of accidental leaks or spills of refined petroleum products, NGL, natural gas and CO2.
	Portland Harbor Superfund Site, Willamette River, Portland, Oregon
	In December 2000, the EPA issued General Notice letters to potentially responsible parties including GATX Terminals Corporation (n/k/a KMLT). At that time, GATX owned two liquids terminals along the lower reach of the Willamette River, an industrialized area known as Portland Harbor. Portland Harbor is listed on the National Priorities List and is designated as a Superfund Site under CERCLA. A group of potentially responsible parties formed what is known as the Lower Willamette Group (LWG), of which KMLT is a non-voting member and pays a minimal fee to be part of the group. The LWG agreed to conduct the remedial investigation and feasibility study (RI/FS) leading to the proposed remedy for cleanup of the Portland Harbor site. Once the EPA determines the cleanup remedy from the remedial investigations and feasibility studies conducted during the last decade at the site, it will issue a Record of Decision. Currently, KMLT and 90 other parties are involved in a non-judicial allocation process to determine each party’s respective share of the cleanup costs. We are participating in the allocation process on behalf of KMLT and KMBT in connection with their current or former ownership or operation of four facilities located in Portland Harbor. We expect the allocation and RI/FS process to conclude in 2015, after which the EPA is expected to develop a proposed plan leading to a Record of Decision targeted for 2017. We anticipate that the cleanup activities will begin within one year of the issuance of the Record of Decision.
	Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona
	The Roosevelt Irrigation District sued KMGP, KMEP and others under CERCLA for alleged contamination of the water purveyor’s wells. The First Amended Complaint sought $175 million in damages against approximately 70 defendants. On August 6, 2013 plaintiffs filed their Second Amended Complaint seeking monetary damages in unspecified amounts and reducing the number of defendants to 26 including KMEP and SFPP. The claims now presented against KMEP and SFPP are related to alleged releases from a specific parcel within the SFPP Phoenix Terminal and the alleged impact of such releases on water wells owned by the plaintiffs and located in the vicinity of the Terminal. We have filed an answer, general denial, and affirmative defenses in response to the Second Amended Complaint.
	Mission Valley Terminal Lawsuit
	In August 2007, the City of San Diego, on its own behalf and purporting to act on behalf of the People of the State of California, filed a lawsuit against us and several affiliates seeking injunctive relief and unspecified damages allegedly resulting from hydrocarbon and methyl tertiary butyl ether (MTBE) impacted soils and groundwater beneath the City’s stadium property in San Diego arising from historic operations at the Mission Valley terminal facility. The case was filed in the Superior Court of California, San Diego County (Case No. 37-2007-00073033). On September 26, 2007, we removed the case to the U.S. District Court, Southern District of California (Case No. 07CV1883WCAB). The City disclosed in discovery that it is seeking approximately $170 million in damages for alleged lost value/lost profit from the redevelopment of the City’s property and alleged lost use of the water resources underlying the property. Later, in 2010, the City amended its initial disclosures to add claims for restoration of the site as well as a number of other claims that increased its claim for damages to approximately $365 million
	On November 29, 2012, the Court issued a Notice of Tentative Rulings on the parties’ summary adjudication motions. The Court tentatively granted our partial motions for summary judgment on the City’s claims for water and real estate damages and the State’s claims for violations of California Business and Professions Code § 17200, tentatively denied the City’s motion for summary judgment on its claims of liability for nuisance and trespass, and tentatively granted our cross motion for summary judgment on such claims. On January 25, 2013, the Court rendered judgment in favor of all defendants on all claims asserted by the City.
	On February 20, 2013, the City of San Diego filed a notice of appeal to the U.S. Court of Appeals for the Ninth Circuit, which heard oral argument on February 3, 2015. The appeal remains pending.
	This site has been, and currently is, under the regulatory oversight and order of the California Regional Water Quality Control Board (RWQCB).  SFPP has completed the soil and groundwater remediation at the City of San Diego’s stadium property site and conducted quarterly sampling and monitoring through 2014 as part of the compliance evaluation required by the RWQCB. SFPP’s remediation effort is now focused on its adjacent Mission Valley Terminal site.
	Uranium Mines in Vicinity of Cameron, Arizona
	In the 1950s and 1960s, Rare Metals Inc., a historical subsidiary of EPNG, mined approximately twenty uranium mines in the vicinity of Cameron, Arizona, many of which are located on the Navajo Indian Reservation. The mining activities were in response to numerous incentives provided to industry by the U.S. to locate and produce domestic sources of uranium to support the Cold War-era nuclear weapons program. In May 2012, EPNG received a general notice letter from the EPA notifying EPNG of the EPA’s investigation of certain sites and its determination that the EPA considers EPNG to be a potentially responsible party within the meaning of CERCLA. In August 2013, EPNG and the EPA entered into an Administrative Order on Consent and Scope of Work pursuant to which EPNG will conduct a radiological assessment of the surface of the mines. On September 3, 2014, EPNG filed a complaint in the U.S. District Court for the District of Arizona (Case No. 3:14-08165-DGC) seeking cost recovery and contribution from the applicable federal government agencies toward the cost of environmental activities associated with the mines, given the pervasive control of such federal agencies over all aspects of the nuclear weapons program. Defendants filed an answer and counterclaims seeking contribution and recovery of response costs allegedly incurred by the federal agencies in investigating uranium impacts on the Navajo Reservation.
	Lower Passaic River Study Area of the Diamond Alkali Superfund Site, Essex, Hudson, Bergen and Passaic Counties, New Jersey
	EPEC Polymers, Inc. (EPEC Polymers) and EPEC Oil Company Liquidating Trust (EPEC Oil Trust), former El Paso Corporation entities now owned by KMI, are involved in an administrative action under CERCLA known as the Lower Passaic River Study Area Superfund Site (Site) concerning the lower 17-mile stretch of the Passaic River. It has been alleged that EPEC Polymers and EPEC Oil Trust may be potentially responsible parties under CERCLA based on prior ownership and/or operation of properties located along the relevant section of the Passaic River. EPEC Polymers and EPEC Oil Trust entered into two Administrative Orders on Consent (AOCs) which obligate them to investigate and characterize contamination at the Site. They are also part of a joint defense group (JDG) of approximately 70 cooperating parties which have entered into AOCs and are directing and funding the work required by the EPA. Under the first AOC, a remedial investigation and feasibility study of the Site is presently estimated to be completed by 2015. Under the second AOC, the JDG members are conducting a CERCLA removal action at the Passaic River Mile 10.9, including the dredging of sediment in mud flats at this location of the river to a depth of two feet and installation of a cap. The dredging was completed in 2013 and capping work was completed in June 2014. We have established a reserve for the anticipated cost of compliance with the AOCs.
	On April 11, 2014, the EPA announced the issuance of its Focused Feasibility Study (FFS) for the lower eight miles of the Passaic River Study Area, and its proposed plan for remedial alternatives to address the dioxin sediment contamination from the mouth of Newark Bay to River Mile 8.3. The EPA estimates the cost for the alternatives will range from $365 million to $3.2 billion. The EPA’s preferred alternative would involve dredging the river bank-to-bank and installing an engineered cap at an estimated cost of $1.7 billion. In its FFS, the EPA stated that it has identified over 100 industrial facilities as potentially responsible parties and it is likely that there are hundreds more private and public entities that could be named in any litigation concerning responsibility for the Site contamination.
	No final remedy for this portion of the Site will be selected until the public comment and response period for the FFS is completed and the Record of Decision (ROD) is issued by EPA, which is expected in September 2015. Until the ROD is issued there is uncertainty about what remedy will be implemented and the extent of potential costs. There is also uncertainty as to the impact of the RI/FS that the CPG is currently preparing for portions of the Site. Therefore, the scope of potential EPA claims for the lower eight miles of the Passaic River is not reasonably estimable at this time.
	Southeast Louisiana Flood Protection Litigation
	On July 24, 2013, the Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East (SLFPA) filed a petition for damages and injunctive relief in state district court for Orleans Parish, Louisiana (Case No. 13-6911) against TGP, SNG and approximately 100 other energy companies, alleging that defendants’ drilling, dredging, pipeline and industrial operations since the 1930’s have caused direct land loss and increased erosion and submergence resulting in alleged increased storm surge risk, increased flood protection costs and unspecified damages to the plaintiff. The SLFPA asserts claims for negligence, strict liability, public nuisance, private nuisance, and breach of contract. Among other relief, the petition seeks unspecified monetary damages, attorney fees, interest, and injunctive relief in the form of abatement and restoration of the alleged coastal land loss including but not limited to backfilling and re-vegetation of canals, wetlands and reef creation, land bridge construction, hydrologic restoration, shoreline protection, structural protection, and bank stabilization. On August 13, 2013, the suit was removed to the U.S. District Court for the Eastern District of Louisiana. On February 13, 2015, the Court granted defendants’ motion to dismiss the suit for failure to state a claim, and issued an order dismissing the SLFPA’s claims with prejudice. The SLFPA filed a notice of appeal on February 20, 2015.
	Plaquemines Parish Louisiana Coastal Zone Litigation
	On November 8, 2013, the Parish of Plaquemines, Louisiana filed a petition for damages in the state district court for Plaquemines Parish, Louisiana (Docket No. 60-999) against TGP and 17 other energy companies, alleging that defendants’ oil and gas exploration, production and transportation operations in the Bastian Bay, Buras, Empire and Fort Jackson oil and gas fields of Plaquemines Parish caused substantial damage to the coastal waters and nearby lands (Coastal Zone) within the Parish, including the erosion of marshes and the discharge of oil waste and other pollutants which detrimentally affected the quality of state waters and plant and animal life, in violation of the State and Local Coastal Resources Management Act of 1978 (Coastal Zone Management Act). As a result of such alleged violations of the Coastal Zone Management Act, Plaquemines Parish seeks, among other relief, unspecified monetary relief, attorney fees, interest, and payment of costs necessary to restore the allegedly affected Coastal Zone to its original condition, including costs to clear, vegetate and detoxify the Coastal Zone. On December 18, 2013, defendants removed the case to the U.S. District Court for the Eastern District of Louisiana. The plaintiff filed a motion to remand the case to state court, and such motion remains under consideration by the federal court. In connection with this suit, TGP has made two tenders for defense and indemnity: (1) to Anadarko, as successor to the entity that purchased TGP’s oil and gas assets in Bastian Bay, and (2) to Kinetica, which purchased TGP’s pipeline assets in Bastian Bay in 2013. Anadarko has accepted TGP’s tender (limited to oil and gas assets), and Kinetica rejected TGP’s tender. TGP responded to Kinetica be reasserting TGP’s demand for defense and indemnity and reserving its rights.
	General
Although it is not possible to predict the ultimate outcomes, we believe that the resolution of the environmental matters set forth in this note, and other matters to which we and our subsidiaries are a party, will not have a material adverse effect on our business, financial position, results of operations or cash flows. As of March 31, 2015 and December 31, 2014, we have accrued a total reserve for environmental liabilities in the amount of $332 million and $340 million, respectively. In addition, as of both March 31, 2015 and December 31, 2014, we have recorded a receivable of $14 million, for expected cost recoveries that have been deemed probable.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements (Notes)	3 Months Ended
	Mar. 31, 2015
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Accounting Pronouncements	Recent Accounting Pronouncements
	ASU No. 2014-09
	On May 28, 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” This ASU is designed to create greater comparability for financial statement users across industries and jurisdictions. The provisions of ASU No. 2014-09 include a five-step process by which entities will recognize revenue to depict the transfer of goods or services to customers in amounts that reflect the payment to which an entity expects to be entitled in exchange for those goods or services. The standard also will require enhanced disclosures, provide more comprehensive guidance for transactions such as service revenue and contract modifications, and enhance guidance for multiple-element arrangements. ASU No. 2014-09 will be effective for U.S. public companies for annual reporting periods beginning after December 15, 2016, including interim reporting periods (January 1, 2017 for us). Early adoption is not permitted. We are currently reviewing the effect of ASU No. 2014-09 on our revenue recognition.
	ASU No. 2015-02
	On February 18, 2015, the FASB issued ASU No. 2015-02, “Consolidation (Topic 810) - Amendments to the Consolidated Analysis.” This ASU focuses on the consolidation evaluation for reporting organizations that are required to evaluate whether they should consolidate certain legal entities. ASU No. 2015-02 will be effective for U.S. public companies for annual reporting periods beginning after December 15, 2015. Early adoption is allowed, including in any interim period. We are currently reviewing the effect of ASU No. 2015-02 on our consolidation conclusion and disclosure.
	ASU No. 2015-03
	On April 7, 2015, the FASB issued ASU No. 2015-03, “Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Cost.” This ASU is designed to simplify presentation of debt issuance costs. The standard requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The amortization of debt issuance costs also shall be reported as interest expense. ASU No. 2015-03 will be effective for U.S. public companies for annual reporting periods beginning after December 15, 2015, including interim reporting periods (January 1, 2016 for us). Early adoption is permitted. The new guidance shall be applied on a retrospective basis for all periods presented. We are currently reviewing the effect of ASU No. 2015-03.

Guarantee_of_Securities_of_Sub

Guarantee of Securities of Subsidiaries (Notes)	3 Months Ended
	Mar. 31, 2015
Guarantee of Securities of Subsidiaries [Abstract]
Guarantees [Text Block]	Guarantee of Securities of Subsidiaries
	KMI, along with its direct and indirect subsidiaries KMP and Copano, are issuers of certain public debt securities. After the completion of the Merger Transactions, KMI and substantially all of its wholly owned domestic subsidiaries, including KMP and Copano, entered into a cross guarantee agreement whereby each party to the agreement unconditionally guarantees, jointly and severally, the payment of specified indebtedness of each other party to the agreement. Accordingly, with the exception of certain subsidiaries identified as Non-Guarantor Subsidiaries, the parent issuer, subsidiary issuers and other subsidiaries are all guarantors of each series of public debt. As a result of the cross guarantee agreement, a holder of any of the guaranteed public debt securities issued by KMI, KMP or Copano are in the same position with respect to the net assets, income and cash flows of KMI and the Subsidiary Issuers and Guarantors. The only amounts that are not available to the holders of each of the guaranteed public debt securities to satisfy the repayment of such securities are the net assets, income and cash flows of the Subsidiary Non-Guarantors.
	In lieu of providing separate financial statements for each subsidiary issuer and guarantor, we have included the accompanying condensed consolidating financial statements based on Rule 3-10 of the SEC’s Regulation S-X.  We have presented each of the parent and subsidiary issuers in separate columns in this single set of condensed consolidating financial statements.
	On January 1, 2015, EPB and its subsidiary, EPPOC merged with and into KMP with KMP surviving the merger. As a result of such merger, all of the wholly owned subsidiaries of EPB became wholly owned subsidiaries of KMP and effective January 1, 2015, EPB is no longer a Subsidiary Issuer and Guarantor. The condensed consolidating financial information reflects this transaction for all periods presented below.
	Excluding fair value adjustments, as of March 31, 2015, Parent Issuer and Guarantor, Subsidiary Issuer and Guarantor-KMP, Subsidiary Issuer and Guarantor-Copano, and Subsidiary Guarantors had $14,226 million, $20,360 million, $332 million, and $7,401 million of Guaranteed Notes outstanding, respectively.   Excluding fair value adjustments, as of December 31, 2014, Parent Issuer and Guarantor, Subsidiary Issuer and Guarantor-KMP, Subsidiary Issuer and Guarantor-Copano, and Subsidiary Guarantors had $12,674 million, $20,660 million, $332 million, and $6,463 million of Guaranteed Notes outstanding, respectively. Included in the Subsidiary Guarantors debt balance as presented in the accompanying March 31, 2015 and December 31, 2014 condensed consolidating balance sheets are approximately $177 million and $178 million, respectively, of capitalized lease debt that is not subject to the cross guarantee agreement.
	The accounts within the Parent Issuer and Guarantor, Subsidiary Issuer and Guarantor-KMP, Subsidiary Issuer and Guarantor-Copano, Subsidiary Guarantors and Subsidiary Non-guarantors are presented using the equity method of accounting for investments in subsidiaries, including subsidiaries that are guarantors and non-guarantors, for purposes of these condensed consolidating financial statements only.  These intercompany investments and related activity eliminate in consolidation and are presented separately in the accompanying balance sheets and statements of income and cash flows.
	A significant amount of each Issuers’ income and cash flow is generated by its respective subsidiaries.  As a result, the funds necessary to meet its debt service and/or guarantee obligations are provided in large part by distributions or advances it receives from its respective subsidiaries.  We utilize a centralized cash pooling program among our majority-owned and consolidated subsidiaries, including the Subsidiary Issuers and Guarantors and Non-Guarantor Subsidiaries. The following Condensed Consolidating Statements of Cash Flows present the intercompany loan and distribution activity, as well as cash collection and payments made on behalf of our subsidiaries, as cash activities.
	Effective November 26, 2014, the Merger Transactions close date, KMR merged into KMI.  Therefore, for all periods presented KMR’s financial statement balances and activities are reflected within the Parent Issuer and Guarantor column.
	Condensed Consolidating Statements of Income and Comprehensive Income
	for the Three Months Ended March 31, 2015
	(In Millions)
	(Unaudited)
		Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating Adjustments			Consolidated KMI
		Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors
		Guarantor			Guarantor -			Guarantor -
					KMP			Copano
	Total Revenues	$	9		$	—		$	—		$	3,226		$	375		$	(13	)	$	3,597
	Operating costs, expenses and other
	Costs of sales	—			—			—			1,001			89			—			1,090
	Depreciation, depletion and amortization	5			—			—			442			91			—			538
	Other operating expenses	12			38			1			685			168			(13		)	891
	Total operating costs, expenses and other	17			38			1			2,128			348			(13		)	2,519
	Operating (loss) income	(8		)	(38		)	(1		)	1,098			27			—			1,078
	Other income (expense)
	Earnings (losses) from consolidated subsidiaries	605			883			(23		)	548			16			(2,029		)	—
	Earnings from equity investments	—			—			—			76			—			—			76
	Interest, net	(104		)	(27		)	(12		)	(355		)	(14		)	—			(512		)
	Amortization of excess cost of equity investments and other, net	—			—			—			(3		)	4			—			1
	Income (loss) before income taxes	493			818			(36		)	1,364			33			(2,029		)	643
	Income tax expense	(64		)	(2		)	—			(157		)	(1		)	—			(224		)
	Net income (loss)	429			816			(36		)	1,207			32			(2,029		)	419
	Net loss attributable to noncontrolling interests	—			—			—			—			—			10			10
	Net income (loss) attributable to controlling interests	$	429		$	816		$	(36	)	$	1,207		$	32		$	(2,019	)	$	429
	Net Income	$	429		$	816		$	(36	)	$	1,207		$	32		$	(2,029	)	$	419
	Total other comprehensive loss	(176		)	(238		)	—			(295		)	(164		)	697			(176		)
	Comprehensive income (loss)	253			578			(36		)	912			(132		)	(1,332		)	243
	Comprehensive loss attributable to noncontrolling interests	—			—			—			—			—			10			10
	Comprehensive income (loss) attributable to controlling interests	$	253		$	578		$	(36	)	$	912		$	(132	)	$	(1,322	)	$	253
	Condensed Consolidating Statements of Income and Comprehensive Income
	for the Three Months Ended March 31, 2014
	(In Millions)
	(Unaudited)
		Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating Adjustments			Consolidated KMI
		Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors
		Guarantor			Guarantor -			Guarantor -
					KMP			Copano
	Total Revenues	$	9		$	—		$	—		$	3,630		$	406		$	2		$	4,047
	Operating costs, expenses and other
	Costs of sales	—			—			—			1,497			132			14			1,643
	Depreciation, depletion and amortization	5			—			—			399			92			—			496
	Other operating expenses	8			1			7			639			118			(12		)	761
	Total operating costs, expenses and other	13			1			7			2,535			342			2			2,900
	Operating (loss) income	(4		)	(1		)	(7		)	1,095			64			—			1,147
	Other income (expense)
	Earnings from consolidated subsidiaries	506			947			44			359			456			(2,312		)	—
	Earnings from equity investments	—			—			—			99			—			—			99
	Interest, net	(132		)	(24		)	(11		)	(250		)	(31		)	—			(448		)
	Amortization of excess cost of equity investments and other, net	—			—			—			(7		)	10			—			3
	Income before income taxes	370			922			26			1,296			499			(2,312		)	801
	Income tax expense	(34		)	(3		)	—			(11		)	(152		)	—			(200		)
	Net income	336			919			26			1,285			347			(2,312		)	601
	Net income attributable to noncontrolling interests	(49		)	(69		)	—			—			—			(196		)	(314		)
	Net income attributable to controlling interests	$	287		$	850		$	26		$	1,285		$	347		$	(2,508	)	$	287
	Net Income	$	336		$	919		$	26		$	1,285		$	347		$	(2,312	)	$	601
Total other comprehensive loss	(49		)	(118		)	—			(146		)	(110		)	329			(94		)
Comprehensive income	287			801			26			1,139			237			(1,983		)	507
Comprehensive income attributable to noncontrolling interests	(38		)	(68		)	—			—			—			(152		)	(258		)
Comprehensive income attributable to controlling interests	$	249		$	733		$	26		$	1,139		$	237		$	(2,135	)	$	249
Condensed Consolidating Balance Sheets as of March 31, 2015
(In Millions)
(Unaudited)
	Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating			Consolidated KMI
	Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors			Adjustments
	Guarantor			Guarantor -			Guarantor -
				KMP			Copano
ASSETS
Cash and cash equivalents	$	13		$	15		$	—		$	40		$	191		$	—		$	259
Other current assets - affiliates	3,138			1,833			18			12,665			574			(18,228		)	—
All other current assets	202			153			1			2,354			333			(13		)	3,030
Property, plant and equipment, net	277			—			1			31,462			8,549			—			40,289
Investments	16			2			—			5,885			108			—			6,011
Investments in subsidiaries	32,381			31,011			1,888			17,741			3,324			(86,345		)	—
Goodwill	15,089			22			920			5,688			3,188			—			24,907
Notes receivable from affiliates	4,590			22,593			—			2,256			323			(29,762		)	—
Deferred tax assets	—			—			—			9,159			—			(3,614		)	5,545
Other non-current assets	310			449			—			5,236			128			—			6,123
Total assets	$	56,016		$	56,078		$	2,828		$	92,486		$	16,718		$	(137,962	)	$	86,164
LIABILITIES AND STOCKHOLDERS’ EQUITY
Liabilities
Current portion of debt	$	963		$	875		$	—		$	1,471		$	126		$	—		$	3,435
Other current liabilities - affiliates	551			13,417			276			3,343			641			(18,228		)	—
All other current liabilities	302			224			16			2,105			715			(13		)	3,349
Long-term debt	13,965			20,271			384			6,510			694			—			41,824
Notes payable to affiliates	2,542			448			606			24,784			1,382			(29,762		)	—
Deferred income taxes	2,126			—			2			—			1,486			(3,614		)	—
All other long-term liabilities and deferred credits	538			175			—			989			495			—			2,197
Total liabilities	20,987			35,410			1,284			39,202			5,539			(51,617		)	50,805
Stockholders’ equity
Total KMI equity	35,029			20,668			1,544			53,284			11,179			(86,675		)	35,029
Noncontrolling interests	—			—			—			—			—			330			330
Total stockholders’ equity	35,029			20,668			1,544			53,284			11,179			(86,345		)	35,359
Total liabilities and stockholders’ equity	$	56,016		$	56,078		$	2,828		$	92,486		$	16,718		$	(137,962	)	$	86,164
Condensed Consolidating Balance Sheets as of December 31, 2014
(In Millions)
	Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating			Consolidated KMI
	Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors			Adjustments
	Guarantor			Guarantor -			Guarantor -
				KMP			Copano
ASSETS
Cash and cash equivalents	$	4		$	15		$	—		$	17		$	279		$	—		$	315
Other current assets - affiliates	1,868			1,335			11			11,573			403			(15,190		)	—
All other current assets	397			152			3			2,547			358			(20		)	3,437
Property, plant and equipment, net	263			—			5			29,490			8,806			—			38,564
Investments	16			1			—			5,910			109			—			6,036
Investments in subsidiaries	31,372			33,414			1,911			17,868			3,337			(87,902		)	—
Goodwill	15,087			22			920			5,419			3,206			—			24,654
Notes receivable from affiliates	4,459			19,832			—			2,415			496			(27,202		)	—
Deferred tax assets	—			—			—			9,256			—			(3,605		)	5,651
Other non-current assets	287			360			—			3,782			112			—			4,541
Total assets	$	53,753		$	55,131		$	2,850		$	88,277		$	17,106		$	(133,919	)	$	83,198
LIABILITIES AND STOCKHOLDERS’ EQUITY
Liabilities
Current portion of debt	$	1,486		$	699		$	—		$	381		$	151		$	—		$	2,717
Other current liabilities - affiliates	709			11,949			115			1,551			866			(15,190		)	—
All other current liabilities	319			498			12			1,812			1,024			(20		)	3,645
Long-term debt	11,862			20,675			386			6,609			714			—			40,246
Notes payable to affiliates	2,619			153			753			22,437			1,240			(27,202		)	—
Deferred income taxes	2,099			—			2			—			1,504			(3,605		)	—
Other long-term liabilities and deferred credits	583			78			2			987			514			—			2,164
Total liabilities	19,677			34,052			1,270			33,777			6,013			(46,017		)	48,772
Stockholders’ equity
Total KMI equity	34,076			21,079			1,580			54,500			11,093			(88,252		)	34,076
Noncontrolling interests	—			—			—			—			—			350			350
Total stockholders’ equity	34,076			21,079			1,580			54,500			11,093			(87,902		)	34,426
Total liabilities and stockholders’ equity	$	53,753		$	55,131		$	2,850		$	88,277		$	17,106		$	(133,919	)	$	83,198
Condensed Consolidating Statements of Cash Flows for the Three Months Ended March 31, 2015
(In Millions)
(Unaudited)
	Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating Adjustments			Consolidated KMI
	Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors
	Guarantor			Guarantor -			Guarantor -
				KMP			Copano
Net cash (used in) provided by operating activities	$	(224	)	$	3,675		$	139		$	424		$	(167	)	$	(2,591	)	$	1,256
Cash flows from investing activities
Funding to affiliates	(246		)	(4,664		)	—			(1,432		)	(98		)	6,440			—
Capital expenditures	(18		)	—			(2		)	(786		)	(95		)	4			(897		)
Contributions to investments	—			—			—			(30		)	—			—			(30		)
Investment in KMP	(159		)	—			—			—			—			159			—
Acquisitions of assets and investments	(1,709		)	—			—			(155		)	—			—			(1,864		)
Distributions from equity investments in excess of cumulative earnings	14			—			—			36			—			—			50
Other, net	—			(31		)	4			4			(7		)	(4		)	(34		)
Net cash (used in) provided by investing activities	(2,118		)	(4,695		)	2			(2,363		)	(200		)	6,599			(2,775		)
Cash flows from financing activities
Issuance of debt	7,136			—			—			—			—			—			7,136
Payment of debt	(5,967		)	(300		)	—			(36		)	(2		)	—			(6,305		)
Funding from (to) affiliates	534			2,311			(141		)	3,400			336			(6,440		)	—
Debt issuance costs	(16		)	—			—			—			—			—			(16		)
Issuances of shares	1,626			—			—			—			—			—			1,626
Cash dividends	(962		)	—			—			—			—			—			(962		)
Contributions from parents	—			156			—			3			—			(159		)	—
Distributions to parents	—			(1,147		)	—			(1,404		)	(50		)	2,601			—
Distributions to noncontrolling interests	—			—			—			—			—			(10		)	(10		)
Other, net	—			—			—			(1		)	—			—			(1		)
Net cash provided by (used in) financing activities	2,351			1,020			(141		)	1,962			284			(4,008		)	1,468
Effect of exchange rate changes on cash and cash equivalents	—			—			—			—			(5		)	—			(5		)
Net increase (decrease) in cash and cash equivalents	9			—			—			23			(88		)	—			(56		)
Cash and cash equivalents, beginning of period	4			15			—			17			279			—			315
Cash and cash equivalents, end of period	$	13		$	15		$	—		$	40		$	191		$	—		$	259
Condensed Consolidating Statements of Cash Flows for the Three Months Ended March 31, 2014
(In Millions)
(Unaudited)
	Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating Adjustments			Consolidated KMI
	Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors
	Guarantor			Guarantor -			Guarantor -
				KMP			Copano
Net cash provided by operating activities	$	438		$	1,435		$	79		$	740		$	214		$	(1,788	)	$	1,118
Cash flows from investing activities
Funding to affiliates	(64		)	(2,986		)	—			(1,168		)	(210		)	4,428			—
Capital expenditures	(15		)	—			(27		)	(599		)	(204		)	—			(845		)
Contributions to investments	—			(76		)	—			(36		)	—			76			(36		)
Investment in KMP	(11		)	—			—			—			—			11			—
Acquisitions of assets and investments	—			—			—			(990		)	—			—			(990		)
Distributions from equity investments in excess of cumulative earnings	10			156			—			38			—			(166		)	38
Other, net	—			(22		)	—			23			13			—			14
Net cash used in investing activities	(80		)	(2,928		)	(27		)	(2,732		)	(401		)	4,349			(1,819		)
Cash flows from financing activities
Issuance of debt	643			4,548			—			—			—			—			5,191
Payment of debt	(491		)	(3,618		)	—			(73		)	(2		)	—			(4,184		)
Funding from (to) affiliates	39			1,010			(53		)	3,280			152			(4,428		)	—
Debt issuance costs	(2		)	(10		)	—			—			—			—			(12		)
Cash dividends	(425		)	—			—			—			—			—			(425		)
Repurchases of shares and warrants	(149		)	—			—			—			—			—			(149		)
Contributions from parents	—			661			—			83			24			(768		)	—
Contributions from noncontrolling interests	—			—			—			—			—			684			684
Distributions to parents	—			(1,080		)	—			(1,310		)	(39		)	2,429			—
Distributions to noncontrolling interests	—			—			—			—			—			(479		)	(479		)
Other, net	—			(2		)	—			1			—			1			—
Net cash (used in) provided by financing activities	(385		)	1,509			(53		)	1,981			135			(2,561		)	626
Effect of exchange rate changes on cash and cash equivalents	—			—			—			—			(10		)	—			(10		)
Net (decrease) increase in cash and cash equivalents	(27		)	16			(1		)	(11		)	(62		)	—			(85		)
Cash and cash equivalents, beginning of period	83			88			1			17			409			—			598
Cash and cash equivalents, end of period	$	56		$	104		$	—		$	6		$	347		$	—		$	513

General_Policies

General (Policies)	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]
Basis of Accounting, Policy [Policy Text Block]	Basis of Presentation
	General
	Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars, except where stated otherwise. Our accompanying unaudited consolidated financial statements have been prepared under the rules and regulations of the United States Securities and Exchange Commission (SEC). These rules and regulations conform to the accounting principles contained in the FASB’s Accounting Standards Codification, the single source of GAAP. Under such rules and regulations, all significant intercompany items have been eliminated in consolidation. Additionally, certain amounts from prior years have been reclassified to conform to the current presentation.
	Interim results are not necessarily indicative of results for a full year; accordingly, you should read these consolidated financial statements in conjunction with our consolidated financial statements and related notes included in our 2014 Form 10-K.
Earnings Per Share [Policy Text Block]	Earnings per Share
	We calculate earnings per share using the two-class method. Earnings were allocated to Class P shares of common stock and participating securities based on the amount of dividends paid in the current period plus an allocation of the undistributed earnings or excess distributions over earnings to the extent that each security participates in earnings or excess distributions over earnings. Our unvested restricted stock awards do not participate in excess distributions over earnings.

General_Tables

General (Tables)	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Net Income for Shareholders and Participating Securities [Table Text Block]	The following tables set forth the allocation of net income available to shareholders for Class P shares and for participating securities and the reconciliation of Basic Weighted-Average Number of Shares Outstanding to Diluted Weighted-Average Number of Shares Outstanding (in millions):
		Three Months Ended March 31,
		2015			2014
	Class P	$	426		$	284
	Participating securities(a)	3			3
	Net Income Attributable to Kinder Morgan, Inc.	$	429		$	287
		Three Months Ended March 31,
		2015		2014
	Basic Weighted-Average Number of Shares Outstanding	2,141		1,029
	Effect of dilutive securities:
	Warrants(b)	10		—
	Diluted Weighted-Average Number of Shares Outstanding	2,151		1,029
	________
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
	(b)	Each of our warrants entitles the holder to purchase one share of our common stock for an exercise price of $40 per share, payable in cash or by cashless exercise, at any time until May 25, 2017.
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]	The following potential common stock equivalents are antidilutive and, accordingly, are excluded from the determination of diluted earnings per share (in millions on a weighted-average basis):
		Three Months Ended March 31,
		2015		2014
	Unvested restricted stock awards	7		7
	Warrants to purchase our Class P shares	289		341
	Convertible trust preferred securities	9		10
	_______

Acquisitions_Tables

Acquisitions (Tables)	3 Months Ended
	Mar. 31, 2015
Business Acquisition [Line Items]
Schedule of Purchase Price Allocation [Table Text Block]	Our preliminary allocation of the purchase price for each of our significant acquisitions during the three months ended March 31, 2015 (in millions) is detailed below. The evaluation of the assigned fair values is ongoing and subject to adjustment.
		Acquisitions
		Hiland			Vopak Terminal Assets
	Purchase Price Allocation:
	Current assets	$	44		$	3
	Property, plant and equipment	1,521			131
	Goodwill	238			29
	Other intangibles(a)	1,507			—
	Total assets acquired	3,310			163
	Current liabilities	(187		)	(2		)
	Debt	(1,411		)	—
	Other liabilities	(3		)	(3		)
	Cash consideration	$	1,709		$	158

Debt_Tables

Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Schedule of Debt [Table Text Block]	The following table provides detail on the principal amount of our outstanding debt balances. The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions):
			March 31, 2015		31-Dec-14
	KMI and Subsidiaries
	Senior notes, 1.50% through 8.25%, due 2015 through 2098(a)		$	13,330	$	11,438
	Credit facility due November 26, 2019(b)		600		850
	Commercial paper borrowings(b)		296		386
	KMP
	Senior notes, 2.65% through 9.00%, due 2015 through 2044(c)		20,360		20,660
	TGP senior notes, 7.00% through 8.375%, due 2016 through 2037		1,790		1,790
	EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032		1,115		1,115
	Copano senior notes, 7.125%, due April 1, 2021		332		332
	CIG senior notes, 5.95% through 6.85%, due 2015 through 2037		440		475
	SNG notes, 4.40% through 8.00%, due 2017 through 2032		1,211		1,211
	Other Subsidiary Borrowings (as obligor)
	Kinder Morgan Finance Company, LLC, senior notes, 5.70% through 6.40%, due 2016 through 2036		1,636		1,636
	Hiland Partners Holdings LLC, senior notes, 5.50% and 7.25%, due 2020 and 2022(d)		975		—
	EPC Building, LLC, promissory note, 3.967%, due 2015 through 2035		450		453
	Preferred securities, 4.75%, due March 31, 2028		232		280
	KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock		100		100
	Other miscellaneous debt		301		303
	Total debt – KMI and Subsidiaries		43,168		41,029
	Less: Current portion of debt(e)		3,435		2,717
	Total long-term debt – KMI and Subsidiaries(f)		$	39,733	$	38,312
	_______
	(a)	March 31, 2015 amount includes senior notes that are denominated in Euros and have been converted and are reported at the March 31, 2015 exchange rate of 1.0731 U.S. dollars per Euro. We also entered into cross-currency swap agreements associated with these senior notes (see Note 5).
	(b)	As of March 31, 2015 and December 31, 2014, the weighted average interest rates on our credit facility borrowings, including commercial paper borrowings, were 1.56% and 1.54%, respectively.
	(c)	On January 1, 2015, EPB and EPPOC merged with and into KMP. On that date, KMP succeeded EPPOC as the issuer of approximately $2.9 billion of EPPOC’s senior notes, which were guaranteed by EPB, and EPB and EPPOC ceased to be obligors for those senior notes.
	(d)	Represents the principal amount of senior notes assumed in the Hiland acquisition.
	(e)	Amounts include outstanding credit facility and commercial paper borrowings.
	(f)	As of March 31, 2015 and December 31, 2014, our “Debt fair value adjustments” increased our combined debt balances by $2,091 million and $1,934 million, respectively. In addition to all unamortized debt discount/premium amounts and purchase accounting on our debt balances, our debt fair value adjustments also include (i) amounts associated with the offsetting entry for hedged debt; and (ii) any unamortized portion of proceeds received from the early termination of interest rate swap agreements.
Schedule of Significant Long-Term Debt Issuances and Payments [Table Text Block]	following are significant long-term debt issuances and repayments made during the three months ended March 31, 2015:
	Issuances		$800 million 5.05% notes due 2046
			$815 million 1.50% notes due 2022(a)
			$543 million 2.25% notes due 2027(a)
	Repayments		$300 million 5.625% notes due 2015
			$250 million 5.15% notes due 2015
	_______
	(a)	Senior notes are denominated in Euros and are presented above in U.S. dollars at the exchange rate on the issuance date of 1.086 U.S. dollars per Euro. We also entered into cross-currency swap agreements associated with these senior notes (see Note 5).

Stockholders_Equity_Tables

Stockholders' Equity (Tables)	3 Months Ended
	Mar. 31, 2015
Stockholders' Equity Note [Abstract]
Schedule of Dividends Payable [Table Text Block]	The following table provides information about our per share dividends:
		Three Months Ended March 31,
		2015		2014
	Per common share cash dividend declared for the period	$	0.48	$	0.42
	Per common share cash dividend paid in the period	$	0.45	$	0.41

Risk_Management_Tables

Risk Management (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]	Changes in the components of our “Accumulated other comprehensive loss” not including non-controlling interests are summarized as follows (in millions):
		Net unrealized				Foreign				Pension and				Total
		gains/(losses)				currency				other				accumulated other
		on cash flow				translation				postretirement				comprehensive income/(loss)
		hedge derivatives				adjustments				liability adjustments
	Balance as of December 31, 2014	$	327			$	(108	)		$	(236	)		$	(17	)
	Other comprehensive loss before reclassifications	(2		)		(108		)		6				(104		)
	Amounts reclassified from accumulated other comprehensive loss	(72		)		—				—				(72		)
	Net current-period other comprehensive loss	(74		)		(108		)		6				(176		)
	Balance as of March 31, 2015	$	253			$	(216	)		$	(230	)		$	(193	)
		Net unrealized				Foreign				Pension and				Total
		gains/(losses)				currency				other				accumulated other
		on cash flow				translation				postretirement				comprehensive loss
		hedge derivatives				adjustments				liability adjustments
	Balance as of December 31, 2013	$	(3	)		$	2			$	(23	)		$	(24	)
	Other comprehensive loss before reclassifications	(19		)		(25		)		—				(44		)
	Amounts reclassified from accumulated other comprehensive loss	6				—				—				6
	Net current-period other comprehensive loss	(13		)		(25		)		—				(38		)
	Balance as of March 31, 2014	$	(16	)		$	(23	)		$	(23	)		$	(62	)
Schedule of Derivative Instruments	As of March 31, 2015, we had entered into the following outstanding commodity forward contracts to hedge our forecasted energy commodity purchases and sales:
		Net open position long/(short)
	Derivatives designated as hedging contracts
	Crude oil fixed price	(12.8	)		MMBbl
	Crude oil basis	(12.1	)		MMBbl
	Natural gas fixed price	(50.7	)		Bcf
	Natural gas basis	(25.9	)		Bcf
	Derivatives not designated as hedging contracts
	Crude oil fixed price	(14.2	)		MMBbl
	Crude oil basis	(0.3	)		MMBbl
	Natural gas fixed price	(17.9	)		Bcf
	Natural gas basis	(16.5	)		Bcf
	NGL fixed price	(52.7	)		MMBbl
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table summarizes the fair values of our derivative contracts included in our accompanying consolidated balance sheets (in millions):
	Fair Value of Derivative Contracts
					Asset derivatives								Liability derivatives
					March 31,				December 31,				March 31,				December 31,
					2015				2014				2015				2014
			Balance sheet location		Fair value								Fair value
	Derivatives designated as hedging contracts
	Natural gas and crude derivative contracts		Fair value of derivative contracts/(Other current liabilities)		$	318			$	309			$	(63	)		$	(34	)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		44				6				(2		)		—
	Subtotal				362				315				(65		)		(34		)
	Interest rate swap agreements		Fair value of derivative contracts/(Other current liabilities)		171				143				—				—
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		329				260				(5		)		(53		)
	Subtotal				500				403				(5		)		(53		)
	Cross-currency swap agreements		Fair value of derivative contracts/(Other current liabilities)		—				—				(31		)		—
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		—				—				(23		)		—
	Subtotal				—				—				(54		)		—
	Total				862				718				(124		)		(87		)
	Derivatives not designated as hedging contracts
	Natural gas, crude and NGL derivative contracts		Fair value of derivative contracts/(Other current liabilities)		62				73				(1		)		(2		)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		174				196				(1		)		—
	Subtotal				236				269				(2		)		(2		)
	Power derivative contracts		Fair value of derivative contracts/(Other current liabilities)		10				10				(56		)		(57		)
			Deferred charges and other assets/(Other long-term liabilities and deferred credits)		1				—				(4		)		(16		)
	Subtotal				11				10				(60		)		(73		)
	Total				247				279				(62		)		(75		)
	Total derivatives				$	1,109			$	997			$	(186	)		$	(162	)
	_______
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance	The following tables summarize the impact of our derivative contracts on our accompanying consolidated statements of income (in millions):
	Derivatives in fair value hedging relationships		Location of gain/(loss) recognized in income on derivatives		Amount of gain/(loss) recognized in income
					on derivatives and related hedged item
					Three Months Ended March 31,
					2015				2014
	Interest rate swap agreements		Interest expense		$	145			$	55
	Hedged fixed rate debt		Interest expense		$	(139	)		$	(55	)
	Derivatives in cash flow hedging relationships		Amount of gain/(loss)								Location of gain/(loss) reclassified from Accumulated OCI into income (effective portion)		Amount of gain/(loss) reclassified from Accumulated OCI							Location of gain/(loss) recognized in income on	Amount of gain/(loss)
			recognized in OCI										into income (effective portion)(b)							derivative (ineffective portion and amount excluded from	recognized in income
			on derivative (effective portion)(a)																	effectiveness testing)	on derivative
																					(ineffective portion
																					and amount
																					excluded from
																					effectiveness testing)
			Three Months Ended March 31,										Three Months Ended March 31,								Three Months Ended March 31,
			2015				2014						2015				2014				2015		2014
	Energy commodity		$	35			$	(43	)		Revenues—Natural		$	24			$	(9	)	Revenues—Natural	$	—	$	—
	derivative contracts										gas sales									gas sales
											Revenues—Product		64				(6		)	Revenues—Product	7		(5		)
											sales and other									sales and other
											Costs of sales		(5		)		1			Costs of sales	—		—
	Interest rate swap		(3		)		(2		)		Interest expense		(1		)		—			Interest expense	—		—
	agreements
	Cross-currency swap		(34		)		—				Other, net		(10		)		—
	Total		$	(2	)		$	(45	)		Total		$	72			$	(14	)	Total	$	7	$	(5	)
	_______
	(a)	We expect to reclassify an approximate $175 million gain associated with cash flow hedge price risk management activities included in our accumulated other comprehensive loss balances as of March 31, 2015 into earnings during the next twelve months (when the associated forecasted sales and purchases are also expected to occur), however, actual amounts reclassified into earnings could vary materially as a result of changes in market prices.
	(b)	Amounts reclassified were the result of the hedged forecasted transactions actually affecting earnings (i.e., when the forecasted sales and purchases actually occurred).
	Derivatives not designated as accounting hedges		Location of gain/(loss) recognized in income on derivatives		Amount of gain/(loss) recognized in income on derivatives
					Three Months Ended March 31,
					2015				2014
	Energy commodity derivative contracts		Revenues—Natural gas sales		$	4			$	(7	)
			Revenues—Product sales and other		45				(1		)
			Costs of sales		(3		)		10
			Other expense (income)		—				(2		)
	Total(a)				$	46			$	—
	_______
	(a) As of March 31, 2015, includes an approximate $5 million loss associated with natural gas, crude and NGL derivative contract settlements.

Fair_Value_Tables

Fair Value (Tables)	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following two tables summarize the fair value measurements of our (i) energy commodity derivative contracts; (ii) interest rate swap agreements; and (iii) cross-currency swap agreements, based on the three levels established by the Codification (in millions). The tables also identify the impact of derivative contracts which we have elected to present on our accompanying consolidated balance sheets on a gross basis that are eligible for netting under master netting agreements.
		Balance sheet asset																		Net amount
		fair value measurements by level
		Level 1			Level 2			Level 3			Gross amount			Contracts available for netting			Cash collateral held(b)
	As of March 31, 2015
	Energy commodity derivative contracts(a)	$	39		$	559		$	11		$	609		$	(70	)	$	—		$	539
	Interest rate swap agreements	$	—		$	500		$	—		$	500		$	(3	)	$	—		$	497
	As of December 31, 2014
	Energy commodity derivative contracts(a)	$	49		$	533		$	12		$	594		$	(46	)	$	(13	)	$	535
	Interest rate swap agreements	$	—		$	403		$	—		$	403		$	(44	)	$	—		$	359
		Balance sheet liability																		Net amount
		fair value measurements by level
		Level 1			Level 2			Level 3			Gross amount			Contracts available for netting			Collateral posted(c)
	As of March 31, 2015
	Energy commodity derivative contracts(a)	$	(26	)	$	(41	)	$	(60	)	$	(127	)	$	70		$	44		$	(13	)
	Interest rate swap agreements	$	—		$	(5	)	$	—		$	(5	)	$	3		$	—		$	(2	)
	Cross-currency swap agreements	$	—		$	(54	)	$	—		$	(54	)	$	—		$	—		$	(54	)
	As of December 31, 2014
	Energy commodity derivative contracts(a)	$	(25	)	$	(11	)	$	(73	)	$	(109	)	$	46		$	47		$	(16	)
	Interest rate swap agreements	$	—		$	(53	)	$	—		$	(53	)	$	44		$	—		$	(9	)
	_______
	(a)	Level 1 consists primarily of New York Mercantile Exchange (NYMEX) natural gas futures.  Level 2 consists primarily of OTC West Texas Intermediate (WTI) swaps and options.  Level 3 consists primarily of power derivative contracts.
	(b)	Cash margin deposits held by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current liabilities” on our accompanying consolidated balance sheets.
	(c)	Cash margin deposits posted by us associated with our energy commodity contract positions and OTC swap agreements and reported within “Other current assets” on our accompanying consolidated balance sheets.
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation	The table below provides a summary of changes in the fair value of our Level 3 energy commodity derivative contracts (in millions):
	Significant unobservable inputs (Level 3)
		Three Months Ended March 31,
		2015			2014
	Derivatives-net asset (liability)
	Beginning of Period	$	(61	)	$	(110	)
	Total gains or (losses)
	Included in earnings	—			7
	Included in other comprehensive loss	—			(1		)
	Settlements	12			4
	End of Period	$	(49	)	$	(100	)
	The amount of total gains or (losses) for the period included in earnings attributable to the change in unrealized gains or (losses) relating to assets held at the reporting date	$	1		$	3
	_______
Schedule of Debt [Table Text Block]	The estimated fair value of our outstanding debt balances (the carrying amounts below include both short-term and long-term and debt fair value adjustments), is disclosed below (in millions):
		March 31, 2015						December 31, 2014
		Carrying			Estimated			Carrying			Estimated
		value			fair value			value			fair value
	Total debt	$	45,259		$	46,480		$	42,963		$	43,582
	_______
	We used Level 2 input values to measure the estimated fair value of our outstanding debt balances as of both March 31, 2015 and December 31, 2014.

Reportable_Segments_Tables

Reportable Segments (Tables)	3 Months Ended
	Mar. 31, 2015
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Financial information by segment follows (in millions):
		Three Months Ended March 31,
		2015			2014
	Revenues
	Natural Gas Pipelines
	Revenues from external customers	$	2,177		$	2,557
	Intersegment revenues	3			4
	CO2	446			483
	Terminals	457			391
	Products Pipelines	444			534
	Kinder Morgan Canada	60			69
	Other	4			4
	Total segment revenues	3,591			4,042
	Other revenues	9			9
	Less: Total intersegment revenues	(3		)	(4		)
	Total consolidated revenues	$	3,597		$	4,047
		Three Months Ended March 30,
		2015			2014
	Segment Earnings Before DD&A(a)
	Natural Gas Pipelines	$	1,015		$	1,070
	CO2	336			363
	Terminals	270			210
	Products Pipelines	246			208
	Kinder Morgan Canada	41			48
	Other	(6		)	7
	Total segment earnings before DD&A	1,902			1,906
	DD&A expense	(538		)	(496		)
	Amortization of excess cost of investments	(12		)	(10		)
	Other revenues	9			9
	General and administrative expense	(216		)	(172		)
	Interest expense, net of unallocable interest income	(514		)	(450		)
	Unallocable income tax expense	(212		)	(186		)
	Total consolidated net income	$	419		$	601
		March 31,			December 31,
		2015			2014
	Assets
	Natural Gas Pipelines	$	54,539		$	52,523
	CO2	5,318			5,227
	Terminals	9,071			8,850
	Products Pipelines	8,364			7,179
	Kinder Morgan Canada	1,480			1,593
	Other	443			459
	Total segment assets	79,215			75,831
	Corporate assets(b)	6,920			7,311
	Assets held for sale	29			56
	Total consolidated assets	$	86,164		$	83,198
	_______
	(a)	We evaluate performance based on each segment’s earnings before DD&A. Amounts include revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income), net, and losses on impairments of long-lived assets and equity investments. Operating expenses include natural gas purchases and other costs of sales, operations and maintenance expenses, and taxes, other than income taxes.
	(b)	Includes cash and cash equivalents, margin and restricted deposits, unallocable interest receivable, prepaid assets and deferred charges, risk management assets related to debt fair value adjustments and miscellaneous corporate assets (such as information technology and telecommunications equipment) not allocated to individual segments.

Pension_and_Other_Postretireme1

Pension and Other Postretirement Benefit Plans (Tables)	3 Months Ended
	Mar. 31, 2015
Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract]
Schedule of Net Benefit Costs [Table Text Block]	The components of net benefit plan (credit) expense for our pension and other postretirement benefit (OPEB) plans are as follows (in millions):
		Pension Benefits						OPEB
		Three Months Ended March 31,						Three Months Ended March 31,
		2015			2014			2015			2014
	Service cost	$	6		$	7		$	—		$	—
	Interest cost	24			27			6			7
	Expected return on assets	(43		)	(43		)	(6		)	(6		)
	Amortization of prior service credits	—			—			(1		)	(1		)
	Amortization of net actuarial loss	1			—			—			—
	Net benefit plan credit	$	(12	)	$	(9	)	$	(1	)	$	—

Income_Taxes_Tables

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	Income tax expense included in our accompanying consolidated statements of income were as follows (in millions, except percentages):
		Three Months Ended March 31,
		2015			2014
	Income tax expense	$	224		$	200
	Effective tax rate	34.8		%	25		%

Guarantee_of_Securities_of_Sub1

Guarantee of Securities of Subsidiaries (Tables)	3 Months Ended
	Mar. 31, 2015
Guarantee of Securities of Subsidiaries [Abstract]
Condensed Consolidating Statements of Income and Comprehensive Income [Table Text Block]	Condensed Consolidating Statements of Income and Comprehensive Income
	for the Three Months Ended March 31, 2015
	(In Millions)
	(Unaudited)
		Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating Adjustments			Consolidated KMI
		Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors
		Guarantor			Guarantor -			Guarantor -
					KMP			Copano
	Total Revenues	$	9		$	—		$	—		$	3,226		$	375		$	(13	)	$	3,597
	Operating costs, expenses and other
	Costs of sales	—			—			—			1,001			89			—			1,090
	Depreciation, depletion and amortization	5			—			—			442			91			—			538
	Other operating expenses	12			38			1			685			168			(13		)	891
	Total operating costs, expenses and other	17			38			1			2,128			348			(13		)	2,519
	Operating (loss) income	(8		)	(38		)	(1		)	1,098			27			—			1,078
	Other income (expense)
	Earnings (losses) from consolidated subsidiaries	605			883			(23		)	548			16			(2,029		)	—
	Earnings from equity investments	—			—			—			76			—			—			76
	Interest, net	(104		)	(27		)	(12		)	(355		)	(14		)	—			(512		)
	Amortization of excess cost of equity investments and other, net	—			—			—			(3		)	4			—			1
	Income (loss) before income taxes	493			818			(36		)	1,364			33			(2,029		)	643
	Income tax expense	(64		)	(2		)	—			(157		)	(1		)	—			(224		)
	Net income (loss)	429			816			(36		)	1,207			32			(2,029		)	419
	Net loss attributable to noncontrolling interests	—			—			—			—			—			10			10
	Net income (loss) attributable to controlling interests	$	429		$	816		$	(36	)	$	1,207		$	32		$	(2,019	)	$	429
	Net Income	$	429		$	816		$	(36	)	$	1,207		$	32		$	(2,029	)	$	419
	Total other comprehensive loss	(176		)	(238		)	—			(295		)	(164		)	697			(176		)
	Comprehensive income (loss)	253			578			(36		)	912			(132		)	(1,332		)	243
	Comprehensive loss attributable to noncontrolling interests	—			—			—			—			—			10			10
	Comprehensive income (loss) attributable to controlling interests	$	253		$	578		$	(36	)	$	912		$	(132	)	$	(1,322	)	$	253
	Condensed Consolidating Statements of Income and Comprehensive Income
	for the Three Months Ended March 31, 2014
	(In Millions)
	(Unaudited)
		Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating Adjustments			Consolidated KMI
		Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors
		Guarantor			Guarantor -			Guarantor -
					KMP			Copano
	Total Revenues	$	9		$	—		$	—		$	3,630		$	406		$	2		$	4,047
	Operating costs, expenses and other
	Costs of sales	—			—			—			1,497			132			14			1,643
	Depreciation, depletion and amortization	5			—			—			399			92			—			496
	Other operating expenses	8			1			7			639			118			(12		)	761
	Total operating costs, expenses and other	13			1			7			2,535			342			2			2,900
	Operating (loss) income	(4		)	(1		)	(7		)	1,095			64			—			1,147
	Other income (expense)
	Earnings from consolidated subsidiaries	506			947			44			359			456			(2,312		)	—
	Earnings from equity investments	—			—			—			99			—			—			99
	Interest, net	(132		)	(24		)	(11		)	(250		)	(31		)	—			(448		)
	Amortization of excess cost of equity investments and other, net	—			—			—			(7		)	10			—			3
	Income before income taxes	370			922			26			1,296			499			(2,312		)	801
	Income tax expense	(34		)	(3		)	—			(11		)	(152		)	—			(200		)
	Net income	336			919			26			1,285			347			(2,312		)	601
	Net income attributable to noncontrolling interests	(49		)	(69		)	—			—			—			(196		)	(314		)
	Net income attributable to controlling interests	$	287		$	850		$	26		$	1,285		$	347		$	(2,508	)	$	287
	Net Income	$	336		$	919		$	26		$	1,285		$	347		$	(2,312	)	$	601
	Total other comprehensive loss	(49		)	(118		)	—			(146		)	(110		)	329			(94		)
	Comprehensive income	287			801			26			1,139			237			(1,983		)	507
	Comprehensive income attributable to noncontrolling interests	(38		)	(68		)	—			—			—			(152		)	(258		)
	Comprehensive income attributable to controlling interests	$	249		$	733		$	26		$	1,139		$	237		$	(2,135	)	$	249
Condensed Balance Sheet [Table Text Block]	Condensed Consolidating Balance Sheets as of March 31, 2015
	(In Millions)
	(Unaudited)
		Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating			Consolidated KMI
		Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors			Adjustments
		Guarantor			Guarantor -			Guarantor -
					KMP			Copano
	ASSETS
	Cash and cash equivalents	$	13		$	15		$	—		$	40		$	191		$	—		$	259
	Other current assets - affiliates	3,138			1,833			18			12,665			574			(18,228		)	—
	All other current assets	202			153			1			2,354			333			(13		)	3,030
	Property, plant and equipment, net	277			—			1			31,462			8,549			—			40,289
	Investments	16			2			—			5,885			108			—			6,011
	Investments in subsidiaries	32,381			31,011			1,888			17,741			3,324			(86,345		)	—
	Goodwill	15,089			22			920			5,688			3,188			—			24,907
	Notes receivable from affiliates	4,590			22,593			—			2,256			323			(29,762		)	—
	Deferred tax assets	—			—			—			9,159			—			(3,614		)	5,545
	Other non-current assets	310			449			—			5,236			128			—			6,123
	Total assets	$	56,016		$	56,078		$	2,828		$	92,486		$	16,718		$	(137,962	)	$	86,164
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Liabilities
	Current portion of debt	$	963		$	875		$	—		$	1,471		$	126		$	—		$	3,435
	Other current liabilities - affiliates	551			13,417			276			3,343			641			(18,228		)	—
	All other current liabilities	302			224			16			2,105			715			(13		)	3,349
	Long-term debt	13,965			20,271			384			6,510			694			—			41,824
	Notes payable to affiliates	2,542			448			606			24,784			1,382			(29,762		)	—
	Deferred income taxes	2,126			—			2			—			1,486			(3,614		)	—
	All other long-term liabilities and deferred credits	538			175			—			989			495			—			2,197
	Total liabilities	20,987			35,410			1,284			39,202			5,539			(51,617		)	50,805
	Stockholders’ equity
	Total KMI equity	35,029			20,668			1,544			53,284			11,179			(86,675		)	35,029
	Noncontrolling interests	—			—			—			—			—			330			330
	Total stockholders’ equity	35,029			20,668			1,544			53,284			11,179			(86,345		)	35,359
	Total liabilities and stockholders’ equity	$	56,016		$	56,078		$	2,828		$	92,486		$	16,718		$	(137,962	)	$	86,164
	Condensed Consolidating Balance Sheets as of December 31, 2014
	(In Millions)
		Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating			Consolidated KMI
		Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors			Adjustments
		Guarantor			Guarantor -			Guarantor -
					KMP			Copano
	ASSETS
	Cash and cash equivalents	$	4		$	15		$	—		$	17		$	279		$	—		$	315
	Other current assets - affiliates	1,868			1,335			11			11,573			403			(15,190		)	—
	All other current assets	397			152			3			2,547			358			(20		)	3,437
	Property, plant and equipment, net	263			—			5			29,490			8,806			—			38,564
	Investments	16			1			—			5,910			109			—			6,036
	Investments in subsidiaries	31,372			33,414			1,911			17,868			3,337			(87,902		)	—
	Goodwill	15,087			22			920			5,419			3,206			—			24,654
	Notes receivable from affiliates	4,459			19,832			—			2,415			496			(27,202		)	—
	Deferred tax assets	—			—			—			9,256			—			(3,605		)	5,651
	Other non-current assets	287			360			—			3,782			112			—			4,541
	Total assets	$	53,753		$	55,131		$	2,850		$	88,277		$	17,106		$	(133,919	)	$	83,198
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Liabilities
	Current portion of debt	$	1,486		$	699		$	—		$	381		$	151		$	—		$	2,717
	Other current liabilities - affiliates	709			11,949			115			1,551			866			(15,190		)	—
	All other current liabilities	319			498			12			1,812			1,024			(20		)	3,645
	Long-term debt	11,862			20,675			386			6,609			714			—			40,246
	Notes payable to affiliates	2,619			153			753			22,437			1,240			(27,202		)	—
	Deferred income taxes	2,099			—			2			—			1,504			(3,605		)	—
	Other long-term liabilities and deferred credits	583			78			2			987			514			—			2,164
	Total liabilities	19,677			34,052			1,270			33,777			6,013			(46,017		)	48,772
	Stockholders’ equity
	Total KMI equity	34,076			21,079			1,580			54,500			11,093			(88,252		)	34,076
Noncontrolling interests	—			—			—			—			—			350			350
Total stockholders’ equity	34,076			21,079			1,580			54,500			11,093			(87,902		)	34,426
Total liabilities and stockholders’ equity	$	53,753		$	55,131		$	2,850		$	88,277		$	17,106		$	(133,919	)	$	83,198
Condensed Cash Flow Statement [Table Text Block]	Condensed Consolidating Statements of Cash Flows for the Three Months Ended March 31, 2015
	(In Millions)
	(Unaudited)
		Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating Adjustments			Consolidated KMI
		Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors
		Guarantor			Guarantor -			Guarantor -
					KMP			Copano
	Net cash (used in) provided by operating activities	$	(224	)	$	3,675		$	139		$	424		$	(167	)	$	(2,591	)	$	1,256
	Cash flows from investing activities
	Funding to affiliates	(246		)	(4,664		)	—			(1,432		)	(98		)	6,440			—
	Capital expenditures	(18		)	—			(2		)	(786		)	(95		)	4			(897		)
	Contributions to investments	—			—			—			(30		)	—			—			(30		)
	Investment in KMP	(159		)	—			—			—			—			159			—
	Acquisitions of assets and investments	(1,709		)	—			—			(155		)	—			—			(1,864		)
	Distributions from equity investments in excess of cumulative earnings	14			—			—			36			—			—			50
	Other, net	—			(31		)	4			4			(7		)	(4		)	(34		)
	Net cash (used in) provided by investing activities	(2,118		)	(4,695		)	2			(2,363		)	(200		)	6,599			(2,775		)
	Cash flows from financing activities
	Issuance of debt	7,136			—			—			—			—			—			7,136
	Payment of debt	(5,967		)	(300		)	—			(36		)	(2		)	—			(6,305		)
	Funding from (to) affiliates	534			2,311			(141		)	3,400			336			(6,440		)	—
	Debt issuance costs	(16		)	—			—			—			—			—			(16		)
	Issuances of shares	1,626			—			—			—			—			—			1,626
	Cash dividends	(962		)	—			—			—			—			—			(962		)
	Contributions from parents	—			156			—			3			—			(159		)	—
	Distributions to parents	—			(1,147		)	—			(1,404		)	(50		)	2,601			—
	Distributions to noncontrolling interests	—			—			—			—			—			(10		)	(10		)
	Other, net	—			—			—			(1		)	—			—			(1		)
	Net cash provided by (used in) financing activities	2,351			1,020			(141		)	1,962			284			(4,008		)	1,468
	Effect of exchange rate changes on cash and cash equivalents	—			—			—			—			(5		)	—			(5		)
	Net increase (decrease) in cash and cash equivalents	9			—			—			23			(88		)	—			(56		)
	Cash and cash equivalents, beginning of period	4			15			—			17			279			—			315
	Cash and cash equivalents, end of period	$	13		$	15		$	—		$	40		$	191		$	—		$	259
	Condensed Consolidating Statements of Cash Flows for the Three Months Ended March 31, 2014
	(In Millions)
	(Unaudited)
		Parent			Subsidiary			Subsidiary			Subsidiary			Subsidiary			Consolidating Adjustments			Consolidated KMI
		Issuer and			Issuer and			Issuer and			Guarantors			Non-Guarantors
		Guarantor			Guarantor -			Guarantor -
					KMP			Copano
	Net cash provided by operating activities	$	438		$	1,435		$	79		$	740		$	214		$	(1,788	)	$	1,118
	Cash flows from investing activities
	Funding to affiliates	(64		)	(2,986		)	—			(1,168		)	(210		)	4,428			—
	Capital expenditures	(15		)	—			(27		)	(599		)	(204		)	—			(845		)
	Contributions to investments	—			(76		)	—			(36		)	—			76			(36		)
	Investment in KMP	(11		)	—			—			—			—			11			—
	Acquisitions of assets and investments	—			—			—			(990		)	—			—			(990		)
	Distributions from equity investments in excess of cumulative earnings	10			156			—			38			—			(166		)	38
	Other, net	—			(22		)	—			23			13			—			14
	Net cash used in investing activities	(80		)	(2,928		)	(27		)	(2,732		)	(401		)	4,349			(1,819		)
	Cash flows from financing activities
	Issuance of debt	643			4,548			—			—			—			—			5,191
	Payment of debt	(491		)	(3,618		)	—			(73		)	(2		)	—			(4,184		)
	Funding from (to) affiliates	39			1,010			(53		)	3,280			152			(4,428		)	—
	Debt issuance costs	(2		)	(10		)	—			—			—			—			(12		)
	Cash dividends	(425		)	—			—			—			—			—			(425		)
	Repurchases of shares and warrants	(149		)	—			—			—			—			—			(149		)
	Contributions from parents	—			661			—			83			24			(768		)	—
	Contributions from noncontrolling interests	—			—			—			—			—			684			684
	Distributions to parents	—			(1,080		)	—			(1,310		)	(39		)	2,429			—
	Distributions to noncontrolling interests	—			—			—			—			—			(479		)	(479		)
	Other, net	—			(2		)	—			1			—			1			—
	Net cash (used in) provided by financing activities	(385		)	1,509			(53		)	1,981			135			(2,561		)	626
	Effect of exchange rate changes on cash and cash equivalents	—			—			—			—			(10		)	—			(10		)
Net (decrease) increase in cash and cash equivalents	(27		)	16			(1		)	(11		)	(62		)	—			(85		)
Cash and cash equivalents, beginning of period	83			88			1			17			409			—			598
Cash and cash equivalents, end of period	$	56		$	104		$	—		$	6		$	347		$	—		$	513

General_Organization_Details

General Organization (Details) (USD $)	0 Months Ended	3 Months Ended		11 Months Ended
	Nov. 25, 2014	Mar. 31, 2015	Mar. 31, 2014	Nov. 25, 2014
General [Line Items]
Loss on impairments of equity investments		$26,000,000	$0
Enterprise Market Value		130,000,000,000
Miles Of Pipeline		84,000
Number Of Pipeline Terminals Owned Interest In And Or Operated		180
Loss on impairments of long-lived assets and equity investments		77,000,000	0
Other Significant Noncash Transaction, Value of Consideration Given	77,000,000,000
KMP [Member]
General [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				10.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest				2.00%
EPB [Member]
General [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				39.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest				2.00%
Natural Gas Pipelines [Member]
General [Line Items]
Loss on impairments of long-lived assets and equity investments		77,000,000
Natural Gas Pipelines [Member] | Fort Union Gas Gathering L.L.C. and Bighorn Gas Gathering L.L.C. [Member]
General [Line Items]
Loss on impairments of equity investments		$26,000,000

General_Basis_of_Presentation_

General Basis of Presentation (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Segment Reporting Information [Line Items]
Loss on impairments of long-lived assets and equity investments	$77	$0
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Loss on impairments of long-lived assets and equity investments	77
Loss on impairments of long-lived assets	$51

General_Earnings_Per_Share_Det

General Earnings Per Share (Details) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net Income Attributable to Kinder Morgan, Inc.	$429	$287
Incremental Common Shares Attributable to Dilutive Effect of Warrants	10	0
Diluted Weighted-Average Number of Shares Outstanding	2,151	1,029
Class of Warrant or Right, Exercise Price of Warrants or Rights	$40
Class P [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net (loss) income attributable to Kinder Morgan, Inc.	426	284
Basic Weighted-Average Number of Shares Outstanding	2,141	1,029
Participating Securities [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net (loss) income attributable to Kinder Morgan, Inc.	$3	$3
Restricted Stock [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	7	7
Warrant [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	289	341
Convertible Preferred Stock [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	9	10

General_Recent_Developments_De

General Recent Developments (Details) (Kinder Morgan, Inc. [Member], USD $)	3 Months Ended
In Billions, unless otherwise specified	Mar. 31, 2015
Kinder Morgan, Inc. [Member]
Business Acquisition [Line Items]
Line of Credit Facility, Current Borrowing Capacity	$4
Debt Instrument, Term	5 years

Acquisitions_Acquisitions_Hila

Acquisitions Acquisitions Hiland (Details) (USD $)	3 Months Ended		0 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Feb. 13, 2015
Business Acquisition [Line Items]
Repayments of Debt	$6,305	$4,184
Hiland Partners, LP [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred			3,120
Repayments of Debt			368
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill	$1,507

Acquisitions_Acquisitions_Vopa

Acquisitions Acquisitions Vopak (Details) (Royal Vopak assets [Member], USD $)	0 Months Ended	3 Months Ended
In Millions, unless otherwise specified	Feb. 27, 2015	Mar. 31, 2015
Business Acquisition [Line Items]
Number of terminals	3
Number of Real Estate Properties	1
Payments to Acquire Businesses, Gross	$158	$158
Galena Park, Texas [Member]
Business Acquisition [Line Items]
Area of Land (acres)	36
Storage Capacity (barrels)	1,069,500
NORTH CAROLINA
Business Acquisition [Line Items]
Number of terminals	2
North Wilmington, North Carolina [Member]
Business Acquisition [Line Items]
Number of terminals	1
South Wilmington, North Carolina [Member]
Business Acquisition [Line Items]
Number of terminals	1

Acquisitions_Purchase_Price_Al

Acquisitions Purchase Price Allocation (Details) (USD $)	3 Months Ended	0 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Feb. 27, 2015	Dec. 31, 2014
Business Acquisition [Line Items]
Goodwill	$24,907		$24,654
Hiland Partners, LP [Member]
Business Acquisition [Line Items]
Current assets	44
Property, plant, and equipment	1,521
Goodwill	238
Other intangibles	1,507
Total assets acquired	3,310
Current liabilities	-187
Debt	-1,411
Other liabilities	-3
Cash consideration	1,709
Finite-Lived Intangible Asset, Useful Life	16 years 5 months
Royal Vopak assets [Member]
Business Acquisition [Line Items]
Current assets	3
Property, plant, and equipment	131
Goodwill	29
Other intangibles	0
Total assets acquired	163
Current liabilities	-2
Debt	0
Other liabilities	-3
Cash consideration	$158	$158

Debt_Details

Debt (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014	Feb. 13, 2015	Jan. 01, 2015
Debt Instrument [Line Items]
Preferred interest in general partner of KMP	$100,000,000	$100,000,000
Current portion of debt	3,435,000,000	2,717,000,000
Total long-term debt	41,824,000,000	40,246,000,000
Debt fair value adjustments	2,091,000,000	1,934,000,000
Kinder Morgan, Inc. [Member] | KMI Senior Notes,1.50% through 8.25%, due 2015 through 2098 [Member]
Debt Instrument [Line Items]
Senior Notes	13,330,000,000	11,438,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	1.50%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.25%
Kinder Morgan, Inc. [Member] | Senior unsecured revolving credit facility [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	600,000,000	850,000,000
Kinder Morgan, Inc. [Member] | Commercial Paper [Member]
Debt Instrument [Line Items]
Commercial Paper	296,000,000	386,000,000
Kinder Morgan, Inc. [Member] | Revolving Credit Facility [Member] | KMI Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	1.56%	1.54%
Kinder Morgan Energy Partners, L.P. [Member] | KMP Senior notes, 2.65% through 9.00%, due 2015 through 2044 [Member]
Debt Instrument [Line Items]
Senior Notes	20,360,000,000	20,660,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	2.65%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	9.00%
TGP [Member] | KMP Senior notes, 7.00% through 8.375%, due 2016 through 2037 [Member]
Debt Instrument [Line Items]
Senior Notes	1,790,000,000	1,790,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	7.00%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.38%
EPNG [Member] | KMP 5.95% through 8.625%, due 2017 through 2032 [Member]
Debt Instrument [Line Items]
Senior Notes	1,115,000,000	1,115,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.95%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.63%
Copano Energy, L.L.C. [Member]
Debt Instrument [Line Items]
Long-term Debt	332,000,000	332,000,000
Total long-term debt	384,000,000	386,000,000
Copano Energy, L.L.C. [Member] | KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]
Debt Instrument [Line Items]
Senior Notes	332,000,000	332,000,000
Debt Instrument, Interest Rate, Stated Percentage	7.13%
Colorado Interstate Gas Company, L.L.C. [Member] | KMP Notes, 5.95% through 6.85%, due 2015 through 2037 [Member]
Debt Instrument [Line Items]
Senior Notes	440,000,000	475,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.95%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	6.85%
SNG [Member] | KMP Notes, 4.40% through 8.00%, due 2017 through 2032 [Member]
Debt Instrument [Line Items]
Notes Payable	1,211,000,000	1,211,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	4.40%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.00%
Kinder Morgan Finance Company, LLC [Member] | KMI 5.70% through 6.40% series, due 2016 through 2036 [Member]
Debt Instrument [Line Items]
Senior Notes	1,636,000,000	1,636,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.70%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	6.40%
Hiland Partners Holdings LLC [Member] | KMI Senior Notes, 5.50% and 7.25%, due 2020 and 2022 [Member]
Debt Instrument [Line Items]
Senior Notes	975,000,000	0	975,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.50%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	7.25%
EPC Building LLC [Member] | KMI Promissory note 3.967%, due 2015 through 2035 [Member] [Member]
Debt Instrument [Line Items]
Notes Payable	450,000,000	453,000,000
Debt Instrument, Interest Rate, Stated Percentage	3.97%
Capital Trust I [Member] | KMI EP Capital Trust I 4.75%, due 2028 [Member]
Debt Instrument [Line Items]
Senior Notes	232,000,000	280,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.75%
Kinder Morgan G.P., Inc. [Member] | KMI $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock [Member]
Debt Instrument [Line Items]
Preferred interest in general partner of KMP	100,000,000	100,000,000
Liquidation value of note	$1,000
KMI AND KMP [Member] | Other Miscellaneous Subsidiary Debt [Member]
Debt Instrument [Line Items]
Notes Payable	301,000,000	303,000,000
Kinder Morgan, Inc and Subsidiaries [Member]
Debt Instrument [Line Items]
Long-term Debt	43,168,000,000	41,029,000,000
Total long-term debt	39,733,000,000	38,312,000,000
Financial Guarantee [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Debt Instrument [Line Items]
Indemnified by parent of subsidiary debt				$2,900,000,000
Euro Member Countries, Euro | Senior Notes [Member]
Debt Instrument [Line Items]
Foreign Currency Exchange Rate, Translation	1.0731		1.086

Debt_Credit_Facilities_Details

Debt Credit Facilities (Details) (Kinder Morgan, Inc. [Member], USD $)	3 Months Ended	0 Months Ended
	Mar. 31, 2015	Feb. 13, 2015	Dec. 31, 2014
Line of Credit Facility [Line Items]
Line of Credit Facility, Current Borrowing Capacity	$4,000,000,000
Debt Instrument, Term	5 years
Line of Credit Facility, Remaining Borrowing Capacity	2,976,000,000
Letters of Credit Outstanding, Amount	128,000,000
Senior unsecured revolving credit facility [Member]
Line of Credit Facility [Line Items]
Long-term Line of Credit	600,000,000		850,000,000
Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper	296,000,000		386,000,000
Commercial Paper, Current Borrowing Capacity	4,000,000,000
Bridge Loan [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Term		6 months
Line of Credit Facility, Maximum Amount Outstanding During Period		$1,641,000,000

Debt_Hiland_Debt_Acquired_Deta

Debt Hiland Debt Acquired (Details) (USD $)	3 Months Ended		0 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Feb. 13, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Repayments of Debt	$6,305	$4,184
Hiland Partners Holdings LLC [Member] | KMI Senior Notes, 5.50% and 7.25%, due 2020 and 2022 [Member]
Debt Instrument [Line Items]
Senior Notes	975		975	0
KMI Acquisition of Hiland Partners Holding LLC [Member] | Hiland Partners Holdings LLC [Member] | KMI Senior Notes, 5.50% and 7.25%, due 2020 and 2022 [Member]
Debt Instrument [Line Items]
Debt Instrument, Fair Value Disclosure			1,043
Hiland Partners, LP [Member]
Debt Instrument [Line Items]
Repayments of Debt			$368

Debt_Issuances_and_Repaymenrts

Debt Issuances and Repaymenrts (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Feb. 13, 2015
Debt Instrument [Line Items]
Repayments of Debt	$6,305	$4,184
Kinder Morgan, Inc. [Member] | KMI 5.05% Senior Notes Due 2046 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt	800
Debt Instrument, Interest Rate, Stated Percentage	5.05%
Kinder Morgan, Inc. [Member] | KMI 1.50% Senior Notes Due 2022 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt	815
Debt Instrument, Interest Rate, Stated Percentage	1.50%
Kinder Morgan, Inc. [Member] | KMI 2.25% Senior Notes Due 2027 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt	543
Debt Instrument, Interest Rate, Stated Percentage	2.25%
Kinder Morgan, Inc. [Member] | KMI 5.15% Senior Notes due March 1, 2015 [Member]
Debt Instrument [Line Items]
Repayments of Debt	250
Debt Instrument, Interest Rate, Stated Percentage	5.15%
Kinder Morgan Energy Partners, L.P. [Member] | KMP 5.625% Senior Notes due February 15, 2015 [Member]
Debt Instrument [Line Items]
Repayments of Debt	$300
Debt Instrument, Interest Rate, Stated Percentage	5.63%
Euro Member Countries, Euro | Senior Notes [Member]
Debt Instrument [Line Items]
Foreign Currency Exchange Rate, Translation	1.0731		1.086

Stockholders_Equity_Common_Equ

Stockholders' Equity Common Equity (Details) (USD $)	3 Months Ended		0 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Apr. 16, 2015	Apr. 06, 2015	Dec. 19, 2014
Class of Stock [Line Items]
Stock Issued During Period, Value, New Issues	$1,626
Class P [Member]
Class of Stock [Line Items]
Stock Issued During Period, Shares, New Issues	39,000,000
Dividends Per Common Share Declared for the Period	$0.48	$0.42
Common Stock, Dividends, Per Share, Cash Paid	$0.45	$0.41
Dividend Declared [Member]
Class of Stock [Line Items]
Dividends Per Common Share Declared for the Period			$0.48
Equity distribution agreement [Member] | Class P [Member]
Class of Stock [Line Items]
Value of Stock Available for Sale Under Equity Distribution Agreement					5,000
Stock Issued During Period, Shares, New Issues	39,398,245
Sold Shares of Class P Stock	39,398,245
Stock Issued During Period, Value, New Issues	$1,738
Equity distribution agreement [Member] | Subsequent Event [Member] | Class P [Member]
Class of Stock [Line Items]
Stock Issued During Period, Shares, New Issues				2,692,672

Risk_Management_Energy_Commodi

Risk Management Energy Commodity Price Risk Management (Details) (Energy Related Derivative [Member], Forward Contracts [Member])	Mar. 31, 2015
	MMBbls
Crude Oil Fixed Price [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-12.8
Crude Oil Fixed Price [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-14.2
Crude Oil Basis [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-12.1
Crude Oil Basis [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-0.3
Natural Gas Fixed Price [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-50.7
Natural Gas Fixed Price [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-17.9
Natural Gas Basis [Member] | Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-25.9
Natural Gas Basis [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-16.5
Natural Gas Liquids Fixed Price [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Net open position long/(short)	-52.7

Risk_Management_Interest_Rate_

Risk Management Interest Rate Risk Management (Details) (Interest Rate Swap [Member], USD $)	1 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014	Mar. 30, 2015
Derivative [Line Items]
Derivative, Notional Amount	$9,700	$9,200
KMI 5.625% Senior Notes due November 15, 2023 [Member]
Derivative [Line Items]
Derivative, Notional Amount			600
Number of Fixed-to-Variable Interest Rate Swap Agreements Entered Into	$0
Interest rate, stated percentage	5.63%

Risk_Management_Risk_Managemen

Risk Management Risk Management Foreign Currency Risk Management (Details)	3 Months Ended
	Mar. 31, 2015
KMI 1.50% Senior Notes Due 2022 [Member] | Currency Swap [Member]
Derivative [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.79%
KMI 2.25% Senior Notes Due 2027 [Member] | Currency Swap [Member]
Derivative [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.67%
Kinder Morgan, Inc. [Member]
Derivative [Line Items]
Debt Instrument, Term	5 years
Kinder Morgan, Inc. [Member] | KMI 1.50% Senior Notes Due 2022 [Member]
Derivative [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	1.50%
Debt Instrument, Term	7 years
Kinder Morgan, Inc. [Member] | KMI 2.25% Senior Notes Due 2027 [Member]
Derivative [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.25%
Debt Instrument, Term	12 years

Risk_Management_Fair_Value_of_

Risk Management Fair Value of Derivative Contracts (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Designated as Hedging Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	$862	$718
Derivative Liability, Fair Value, Net	-124	-87
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	1,109	997
Derivative Liability, Fair Value, Net	-186	-162
Energy Related Derivative [Member] | Designated as Hedging Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	362	315
Derivative Liability, Fair Value, Net	-65	-34
Energy Related Derivative [Member] | Designated as Hedging Contracts [Member] | Fair Value of Derivatives Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	318	309
Energy Related Derivative [Member] | Designated as Hedging Contracts [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-63	-34
Energy Related Derivative [Member] | Designated as Hedging Contracts [Member] | Non-current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	44	6
Energy Related Derivative [Member] | Designated as Hedging Contracts [Member] | Other Long-Term Liabilities and Deferred Credits [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-2	0
Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	236	269
Derivative Liability, Fair Value, Net	-2	-2
Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Fair Value of Derivatives Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	62	73
Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-1	-2
Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Non-current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	174	196
Energy Related Derivative [Member] | Not Designated as Hedging Instrument [Member] | Other Long-Term Liabilities and Deferred Credits [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-1	0
Interest Rate Swap [Member] | Designated as Hedging Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	500	403
Derivative Liability, Fair Value, Net	-5	-53
Currency Swap [Member] | Designated as Hedging Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	0	0
Derivative Liability, Fair Value, Net	-54	0
Power Derivative Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	11	10
Derivative Liability, Fair Value, Net	-60	-73
Power Derivative Contract [Member] | Not Designated as Hedging Instrument [Member] | Fair Value of Derivatives Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	10	10
Power Derivative Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-56	-57
Power Derivative Contract [Member] | Not Designated as Hedging Instrument [Member] | Non-current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	1	0
Power Derivative Contract [Member] | Not Designated as Hedging Instrument [Member] | Other Long-Term Liabilities and Deferred Credits [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-4	-16
Commodity Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	247	279
Derivative Liability, Fair Value, Net	-62	-75
Fair Value Hedging [Member] | Interest Rate Swap [Member] | Designated as Hedging Contracts [Member] | Fair Value of Derivatives Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	171	143
Fair Value Hedging [Member] | Interest Rate Swap [Member] | Designated as Hedging Contracts [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	0	0
Fair Value Hedging [Member] | Interest Rate Swap [Member] | Designated as Hedging Contracts [Member] | Non-current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	329	260
Fair Value Hedging [Member] | Interest Rate Swap [Member] | Designated as Hedging Contracts [Member] | Other Long-Term Liabilities and Deferred Credits [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-5	-53
Fair Value Hedging [Member] | Currency Swap [Member] | Designated as Hedging Contracts [Member] | Fair Value of Derivatives Contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	0	0
Fair Value Hedging [Member] | Currency Swap [Member] | Designated as Hedging Contracts [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	-31	0
Fair Value Hedging [Member] | Currency Swap [Member] | Designated as Hedging Contracts [Member] | Non-current-Fair value of derivative contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Net	0	0
Fair Value Hedging [Member] | Currency Swap [Member] | Designated as Hedging Contracts [Member] | Other Long-Term Liabilities and Deferred Credits [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Net	($23)	$0

Risk_Management_Effect_of_Deri

Risk Management Effect of Derivative Contracts on the Income Statement (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Energy Related Derivative [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$46	$0
Derivative, Loss on Derivative	5
Energy Related Derivative [Member] | Natural Gas Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	4	-7
Energy Related Derivative [Member] | Revenues - Product sales and other [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	45	-1
Energy Related Derivative [Member] | Gas purchases and other costs of sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-3	10
Energy Related Derivative [Member] | Other Income (Expense) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0	-2
Designated as Hedging Instrument [Member] | Operating Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	72	-14
Amount of gain/(loss)recognized in incomeon derivative(ineffective portionand amountexcluded fromeffectiveness testing)	7	-5
Designated as Hedging Instrument [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)recognized in OCI on derivative(effective portion)	-2	-45
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Interest expense [Member] | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss) recognized in income on derivative	145	55
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Interest expense [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	-1	0
Amount of gain/(loss)recognized in incomeon derivative(ineffective portionand amountexcluded fromeffectiveness testing)	0	0
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)recognized in OCI on derivative(effective portion)	-3	-2
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Interest expense [Member] | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss) recognized in income on derivative	-139	-55
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Loss to be reclassified within twelve months		175
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Natural Gas Revenue [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	24	-9
Amount of gain/(loss)recognized in incomeon derivative(ineffective portionand amountexcluded fromeffectiveness testing)	0	0
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Revenues - Product sales and other [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	64	-6
Amount of gain/(loss)recognized in incomeon derivative(ineffective portionand amountexcluded fromeffectiveness testing)	7	-5
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Gas purchases and other costs of sales [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	-5	1
Amount of gain/(loss)recognized in incomeon derivative(ineffective portionand amountexcluded fromeffectiveness testing)	0	0
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)recognized in OCI on derivative(effective portion)	35	-43
Designated as Hedging Instrument [Member] | Currency Swap [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)recognized in OCI on derivative(effective portion)	-34	0
Designated as Hedging Instrument [Member] | Other Credit Derivatives [Member] | Other Expense [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	($10)	$0

Risk_Management_Credit_Risks_D

Risk Management Credit Risks (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
Energy Related Derivative [Member]
Credit Derivatives [Line Items]
Letters of Credit Outstanding, Amount	$20,000,000	$20,000,000
Energy Related Derivative [Member] | One notch credit downgrade [Member]
Credit Derivatives [Line Items]
Additional Collateral, Aggregate Fair Value	1,000,000
Energy Related Derivative [Member] | Two notch credit downgrade [Member]
Credit Derivatives [Line Items]
Additional Collateral, Aggregate Fair Value	0
Contract and Over the Counter [Member] | Interest Rate Swap [Member]
Credit Derivatives [Line Items]
Derivative, Collateral, Right to Reclaim Cash	0	0
Contract and Over the Counter [Member] | Energy Related Derivative [Member]
Credit Derivatives [Line Items]
Derivative, Collateral, Right to Reclaim Cash	$44,000,000	$47,000,000

Risk_Management_Reporting_of_A

Risk Management Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	$327	($3)
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	-108	2
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	-236	-23
Accumulated other comprehensive loss	-17	-24
Other Comprehensive Income Unrealized Gain Loss On Derivatives Arising During Period Net Of Tax Portion Attributable To Parent	-2	-19
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	-72	6
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-74	-13
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Gain (Loss) Arising During Period, Net of Tax	-108	-25
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Net of Tax	0	0
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment and Impact of Merger Transactions, Net of Tax, Portion Attributable to Parent	-108	-25
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Reclassification Adjustments, Net of Tax	6	0
Other Comprehensive Income Loss Reclassification Adjustment From AOCI Pension And Other Postretiremen tBenefit Plans Net Of Tax Portion Attributable To Parent	0	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax	6	0
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	-176	-38
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	253	-16
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	-216	-23
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	-230	-23
Accumulated other comprehensive loss	-193	-62
OCI before Reclassifications [Member]
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Roll Forward]
Other comprehensive income (loss) before reclassifications, net of tax, portion attributable to parent	-104	-44
Amounts reclassified from AOCI [Member]
Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income [Roll Forward]
Other comprehensive income reclassified from accumulated other comprehensive income, net of tax, portion attributable to parent	($72)	$6

Fair_Value_Fair_Value_of_Deriv

Fair Value Fair Value of Derivative Contracts (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	$609		$594
Derivative Liability	-127		-109
Fair Value, Assets Liabilites Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	-61	-110
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	0	7
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)	0	-1
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	12	4
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	-49	-100
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	1	3
Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	500		403
Derivative Liability	-5		-53
Currency Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	-54
Quoted prices in active markets for identical assets (Level 1) [Member] | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	39		49
Derivative Liability	-26		-25
Quoted prices in active markets for identical assets (Level 1) [Member] | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0		0
Derivative Liability	0		0
Quoted prices in active markets for identical assets (Level 1) [Member] | Currency Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	0
Significant other observable inputs (Level 2) [Member] | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	559		533
Derivative Liability	-41		-11
Significant other observable inputs (Level 2) [Member] | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	500		403
Derivative Liability	-5		-53
Significant other observable inputs (Level 2) [Member] | Currency Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	-54
Significantunobservable inputs (Level 3) [Member] | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	11		12
Derivative Liability	-60		-73
Significantunobservable inputs (Level 3) [Member] | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0		0
Derivative Liability	0		0
Significantunobservable inputs (Level 3) [Member] | Currency Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	0
Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	539		535
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	-13		-16
Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	497		359
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	-2		-9
Currency Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	-54
Not Offset on Balance Sheet [Member] | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Asset Adjustment for Financial Instruments subject to Master Netting Agreement but Presented Gross	-70		-46
Net Liability Adjustment for Financial Instruments Subject to Master Netting Agreement but Presented Gross	70		46
Not Offset on Balance Sheet [Member] | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Asset Adjustment for Financial Instruments subject to Master Netting Agreement but Presented Gross	-3		-44
Net Liability Adjustment for Financial Instruments Subject to Master Netting Agreement but Presented Gross	3		44
Not Offset on Balance Sheet [Member] | Currency Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Liability Adjustment for Financial Instruments Subject to Master Netting Agreement but Presented Gross	0
Contract and Over the Counter [Member] | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative, Collateral, Obligation to Return Cash	0		-13
Derivative, Collateral, Right to Reclaim Cash	44		47
Contract and Over the Counter [Member] | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative, Collateral, Obligation to Return Cash	0		0
Derivative, Collateral, Right to Reclaim Cash	0		0
Contract and Over the Counter [Member] | Currency Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative, Collateral, Right to Reclaim Cash	$0

Fair_Value_Fair_Value_of_Finan

Fair Value Fair Value of Financial Instruments (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Estimate of Fair Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	$46,480	$43,582
Reported Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	$45,259	$42,963

Reportable_Segments_Details

Reportable Segments (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Revenues	$3,597	$4,047
Segment earnings before DD&A	1,902	1,906
Depreciation, depletion and amortization	-538	-496
Amortization of excess cost of equity investments	-12	-10
Product sales and other	842	1,121
General and administrative expenses	-216	-172
Interest, net	-512	-448
Income Tax Expense (Benefit)	-224	-200
Net income	419	601
Assets	86,164		83,198
Assets held for sale	29		56
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Revenues	2,177	2,557
Segment earnings before DD&A	1,015	1,070
Assets	54,539		52,523
CO2 [Member]
Segment Reporting Information [Line Items]
Revenues	446	483
Segment earnings before DD&A	336	363
Assets	5,318		5,227
Terminals [Member]
Segment Reporting Information [Line Items]
Revenues	457	391
Segment earnings before DD&A	270	210
Assets	9,071		8,850
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Revenues	444	534
Segment earnings before DD&A	246	208
Assets	8,364		7,179
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Revenues	60	69
Segment earnings before DD&A	41	48
Assets	1,480		1,593
All Other Segments [Member]
Segment Reporting Information [Line Items]
Revenues	4	4
Segment earnings before DD&A	-6	7
Assets	443		459
Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenues	3,591	4,042
Assets	79,215		75,831
Unallocated [Member]
Segment Reporting Information [Line Items]
Product sales and other	9	9
Interest, net	-514	-450
Income Tax Expense (Benefit)	-212	-186
Corporate [Member]
Segment Reporting Information [Line Items]
Assets	6,920		7,311
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	-3	-4
Intersegment Revenues [Member] | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Revenues	$3	$4

Pension_and_Other_Postretireme2

Pension and Other Postretirement Benefit Plans (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$6	$7
Interest cost	24	27
Expected return on assets	-43	-43
Amortization of prior service credits	0	0
Amortization of net actuarial loss	1	0
Net benefit plan credit	-12	-9
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	0
Interest cost	6	7
Expected return on assets	-6	-6
Amortization of prior service credits	-1	-1
Amortization of net actuarial loss	0	0
Net benefit plan credit	($1)	$0

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Operating Loss Carryforwards [Line Items]
Income Tax Expense (Benefit)	$224	$200
Effective tax rate	34.80%	25.00%
Federal statutory income tax rate	35.00%	35.00%
Florida Gas Pipeline [Member]
Operating Loss Carryforwards [Line Items]
Ownership interest	50.00%	50.00%

Federal_Energy_Regulatory_Comm

Federal Energy Regulatory Commission Proceedings (Details) (Regulated Operation [Member], Federal Energy Regulatory Commission [Member], Various Shippers [Member], Unfavorable Regulatory Action [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015
SFPP [Member] | Repreations, Refunds, and Rate Reductions [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency Period of Time Litigation Concerns	2 years
SFPP [Member] | Annual Rate Reductions [Member] | Pending Litigation [Member]
SFPP [Abstract]
Loss Contingency, Damages Sought, Value	20
SFPP [Member] | Revenue Subject to Refund [Member] | Pending Litigation [Member]
SFPP [Abstract]
Loss Contingency, Damages Sought, Value	110
2008 rate case and the 2010 rate case [Member] | EPNG [Member] | Opinion 517 issued and implemented (rehearing pending); and Opinion 528 issued and is awaiting filing of court document) [Member]
EPNG [Abstract]
Loss Contingency, Pending Claims, Number	2

California_Public_Utilities_Co

California Public Utilities Commission Proceedings (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Loss Contingencies [Line Items]
Accrued contingencies	$399	$383
Regulated Operation [Member] | Revenue Subject to Refund [Member] | SFPP [Member] | Various Shippers [Member] | California Public Utilities Commission [Member] | Unfavorable Regulatory Action [Member] | Settled Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	319
Letter of Credit [Member] | SFPP [Member] | California Public Utilities Commission [Member]
Loss Contingencies [Line Items]
Accrued contingencies	$100

Other_Commercial_Matters_Detai

Other Commercial Matters (Details) (USD $)	9 Months Ended	0 Months Ended	3 Months Ended	1 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Oct. 25, 2013	Mar. 31, 2015	Mar. 31, 2011
Plains Gas Solutions, LLC v. Tennessee Gas Pipeline Company, L.L.C. et al [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	$100
Merger Transactions [Member] | Kinder Morgan Energy Partners, L.P. and El Paso Pipeline Partners, L.P. [Member]
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number			5
Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member] | SFPP L.P. [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value		22.3
Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member] | SFPP L.P. [Member] | Loss on Long-term Purchase Commitment [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Initial Award Amount, Annual Rent Payable			14
SFPP, L.P. vs. UPRR on relocation costs [Member] | SFPP L.P. [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss contingency, settlement tentative by court, value			42.5
Price Reporting Litigation [Member] | Kinder Morgan Bulk Terminals, Inc. [Member] | Price Reporting Litigation [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value			$140
EPB Acquisition of 25% Ownership Interest in SNG [Member] | Allen vs El Paso GP [Member] | El Paso Pipeline Partners, L.P. [Member] | SNG [Member]
Loss Contingencies [Line Items]
Business Acquisition, Additional Percentage of Interest Acquired				25.00%
2014 - 2023 [Member] | Union Pacific Railroad Company v. Santa Fe Pacific Pipelines, Inc., SFPP, L.P., Kinder Morgan Operating L.P. “D”, Kinder Morgan G.P., Inc., et al. [Member] | SFPP L.P. [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Lessee Leasing Arrangements, Operating Leases, Term of Contract		10 years

Litigation_Environmental_and_O1

Litigation, Environmental and Other Contingencies Litigation General (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Loss Contingencies [Line Items]
Estimated Litigation Liability	$518	$400
SFPP [Member] | Revenue Subject to Refund [Member] | California Public Utilities Commission [Member] | Various Shippers [Member] | Regulated Operation [Member] | Unfavorable Regulatory Action [Member] | Settled Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	$319

Environmental_Matters_Details

Environmental Matters (Details) (USD $)	240 Months Ended	0 Months Ended	3 Months Ended	1 Months Ended	12 Months Ended	1 Months Ended	0 Months Ended
In Millions, unless otherwise specified	Dec. 31, 1969	Aug. 06, 2013	Mar. 31, 2015	Aug. 31, 2007	Dec. 31, 2010	Dec. 31, 2000	Jul. 24, 2013	Nov. 08, 2013	Dec. 31, 2014
						Terminals
Loss Contingencies [Line Items]
Accrual for environmental loss contingencies			$332						$340
Environmental recoveries receivable			14						14
Rare Metals Inc. [Member]
Loss Contingencies [Line Items]
Number of Uranium Mines	20
Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona [Member] | Pending Litigation [Member] | SFPP Phoenix Terminal [Member] | Unfavorable Regulatory Action [Member] | KMEP and SFPP [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value			175
Loss Contingency, Number of Defendants		26	70
United States District Court, Southern District of California, case number 07CV1883WCAB [Member] | Pending Litigation [Member] | Mission Valley Terminal Facility [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value				170	365
Lower Passaic River Study Area [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Number of Parties at a Joint Defense Group			70
Number of Facilities			100
Portland Harbor Superfund Site, Willamette River, Portland, Oregon [Member] | Environmental Protection Agency [Member] | Regulated Operation [Member] | Portland Harbor Superfund Site, Willamette River, Portland, Oregon [Member] | GATX Terminals Corporation (n/k/a KMLT) [Member]
Loss Contingencies [Line Items]
Number of Liquid Terminals			4			2
Number of Parties Involved In Site Cleanup Allocation Negotiations			90
Southeast Louisiana Flood Protection Litigation [Member] | Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East [Member] | TGP and SNG [Member]
Loss Contingencies [Line Items]
Loss Contingency, Number of Defendants							100
Plaquemines Parish, Louisiana (Docket No. 60-999) [Member] | Parish of Plaquemines, Louisiana [Member] | Bastian Bay, Buras, Empire and Fort Jackson oil and gas fields of Plaquemines Parish [Member] | Tennessee Gas Pipeline Company LLC [Member]
Loss Contingencies [Line Items]
Loss Contingency, Number of Defendants								17
Minimum [Member] | Lower Passaic River Study Area [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense			365
Maximum [Member] | Lower Passaic River Study Area [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense			3,200
Preferred alternative [Member] | Lower Passaic River Study Area [Member] | Pending Litigation [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense			$1,700

Guarantee_of_Securities_of_Sub2

Guarantee of Securities of Subsidiaries (Details Textual) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Subsidiary Issuer and Guarantor-KMP [Member]
Long-term Debt	$20,360	$20,660
Subsidiary Issuer and Guarantor-Copano [Member]
Long-term Debt	332	332
Subsidiary Guarantors [Member]
Long-term Debt	7,401	6,463
Capitalized Lease Debt Not Subject to Cross Guarantee Agreement	177	178
Parent Issuer and Guarantor [Member]
Long-term Debt	$14,226	$12,674

Guarantee_of_Securities_of_Sub3

Guarantee of Securities of Subsidiaries Condensed Consolidated Statements of Income and Comprehensive Income (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Condensed Income Statements, Captions [Line Items]
Total Revenues	$3,597	$4,047
Depreciation, depletion and amortization	538	496
Other operating expenses	4	-4
Total Operating Costs, Expenses and Other	2,519	2,900
Operating (loss) income	-1,078	-1,147
Earnings from equity investments	102	99
Interest, net	-512	-448
Amortization of excess cost of equity investments and other, net	13	13
Income Tax Expense (Benefit)	-224	-200
Net Income	419	601
Net Loss (Income) Attributable to Noncontrolling Interests	10	-314
Net Income Attributable to Kinder Morgan, Inc.	429	287
Total other comprehensive loss	-176	-94
Comprehensive income (loss)	243	507
Comprehensive income (loss) attributable to noncontrolling interests	10	-258
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	253	249
Consolidating Adjustments [Member]
Condensed Income Statements, Captions [Line Items]
Total Revenues	-13	2
Cost of sales	0	14
Depreciation, depletion and amortization	0	0
Other operating expenses	-13	-12
Total Operating Costs, Expenses and Other	-13	2
Operating (loss) income	0	0
Earnings (losses) from consolidated subsidiaries	-2,029	-2,312
Earnings from equity investments	0	0
Interest, net	0	0
Amortization of excess cost of equity investments and other, net	0	0
Income (loss) before income taxes	-2,029	-2,312
Income Tax Expense (Benefit)	0	0
Net Income	-2,029	-2,312
Net Loss (Income) Attributable to Noncontrolling Interests	10	-196
Net Income Attributable to Kinder Morgan, Inc.	-2,019	-2,508
Total other comprehensive loss	697	329
Comprehensive income (loss)	-1,332	-1,983
Comprehensive income (loss) attributable to noncontrolling interests	10	-152
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-1,322	-2,135
Parent Issuer and Guarantor [Member]
Condensed Income Statements, Captions [Line Items]
Total Revenues	9	9
Cost of sales	0	0
Depreciation, depletion and amortization	5	5
Other operating expenses	12	8
Total Operating Costs, Expenses and Other	17	13
Operating (loss) income	8	4
Earnings (losses) from consolidated subsidiaries	605	506
Earnings from equity investments	0	0
Interest, net	-104	-132
Amortization of excess cost of equity investments and other, net	0	0
Income (loss) before income taxes	493	370
Income Tax Expense (Benefit)	-64	-34
Net Income	429	336
Net Loss (Income) Attributable to Noncontrolling Interests	0	-49
Net Income Attributable to Kinder Morgan, Inc.	429	287
Total other comprehensive loss	-176	-49
Comprehensive income (loss)	253	287
Comprehensive income (loss) attributable to noncontrolling interests	0	-38
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	253	249
Subsidiary Issuer and Guarantor-KMP [Member]
Condensed Income Statements, Captions [Line Items]
Total Revenues	0	0
Cost of sales	0	0
Depreciation, depletion and amortization	0	0
Other operating expenses	38	1
Total Operating Costs, Expenses and Other	38	1
Operating (loss) income	38	1
Earnings (losses) from consolidated subsidiaries	883	947
Earnings from equity investments	0	0
Interest, net	-27	-24
Amortization of excess cost of equity investments and other, net	0	0
Income (loss) before income taxes	818	922
Income Tax Expense (Benefit)	-2	-3
Net Income	816	919
Net Loss (Income) Attributable to Noncontrolling Interests	0	-69
Net Income Attributable to Kinder Morgan, Inc.	816	850
Total other comprehensive loss	-238	-118
Comprehensive income (loss)	578	801
Comprehensive income (loss) attributable to noncontrolling interests	0	-68
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	578	733
Subsidiary Issuer and Guarantor-Copano [Member]
Condensed Income Statements, Captions [Line Items]
Total Revenues	0	0
Cost of sales	0	0
Depreciation, depletion and amortization	0	0
Other operating expenses	1	7
Total Operating Costs, Expenses and Other	1	7
Operating (loss) income	1	7
Earnings (losses) from consolidated subsidiaries	-23	44
Earnings from equity investments	0	0
Interest, net	-12	-11
Amortization of excess cost of equity investments and other, net	0	0
Income (loss) before income taxes	-36	26
Income Tax Expense (Benefit)	0	0
Net Income	-36	26
Net Loss (Income) Attributable to Noncontrolling Interests	0	0
Net Income Attributable to Kinder Morgan, Inc.	-36	26
Total other comprehensive loss	0	0
Comprehensive income (loss)	-36	26
Comprehensive income (loss) attributable to noncontrolling interests	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-36	26
Subsidiaries Guarantors [Member]
Condensed Income Statements, Captions [Line Items]
Total Revenues	3,226	3,630
Cost of sales	1,001	1,497
Depreciation, depletion and amortization	442	399
Other operating expenses	685	639
Total Operating Costs, Expenses and Other	2,128	2,535
Operating (loss) income	-1,098	-1,095
Earnings (losses) from consolidated subsidiaries	548	359
Earnings from equity investments	76	99
Interest, net	-355	-250
Amortization of excess cost of equity investments and other, net	-3	-7
Income (loss) before income taxes	1,364	1,296
Income Tax Expense (Benefit)	-157	-11
Net Income	1,207	1,285
Net Loss (Income) Attributable to Noncontrolling Interests	0	0
Net Income Attributable to Kinder Morgan, Inc.	1,207	1,285
Total other comprehensive loss	-295	-146
Comprehensive income (loss)	912	1,139
Comprehensive income (loss) attributable to noncontrolling interests	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	912	1,139
Subsidiary Non-Guarantors [Member]
Condensed Income Statements, Captions [Line Items]
Total Revenues	375	406
Cost of sales	89	132
Depreciation, depletion and amortization	91	92
Other operating expenses	168	118
Total Operating Costs, Expenses and Other	348	342
Operating (loss) income	-27	-64
Earnings (losses) from consolidated subsidiaries	16	456
Earnings from equity investments	0	0
Interest, net	-14	-31
Amortization of excess cost of equity investments and other, net	4	10
Income (loss) before income taxes	33	499
Income Tax Expense (Benefit)	-1	-152
Net Income	32	347
Net Loss (Income) Attributable to Noncontrolling Interests	0	0
Net Income Attributable to Kinder Morgan, Inc.	32	347
Total other comprehensive loss	-164	-110
Comprehensive income (loss)	-132	237
Comprehensive income (loss) attributable to noncontrolling interests	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-132	237
Consolidated KMI [Member]
Condensed Income Statements, Captions [Line Items]
Total Revenues	3,597	4,047
Cost of sales	1,090	1,643
Depreciation, depletion and amortization	538	496
Other operating expenses	891	761
Total Operating Costs, Expenses and Other	2,519	2,900
Operating (loss) income	-1,078	-1,147
Earnings (losses) from consolidated subsidiaries	0	0
Earnings from equity investments	76	99
Interest, net	-512	-448
Amortization of excess cost of equity investments and other, net	1	3
Income (loss) before income taxes	643	801
Income Tax Expense (Benefit)	-224	-200
Net Income	419	601
Net Loss (Income) Attributable to Noncontrolling Interests	10	-314
Net Income Attributable to Kinder Morgan, Inc.	429	287
Total other comprehensive loss	-176	-94
Comprehensive income (loss)	243	507
Comprehensive income (loss) attributable to noncontrolling interests	10	-258
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$253	$249

Guarantee_of_Securities_of_Sub4

Guarantee of Securities of Subsidiaries Condensed Consolidating Balance Sheets (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	$259	$315	$513	$598
Other current assets	540	746
Property, plant and equipment, net	40,289	38,564
Investments	6,011	6,036
Goodwill	24,907	24,654
Deferred tax assets	5,545	5,651
Other non-current assets	2,361	2,239
Total Assets	86,164	83,198
Long-term debt	41,824	40,246
Total Liabilities	50,805	48,772
Total KMI equity	35,029	34,076
Noncontrolling interests	330	350
Total stockholders' equity	35,359	34,426	28,434	28,285
Total liabilities and stockholders' equity	86,164	83,198
Consolidating Adjustments [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	0	0	0	0
Other current assets	-13	-20
Property, plant and equipment, net	0	0
Investments	0	0
Investments in subsidiaries	-86,345	-87,902
Goodwill	0	0
Notes receivable from affiliates	-29,762	-27,202
Deferred tax assets	-3,614	-3,605
Other non-current assets	0	0
Total Assets	-137,962	-133,919
Current portion of debt	0	0
Other current liabilities	-13	-20
Long-term debt	0	0
Notes payable to affiliates	-29,762	-27,202
Deferred income taxes	-3,614	-3,605
All other long-term liabilities and deferred credits	0	0
Total Liabilities	-51,617	-46,017
Total KMI equity	-86,675	-88,252
Noncontrolling interests	330	350
Total stockholders' equity	-86,345	-87,902
Total liabilities and stockholders' equity	-137,962	-133,919
Parent Issuer and Guarantor [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	13	4	56	83
Other current assets	202	397
Property, plant and equipment, net	277	263
Investments	16	16
Investments in subsidiaries	32,381	31,372
Goodwill	15,089	15,087
Notes receivable from affiliates	4,590	4,459
Deferred tax assets	0	0
Other non-current assets	310	287
Total Assets	56,016	53,753
Current portion of debt	963	1,486
Other current liabilities	302	319
Long-term debt	13,965	11,862
Notes payable to affiliates	2,542	2,619
Deferred income taxes	2,126	2,099
All other long-term liabilities and deferred credits	538	583
Total Liabilities	20,987	19,677
Total KMI equity	35,029	34,076
Noncontrolling interests	0	0
Total stockholders' equity	35,029	34,076
Total liabilities and stockholders' equity	56,016	53,753
Subsidiary Issuer and Guarantor-KMP [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	15	15	104	88
Other current assets	153	152
Property, plant and equipment, net	0	0
Investments	2	1
Investments in subsidiaries	31,011	33,414
Goodwill	22	22
Notes receivable from affiliates	22,593	19,832
Deferred tax assets	0	0
Other non-current assets	449	360
Total Assets	56,078	55,131
Current portion of debt	875	699
Other current liabilities	224	498
Long-term debt	20,271	20,675
Notes payable to affiliates	448	153
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	175	78
Total Liabilities	35,410	34,052
Total KMI equity	20,668	21,079
Noncontrolling interests	0	0
Total stockholders' equity	20,668	21,079
Total liabilities and stockholders' equity	56,078	55,131
Subsidiary Issuer and Guarantor-Copano [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	0	0	0	1
Other current assets	1	3
Property, plant and equipment, net	1	5
Investments	0	0
Investments in subsidiaries	1,888	1,911
Goodwill	920	920
Notes receivable from affiliates	0	0
Deferred tax assets	0	0
Other non-current assets	0	0
Total Assets	2,828	2,850
Current portion of debt	0	0
Other current liabilities	16	12
Long-term debt	384	386
Notes payable to affiliates	606	753
Deferred income taxes	2	2
All other long-term liabilities and deferred credits	0	2
Total Liabilities	1,284	1,270
Total KMI equity	1,544	1,580
Noncontrolling interests	0	0
Total stockholders' equity	1,544	1,580
Total liabilities and stockholders' equity	2,828	2,850
Subsidiaries Guarantors [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	40	17	6	17
Other current assets	2,354	2,547
Property, plant and equipment, net	31,462	29,490
Investments	5,885	5,910
Investments in subsidiaries	17,741	17,868
Goodwill	5,688	5,419
Notes receivable from affiliates	2,256	2,415
Deferred tax assets	9,159	9,256
Other non-current assets	5,236	3,782
Total Assets	92,486	88,277
Current portion of debt	1,471	381
Other current liabilities	2,105	1,812
Long-term debt	6,510	6,609
Notes payable to affiliates	24,784	22,437
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	989	987
Total Liabilities	39,202	33,777
Total KMI equity	53,284	54,500
Noncontrolling interests	0	0
Total stockholders' equity	53,284	54,500
Total liabilities and stockholders' equity	92,486	88,277
Subsidiary Non-Guarantors [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	191	279	347	409
Other current assets	333	358
Property, plant and equipment, net	8,549	8,806
Investments	108	109
Investments in subsidiaries	3,324	3,337
Goodwill	3,188	3,206
Notes receivable from affiliates	323	496
Deferred tax assets	0	0
Other non-current assets	128	112
Total Assets	16,718	17,106
Current portion of debt	126	151
Other current liabilities	715	1,024
Long-term debt	694	714
Notes payable to affiliates	1,382	1,240
Deferred income taxes	1,486	1,504
All other long-term liabilities and deferred credits	495	514
Total Liabilities	5,539	6,013
Total KMI equity	11,179	11,093
Noncontrolling interests	0	0
Total stockholders' equity	11,179	11,093
Total liabilities and stockholders' equity	16,718	17,106
Consolidated KMI [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Cash and cash equivalents	259	315	513	598
Other current assets	3,030	3,437
Property, plant and equipment, net	40,289	38,564
Investments	6,011	6,036
Investments in subsidiaries	0	0
Goodwill	24,907	24,654
Notes receivable from affiliates	0	0
Deferred tax assets	5,545	5,651
Other non-current assets	6,123	4,541
Total Assets	86,164	83,198
Current portion of debt	3,435	2,717
Other current liabilities	3,349	3,645
Long-term debt	41,824	40,246
Notes payable to affiliates	0	0
Deferred income taxes	0	0
All other long-term liabilities and deferred credits	2,197	2,164
Total Liabilities	50,805	48,772
Total KMI equity	35,029	34,076
Noncontrolling interests	330	350
Total stockholders' equity	35,359	34,426
Total liabilities and stockholders' equity	86,164	83,198
Affiliated Entity [Member] | Consolidating Adjustments [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	-18,228	-15,190
Other current liabilities	-18,228	-15,190
Affiliated Entity [Member] | Parent Issuer and Guarantor [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	3,138	1,868
Other current liabilities	551	709
Affiliated Entity [Member] | Subsidiary Issuer and Guarantor-KMP [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	1,833	1,335
Other current liabilities	13,417	11,949
Affiliated Entity [Member] | Subsidiary Issuer and Guarantor-Copano [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	18	11
Other current liabilities	276	115
Affiliated Entity [Member] | Subsidiaries Guarantors [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	12,665	11,573
Other current liabilities	3,343	1,551
Affiliated Entity [Member] | Subsidiary Non-Guarantors [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	574	403
Other current liabilities	641	866
Affiliated Entity [Member] | Consolidated KMI [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Other current assets	0	0
Other current liabilities	$0	$0

Guarantee_of_Securities_of_Sub5

Guarantee of Securities of Subsidiaries Condensed Consolidating Statements of Cash Flows (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	$1,256	$1,118
Capital expenditures	-897	-845
Contributions to investments	-30	-36
Acquisitions of assets and investments	-1,859	-960
Distributions from equity investments in excess of cumulative earnings	50	38
Other, net	-34	14
Net cash (used in) provided by investing activities	-2,775	-1,819
Issuance of debt	7,136	5,191
Payment of debt	-6,305	-4,184
Debt issuance costs	-16	-12
Issuances of shares	1,626	0
Cash dividends	-962	-425
Repurchases of shares and warrants	0	-149
Contributions from noncontrolling interests	0	684
Distributions to noncontrolling interests	-10	-479
Other, net	-1	0
Net cash (used in) provided by financing activities	1,468	626
Effect of Exchange Rate Changes on Cash and Cash Equivalents	-5	-10
Net (decrease) increase in cash and cash equivalents	-56	-85
Cash and Cash Equivalents, beginning of period	315	598
Cash and Cash Equivalents, end of period	259	513
Consolidating Adjustments [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	-2,591	-1,788
Funding to affiliates	6,440	4,428
Capital expenditures	4	0
Contributions to investments	0	76
Investment in KMP	159	11
Acquisitions of assets and investments	0	0
Distributions from equity investments in excess of cumulative earnings	0	-166
Other, net	-4	0
Net cash (used in) provided by investing activities	6,599	4,349
Issuance of debt	0	0
Payment of debt	0	0
Funding from (to) affiliates	-6,440	-4,428
Debt issuance costs	0	0
Issuances of shares	0
Cash dividends	0	0
Repurchases of shares and warrants		0
Contributions from parents	-159	-768
Contributions from noncontrolling interests		684
Distributions to parents	2,601	2,429
Distributions to noncontrolling interests	-10	-479
Other, net	0	1
Net cash (used in) provided by financing activities	-4,008	-2,561
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0
Net (decrease) increase in cash and cash equivalents	0	0
Cash and Cash Equivalents, beginning of period	0	0
Cash and Cash Equivalents, end of period	0	0
Parent Issuer and Guarantor [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	-224	438
Funding to affiliates	-246	-64
Capital expenditures	-18	-15
Contributions to investments	0	0
Investment in KMP	-159	-11
Acquisitions of assets and investments	-1,709	0
Distributions from equity investments in excess of cumulative earnings	14	10
Other, net	0	0
Net cash (used in) provided by investing activities	-2,118	-80
Issuance of debt	7,136	643
Payment of debt	-5,967	-491
Funding from (to) affiliates	534	39
Debt issuance costs	-16	-2
Issuances of shares	1,626
Cash dividends	-962	-425
Repurchases of shares and warrants		-149
Contributions from parents	0	0
Contributions from noncontrolling interests		0
Distributions to parents	0	0
Distributions to noncontrolling interests	0	0
Other, net	0	0
Net cash (used in) provided by financing activities	2,351	-385
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0
Net (decrease) increase in cash and cash equivalents	9	-27
Cash and Cash Equivalents, beginning of period	4	83
Cash and Cash Equivalents, end of period	13	56
Subsidiary Issuer and Guarantor-KMP [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	3,675	1,435
Funding to affiliates	-4,664	-2,986
Capital expenditures	0	0
Contributions to investments	0	-76
Investment in KMP	0	0
Acquisitions of assets and investments	0	0
Distributions from equity investments in excess of cumulative earnings	0	156
Other, net	-31	-22
Net cash (used in) provided by investing activities	-4,695	-2,928
Issuance of debt	0	4,548
Payment of debt	-300	-3,618
Funding from (to) affiliates	2,311	1,010
Debt issuance costs	0	-10
Issuances of shares	0
Cash dividends	0	0
Repurchases of shares and warrants		0
Contributions from parents	156	661
Contributions from noncontrolling interests		0
Distributions to parents	-1,147	-1,080
Distributions to noncontrolling interests	0	0
Other, net	0	-2
Net cash (used in) provided by financing activities	1,020	1,509
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0
Net (decrease) increase in cash and cash equivalents	0	16
Cash and Cash Equivalents, beginning of period	15	88
Cash and Cash Equivalents, end of period	15	104
Subsidiary Issuer and Guarantor-Copano [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	139	79
Funding to affiliates	0	0
Capital expenditures	-2	-27
Contributions to investments	0	0
Investment in KMP	0	0
Acquisitions of assets and investments	0	0
Distributions from equity investments in excess of cumulative earnings	0	0
Other, net	4	0
Net cash (used in) provided by investing activities	2	-27
Issuance of debt	0	0
Payment of debt	0	0
Funding from (to) affiliates	-141	-53
Debt issuance costs	0	0
Issuances of shares	0
Cash dividends	0	0
Repurchases of shares and warrants		0
Contributions from parents	0	0
Contributions from noncontrolling interests		0
Distributions to parents	0	0
Distributions to noncontrolling interests	0	0
Other, net	0	0
Net cash (used in) provided by financing activities	-141	-53
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0
Net (decrease) increase in cash and cash equivalents	0	-1
Cash and Cash Equivalents, beginning of period	0	1
Cash and Cash Equivalents, end of period	0	0
Subsidiaries Guarantors [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	424	740
Funding to affiliates	-1,432	-1,168
Capital expenditures	-786	-599
Contributions to investments	-30	-36
Investment in KMP	0	0
Acquisitions of assets and investments	-155	-990
Distributions from equity investments in excess of cumulative earnings	36	38
Other, net	4	23
Net cash (used in) provided by investing activities	-2,363	-2,732
Issuance of debt	0	0
Payment of debt	-36	-73
Funding from (to) affiliates	3,400	3,280
Debt issuance costs	0	0
Issuances of shares	0
Cash dividends	0	0
Repurchases of shares and warrants		0
Contributions from parents	3	83
Contributions from noncontrolling interests		0
Distributions to parents	-1,404	-1,310
Distributions to noncontrolling interests	0	0
Other, net	-1	1
Net cash (used in) provided by financing activities	1,962	1,981
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0
Net (decrease) increase in cash and cash equivalents	23	-11
Cash and Cash Equivalents, beginning of period	17	17
Cash and Cash Equivalents, end of period	40	6
Subsidiary Non-Guarantors [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	-167	214
Funding to affiliates	-98	-210
Capital expenditures	-95	-204
Contributions to investments	0	0
Investment in KMP	0	0
Acquisitions of assets and investments	0	0
Distributions from equity investments in excess of cumulative earnings	0	0
Other, net	-7	13
Net cash (used in) provided by investing activities	-200	-401
Issuance of debt	0	0
Payment of debt	-2	-2
Funding from (to) affiliates	336	152
Debt issuance costs	0	0
Issuances of shares	0
Cash dividends	0	0
Repurchases of shares and warrants		0
Contributions from parents	0	24
Contributions from noncontrolling interests		0
Distributions to parents	-50	-39
Distributions to noncontrolling interests	0	0
Other, net	0	0
Net cash (used in) provided by financing activities	284	135
Effect of Exchange Rate Changes on Cash and Cash Equivalents	-5	-10
Net (decrease) increase in cash and cash equivalents	-88	-62
Cash and Cash Equivalents, beginning of period	279	409
Cash and Cash Equivalents, end of period	191	347
Consolidated KMI [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	1,256	1,118
Funding to affiliates	0	0
Capital expenditures	-897	-845
Contributions to investments	-30	-36
Investment in KMP	0	0
Acquisitions of assets and investments	-1,864	-990
Distributions from equity investments in excess of cumulative earnings	50	38
Other, net	-34	14
Net cash (used in) provided by investing activities	-2,775	-1,819
Issuance of debt	7,136	5,191
Payment of debt	-6,305	-4,184
Funding from (to) affiliates	0	0
Debt issuance costs	-16	-12
Issuances of shares	1,626
Cash dividends	-962	-425
Repurchases of shares and warrants		-149
Contributions from parents	0	0
Contributions from noncontrolling interests		684
Distributions to parents	0	0
Distributions to noncontrolling interests	-10	-479
Other, net	-1	0
Net cash (used in) provided by financing activities	1,468	626
Effect of Exchange Rate Changes on Cash and Cash Equivalents	-5	-10
Net (decrease) increase in cash and cash equivalents	-56	-85
Cash and Cash Equivalents, beginning of period	315	598
Cash and Cash Equivalents, end of period	$259	$513