Kinder Morgan (KMI) 10-K 23 Feb 15 2014 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Feb. 02, 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		2,130,052,022
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Revenues
Natural gas sales	$4,115	$3,605	$2,511
Services	7,650	6,677	5,013
Product sales and other	4,461	3,788	2,449
Total Revenues	16,226	14,070	9,973
Operating Costs, Expenses and Other
Costs of sales	6,278	5,253	3,057
Operations and maintenance	2,157	2,112	1,702
Depreciation, depletion and amortization	2,040	1,806	1,419
General and administrative	610	613	929
Taxes, other than income taxes	418	395	286
Loss on impairments of long-lived assets	272	0	0
Other expense (income), net	3	-99	-13
Total Operating Costs, Expenses and Other	11,778	10,080	7,380
Operating Income	4,448	3,990	2,593
Other Income (Expense)
Earnings from equity investments	406	327	153
Amortization of excess cost of equity investments	-45	-39	-23
Interest, net	-1,798	-1,675	-1,399
Gain on remeasurement of previously held equity investments to fair value (Note 3)	0	558	0
Gain on sale of investments in Express pipeline system (Note 3)	0	224	0
Other, net	80	53	19
Total Other Income (Expense)	-1,357	-552	-1,250
Income from Continuing Operations Before Income Taxes	3,091	3,438	1,343
Income Tax Expense	-648	-742	-139
Income from Continuing Operations	2,443	2,696	1,204
Discontinued Operations (Note 3)
Income from operations of the FTC Natural Gas Pipelines disposal group and other, net of tax	0	0	160
Loss on sale and the remeasurement of the FTC Natural Gas Pipelines disposal group to fair value, net of tax	0	-4	-937
Loss from Discontinued Operations, Net of Tax	0	-4	-777
Net Income	2,443	2,692	427
Net Income Attributable to Noncontrolling Interests	-1,417	-1,499	-112
Net Income Attributable to Kinder Morgan, Inc.	$1,026	$1,193	$315
Diluted Weighted-Average Number of Shares Outstanding
Dividends Per Common Share Declared for the Period	$1.74	$1.60	$1.40
Class P [Member]
Earnings Per Share
Basic and Diluted Earnings Per Common Share From Continuing Operations	$0.89	$1.15	$0.56
Basic and Diluted Loss Per Common Share From Discontinued Operations	$0	$0	($0.21)
Total Basic and Diluted Earnings Per Common Share	$0.89	$1.15	$0.35
Basic Weighted-Average Number of Shares Outstanding
Basic Weighted-Average Number of Shares Outstanding	1,137	1,036	461
Diluted Weighted-Average Number of Shares Outstanding
Diluted Weighted-Average Number of Shares Outstanding	1,137	1,036	908
Common Class A [Member]
Earnings Per Share
Basic and Diluted Earnings Per Common Share From Continuing Operations			$0.47
Basic and Diluted Loss Per Common Share From Discontinued Operations			($0.21)
Total Basic and Diluted Earnings Per Common Share			$0.26
Basic Weighted-Average Number of Shares Outstanding
Basic Weighted-Average Number of Shares Outstanding			446
Diluted Weighted-Average Number of Shares Outstanding
Diluted Weighted-Average Number of Shares Outstanding			446

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Kinder Morgan, Inc.
Net income	$1,026	$1,193	$315
Other comprehensive income (loss), net of tax
Change in fair value of derivatives utilized for hedging purposes (net of tax (expense) benefit of $(150), $6 and $(19), respectively)	254	-14	32
Reclassification of change in fair value of derivatives to net income (net of tax benefit (expense) of $13, $(2) and $3, respectively)	-22	4	-5
Foreign currency translation adjustments (net of tax benefit (expense) of $41, $22, and $(8), respectively)	-68	-49	14
Benefit plan adjustments (net of tax benefit (expense) of $125, $(88) and $30, respectively)	-213	153	-44
Total other comprehensive (loss) income	-49	94	-3
Total comprehensive income	977	1,287	312
Noncontrolling Interests
Net income	1,417	1,499	112
Other comprehensive income (loss), net of tax
Change in fair value of derivatives utilized for hedging purposes (net of tax (expense) benefit of $(13), $4 and $(7), respectively)	155	-24	50
Reclassification of change in fair value of derivatives to net income (net of tax benefit (expense) of $-, $(1) and $-, respectively)	-3	7	-3
Foreign currency translation adjustments (net of tax benefit (expense) of $7, $9 and $(2), respectively)	-70	-54	18
Benefit plan adjustments (net of tax benefit (expense) of $1, $(3) and $-, respectively)	-13	17	9
Total other comprehensive income (loss)	69	-54	74
Total comprehensive income	1,486	1,445	186
Total
Net income	2,443	2,692	427
Other comprehensive loss, net of tax
Change in fair value of derivatives utilized for hedging purposes (net of tax (expense) benefit of $(163), $10 and $(26), respectively)	409	-38	82
Reclassification of change in fair value of derivatives to net income (net of tax benefit (expense) of $13, $(3) and $3, respectively)	-25	11	-8
Foreign currency translation adjustments (net of tax benefit (expense) of $48, $31 and $(10), respectively)	-138	-103	32
Benefit plan adjustments (net of tax benefit (expense) of $126, $(91) and $30, respectively)	-226	170	-35
Total other comprehensive income	20	40	71
Total comprehensive income	$2,463	$2,732	$498

CONSOLIDATED_STATEMENTS_OF_COM1

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME, TAX (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax, Portion Attributable to Parent	$150	($6)	$19
Kinder Morgan, Inc., Tax [Abstract]
Reclassification of change in fair value of derivatives to net income	13	-2	3
Foreign currency translation adjustments	41	22	-8
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax, Portion Attributable to Parent	125	-88	30
Noncontrolling Interests, Tax
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax, Portion Attributable to Noncontrolling Interest	-13	4	-7
Other Comprehensive Income Loss Reclassification Adjustment From AOCI On Derivatives Tax Attributable To Noncontrolling Interests	0	1	0
Foreign currency translation adjustments	7	9	-2
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax, Portion Attributable to Noncontrolling Interest	1	-3	0
Total, Tax
Change in fair value of derivatives utilized for hedging purposes	-163	10	-26
Reclassification of change in fair value of derivatives to net income	13	-3	3
Foreign currency translation adjustments	48	31	-10
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax	$126	($91)	$30

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current assets
Cash and cash equivalents	$315	$598
Accounts receivable, net	1,641	1,721
Fair value of derivative contracts	535	116
Inventories	459	430
Deferred income taxes	56	567
Other current assets	746	436
Total current assets	3,752	3,868
Property, plant and equipment, net	38,564	35,847
Investments	6,036	5,951
Goodwill	24,654	24,504
Other intangibles, net	2,302	2,438
Deferred income taxes, non-current	5,651	0
Deferred charges and other assets	2,239	2,577
Total Assets	83,198	75,185
Current liabilities
Current portion of debt	2,717	2,306
Accounts payable	1,588	1,676
Accrued interest	637	565
Accrued contingencies	383	584
Other current liabilities	1,037	944
Total current liabilities	6,362	6,075
Long-term debt
Outstanding	38,212	31,810
Preferred interest in general partner of KMP	100	100
Debt fair value adjustments	1,934	1,977
Total long-term debt	40,246	33,887
Deferred income taxes	0	4,651
Other long-term liabilities and deferred credits	2,164	2,287
Total long-term liabilities and deferred credits	42,410	40,825
Total Liabilities	48,772	46,900
Stockholders’ Equity
Preferred stock	0	0
Additional paid-in capital	36,178	14,479
Retained deficit	-2,106	-1,372
Accumulated other comprehensive loss	-17	-24
Total Kinder Morgan, Inc.’s stockholders’ equity	34,076	13,093
Noncontrolling interests	350	15,192
Total Stockholders’ Equity	34,426	28,285
Total Liabilities and Stockholders’ Equity	83,198	75,185
Class P [Member]
Stockholders’ Equity
Class P shares, $0.01 par value, 4,000,000,000 and 2,000,000,000 shares, respectively, authorized, 2,125,147,116 and 1,030,677,076 shares, respectively, issued and outstanding	21	10
KMI $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock [Member] | Kinder Morgan G.P., Inc. [Member]
Stockholders’ Equity
Preferred stock	$100	$100

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Stockholders’ Equity
Preferred stock, par value (in dollars per share)	$0.01	$0.01
Preferred stock, shares authorized (in shares)	10,000,000	10,000,000
Preferred stock, shares outstanding (in shares)	0	0
Class P [Member]
Stockholders’ Equity
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares authorized (in shares)	4,000,000,000	2,000,000,000
Common stock, shares issued (in shares)	2,125,147,116	1,030,677,076
Common stock, shares outstanding (in shares)	2,125,147,116	1,030,677,076

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash Flows From Operating Activities
Net income	$2,443	$2,692	$427
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion, and amortization	2,040	1,806	1,426
Deferred income taxes	615	640	47
Amortization of excess cost of equity investments	45	39	23
Asset Impairment Charges	272	0	0
(Gain) loss from the remeasurement of net assets to fair value and the sale of discontinued operations (net of cash selling expenses), net of tax (Note 3)	0	-556	859
Gain on sale of investments in Express pipeline system (Note 3)	0	-224	0
Loss on early extinguishment of debt	0	0	82
Noncash compensation expense on settlement of EP stock awards	0	0	87
Earnings from equity investments	-406	-327	-223
Distributions from equity investments	381	398	381
Proceeds from termination of interest rate swap agreements	0	96	53
Pension contribution and noncash pension benefit credits	88	120	31
Changes in components of working capital, net of the effects of acquisitions
Accounts receivable	-84	-131	-231
Income tax receivable	-195	0	0
Inventories	-30	-53	-92
Other current assets	-31	-24	32
Accounts payable	-1	-36	70
Accrued interest	75	42	-26
Accrued contingencies and other current liabilities	108	-100	-68
Rate reparations, refunds and other litigation reserve adjustments	-280	174	-39
Other, net	-397	-194	31
Net Cash Provided by Operating Activities	4,467	4,122	2,808
Cash Flows From Investing Activities
Acquisition of assets and investments, net of cash acquired	0	0
Proceeds from Sale of Equity Method Investments	0	490	0
Proceeds from disposal of discontinued operations	0	0	1,791
Capital expenditures	-3,617	-3,369	-2,022
Sale or casualty of property, plant and equipment, and other net assets, net of removal costs	5	87	154
Contributions to investments	-389	-217	-192
Distributions from equity investments in excess of cumulative earnings	182	185	200
Other, net	-3	-6	25
Net Cash Used in Investing Activities	-5,210	-3,122	-5,097
Cash Flows From Financing Activities
Issuance of debt	24,573	13,581	18,148
Payment of debt	-17,801	-12,393	-14,755
Debt issue costs	-89	-38	-111
Cash dividends (Note 10)	-1,760	-1,622	-1,184
Repurchases of shares and warrants	-192	-637	-157
Cash consideration of Merger Transactions (Note 1)	-3,937	0	0
Merger Transactions costs	-74	0	0
Contributions from noncontrolling interests	1,767	1,706	1,939
Distributions to noncontrolling interests	-2,013	-1,692	-1,219
Other, net	-3	0	-77
Net Cash Provided by (Used in) Financing Activities	471	-1,095	2,584
Effect of Exchange Rate on Cash and Cash Equivalents	-11	-21	8
Net (decrease) increase in Cash and Cash Equivalents	-283	-116	303
Cash and Cash Equivalents, beginning of period	598	714	411
Cash and Cash Equivalents, end of period	315	598	714
Noncash Investing and Financing Activities
Net assets and liabilities or noncontrolling interests acquired by the issuance of shares and warrants (Notes 1 and 3)	16,023	0	11,454
Assets acquired by the assumption or incurrence of liabilities	106	1,510	0
Assets acquired or liabilities settled by contributions from noncontrolling interests	0	3,733	306
Supplemental Disclosures of Cash Flow Information
Cash paid during the period for interest (net of capitalized interest)	1,718	1,652	1,349
Cash paid during the period for income taxes (net of refunds)	227	67	182
El Paso Corporation [Member]
Cash Flows From Investing Activities
Acquisition of assets and investments, net of cash acquired			-4,970
Other Acquisitions [Member]
Cash Flows From Investing Activities
Acquisition of assets and investments, net of cash acquired	($1,388)	($292)	($83)

CONSOLIDATED_STATEMENTS_OF_CAS1

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2012
Cash acquired from acquisition	$6,581

CONSOLIDATED_STATEMENT_OF_STOC

CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY (USD $)	Total	Class A B and C [Member]	Common Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Parent [Member]	Parent [Member]	Noncontrolling Interest [Member]	KMP, EPB and KMR [Member]	KMP, EPB and KMR [Member]	KMP, EPB and KMR [Member]	KMP, EPB and KMR [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	El Paso Corporation [Member]	KMP Acquisiton of Copano Energy LLC [Member]	KMP Acquisiton of Copano Energy LLC [Member]	KMP Acquisiton of Copano Energy LLC [Member]	EP Trust I Preferred [Member]	EP Trust I Preferred [Member]	EP Trust I Preferred [Member]
In Millions				Class A B and C [Member]		Class A B and C [Member]		Class A B and C [Member]			Class A B and C [Member]			Additional Paid-in Capital [Member]	Parent [Member]	Noncontrolling Interest [Member]		Common Stock [Member]	Additional Paid-in Capital [Member]	Parent [Member]	Noncontrolling Interest [Member]		Parent [Member]	Noncontrolling Interest [Member]		Additional Paid-in Capital [Member]	Parent [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Dec. 31, 2011	$8,568
Stockholders' Equity Attributable to Noncontrolling Interest at Dec. 31, 2011												5,247
Stockholders' Equity Attributable to Parent at Dec. 31, 2011			8		3,431		-3		-115	3,321
Issuance of shares for EP acquisition																	10,601	3	10,598	10,601
Issuance of warrants for EP acquisition																	863		863	863
Acquisition of noncontrolling interests																	3,797			0	3,797
Warrants repurchased	-157				-157					-157
EP Trust I Preferred security conversions																									14	14	14
Class A, Class B and Class C share conversions		-71		-1		1		-71			-71
Amortization of Restricted Shares	14				14					14
Impact from equity transactions of KMP, EPB and KMR													-38	64	64	-102
Tax Impact on Stock Based Compensation	90				90					90
Net income	315						315			315
Net Income (Loss) Attributable to Noncontrolling Interest	112											112
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	427
Distributions	-1,219									0		-1,219
Contributions	2,329									0		2,329
Cash dividends	-1,184						-1,184			-1,184
Other	-5				-1					-1		-4
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	-3								-3	-3
Other Comprehensive (Income) Loss, Net of Tax, Portion Attributable to Noncontrolling Interest	74											74
Other Comprehensive Income (Loss), Net of Tax	71
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Dec. 31, 2012	24,100
Stockholders' Equity Attributable to Noncontrolling Interest at Dec. 31, 2012												10,234
Stockholders' Equity Attributable to Parent at Dec. 31, 2012			10		14,917		-943		-118	13,866
Acquisition of noncontrolling interests																						17	0	17
Shares repurchased	-172				-172					-172
Warrants repurchased	-465				-465					-465
EP Trust I Preferred security conversions																									3	3	3
Warrant exercised	1				1					1
Amortization of Restricted Shares	35				35					35
Impact from equity transactions of KMP, EPB and KMR													-93	161	161	-254
Net income	1,193						1,193			1,193
Net Income (Loss) Attributable to Noncontrolling Interest	1,499											1,499
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	2,692
Distributions	-1,692									0		-1,692
Contributions	5,439									0		5,439
Cash dividends	-1,622						-1,622			-1,622
Other	2				-1					-1		3
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	94								94	94
Other Comprehensive (Income) Loss, Net of Tax, Portion Attributable to Noncontrolling Interest	-54											-54
Other Comprehensive Income (Loss), Net of Tax	40
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Dec. 31, 2013	28,285
Stockholders' Equity Attributable to Noncontrolling Interest at Dec. 31, 2013	15,192											15,192
Stockholders' Equity Attributable to Parent at Dec. 31, 2013	13,093		10		14,479		-1,372		-24	13,093
Impact of Merger Transactions	5,955		11		21,880					21,891		-15,936
Merger Transactions Costs	-75				-75					-75
Shares repurchased	-94				-94					-94
Warrants repurchased	-98				-98					-98
Amortization of Restricted Shares	57				57					57
Impact from equity transactions of KMP, EPB and KMR													-19	36	36	-55
Net income	1,026						1,026			1,026
Net Income (Loss) Attributable to Noncontrolling Interest	1,417											1,417
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	2,443
Distributions	-2,013									0		-2,013
Contributions	1,767									0		1,767
Cash dividends	-1,760						-1,760			-1,760
Other	-11				-7					-7		-4
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	-49								-49	-49
Other Comprehensive (Income) Loss, Net of Tax, Portion Attributable to Noncontrolling Interest	69											69
Other Comprehensive Income (Loss), Net of Tax	20
Impact of Merger Transactions on Accumulated other comprehensive loss	-31								56	56		-87
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Dec. 31, 2014	34,426
Stockholders' Equity Attributable to Noncontrolling Interest at Dec. 31, 2014	350											350
Stockholders' Equity Attributable to Parent at Dec. 31, 2014	$34,076		$21		$36,178		($2,106)		($17)	$34,076

General_Notes

General (Notes)	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	1.  General
	We are the largest energy infrastructure and the third largest energy company in North America with an enterprise value of more than $125 billion and unless the context requires otherwise, references to “we,” “us,” “our,” or “KMI” are intended to mean Kinder Morgan, Inc. and its consolidated subsidiaries. We own an interest in or operate approximately 80,000 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, 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. (NYSE: KMP) and El Paso Pipeline Partners, L.P. (NYSE: EPB) and all of the outstanding shares of Kinder Morgan Management, LLC (NYSE: KMR) that we did not already own. The transactions, valued at approximately $77 billion, are referred to collectively as the “Merger Transactions.”
	Upon completion of the Merger Transactions: (i) each publicly held KMR share received 2.4849 shares of KMI common stock; (ii) through the election and proration mechanisms in the KMP merger agreement, on average, each common unit held by a public KMP unitholder received 2.1931 shares of KMI common stock and $10.77 in cash; and (iii) through the election and proration mechanisms in the EPB merger agreement, on average, each common unit held by a public EPB unitholder received 0.9451 shares of KMI common stock and $4.65 in cash. The cash payments to the public unitholders of KMP and EPB totaled approximately $3.9 billion.
	As we controlled each of KMP, KMR and EPB and continued to control each of them after the Merger Transactions, the changes in our ownership interest in each of KMP, KMR and EPB were accounted for as an equity transaction and no gain or loss was recognized in our consolidated statements of income resulting from the Merger Transactions. After closing the KMR Merger Transaction, KMR was merged with and into KMI. On January 1, 2015, EPB and its subsidiary, EPPOC merged with and into KMP and were dissolved.
	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 was eliminated.
	The equity interests in KMP, EPB and KMR (which are all consolidated in our financial statements) owned by the public prior to November 26, 2014 are reflected within “Noncontrolling interests” in our accompanying December 31, 2013 consolidated balance sheet. 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 income attributable to noncontrolling interests” in our accompanying consolidated statements of income.
	Our common stock trades on the NYSE under the symbol “KMI.”

Summary_of_Significant_Account

Summary of Significant Accounting Policies Significant Accounting Policies (Notes)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Significant Accounting Policies [Text Block]	Summary of Significant Accounting Policies
	Basis of Presentation
	Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars.
	Our accompanying consolidated financial statements have been prepared under the rules and regulations of the 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.
	Use of Estimates
	Certain amounts included in or affecting our financial statements and related disclosures must be estimated, requiring us to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time our financial statements are prepared. These estimates and assumptions affect the amounts we report for assets and liabilities, our revenues and expenses during the reporting period, and our disclosure of contingent assets and liabilities at the date of our financial statements. We evaluate these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods we consider reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from our estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known.
	In addition, we believe that certain accounting policies are of more significance in our financial statement preparation process than others, and set out below are the principal accounting policies we apply in the preparation of our consolidated financial statements.
	Cash Equivalents and Restricted Deposits
	We define cash equivalents as all highly liquid short-term investments with original maturities of three months or less.
	Restricted cash of $118 million and $75 million as of December 31, 2014 and 2013, respectively is included in “Other current assets.”
	Accounts Receivable
	The amounts reported as “Accounts receivable, net” on our accompanying consolidated balance sheets as of December 31, 2014 and 2013 primarily consist of amounts due from customers.
	Our policy for determining an appropriate allowance for doubtful accounts varies according to the type of business being conducted and the customers being served.  Generally, we make periodic reviews and evaluations of the appropriateness of the allowance for doubtful accounts based on a historical analysis of uncollected amounts, and we record adjustments as necessary for changed circumstances and customer-specific information.  When specific receivables are determined to be uncollectible, the reserve and receivable are relieved.
	Inventories
	Our inventories consist of materials and supplies and products such as, NGL, crude oil, condensate, refined petroleum products, transmix and natural gas. We report these assets at the lower of weighted-average cost or market. We report materials and supplies inventories at cost, and periodically review for physical deterioration and obsolescence.
	Gas Imbalances
	We value gas imbalances due to or due from interconnecting pipelines at the lower of cost or market or index prices. As of December 31, 2014 and 2013, our gas imbalance receivables—including both trade and related party receivables—totaled $103 million and $83 million, respectively, and we included these amounts within “Other current assets” on our accompanying consolidated balance sheets. As of December 31, 2014 and 2013, our gas imbalance payables—consisting of only trade payables—totaled $36 million and $34 million, respectively, and we included these amounts within “Other current liabilities” on our accompanying consolidated balance sheets.
	Property, Plant and Equipment
	Capitalization, Depreciation and Depletion and Disposals
	We report property, plant and equipment at its acquisition cost. We expense costs for routine maintenance and repairs in the period incurred.
	We generally compute depreciation using either the straight-line method based on estimated economic lives or, for certain depreciable assets, we employ the composite depreciation method, applying a single depreciation rate for a group of assets. Generally, we apply composite depreciation rates to functional groups of property having similar economic characteristics. The rates range from 0.9% to 23.0% excluding certain short-lived assets such as vehicles. For FERC-regulated entities, the FERC-accepted composite depreciation rate is applied to the total cost of the composite group until the net book value equals the salvage value. For other entities, depreciation estimates are based on various factors, including age (in the case of acquired assets), manufacturing specifications, technological advances and historical data concerning useful lives of similar assets. Uncertainties that impact these estimates included changes in laws and regulations relating to restoration and abandonment requirements, economic conditions, and supply and demand in the area. When assets are put into service, we make estimates with respect to useful lives (and salvage values where appropriate) that we believe are reasonable. Subsequent events could cause us to change our estimates, thus impacting the future calculation of depreciation and amortization expense. Historically, adjustments to useful lives have not had a material impact on our aggregate depreciation levels from year to year.
	Our oil and gas producing activities are accounted for under the successful efforts method of accounting. Under this method costs that are incurred to acquire leasehold and subsequent development costs are capitalized. Costs that are associated with the drilling of successful exploration wells are capitalized if proved reserves are found. Costs associated with the drilling of exploratory wells that do not find proved reserves, geological and geophysical costs, and costs of certain non-producing leasehold costs are expensed as incurred. The capitalized costs of our producing oil and gas properties are depreciated and depleted by the units-of-production method. Other miscellaneous property, plant and equipment are depreciated over the estimated useful lives of the asset.
	We engage in enhanced recovery techniques in which CO2 is injected into certain producing oil reservoirs. In some cases, the acquisition cost of the CO2 associated with enhanced recovery is capitalized as part of our development costs when it is injected. The acquisition cost associated with pressure maintenance operations for reservoir management is expensed when it is injected. When CO2 is recovered in conjunction with oil production, it is extracted and re-injected, and all of the associated costs are expensed as incurred. Proved developed reserves are used in computing units of production rates for drilling and development costs, and total proved reserves are used for depletion of leasehold costs. The units-of-production rate is determined by field.
	A gain on the sale of property, plant and equipment used in our oil and gas producing activities or in our bulk and liquids terminal activities is calculated as the difference between the cost of the asset disposed of, net of depreciation, and the sales proceeds received. A gain on an asset disposal is recognized in income in the period that the sale is closed. A loss on the sale of property, plant and equipment is calculated as the difference between the cost of the asset disposed of, net of depreciation, and the sales proceeds received or the market value if the asset is being held for sale. A loss is recognized when the asset is sold or when the net cost of an asset held for sale is greater than the market value of the asset. For our pipeline system assets under the composite method of depreciation, we generally charge the original cost of property sold or retired to accumulated depreciation and amortization, net of salvage and cost of removal. Gains and losses are booked for operating unit sales and land sales and are recorded to income or expense accounts in accordance with regulatory accounting guidelines. In those instances where we receive recovery in tariff rates related to losses on dispositions of operating units, we record a regulatory asset for the estimated recoverable amount.
	Impairments
	We review long-lived assets for impairment whenever events or changes in circumstances indicate that our carrying amount of an asset may not be recoverable.  We recognize impairment losses when estimated future cash flows expected to result from our use of the asset and its eventual disposition is less than its carrying amount.
	We evaluate our oil and gas producing properties for impairment of value on a field-by-field basis or, in certain instances, by logical grouping of assets if there is significant shared infrastructure, using undiscounted future cash flows based on total proved and risk-adjusted probable and possible reserves.  For the purpose of impairment testing, adjustments for the inclusion of risk-adjusted probable and possible reserves, as well as forward curve pricing, will cause impairment calculation cash flows to differ from the amounts presented in our supplemental information on oil and gas producing activities disclosed in “Supplemental Information on Oil and Gas Producing Activities (Unaudited).”
	Oil and gas producing properties deemed to be impaired are written down to their fair value, as determined by discounted future cash flows based on total proved and risk-adjusted probable and possible reserves or, if available, comparable market values.  Unproved oil and gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment.
	Asset Retirement Obligations
	We record liabilities for obligations related to the retirement and removal of long-lived assets used in our businesses.  We record, as liabilities, the fair value of asset retirement obligations on a discounted basis when they are incurred, which is typically at the time the assets are installed or acquired.  Amounts recorded for the related assets are increased by the amount of these obligations.  Over time, the liabilities increase due to the change in their present value, and the initial capitalized costs are depreciated over the useful lives of the related assets.  The liabilities are eventually extinguished when the asset is taken out of service.
	Equity method of accounting
	We account for investments—which we do not control, but do have the ability to exercise significant influence—by the equity method of accounting. Under this method, our equity investments are carried originally at our acquisition cost, increased by our proportionate share of the investee’s net income and by contributions made, and decreased by our proportionate share of the investee’s net losses and by distributions received.
	Goodwill
	Goodwill represents the excess of the cost of an acquisition price over the fair value of the acquired net assets, and such amounts are reported separately on our consolidated balance sheets.  As of December 31, 2014 and 2013 our total goodwill was $24,654 million and $24,504 million, respectively.  Goodwill is not amortized, but instead is tested for impairment annually or on an interim basis if events or circumstances indicate that the fair value of the asset has decreased below its carrying value. We perform our goodwill impairment test on May 31 of each year.  There were no impairment charges resulting from our May 31, 2014 or 2013 impairment testing, and no event indicating an impairment has occurred subsequent to May 31, 2014 other than as described below.
	If a significant portion of one of our business segments is disposed of (that also constitutes a business), we allocate goodwill based on the relative fair values of the portion of the segment being disposed of and the portion of the segment remaining. During 2014, we recorded a $29 million write-down associated with a pending sale of certain terminals to a third-party, including $2 million of goodwill.
	Revenue Recognition Policies
	We recognize revenues as services are rendered or goods are delivered and, if applicable, title has passed.  We recognize natural gas sales revenues and NGL sales revenue when the natural gas or NGL is sold to a purchaser at a fixed or determinable price, delivery has occurred and title has transferred, and collectability of the revenue is reasonably assured. Our sales and purchases of natural gas and NGL are primarily accounted for on a gross basis as natural gas sales or product sales, as applicable, and cost of sales.
	In addition to storing and transporting a significant portion of the natural gas volumes we purchase and resell, we provide various types of natural gas storage and transportation services for third-party customers.  Under these contracts, the natural gas remains the property of these customers at all times. In many cases, generally described as firm service, the customer pays a two-part rate that includes (i) a fixed fee reserving the right to transport or store natural gas in our facilities and (ii) a per-unit rate for volumes actually transported or injected into/withdrawn from storage.  The fixed-fee component of the overall rate is recognized as revenue in the period the service is provided.  The per-unit charge is recognized as revenue when the volumes are delivered to the customers’ agreed upon delivery point, or when the volumes are injected into/withdrawn from our storage facilities.
	In other cases, generally described as interruptible service, there is no fixed fee associated with the services because the customer accepts the possibility that service may be interrupted at our discretion in order to serve customers who have purchased firm service.  In the case of interruptible service, revenue is recognized in the same manner utilized for the per-unit rate for volumes actually transported under firm service agreements.
	We provide crude oil and refined petroleum products transportation and storage services to customers.  Revenues are recorded when products are delivered and services have been provided, and adjusted according to terms prescribed by the toll settlements with shippers and approved by regulatory authorities.
	We recognize bulk terminal transfer service revenues based on volumes loaded and unloaded.  We recognize liquids terminal tank rental revenue ratably over the contract period. We recognize liquids terminal throughput revenue based on volumes received and volumes delivered.  We recognize transmix processing revenues based on volumes processed or sold, and if applicable, when title has passed.  We recognize energy-related product sales revenues based on delivered quantities of product.
	Revenues from the sale of crude oil, NGL, CO2 and natural gas production within the CO2 business segment are recorded using the entitlement method.  Under the entitlement method, revenue is recorded when title passes based on our net interest.  We record our entitled share of revenues based on entitled volumes and contracted sales prices. Since there is a ready market for oil and gas production, we sell the majority of our products soon after production at various locations, at which time title and risk of loss pass to the buyer.
	Environmental Matters
	We capitalize or expense, as appropriate, environmental expenditures.  We capitalize certain environmental expenditures required in obtaining rights-of-way, regulatory approvals or permitting as part of the construction. We accrue and expense environmental costs that relate to an existing condition caused by past operations, which do not contribute to current or future revenue generation.  We generally do not discount environmental liabilities to a net present value, and we record environmental liabilities when environmental assessments and/or remedial efforts are probable and we can reasonably estimate the costs.  Generally, our recording of these accruals coincides with our completion of a feasibility study or our commitment to a formal plan of action.  We recognize receivables for anticipated associated insurance recoveries when such recoveries are deemed to be probable. We record at fair value, where appropriate, environmental liabilities assumed in a business combination.
	We routinely conduct reviews of potential environmental issues and claims that could impact our assets or operations.  These reviews assist us in identifying environmental issues and estimating the costs and timing of remediation efforts.  We also routinely adjust our environmental liabilities to reflect changes in previous estimates.  In making environmental liability estimations, we consider the material effect of environmental compliance, pending legal actions against us, and potential third-party liability claims.  Often, as the remediation evaluation and effort progresses, additional information is obtained, requiring revisions to estimated costs.  These revisions are reflected in our income in the period in which they are reasonably determinable.
	Pensions and Other Postretirement Benefits
	We recognize the differences between the fair value of each of our and our consolidated subsidiaries’ pension and other postretirement benefit plans’ assets and the benefit obligations as either assets or liabilities on our balance sheet. We record deferred plan costs and income—unrecognized losses and gains, unrecognized prior service costs and credits, and any remaining unamortized transition obligations—in “Accumulated other comprehensive loss” or as a regulatory asset or liability for certain of our regulated operations, until they are amortized to be recognized as a component of benefit expense.
	Noncontrolling Interests
	Noncontrolling interests represents the outstanding ownership interests in our consolidated subsidiaries that are not owned by us.  In our accompanying consolidated income statements, the noncontrolling interest in the net income (or loss) of our consolidated subsidiaries is shown as an allocation of our consolidated net income and is presented separately as “Net income attributable to noncontrolling interests.”  In our accompanying consolidated balance sheets, noncontrolling interests represents the ownership interests in our consolidated subsidiaries’ net assets held by parties other than us.  It is presented separately as “Noncontrolling interests” within “Stockholders’ Equity.”
	Income Taxes
	Income tax expense is recorded based on an estimate of the effective tax rate in effect or to be in effect during the relevant periods.  Deferred income tax assets and liabilities are recognized for temporary differences between the basis of assets and liabilities for financial reporting and tax purposes.  Changes in tax legislation are included in the relevant computations in the period in which such changes are effective.  Deferred tax assets are reduced by a valuation allowance for the amount of any tax benefit we do not expect to be realized.
	In determining the deferred income tax asset and liability balances attributable to our investments, we apply an accounting policy that looks through our investments. The application of this policy resulted in no deferred income taxes being provided on the difference between the book and tax basis on the non-tax-deductible goodwill portion of our investments, including our investment in KMP as the KMP partnership remains in place following the Merger Transactions.
	Foreign Currency Transactions and Translation
	Foreign currency transaction gains or losses result from a change in exchange rates between (i) the functional currency, for example the Canadian dollar for a Canadian subsidiary and (ii) the currency in which a foreign currency transaction is denominated, for example the U.S. dollar for a Canadian subsidiary.  In our accompanying consolidated statements of income, gains and losses from our foreign currency transactions are included within “Other Income (Expense)—Other, net.”
	Foreign currency translation is the process of expressing, in U.S. dollars, amounts recorded in a local functional currency other than U.S. dollars, for example the Canadian dollar for a Canadian subsidiary.  We translate the assets and liabilities of each of our consolidated foreign subsidiaries that have a local functional currency to U.S. dollars at year-end exchange rates.  Income and expense items are translated at weighted-average rates of exchange prevailing during the year and stockholders’ equity accounts are translated by using historical exchange rates.  The cumulative translation adjustments balance is reported as a component of “Accumulated other comprehensive loss.”
	Comprehensive Income
	For each of the years ended December 31, 2014, 2013 and 2012, the difference between our net income and our comprehensive income resulted from (i) unrealized gains or losses on derivative contracts accounted for as cash flow hedges; (ii) foreign currency translation adjustments; and (iii) unrealized gains or losses related to changes in pension and other postretirement benefit plan liabilities. For more information on our risk management activities, see Note 13.
	Risk Management Activities
	We utilize energy commodity derivative contracts for the purpose of mitigating our risk resulting from fluctuations in the market price of natural gas, NGL and crude oil.  In addition, we enter into interest rate swap agreements for the purpose of hedging the interest rate risk associated with our debt obligations. We measure our derivative contracts at fair value and we report them on our balance sheet as either an asset or liability.  If the derivative transaction qualifies for and is designated as a normal purchase and sale, it is exempted from fair value accounting and is accounted for using traditional accrual accounting.
	Furthermore, changes in our derivative contracts’ fair values are recognized currently in earnings unless hedge accounting is applied.  If a derivative contract meets specific accounting criteria, the contract’s gains and losses are allowed to offset related results on the hedged item in our income statement, and we may formally designate the derivative contract as a hedge and document and assess the effectiveness of the contract associated with the transaction that receives hedge accounting.  Only designated qualifying items that are effectively offset by changes in fair value or cash flows during the term of the hedge are eligible to use the special accounting for hedging.
	Our derivative contracts that hedge our energy commodity price risks involve our normal business activities, which include the purchase and sale of natural gas, NGL and crude oil, and we may designate these derivative contracts as cash flow hedges—derivative contracts that hedge exposure to variable cash flows of forecasted transactions—and the effective portion of these derivative contracts’ gain or loss is initially reported as a component of other comprehensive income (outside earnings) and subsequently reclassified into earnings when the forecasted transactions affect earnings.  The ineffective portion of the gain or loss is reported in earnings immediately.
	Regulatory Assets and Liabilities
	Regulatory assets and liabilities represent probable future revenues or expenses associated with certain charges and credits that will be recovered from or refunded to customers through the ratemaking process.  We included the amounts of our regulatory assets and liabilities within “Other current assets,” “Deferred charges and other assets,” “Other current liabilities” and “Other long-term liabilities and deferred credits,” respectively, in our accompanying consolidated balance sheets. As of December 31, 2014, the recovery period for these regulatory assets was approximately one year to forty-two years.
	The following table summarizes our regulatory asset and liability balances as of December 31, 2014 and 2013 (in millions):
	December 31,
	2014				2013
Current regulatory assets	$	81			$	91
Non-current regulatory assets	406				446
Total regulatory assets	$	487			$	537
Current regulatory liabilities	$	189			$	135
Non-current regulatory liabilities	290				397
Total regulatory liabilities	$	479			$	532
_______
On July 26, 2012, TGP filed an application with the FERC seeking authority to abandon by sale certain natural gas facilities located offshore in the Gulf of Mexico and onshore in the state of Louisiana, as well as a related offer of settlement that addressed the proposed rate and accounting treatment associated with the sale. The offer of settlement provided for a rate adjustment to TGP’s maximum tariff rates upon the transfer of the assets and established a regulatory asset for a portion of the unrecovered net book value of the facilities to be sold. Effective September 1, 2013, following the FERC’s approval of both the requested abandonment authorization and the offer of settlement, TGP sold these assets, and in 2013, TGP recognized both a $93 million increase in regulatory assets and a $36 million gain from the sale of assets.
Transfer of Net Assets Between Entities Under Common Control
We account for the transfer of net assets between entities under common control by carrying forward the net assets recognized in the balance sheets of each combining entity to the balance sheet of the combined entity, and no other assets or liabilities are recognized as a result of the combination.  Transfers of net assets between entities under common control do not affect the historical income statement or balance sheet of the combined entity.
Earnings per Share
For the years ended December 31, 2014 and 2013, earnings per share was calculated 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 table sets forth the allocation of net income available to shareholders for Class P shares and for participating securities (in millions):
	Year Ended December 31,
	2014				2013
Class P	$	1,015			$	1,187
Participating securities(a)	11				6
Net Income Attributable to Kinder Morgan, Inc.	$	1,026			$	1,193
_______
(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
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):
	Year Ended December 31,
	2014			2013
Unvested restricted stock awards	7			4
Outstanding warrants to purchase our Class P shares(a)	312			401
Convertible trust preferred securities	10			10
_______
(a)	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.
On December 26, 2012, the remaining series of our Class A, Class B, and Class C shares were fully-converted and as a result, only our Class P common stock was outstanding as of December 31, 2012 (see Note 10).
For the year ended December 31, 2012, earnings per share was calculated using the two-class method.  Earnings were allocated to each class of common stock based on the amount of dividends paid in the current period for each class of stock 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.  For the investor retained stock, the allocation of undistributed earnings or excess distributions over earnings was in direct proportion to the maximum number of Class P shares into which it could convert.
For the Class P diluted earnings per share computations, total net income attributable to Kinder Morgan, Inc. was divided by the adjusted weighted-average shares outstanding during the period, including all potential common stock equivalents.  This included, for the periods prior to December 26, 2012, the Class P shares into which the investor retained stock (collectively, our Class A, Class B and Class C common stocks) was convertible.  The number of Class P shares on a fully-converted basis was the same before and after any conversion of our investor retained stock.  Each time one Class P share was issued upon conversion of investor retained stock, the number of Class P shares went up by one, and the number of Class P shares into which the investor retained stock was convertible went down by one.  Accordingly, there was no difference between Class P basic and diluted earnings per share because the conversion of Class A, Class B, and Class C shares into Class P shares did not impact the number of Class P shares on a fully-converted basis.  Commencing with the acquisition of EP, potential common stock equivalents also included the Class P shares issuable in connection with the warrants and the trust preferred securities (see Note 10).  As no securities were convertible into Class A shares, the basic and diluted earnings per share computations for Class A shares were the same. For the year ended December 31, 2012, the following potential Class P common stock equivalents were antidilutive and, accordingly, were excluded from the determination of diluted earnings per share; (i) 451 million related to outstanding warrants to purchase our Class P shares; and (ii) 11 million related to convertible trust preferred securities.
The following tables set forth the computation of basic and diluted earnings per share from continuing operations for the year ending December 31, 2012 (in millions, except per share amounts):
	Year ended December 31, 2012
	Income from Continuing Operations Available to Shareholders
	Class P				Class A			Participating			Total
								Securities(a)
Income from continuing operations											$	1,204
Less: income from continuing operations attributable to noncontrolling interests											(696		)
Income from continuing operations attributable to KMI											508
Dividends paid in the period	$	601			$	542		$	41		(1,184		)
Excess distributions over earnings	(344		)		(331		)	(1		)	$	(676	)
Income from continuing operations attributable to shareholders	$	257			$	211		$	40		$	508
Basic earnings per share from continuing operations
Basic weighted-average number of shares outstanding	461				446			N/A
Basic earnings per common share from continuing operations(b)	$	0.56			$	0.47		N/A
Diluted earnings per share from continuing operations
Income from continuing operations attributable to shareholders and assumed conversions(c)	$	508			$	211		N/A
Diluted weighted-average number of shares	908				446			N/A
Diluted earnings per common share from continuing operations(b)	$	0.56			$	0.47		N/A
_______
The following tables set forth the computation of basic and diluted earnings per share for the year ended December 31, 2012 (in millions, except per share amounts):
	Year ended December 31, 2012
	Net Income Available to Shareholders
	Class P				Class A			Participating			Total
								Securities(a)
Net income attributable to KMI											$	315
Dividends paid in the period	$	601			$	542		$	41		(1,184		)
Excess distributions over earnings	(441		)		(426		)	(2		)	$	(869	)
Net income attributable to shareholders	$	160			$	116		$	39		$	315
Basic earnings per share
Basic weighted-average number of shares outstanding	461				446			N/A
Basic earnings per common share(b)	$	0.35			$	0.26		N/A
Diluted earnings per share
Net income attributable to shareholders and assumed conversions(c)	$	315			$	116		N/A
Diluted weighted-average number of shares	908				446			N/A
Diluted earnings per common share(b)	$	0.35			$	0.26		N/A
_______
(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalents payments.
(b)	The Class A shares earnings per share as compared to the Class P shares earnings per share were reduced due to the sharing of economic benefits (including dividends) amongst the Class A, B, and C shares.  Class A, B and C shares owned by Richard Kinder, the sponsor investors, the original shareholders, and other management were referred to as “investor retained stock,” and were convertible into a fixed number of Class P shares.  In the aggregate, our investor retained stock was entitled to receive a dividend per share on a fully-converted basis equal to the dividend per share on our common stock.  The conversion of shares of investor retained stock into Class P shares did not increase our total fully-converted shares outstanding, impact the aggregate dividends we paid or the dividends we paid per share on our Class P common stock.
(c)	For the diluted earnings per share calculation, total net income attributable to each class of common stock was divided by the adjusted weighted-average shares outstanding during the period, including all potential common stock equivalents.

Acquisitions_Notes

Acquisitions (Notes)	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	Acquisitions and Divestitures
	Business Combinations and Acquisitions of Investments
	During 2014, 2013 and 2012, we completed the following significant acquisitions accounted for in accordance with the “Business Combinations” Topic of the Codification.
	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. Additionally, we adjust goodwill as a result of applying the look-through method of recording deferred taxes on the outside book tax basis differences in our investments without regard to non-tax deductible goodwill. We do not expect our recorded goodwill to be deductible for tax purposes.
	The following table discloses our assignment of the purchase price for each of our significant acquisitions (in millions):
				Assignment of Purchase Price
	Ref.	Date	Acquisition	Purchase			Current		Property		Deferred		Goodwill		Long-term debt			Other liabilities			Non-controlling interest			Previously held equity interest
				price			assets		plant &		charges
									equipment		& other
	-1	14-Nov	Pennsylvania and Florida Jones Act Tankers	$	270		$	—	$	270	$	8	$	25	$	—		$	(33	)	$	—		$	—
	-2	14-Jan	American Petroleum Tankers and State Class Tankers	961			6		951		6		64		—			(66		)	—			—
	-3	13-Jun	Goldsmith-Landreth Field Unit	280			—		298		—		—		—			(18		)	—			—
	-4	13-May	Copano	3,733			218		2,788		1,973		963		(1,252		)	(236		)	(17		)	(704		)
	-5	12-May	EP	22,928			7,175		12,921		5,718		18,562		(13,417		)	(4,234		)	(3,797		)	—
	(1) Pennsylvania and Florida Jones Act Tankers
	On November 5, 2014, we acquired two Jones Act tankers from Crowley Maritime Corporation (Crowley) for approximately $270 million. The table above includes an allocation of deferred taxes of $8 million as a decrease to “Goodwill” and an increase to “Deferred charges & other” for the portion of our outside basis difference associated with the underlying goodwill. “Other liabilities” includes (i) $8 million of contingent consideration and (ii) $25 million associated with unfavorable customer contracts representing the amount, on a present value basis, by which the customer contracts were below market day rates at the time of the acquisition. The unfavorable contracts liability is being amortized as a noncash adjustment to revenue over the remaining contract period. The MT Pennsylvania and the MT Florida engage in the marine transportation of crude oil, condensate and refined products in the U.S. domestic trade, commonly referred to as the Jones Act trade, and are currently operating pursuant to multi-year charters with a major integrated oil company. The vessels each have approximately 330 MBbl of cargo capacity and are included in the Terminals business segment. The acquired vessels will continue to be operated by Crowley.
	(2) American Petroleum Tankers and State Class Tankers
	Effective January 17, 2014, we acquired APT and State Class Tankers (SCT) for aggregate consideration of $961 million in cash (the APT acquisition). The table above includes an allocation of deferred taxes of $6 million as a decrease to “Goodwill” and an increase to “Deferred charges & other” for the portion of our outside basis difference associated with the underlying goodwill. “Other liabilities” includes $61 million of unfavorable customer contracts representing the amount, on a present value basis, by which the customer contracts were below market day rates at the time of acquisition. This amount is being amortized as a noncash adjustment to revenue over the remaining contract period.
	APT is engaged in Jones Act trade and its primary assets consist of a fleet of five medium range Jones Act qualified product tankers, each with 330 MBbl of cargo capacity, and each operating pursuant to long-term time charters with high quality counterparties, including major integrated oil companies, major refiners and the U.S. Military Sealift Command. As of the closing date, the vessels’ time charters had an average remaining term of approximately four years, with renewal options to extend the terms by an average of two years. APT’s vessels are operated by Crowley.
	SCT has commissioned the construction of four medium range Jones Act qualified product tankers, each with 330 MBbl of cargo capacity. The SCT vessels are scheduled to be delivered in 2015 and 2016 and are being constructed by General Dynamics’ NASSCO shipyard. We expect to invest approximately $276 million, including capitalized interest, to complete the construction of these four SCT vessels, and upon delivery, the vessels will be operated pursuant to long-term time charters with a major integrated oil company. Each of the time charters has an initial term of five years, with renewal options to extend the term by up to three years. The APT acquisition complements and extends our existing crude oil and refined products transportation and storage business. We include the acquired assets as part of the Terminals business segment.
	(3) Goldsmith Landreth Field Unit
	On June 1, 2013, we acquired certain oil and gas properties, rights, and related assets in the Permian Basin of West Texas from Legado Resources LLC for an aggregate consideration of $298 million consisting of $280 million in cash and assumed liabilities of $18 million (including $12 million of long-term asset retirement obligations). The acquisition of the Goldsmith Landreth San Andres oil field unit includes more than 6,000 acres located in Ector County, Texas. The acquired oil field is in the early stages of CO2 flood development and includes a residual oil zone along with a classic San Andres waterflood. As part of the transaction, we obtained a long-term supply contract for up to 150 MMcf/d of CO2. The acquisition complemented our existing oil and gas producing assets in the Permian Basin, and we included the acquired assets as part of the CO2 business segment.
	(4) Copano
	Effective May 1, 2013, we acquired all of Copano’s outstanding units for a total purchase price of approximately $5.2 billion (including assumed debt and all other assumed liabilities). The transaction was a 100% unit for unit transaction with an exchange ratio of 0.4563 of KMP’s common units for each Copano common unit. KMP issued 43,371,210 of its common units valued at $3,733 million as consideration for the Copano acquisition (based on the $86.08 closing market price of a common unit on the NYSE on the May 1, 2013 issuance date). Due to the fact that our acquisition included the remaining 50% interest in Eagle Ford Gathering LLC (Eagle Ford) that we did not already own, we remeasured the carrying value ($146 million) of our existing 50% equity investment in Eagle Ford to its fair value ($704 million) as of the May 1, 2013 acquisition date. As a result of this remeasurement, we recognized a $558 million non-cash gain and we reported this gain within “Gain on remeasurement of previously held equity investments to fair value” in our accompanying consolidated statement of income for the year ended December 31, 2013.
	(5)  EP
	Effective on May 25, 2012, we acquired all of the outstanding shares of EP for an aggregate consideration of approximately $22.9 billion (excluding assumed debt, but including payments of $87 million for share based awards expensed in the post-combination period). In total, EP shareholders received (i) $11.6 billion in cash; (ii) 330 million KMI Class P shares with a fair value of $10.6 billion (based on the $32.11 closing market price of a Class P share on May 24, 2012); and (iii) 505 million KMI warrants with a fair value of $863 million (based on a fair value of $1.71 per warrant as of May 24, 2012). The warrants have an exercise price of $40 per share and a 5-year term.
	During the year 2012, we incurred $463 million, net of legal recoveries, of pre-tax expenses associated with the EP acquisition, including (i) $160 million in employee severance, retention and bonus costs; (ii) $87 million of accelerated EP stock based compensation allocated to the post-combination period under applicable GAAP rules; (iii) $37 million in advisory fees; (iv) $68 million for legal fees and reserves, net of legal recoveries; (v) a $108 million write-off (due to debt repayments) or amortization of capitalized financing fees associated with the EP acquisition financing; and less (vi) a $29 million benefit associated with pension income.
	Pro Forma Information
	The following summarized unaudited pro forma consolidated income statement information for the years ended December 31, 2014 and 2013, assumes that the Crowley, APT, Copano and the Goldsmith Landreth field unit acquisitions had occurred as of January 1, 2013. We prepared the following summarized unaudited pro forma financial results for comparative purposes only. The summarized unaudited pro forma financial results may not be indicative of the results that would have occurred if these acquisitions had been completed as of January 1, 2013 or the results that will be attained in the future. Amounts presented below are in millions, except for the per share amounts:
			Pro Forma
			Year Ended December 31,
			2014			2013
			(Unaudited)
	Revenues		$	16,260		$	14,911
	Income from continuing operations		2,448			2,665
	Income from discontinued operations, net of tax		—			(4		)
	Net income		2,448			2,661
	Net income attributable to noncontrolling interests		(1,419		)	(1,490		)
	Net income attributable to Kinder Morgan, Inc.		1,029			1,171
	Diluted earnings per common share
	Class P shares		$	0.9		$	1.12
	_______
	Acquisitions Subsequent to December 31, 2014
	On February 13, 2015, we acquired Hiland Partners, LP, a privately held Delaware limited partnership (Hiland) for an aggregate consideration of $3,058 million consisting of $1,715 million in cash and $1,343 million of assumed debt, of which approximately $368 million was immediately paid down after closing. The cash requirements associated with the acquisition were funded primarily from borrowings under a six-month bridge facility, discussed in Note 8 “Debt,” and with proceeds from sales of our Class P shares issued under our equity distribution agreement. 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.
	On February 9, 2015, we announced the acquisition of three U.S. terminals and one undeveloped site from Royal Vopak for approximately $158 million. The acquisition covers (i) a 36-acre, 1,069,500-barrel storage complex at Galena Park, Texas that handles base oils, biodiesel and crude oil and is immediately adjacent to our Galena Park terminal complex; (ii) two terminals in North Carolina, one terminal in North Wilmington that handles chemicals and black oil and one terminal in South Wilmington that is not currently operating; and (iii) an undeveloped site at Perth Amboy, New Jersey, with waterfront access that can be developed. The transaction, subject to customary approvals, is expected to close during the first quarter of 2015.
	Drop-down Assets
	In periods prior to the Merger Transactions, we completed the following drop-down transactions to KMP and EPB.
	•	Effective August 1, 2012, KMP acquired from us a 100% ownership interest in TGP and an initial 50% ownership interest in EPNG, referred to in this report as the August 2012 drop-down transaction;
	•	Effective March 1, 2013, KMP acquired from us the remaining 50% ownership interest it did not already own in both EPNG and the EP midstream assets (see “—KMP Previously Held Investment in El Paso Midstream Investment Company, LLC” following), referred to in this report as the March 2013 drop-down transaction; and
	•	On May 2, 2014, EPB acquired from us our 50% equity interest in Ruby Pipeline Holding Company, L.L.C. (Ruby), our indirect 50% equity interest in Gulf LNG Holdings Group, L.L.C. (Gulf LNG) and our indirect 47.5% equity interest in Young Gas Storage Company, Ltd., referred to in this report as the May 2014 drop-down transaction.
	In this report, we refer to these acquisitions of assets by KMP from us as the drop-down transactions. These drop-down transactions were accounted for as transfers of net assets between entities under common control. Specifically, KMP reflected the acquired assets and assumed liabilities at our carrying value, including our EP purchase accounting adjustments as of May 25, 2012; however our consolidated financial statements were not affected.
	KMP Previously Held Investment in El Paso Midstream Investment Company, LLC
	Effective June 1, 2012, KMP acquired a 50% ownership interest in El Paso Midstream Investment Company, LLC (EP Midstream) for an aggregate consideration of $289 million in common units. EP Midstream is a joint venture that owns gas gathering, processing and treating assets located in the Uinta Basin in Utah and a natural gas and oil gathering system located in the Eagle Ford shale formation in South Texas, collectively referred to in this report as the EP midstream assets.
	Since we owned the remaining 50% of the EP Midstream assets, we consolidated EP Midstream in the accompanying consolidated financial statements effective June 1, 2012. The operating results of the EP midstream assets are included in the Natural Gas Pipelines business segment. No gain or loss on the previously held equity investment was recognized as the fair value of the initial equity investment acquired through our EP acquisition was determined to equal the $289 million purchase price paid by KMP for its 50% interest. As such, the fair value of 100% of EP Midstream was determined to be $578 million.
	We measured the identifiable intangible assets acquired at fair value on the acquisition date, and as a result, we recognized $50 million in “Deferred charges and other assets,” representing the fair value of separate and identifiable relationships with existing customers.  We estimated the remaining useful life of these existing customer relationships to be approximately 10 years.  After measuring all of the identifiable tangible and intangible assets acquired and liabilities assumed at fair value on the acquisition date, we recognized $248 million of “Goodwill.”  We believe the primary item that generated the goodwill is our ability to grow the business by leveraging our pre-existing natural gas operations, and we believe that this value contributed to our acquisition price exceeding the fair value of acquired identifiable net assets and liabilities. This goodwill is not deductible for tax purposes.
	Income Tax Impact of the Drop-Down of EP Assets to KMP
	For income tax purposes, the March 2013 drop-down transaction was treated as a contribution and the August 2012 drop-down transaction was treated as a partial sale, and a partial contribution. As a result of the drop-down transactions, a deferred tax liability arose related to the portion of the outside basis difference associated with the underlying goodwill that was contributed to KMP by us. However, since the drop-downs were transactions between entities under common control, we recognized an offsetting deferred charge of $448 million for the August 2012 and $53 million for the March 2013 drop-down transactions. These balances were being amortized to income tax expense over the remaining useful lives of the transferred assets of approximately 25 years. For the years ended December 31, 2014 and 2013 and the period subsequent to the August 2012 drop-down through December 31, 2012, total income tax expense related to the amortization of the deferred charges was approximately $18 million, $20 million and $7 million, respectively. As a result of the tax impact of the Merger Transactions, the unamortized balance of the deferred charge of $456 million was reversed.
	Divestitures
	The FTC Natural Gas Pipelines Disposal Group – Discontinued Operations
	Following our March 2012 agreement with the U.S. FTC to divest certain assets in order to receive regulatory approval for our EP acquisition, we began accounting for the FTC Natural Gas Pipelines disposal group as discontinued operations (prior to our sale announcement, we included the disposal group in the Natural Gas Pipelines business segment). The FTC Natural Gas Pipelines disposal group’s assets consisted of some natural gas pipeline systems and a natural gas processing operation located in the rocky mountain region. Effective November 1, 2012, we sold the FTC Natural Gas Pipelines disposal group to Tallgrass Energy Partners, LP (now known as Tallgrass Development, LP) (Tallgrass), and we received proceeds of $1,791 million (before cash selling expenses) which we reported separately as “Proceeds from disposal of discontinued operations” within the investing section of our accompanying consolidated statement of cash flows for the year ended December 31, 2012. In November 2012, we also paid selling expenses of $78 million (consisting of certain required tax payments to joint venture partners).
	Additionally, we recognized (i) a $4 million loss for the year ended December 31, 2013, for the true up of the final consideration and certain incremental selling expenses and (ii) a combined remeasurement loss of $937 million for the year ended December 31, 2012, to reflect our assessment of fair value of the disposal group’s net assets as a result of the FTC mandated sale requirement. We reported these loss amounts separately as “Loss on sale and the remeasurement of the FTC Natural Gas Pipelines disposal group to fair value, net of tax” within the discontinued operations section of our consolidated statements of income for the years ended December 31, 2013 and 2012.
	Summarized financial information for the FTC Natural Gas Pipelines disposal group is as follows (in millions):
		Year Ended
		December 31, 2012(a)
Operating revenues	$	227
Operating expenses	(131		)
Depreciation and amortization	(7		)
Other expense	(1		)
Earnings from equity investments	70
Interest income and Other, net	2
Income from operations of the FTC Natural Gas Pipelines disposal group	$	160
_______
(a)	2012 amounts represent financial information for the ten month period ended October 31, 2012. We sold the FTC Natural Gas Pipelines disposal group effective November 1, 2012.
Express Pipeline System
Effective March 14, 2013, we sold both our one-third equity ownership interest in the Express pipeline system and our subordinated debenture investment in Express to Spectra Energy Corp. we received net cash proceeds of $402 million (after paying both a final working capital settlement and certain transaction related selling expenses), and we reported the net cash proceeds received from the sale separately as “Proceeds from sales of assets and investments” within the investing section of our accompanying consolidated statement of cash flows for the year ended December 31, 2013. Additionally, we recognized a combined $224 million pre-tax gain with respect to this sale, and we reported this gain amount separately as “Gain on sale of investments in Express pipeline system” on our accompanying consolidated statement of income for the year ended December 31, 2013. We also recorded an income tax expense of $84 million related to this gain on sale, and we included this expense within “Income Tax Expense.” As of the date of sale, our equity investment in Express totaled $67 million and the note receivable due from Express totaled $110 million.

Income_Taxes_Notes

Income Taxes (Notes)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes
	The components of “Income from Continuing Operations Before Income Taxes” are as follows (in millions):
		Year Ended December 31,
		2014			2013				2012
	U.S.	$	2,941		$	3,107			$	1,246
	Foreign	150			331				97
	Total Income from Continuing Operations Before Income Taxes	$	3,091		$	3,438			$	1,343
	_______
	Components of the income tax provision applicable to continuing operations for federal, foreign and state taxes are as follows (in millions):
		Year Ended December 31,
		2014			2013				2012
	Current tax expense
	Federal	$	(16	)	$	57			$	48
	State	36			36				34
	Foreign	13			9				10
	Total	33			102				92
	Deferred tax expense
	Federal	572			612				49
	State	14			—				4
	Foreign	29			28				(6		)
	Total	615			640				47
	Total tax provision	$	648		$	742			$	139
	_______
	The difference between the statutory federal income tax rate and our effective income tax rate is summarized as follows (in millions, except percentages):
		Year Ended December 31,
		2014						2013						2012
	Federal income tax	$	1,082		35	%		$	1,203			35	%	$	470		35	%
	Increase (decrease) as a result of:
	State deferred tax rate change	—			—	%		(21		)		(0.6	)%	20			1.5	%
	Taxes on foreign earnings	40			1.3	%		112				3.3	%	(6		)	(0.5	)%
	Net effects of consolidating KMP’s and EPB’s U.S. income tax provision	(433		)	(14.0	)%		(488		)		(14.2	)%	(288		)	(21.5	)%
	State income tax, net of federal benefit	37			1.2	%		45				1.3	%	21			1.6	%
	Dividend received deduction	(50		)	(1.6	)%		(54		)		(1.6	)%	(32		)	(2.4	)%
	Adjustments to uncertain tax positions	(5		)	(0.2	)%		(87		)		(2.5	)%	(72		)	(5.3	)%
	Valuation allowance on Investment in NGPL	61			2	%		—				—	%	—			—	%
	Disposition of certain international holdings	(112		)	(3.6	)%		—				—	%	—			—	%
	Other	28			0.9	%		32				0.9	%	26			1.9	%
	Total	$	648		21	%		$	742			21.6	%	$	139		10.3	%
	_______
	Deferred tax assets and liabilities result from the following (in millions):
		December 31,
		2014			2013
	Deferred tax assets
	Employee benefits	$	329		$	238
	Accrued expenses	123			136
	Net operating loss, capital loss, tax credit carryforwards	778			673
	Derivative instruments and interest rate and currency swaps	43			68
	Debt fair value adjustment	102			112
	Investments	4,858			—
	Other	31			43
	Valuation allowances	(154		)	(95		)
	Total deferred tax assets	6,110			1,175
	Deferred tax liabilities
	Property, plant and equipment	373			351
	Investments	—			4,888
	Other	30			20
	Total deferred tax liabilities	403			5,259
	Net deferred tax assets (liabilities)	$	5,707		$	(4,084	)
	Current deferred tax asset	$	56		$	567
	Non-current deferred tax assets (liabilities)	5,651			(4,651		)
	Net deferred tax assets (liabilities)	$	5,707		$	(4,084	)
	_______
	Deferred Tax Assets and Valuation Allowances: As a result of the Merger Transactions, we acquired directly or indirectly all of the equity interests of KMP, KMR and EPB that we and our subsidiaries did not already own. In exchange for their interests in KMP and EPB, we paid stock and cash with a fair market value of approximately $64 billion to the limited partner unit holders. This represents a taxable exchange for which we received a step-up in tax basis in the underlying assets acquired (our investment in KMP and EPB). A deferred tax asset of approximately $10.3 billion related to the book tax basis difference in this investment has been recorded, computed as $64 billion tax basis in excess of $36 billion book basis at our statutory tax rate of 36.48%.
	In accordance with ASC 810-10-45-23, if changes in a parent’s ownership interest do not result in a change in its controlling financial interest in its subsidiary, those changes should be accounted for as equity transactions. No gain or loss is recognized in consolidated net income or comprehensive income. The carrying amount of the noncontrolling interest is adjusted to reflect the change in ownership interest in the subsidiary. Any difference between the fair value of the consideration received or paid and the amount by which the noncontrolling interest is adjusted is recognized in equity attributable to the parent. Therefore, because the transaction conforms to the conditions set forth in ASC 810-10-45-23, we have concluded that the increase in the deferred tax assets should be recorded with the offset to equity rather than the income statement.
The step-up in tax basis results in a deferred tax asset of approximately $4.9 billion primarily related to our investment in KMP and EPB. As book earnings from our investment in KMP and EPB are projected to exceed taxable income (primarily as a result of the partnership’s tax depreciation in excess of book depreciation), the deferred tax asset related to our investment in KMP and EPB is expected to be fully realized.
We recorded a full valuation allowance of $61 million against the deferred tax asset related to our investment in NGPL as we no longer have viable means by which we reasonably expect to recover this asset.
We have deferred tax assets of $466 million related to net operating loss carryovers, $312 million related to alternative minimum and foreign tax credits, and $93 million of valuation allowances related to deferred tax assets at December 31, 2014. As of December 31, 2013, we had deferred tax assets of $354 million related to net operating loss carryovers, $11 million related to capital loss carryovers, $308 million related to alternative minimum and foreign tax credits, and valuation allowances related to deferred tax assets of $95 million. We expect to generate taxable income beginning in 2016 and utilize all federal net operating loss carryforwards and alternative minimum tax carryforwards by the end of 2018.
Expiration Periods for Deferred Tax Assets: As of December 31, 2014, we have U.S. federal net operating loss carryforwards of $906 million, which will expire from 2018 - 2034; state losses of $1.9 billion which will expire from 2014 - 2034; and foreign losses of $213 million, of which approximately $124 million carries over indefinitely and $89 million expires from 2028 - 2035. We also have $300 million of federal alternative minimum tax credits which do not expire; and approximately $11 million of foreign tax credits, the majority of which will expire from 2016 - 2024. Use of our U.S. federal carryforwards is subject to the limitations provided under Sections 382 and 383 of the Internal Revenue Code as well as the separate return limitation rules of Internal Revenue Service regulations.
Unrecognized Tax Benefits: We recognize the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities, based not only on the technical merits of the tax position based on tax law, but also the past administrative practices and precedents of the taxing authority.  The tax benefits recognized in the financial statements from such a position are measured based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate resolution.
A reconciliation of our gross unrecognized tax benefit excluding interest and penalties is as follows (in millions):
	Year Ended December 31,
	2014			2013				2012
Balance at beginning of period	$	209		$	269			$	57
Uncertain tax positions of EP	—			4				289
Subtotal	209			273				346
Additions based on current year tax positions	12			11				11
Additions based on prior year tax positions	—			26				1
Reductions based on prior year tax positions	(3		)	—				—
Reductions based on settlements with taxing authority	(24		)	(86		)		(55		)
Reductions due to lapse in statute of limitations	(5		)	(15		)		(34		)
Balance at end of period	$	189		$	209			$	269
_______
We recognize interest and/or penalties related to income tax matters in income tax expense. As of December 31, 2014, 2013, and 2012, we had $28 million, $29 million and $28 million of accrued interest and $2 million, $2 million and $2 million in accrued penalties, respectively.   All of the $189 million of unrecognized tax benefits, if recognized, would affect our effective tax rate in future periods.  In addition, we believe it is reasonably possible that our liability for unrecognized tax benefits will increase by approximately $1 million during the next year to approximately $190 million.
We are subject to taxation, and have tax years open to examination for the periods 2012-2013 in the U.S., 1999-2013 in various states and 2004-2013 in various foreign jurisdictions.
Schedule of Income before Income Tax, Domestic and Foreign [Table Text Block]	The components of “Income from Continuing Operations Before Income Taxes” are as follows (in millions):
		Year Ended December 31,
		2014			2013				2012
	U.S.	$	2,941		$	3,107			$	1,246
	Foreign	150			331				97
	Total Income from Continuing Operations Before Income Taxes	$	3,091		$	3,438			$	1,343

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment Disclosure [Text Block]	Property, Plant and Equipment
	Classes and Depreciation
	As of December 31, 2014 and 2013, our property, plant and equipment consisted of the following (in millions):
		December 31,
		2014			2013
	Natural gas, liquids, crude oil and CO2 pipelines	$	18,119		$	17,399
	Natural gas, liquids, CO2, and terminals station equipment	21,233			17,960
	Natural gas, liquids (including linefill), and transmix processing	520			259
	Other	3,964			3,656
	Accumulated depreciation, depletion and amortization	(8,369		)	(6,757		)
		35,467			32,517
	Land and land rights-of-way	1,324			1,158
	Construction work in process	1,773			2,172
	Property, plant and equipment, net	$	38,564		$	35,847
	_______
	As of December 31, 2014 and 2013, property, plant and equipment included $15,026 million and $14,957 million, respectively, of assets which were regulated by either the FERC or the NEB. Depreciation, depletion, and amortization expense charged against property, plant and equipment was $1,862 million, $1,663 million, and $1,324 million for the years ended December 31, 2014, 2013, and 2012, respectively.
	Asset Retirement Obligations
	As of December 31, 2014 and 2013, we recognized asset retirement obligations in the aggregate amount of $192 million and $204 million, respectively, of which $7 million and $25 million , respectively, were classified as current. The majority of our asset retirement obligations are associated with our CO2 business segment, where we are required to plug and abandon oil and gas wells that have been removed from service and to remove the surface wellhead equipment and compressors.
	We have various other obligations throughout our businesses to remove facilities and equipment on rights-of-way and other leased facilities.  We currently cannot reasonably estimate the fair value of these obligations because the associated assets have indeterminate lives.  These assets include pipelines, certain processing plants and distribution facilities, and certain bulk and liquids terminal facilities.  An asset retirement obligation, if any, will be recognized once sufficient information is available to reasonably estimate the fair value of the obligation.
	Impairments
	During 2014, continued deteriorating commodity prices for crude oil that is produced by the CO2 segment’s working interest in the Katz Strawn unit caused us to evaluate the carrying value of this oil producing field.  The estimated fair value on these assets was based on the future discounted cash flows using the forward WTI crude oil price curve.  We recognized a $235 million non-cash, pre-tax impairment charge to write-down this asset to its estimated fair value.

Investments_Investments_Notes

Investments Investments (Notes)	12 Months Ended
	Dec. 31, 2014
Investments [Abstract]
Equity Method Investments and Joint Ventures Disclosure [Text Block]	Investments
	Our investments primarily consist of equity investments where we hold significant influence over investee actions and which we account for under the equity method of accounting. As of December 31, 2014 and 2013 our investments consisted of the following (in millions):
		December 31,
		2014			2013
	Citrus Corporation	$	1,805		$	1,875
	Ruby Pipeline Holding Company, L.L.C.	1,123			1,153
	Midcontinent Express Pipeline LLC	748			602
	Gulf LNG Holdings Group, LLC	547			578
	EagleHawk	337			272
	Plantation Pipe Line Company	303			307
	Red Cedar Gathering Company	184			176
	Double Eagle Pipeline LLC	150			144
	Parkway Pipeline LLC	144			131
	Fayetteville Express Pipeline LLC	130			144
	Watco Companies, LLC	103			103
	Fort Union Gas Gathering L.L.C.	70			161
	Sierrita Pipeline LLC	63			19
	Cortez Pipeline Company	17			12
	All others	304			266
	Total equity investments	6,028			5,943
	Bond investments	8			8
	Total investments	$	6,036		$	5,951
	_______
	As shown in the table above, our significant equity investments, as of December 31, 2014 consisted of the following:
	•	Citrus Corporation—We own a 50% interest in Citrus Corporation, the sole owner of Florida Gas Transmission Company, L.L.C. (Florida Gas). Florida Gas transports natural gas to cogeneration facilities, electric utilities, independent power producers, municipal generators, and local distribution companies through a 5,300-mile natural gas pipeline. Energy Transfer Partners L.P. operates and owns the remaining 50% interest;
	•	Ruby Pipeline Holding Company, L.L.C.—We operate and own a 50% interest in Ruby Pipeline Holding Company, L.L.C., the sole owner of Ruby Pipeline natural gas transmission system. The remaining 50% interest is owned by a subsidiary of Veresen Inc. as convertible preferred interests;
	•	Midcontinent Express Pipeline LLC—We operate and own a 50% interest in MEP, the sole owner of the Midcontinent Express natural gas pipeline system.  The remaining 50% ownership interest is owned by subsidiaries of Regency Energy Partners L.P.;
	•	Gulf LNG Holdings Group, LLC—We operate and own a 50% interest in Gulf LNG Holdings Group, LLC, the owner of a LNG receiving, storage and regasification terminal near Pascagoula, Mississippi, as well as pipeline facilities to deliver vaporized natural gas into third party pipelines for delivery into various markets around the country. The remaining 50% ownership interests are wholly and partially owned by subsidiaries of GE Financial Services and The Blackstone Group L.P.;
	•	BHP Billiton Petroleum (Eagle Ford Gathering) LLC, f/k/a EagleHawk Field Services LLC and referred to in this report as EagleHawk—We own a 25% interest in EagleHawk, the sole owner of natural gas and condensate gathering systems serving the producers of the Eagle Ford shale formation. A subsidiary of BHP Billiton operates EagleHawk and owns the remaining 75% ownership interest;
	•	Plantation—We operate and own a 51.17% interest in Plantation, the sole owner of the Plantation refined petroleum products pipeline system.  A subsidiary of Exxon Mobil Corporation owns the remaining interest.  Each investor has an equal number of directors on Plantation’s board of directors, and board approval is required for certain corporate actions that are considered substantive participating rights; therefore, we do not control Plantation, and account for the investment under the equity method;
	•	Red Cedar Gathering Company—We own a 49% interest in Red Cedar Gathering Company, the sole owner of the Red Cedar natural gas gathering, compression and treating system.  The Southern Ute Indian Tribe owns the remaining 51% interest;
	•	Double Eagle Pipeline LLC - We owns a 50% equity interest in Double Eagle Pipeline LLC. The remaining 50% interest is owned by Magellan Midstream Partners;
	•	Parkway Pipeline LLC —We operate and own a 50% interest in Parkway Pipeline LLC, the sole owner of the Parkway Pipeline refined petroleum products pipeline system. Valero Energy Corp. owns the remaining 50% interest;
	•	Fayetteville Express Pipeline LLC —We own a 50% interest in FEP, the sole owner of the Fayetteville Express natural gas pipeline system.  Energy Transfer Partners, L.P. owns the remaining 50% interest and serves as operator of Fayetteville Express Pipeline LLC;
	•	Watco Companies, LLC—We hold a preferred equity investment in Watco Companies, LLC, the largest privately held short line railroad company in the U.S.  We own 100,000 Class A preferred shares and pursuant to the terms of the investment, receive priority, cumulative cash distributions from the preferred shares at a rate of 3.25% per quarter, and participates partially in additional profit distributions at a rate equal to 0.5%.  The preferred shares have no conversion features and hold no voting powers, but do provide us certain approval rights, including the right to appoint one of the members to Watco’s Board of Managers;
	•	Fort Union Gas Gathering LLC—We own a 37.04% equity interest in the Fort Union Gas Gathering LLC. Crestone Powder River LLC, a subsidiary of ONEOK Partners, owns 37.04%; WPX Energy Rocky Mountain, LLC owns 11.11%; and Western Gas Wyoming, LLC owns the remaining 14.81%. Western Gas Resources, Inc. serves as operator of Fort Union Gas Gathering LLC;
	•	Sierrita Pipeline LLC — We operate and own a 35% equity interest in the Sierrita Pipeline LLC. MGI Enterprises U.S. LLC, a subsidiary of PEMEX, owns 35%; and MIT Pipeline Investment Americas, Inc., a subsidiary of Mitsui & Co., Ltd, owns 30%;
	•	Cortez Pipeline Company—We operate and own a 50% interest in the Cortez Pipeline Company, the sole owner of the Cortez carbon dioxide pipeline system.  A subsidiary of Exxon Mobil Corporation owns a 37% interest and Cortez Vickers Pipeline Company owns the remaining 13% interest; and
	•	NGPL Holdco LLC— We operate and own a 20% interest in NGPL Holdco LLC, the owner of NGPL and certain affiliates, collectively referred to in this report as NGPL, a major interstate natural gas pipeline and storage system.
	Our earnings (losses) from equity investments were as follows (in millions):
		Year Ended December 31,
		2014			2013			2012
	Citrus Corporation(a)	$	97		$	84		$	53
	Fayetteville Express Pipeline LLC	55			55			55
	Gulf LNG Holdings Group, LLC(a)	48			47			22
	Midcontinent Express Pipeline LLC	45			40			42
	Red Cedar Gathering Company	33			31			32
	Plantation Pipe Line Company	29			35			32
	Cortez Pipeline Company	25			24			25
	Fort Union Gas Gathering L.L.C.(b)	16			11			—
	Ruby Pipeline Holding Company, L.L.C.(a)	15			(6		)	(5		)
	Watco Companies, LLC	13			13			13
	Parkway Pipeline LLC	8			1			—
	Sierrita Pipeline LLC	3			—			—
	NGPL Holdco LLC(c)	—			(66		)	(198		)
	Double Eagle Pipeline LLC(b)	(1		)	1			—
	EagleHawk	(7		)	9			11
	All others	27			48			71
	Total	$	406		$	327		$	153
	Amortization of excess costs	$	(45	)	$	(39	)	$	(23	)
	_______
	(a)	2012 amounts are for the period from May 25, 2012 through December 31, 2012.
	(b)	2013 amounts are for the period from May 1, 2013 through December 31, 2013.
	(c)	2013 and 2012 amounts include non-cash investment impairment charges, which we recorded in the amount of $65 million and $200 million (pre-tax), respectively.
Summarized combined financial information for our significant equity investments (listed or described above) is reported below (in millions; amounts represent 100% of investee financial information):
		Year Ended December 31,
Income Statement		2014			2013			2012
Revenues		$	3,829		$	3,615		$	3,681
Costs and expenses		3,063			2,803			3,194
Net income (loss)		$	766		$	812		$	487
_______
		December 31,
Balance Sheet		2014			2013
Current assets		$	943		$	950
Non-current assets		20,630			20,782
Current liabilities		1,643			1,451
Non-current liabilities		10,841			11,351
Partners’/owners’ equity		9,089			8,930
_______

Goodwill_and_Other_Intangibles

Goodwill and Other Intangibles (Notes)	12 Months Ended
	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets Disclosure [Text Block]	Goodwill and Other Intangibles
	Goodwill and Excess Investment Cost
	We record the excess of the cost of an acquisition price over the fair value of acquired net assets as an asset on our balance sheet. This amount is referred to and reported separately as “Goodwill” in our accompanying consolidated balance sheets. Goodwill is not subject to amortization but must be tested for impairment at least annually. This test requires us to assign goodwill to an appropriate reporting unit and to determine if the implied fair value of the reporting unit’s goodwill is less than its carrying amount.
	We evaluate goodwill for impairment on May 31 of each year. For this purpose, we have seven reporting units as follows: (i) Products Pipelines (excluding associated terminals); (ii) Products Pipelines Terminals (evaluated separately from Products Pipelines for goodwill purposes); (iii) Natural Gas Pipelines Regulated; (iv) Natural Gas Pipelines Non-Regulated; (v) CO2; (vi) Terminals; and (vii) Kinder Morgan Canada.  During the quarter ended June 30, 2013, we created the Natural Gas Pipelines Non-Regulated reporting unit to include the non-regulated businesses we acquired from Copano on May 1, 2013 as well as other non-regulated businesses that were historically part of the former Natural Gas Pipelines reporting unit (now the Natural Gas Pipelines Regulated reporting unit). We then allocated goodwill between these two reporting units based on the relative fair values of the reporting units.
	There were no impairment charges resulting from our May 31, 2014 impairment testing, and no event indicating an impairment has occurred subsequent to that date. We determined the fair value of each reporting unit as of May 31, 2014 based on a market approach utilizing an average dividend/distribution yield of comparable companies. The value of each reporting unit was determined on a stand-alone basis from the perspective of a market participant and represented the price estimated to be received in a sale of the unit as a whole in an orderly transaction between market participants at the measurement date.
	Changes in the gross amounts of our goodwill and accumulated impairment losses for each of the years ended December 31, 2014 and 2013 are summarized as follows (in millions):
		Natural Gas Pipelines			CO2		Products Pipelines			Terminals			Kinder			Total
													Morgan
													Canada
	Historical Goodwill	$	22,276		$	1,528	$	2,129		$	1,484		$	626		$	28,043
	Accumulated impairment losses	(2,090		)	—		(1,267		)	(677		)	(377		)	(4,411		)
	Balance as of December 31, 2012	20,186			1,528		862			807			249			23,632
	Acquisitions(a)	888			—		—			—			—			888
	Currency translation adjustments	—			—		—			—			(16		)	(16		)
	Balance as of December 31, 2013	21,074			1,528		862			807			233			24,504
	Acquisitions(a)(b)	82			—		—			89			—			171
	Currency translation adjustments	—			—		—			—			(19		)	(19		)
	Impairment	—			—		—			(2		)	—			(2		)
	Balance as of December 31, 2014	$	21,156		$	1,528	$	862		$	894		$	214		$	24,654
	_______
	(a)	2014 and 2013 Natural Gas Pipelines acquisition amounts include $82 million and $881 million, respectively, relating to the May 1, 2013 Copano acquisition as discussed in Note 3. 2013 Natural Gas Pipelines acquisition amount also includes $7 million relating to other EP acquisition assets.
	(b)	2014 Terminals acquisition amount includes $64 million related to the January 17, 2014 APT acquisition and $25 million related to the November 5, 2014 Crowley acquisition.
	For more information on our accounting for goodwill, see Note 2.
	With regard to our equity investments in unconsolidated affiliates, in almost all cases, either (i) the price we paid to acquire our share of the net assets of such equity investees or (ii) the revaluation of our share of the net assets of any retained noncontrolling equity investment (from the sale of a portion of our ownership interest in a consolidated subsidiary, thereby losing our controlling financial interest in the subsidiary) differed from the underlying carrying value of such net assets.  This differential consists of two pieces.  First, an amount related to the difference between the investee’s recognized net assets at book value and at current fair values (representing the appreciated value in plant and other net assets), and secondly, to any premium in excess of fair value (referred to as equity method goodwill) we paid to acquire the investment.  We include both amounts within “Investments” on our accompanying consolidated balance sheets.
	The first differential, representing the excess of the fair market value of our investees’ plant and other net assets over its underlying book value at either the date of acquisition or the date of the loss of control totaled $746 million and $809 million as of December 31, 2014 and 2013, respectively. In almost all instances, this differential, relating to the discrepancy between our share of the investee’s recognized net assets at book values and at current fair values, represents our share of undervalued depreciable assets, and since those assets (other than land) are subject to depreciation, we amortize this portion of our investment cost against our share of investee earnings.  As of December 31, 2014, this excess investment cost is being amortized over a weighted average life of approximately thirteen years.
	The second differential, representing total unamortized excess cost over underlying fair value of net assets acquired (equity method goodwill) totaled $138 million as of both December 31, 2014 and 2013. This differential is not subject to amortization but rather to impairment testing.  Accordingly, in addition to our annual impairment test of goodwill, we periodically reevaluate the amount at which we carry the excess of cost over fair value of net assets accounted for under the equity method, as well as the amortization period for such assets, to determine whether current events or circumstances warrant adjustments to our carrying value and/or revised estimates of useful lives.  Our impairment test considers whether the fair value of the equity investment as a whole, not the underlying net assets, has declined and whether that decline is other than temporary.  As of December 31, 2014, we believed no such impairment had occurred and no reduction in estimated useful lives was warranted.
	Other Intangibles
	Excluding goodwill, our other intangible assets include customer contracts, relationships and agreements, lease value, and technology-based assets.  As of December 31, 2014 and 2013, these intangible assets totaled $2,302 million and $2,438 million, respectively, and primarily consisted of customer contracts, relationships and agreements associated with our Natural Gas Pipelines and Terminals business segments.
	Primarily, these contracts, relationships and agreements relate to the gathering of natural gas, and the handling and storage of petroleum, chemical, and dry-bulk materials, including oil, gasoline and other refined petroleum products, coal, petroleum coke, fertilizer, steel and ores.  We determined the values of these intangible assets by first, estimating the revenues derived from a customer contract or relationship (offset by the cost and expenses of supporting assets to fulfill the contract), and second, discounting the revenues at a risk adjusted discount rate.
	We amortize the costs of our intangible assets to expense in a systematic and rational manner over their estimated useful lives.  The life of each intangible asset is based either on the life of the corresponding customer contract or agreement or, in the case of a customer relationship intangible (the life of which was determined by an analysis of all available data on that business relationship), the length of time used in the discounted cash flow analysis to determine the value of the customer relationship.  Among the factors we weigh, depending on the nature of the asset, are the effect of obsolescence, new technology, and competition.
	For the years ended December 31, 2014, 2013 and 2012, the amortization expense on our intangibles totaled $143 million , $125 million and $86 million, respectively.  Our estimated amortization expense for our intangible assets for each of the next five fiscal years (2015 – 2019) is approximately $142 million, $133 million, $129 million, $126 million, and $125 million , respectively.  As of December 31, 2014, the weighted average amortization period for our intangible assets was approximately nineteen years.

Debt_Notes

Debt (Notes)	12 Months Ended
	Dec. 31, 2014
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 using the effective interest rate method. 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):
		December 31,
		2014				2013
	KMI and Subsidiaries
	Senior term loan facilities, variable rate, due May 24, 2015 and May 6, 2017(a)	$	—			$	1,528
	Senior notes and debentures, 2.00% through 8.25%, due 2014 through 2098(b)(c)(d)	11,438				5,645
	Credit facility due November 26, 2019(e)(f)	850				175
	Commercial paper borrowings(e)(f)	386				—
	KMP
	Senior notes, 2.65% through 9.00%, due 2014 through 2044(b)	17,800				15,600
	Commercial paper borrowings(g)(h)	—				979
	Credit facility due May 1, 2018(g)	—				—
	TGP senior notes, 7.00% through 8.375%, due 2016 through 2037(b)	1,790				1,790
	EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032(b)	1,115				1,115
	Copano senior notes, 7.125% due April 1, 2021(b)	332				332
	EPB
	EPPOC senior notes, 4.10% through 7.50%, due 2015 through 2042(b)(i)	2,860				2,260
	Credit facility due May 27, 2016(g)	—				—
	CIG, senior notes, 5.95% through 6.85%, due 2015 through 2037(b)(j)	475				475
	SLNG senior notes, 9.50% through 9.75%, due 2014 through 2016(b)(k)	—				135
	SNG notes, 4.40% through 8.00%, due 2017 through 2032(b)(l)	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(b)	1,636				1,636
	EPC Building, LLC, promissory note, 3.967%, due 2014 through 2035	453				461
	Preferred securities, 4.75%, due March 31, 2028(d)(m)	280				280
	KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock(n)	100				100
	Other miscellaneous debt(o)	303				494
	Total debt – KMI and Subsidiaries	41,029				34,216
	Less: Current portion of debt(p)	2,717				2,306
	Total long-term debt – KMI and Subsidiaries(q)	$	38,312			$	31,910
	_______
	(a)	The senior secured term loan facility, due May 24, 2015, was repaid and replaced in May 2014 with a new unsecured senior term loan facility due May 6, 2017. The unsecured senior term loan facility was repaid in November 2014 (see “—Credit Facilities and Restrictive Covenants” below).
	(b)	Notes provide for the redemption at any time at a price equal to 100% of the principal amount of the notes plus accrued interest to the redemption date plus a make whole premium.
	(c)	Includes $6.0 billion of senior notes issued on November 26, 2014 as a result of the Merger Transactions (see “—Debt Issuances and Repayments” below).
	(d)	On June 30, 2014, El Paso Issuing Corporation, a wholly-owned subsidiary of El Paso Holdco LLC and the corporate co-issuer under certain guaranteed notes, merged with and into El Paso Holdco LLC, a wholly-owned subsidiary of KMI, and immediately thereafter, El Paso Holdco LLC merged with and into KMI pursuant to an internal restructuring transaction. KMI succeeded El Paso Holdco LLC as issuer with respect to these debt obligations. Consequently, El Paso Holdco LLC ceased to be an obligor with respect to approximately $3.6 billion of outstanding senior notes.
	(e)	As of December 31, 2014 and 2013, the weighted average interest rates on our credit facility borrowings, including commercial paper borrowings in 2014, were 1.54% and 2.67%, respectively.
	(f)	On November 26, 2014, we entered into a $4 billion replacement credit facility and a commercial paper program of up to $4 billion of unsecured notes (see “—Credit Facilities and Restrictive Covenants” below).
	(g)	On November 26, 2014, in conjunction with the Merger Transactions, KMP’s and EPB’s credit facility and KMP’s commercial paper program were terminated.
	(h)	As of December 31, 2013, the average interest rate on KMP’s outstanding commercial paper borrowings was 0.28%. The borrowings under KMP’s commercial paper program were used principally to finance the acquisitions and capital expansions it made during 2014 and 2013.
	(i)	EPPOC’s operating assets are its investments in WIC, CIG, SLNG, Elba Express, SNG, SLC, CPG, EP Ruby, LLC, Southern Gulf LNG Company, L.L.C. and CIG Gas Storage Company LLC. There are no significant restrictions on EPPOC’s ability to access the net assets or cash flows related to its controlling interests in the operating companies either through dividend or loan. The restrictive covenants under these debt obligations are no more restrictive than the restrictive covenants under our credit facility. (See also “—Debt Issuances and Repayments” below.)
	(j)	CIG is subject to a number of restrictions and covenants under its debt obligation. The most restrictive of these include limitations on the incurrence of liens and limitations on sale-leaseback transactions.
	(k)	The SLNG senior notes were repaid on November 26, 2014.
	(l)	Under its indentures, SNG is subject to a number of restrictions and covenants. The most restrictive of these include limitations on the incurrence of liens. Southern Natural Issuing Corporation (SNIC) is a wholly owned finance subsidiary of SNG and is the co-issuer of certain of SNG’s outstanding debt securities. SNIC has no material assets, operations, revenues or cash flows other than those related to its service as a co-issuer of the debt securities. Accordingly, it has no ability to service obligations on the debt securities.
	(m)	Capital Trust I (Trust I), is a 100%-owned business trust that as of December 31, 2014, had $5.6 million of 4.75% trust convertible preferred securities outstanding (referred to as the EP Trust I Preferred Securities). Trust I exists for the sole purpose of issuing preferred securities and investing the proceeds in 4.75% convertible subordinated debentures, which are due 2028. Trust I’s sole source of income is interest earned on these debentures. This interest income is used to pay distributions on the preferred securities. We provide a full and unconditional guarantee of the EP Trust I Preferred Securities. There are no significant restrictions from these securities on our ability to obtain funds from our subsidiaries by distribution, dividend or loan. The EP Trust I Preferred Securities are non-voting (except in limited circumstances), pay quarterly distributions at an annual rate of 4.75%, carry a liquidation value of $50 per security plus accrued and unpaid distributions and are convertible at any time prior to the close of business on March 31, 2028, at the option of the holder, into the following mixed consideration: (i) 0.7197 of a share of our Class P common stock; (ii) $25.18 in cash without interest; and (iii) 1.100 warrants to purchase a share of our Class P common stock. We have the right to redeem these Trust I Preferred Securities at any time. Because of the substantive conversion rights of the securities into the mixed consideration, we bifurcated the fair value of the EP Trust I Preferred Securities into debt and equity components and as of December 31, 2014, the outstanding balance of $280 million (of which $141 million is classified as current) was bifurcated between debt ($248 million) and equity ($32 million). During the years ended December 31, 2014 and 2013, 3,923 and 107,618 EP Trust I Preferred Securities had been converted into (i) 2,820 and 77,442 shares of our Class P common stock; (ii) approximately $99,000 and $3 million in cash; and (iii) 4,315 and 118,377 in warrants, respectively.
	(n)	As of December 31, 2014, KMGP had outstanding 100,000 shares of its $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock due 2057.  Since August 18, 2012, dividends on the preferred stock accumulate at a floating rate of the 3-month LIBOR plus 3.8975% and are payable quarterly in arrears, when and if declared by KMGP’s board of directors, on February 18, May 18, August 18 and November 18 of each year, beginning November 18, 2012.  The preferred stock has approval rights over a commencement of or filing of voluntary bankruptcy by KMP or its SFPP or Calnev subsidiaries (see “—KMGP Preferred Shares” below).
	(o)	In conjunction with the construction of the Totem Gas Storage facility (Totem) and the High Plains pipeline (High Plains), CIG’s joint venture partner in WYCO funded 50% of the construction costs. EPB reflected the payments made by their joint venture partner as other long-term liabilities on the balance sheet during construction and upon project completion, the advances were converted into a financing obligation to WYCO. Upon placing these projects in service, EPB transferred its title in the projects to WYCO and leased the assets back. Although EPB transferred the title in these projects to WYCO, the transfer did not qualify for sale leaseback accounting because of EPB’s continuing involvement through its equity investment in WYCO. As such, the costs of the facilities remain on our balance sheets and the advanced payments received from EPB’s 50% joint venture partner were converted into a financing obligation due to WYCO. As of December 31, 2014, the principal amounts of the Totem and High Plains financing obligations were $73 million and $100 million, respectively, which will be paid in monthly installments through 2039 based on the initial lease term. At the expiration of the initial lease term, the lease agreement shall be extended automatically for the term of related firm service agreements. The interest rate on these obligations is 15.5%, payable on a monthly basis.
	(p)	Includes commercial paper borrowings.
	(q)	Excludes debt fair value adjustments. As of December 31, 2014 and December 31, 2013, our total “Debt fair value adjustments” increased our combined debt carrying amounts by $1,934 million and $1,977 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. For further information about our debt fair value adjustments, see Note 13.
	After the consummation of the Merger Transactions, KMI, KMP and EPB and substantially all of their respective wholly owned subsidiaries with debt entered into a cross guarantee agreement with respect to the existing debt of KMI, KMP, EPB and such subsidiaries, so that KMI and those subsidiaries are liable for the debt of KMI, KMP, EPB and such subsidiaries. Also, see Note 18.
	Credit Facilities and Restrictive Covenants
	On September 19, 2014, we entered into a new five-year $4.0 billion revolving credit agreement with a syndicate of lenders, which can be increased to $5.0 billion if certain conditions are met. The new revolving credit agreement was effective upon the closing of the Merger Transactions on November 26, 2014 and replaced the prior KMI credit agreement, the KMP credit agreement and the EPB credit agreement. On November 26, 2014, we entered into a $4.0 billion commercial paper program through the private placement of short-term notes. The notes mature up to 270 days from the date of issue and are not redeemable or subject to voluntary prepayment by us prior to maturity. The notes are sold at par value less a discount representing an interest factor or if interest bearing, at par. 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, our borrowings under our commercial paper program reduce the borrowings allowed under our credit facility.
	Our credit facility borrowings bear interest at either (i) LIBOR plus an applicable margin ranging from 1.125% to 2.000% per annum based on our credit ratings or (ii) the greatest of (1) the Federal Funds Rate plus 0.5%; (2) the Prime Rate; and (3) LIBOR Rate for a one month eurodollar loan, plus 1%, plus, in each case, an applicable margin ranging from 0.125% to 1.00% per annum based on our credit rating. As of December 31, 2014, we were in compliance with all required financial covenants (described following).
	Our credit facility included the following restrictive covenants as of December 31, 2014:
	•	total debt divided by earnings before interest, income taxes, depreciation and amortization may not exceed:
	•	6.50: 1.00, for the period ended on or prior to December 31, 2017; or
	•	6.25: 1.00, for the period ended after December 31, 2017 and on or prior to December 31, 2018; or
	•	6.00: 1.00, for the period ended after December 31, 2018;
	•	certain limitations on indebtedness, including payments and amendments;
	•	certain limitations on entering into mergers, consolidations, sales of assets and investments;
	•	limitations on granting liens; and
	•	prohibitions on making any dividend to shareholders if an event of default exists or would exist upon making such dividend.
	As of December 31, 2014, we had $850 million outstanding under our credit facility, $386 million outstanding under our commercial paper program and $223 million in letters of credit. Our availability under this facility as of December 31, 2014 was $2,541 million.
	Subsequent Event
On February 4, 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. The credit facility bears interest at the same rate as our $4.0 billion revolving credit facility and the borrowing capacity is reduced by any payments made. As of the date of this filing, we had $1,516 million outstanding under this credit facility.
Copano Debt Acquired
As of the May 1, 2013 Copano acquisition date, KMP assumed the following outstanding Copano debt amounts (i) $404 million of outstanding borrowings under Copano’s revolving credit facility due June 10, 2016; (ii) $249 million aggregate principal amount of Copano’s 7.75% unsecured senior notes due June 1, 2018; and (iii) $510 million aggregate principal amount of Copano’s 7.125% unsecured senior notes due April 1, 2021.
Debt Issuances and Repayments
Apart from the assumption of the Copano debt discussed above, following are significant long-term debt issuances and repayments made during 2014 and 2013:
		2014		2013
Issuances		$650 million senior term loan facility due 2017		$750 million 5.00% notes due 2021
		$500 million 2.00% notes due 2017(b)		$750 million 5.625% notes due 2023
		$1,500 million 3.05% notes due 2019(b)		$251 million EPC Building, LLC 3.967% promissory notes(a)
		$1,500 million 4.30% notes due 2025(b)		$600 million 3.50% notes due 2023
		$750 million 5.30% notes due 2034(b)		$700 million 5.00% notes due 2043
		$1,750 million 5.55% notes due 2045(b)		$800 million 2.65% notes due 2019
		$750 million 3.50% notes due 2021		$650 million 4.15% notes due 2024
		$750 million 5.50% notes due 2044
		$650 million 4.25% notes due 2024
		$550 million 5.40% notes due 2044
		$600 million 4.30% notes due 2024
Repayments		$500 million 5.125% notes due 2014		$500 million 5.00% notes due 2013
		$1,528 million senior term loan facility due 2015		$1,186 million senior term loan facility due 2015
		$650 million senior term loan facility due 2017(b)		$88 million 8.00% notes due 2013
		$207 million 6.875% notes due 2014		$249 million 7.75% notes due 2018(c)
				$178 million portion of 7.125% notes due 2021(d)
________
(a)	In December 2012, our subsidiary, EPC Building, LLC had issued $468 million of 3.967% amortizing promissory notes with payments due 2013 through 2035, of which $217 million was issued to third parties and the remaining $251 million was held by KMI until they were sold to third parties in April of 2013.
(b) Debt issued or repaid associated with the Merger Transactions.
(c) KMP paid $259 million (based on a price of 103.875% of the principal amount) to fully redeem and retire the 7.75% series of senior notes in accordance with the terms and conditions of the indenture governing the notes.
(d) KMP paid $191 million for the partial redemption of the 7.125% senior notes.
KMGP Preferred Shares
The following table provides information about KMGP’s distributions on 100,000 shares of its Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock:
		Year Ended December 31,
		2014				2013
Per share cash distribution declared for the period(a)		$	41.86			$	42.101
Per share cash distribution paid in the period		$	41.877			$	42.169
_______
(a)	On January 21, 2015, KMGP declared a distribution for the three months ended December 31, 2014, of $10.553 per share, which was paid on February 18, 2015 to shareholders of record as of February 2, 2015.
Maturities of Debt
The scheduled maturities of the outstanding debt balances, excluding debt fair value adjustments as of December 31, 2014, are summarized as follows (in millions):
Year		Total
2015		$	2,717
2016		1,684
2017		3,059
2018		2,328
2019		2,819
Thereafter		28,422
Total		$	41,029
_______
Interest Rates, Interest Rate Swaps and Contingent Debt
The weighted average interest rate on all of our borrowings was 5.02% during 2014 and 5.08% during 2013. Information on our interest rate swaps is contained in Note 13. For information about our contingent debt agreements, see Note 12.
Subsequent Event
Subsequent to December 31, 2014, additional EP Trust I Preferred Securities were converted, primarily consisting of 969,117 EP Trust I Preferred Securities converted on January 14, 2015, into (i) 697,473 of our Class P common stock; (ii) approximately $24 million in cash; and (iii) 1,066,028 in warrants.

Recent_Accounting_Pronouncemen

Recent Accounting Pronouncements (Notes)	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
New Accounting Pronouncements and Changes in Accounting Principles [Text Block]	Recent Accounting Pronouncements
	Accounting Standards Updates
	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.

Sharebased_Compensation_and_Em

Share-based Compensation and Employee Benefits Share-based Compensation and Employee Benefits (Notes)	12 Months Ended
	Dec. 31, 2014
Share-based Compensation [Abstract]
Share based compensation and pension and other postretirement benefits disclosure [Text Block]	Share-based Compensation and Employee Benefits
	Share-based Compensation
	Kinder Morgan, Inc.
	Class P Shares
	Stock Compensation Plan for Non-Employee Directors
	We have a Stock Compensation Plan for Non-Employee Directors, in which our eligible non-employee directors participate.  The plan recognizes that the compensation paid to each eligible non-employee director is fixed by our board, generally annually, and that the compensation is payable in cash.  Pursuant to the plan, in lieu of receiving some or all of the cash compensation, each eligible non-employee director may elect to receive shares of Class P common stock.  Each election will be generally at or around the first board meeting in January of each calendar year and will be effective for the entire calendar year.  An eligible director may make a new election each calendar year.  The total number of shares of Class P common stock authorized under the plan is 250,000.  During 2014, 2013 and 2012, we made restricted Class P common stock grants to our non-employee directors of 6,210, 5,710 and 5,520, respectively. These grants were valued at time of issuance at $220,000, $210,000 and $185,000, respectively. All of the restricted stock grants made to non-employee directors vest during a six-month period.
	Restricted Stock and Long-term Incentive Retention Award Plan
	Upon our initial public offering, our restricted stock compensation program replaced our Long-term Incentive Retention Award Plan (discussed below). Our restricted stock compensation program is available to employees eligible under the former Long-term Incentive Retention Award Plan.  The following table sets forth a summary of activity and related balances of our restricted stock excluding that issued to non-employee directors (in millions, except share amounts):
		Year Ended							Year Ended							Year Ended
		December 31, 2014							December 31, 2013							December 31, 2012
		Shares			Weighted Average				Shares			Weighted Average				Shares			Weighted Average
					Grant Date							Grant Date							Grant Date
					Fair Value							Fair Value							Fair Value
	Outstanding at beginning of period	6,382,885			$	239			2,154,022			$	69			1,163,090			$	33
	Granted	1,694,668			61				4,563,495			181				1,463,388			51
	Vested	(460,032	)		(14		)		(83,444	)		(3		)		(102,033	)		(3		)
	Forfeited	(244,227	)		(9		)		(251,188	)		(8		)		(370,423	)		(12		)
	Outstanding at end of period	7,373,294			$	277			6,382,885			$	239			2,154,022			$	69
	Intrinsic value of restricted stock vested during the period				$	17						$	3						$	4
	Restricted stock grants made to employees have vesting periods ranging from 1 year with variable vesting dates to 10 years. Following is a summary of the future vesting of our outstanding restricted stock grants:
	Year		Vesting of Restricted Shares
	2015		713,675
	2016		1,337,884
	2017		1,653,507
	2018		1,111,830
	2019		1,720,568
	2020		580,759
	2021		199,725
	2023		55,346
	Total Outstanding		7,373,294
	_______
	The related expense less estimated forfeitures is recognized ratably over the vesting period of the restricted stock grants.  Upon vesting, the grants will be paid in our Class P common shares.
	During 2014, 2013 and 2012, we recorded $57 million, $35 million and $14 million, respectively, in expense related to restricted stock grants.  At December 31, 2014 and 2013, unrecognized restricted stock compensation expense, less estimated forfeitures, was approximately $170 million and $177 million, respectively.
	From 2006 until our initial public offering, we elected not to make any restricted stock awards as a result of a 2007 going private transaction.  To ensure that certain key employees who had previously received restricted stock and restricted stock unit awards continued under a long-term retention and incentive program, we implemented the Long-term Incentive Retention Award plan.  The plan provided cash awards approved by our compensation committees which were granted in July of each year to recommended key employees.  Senior management was not eligible for these awards.  These grants required the employee to sign a grant agreement.  The grants vested 100% after the third year anniversary of the grant provided the employee remained with us.  The last grants made under this plan were made in July of 2010. During the years ended December 31, 2013 and 2012, we expensed $2 million and $7 million, respectively, related to these grants.
	Pension and Other Postretirement Benefit Plans
	Overview of Retirement Benefit Plans
	Savings Plan
	We maintain a defined contribution plan covering eligible U.S. employees. We contribute 5% of eligible compensation for most of the plan participants. Certain plan participants’ contributions and Company contributions are based on collective bargaining agreements. In connection with the EP acquisition, we assumed EP’s defined contribution savings plan which was merged into our savings plan during 2012. In connection with the Copano acquisition, we assumed Copano’s defined contribution savings plan which was merged into our savings plan during 2013. The total amount charged to expense for our savings plan was approximately $42 million, $40 million, and $32 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	Pension Plans
	Our pension plan is a defined benefit plan that covers substantially all of our U.S. employees and provides benefits under a cash balance formula. A participant in the cash balance plan accrues benefits through contribution credits based on a combination of age and years of service times eligible compensation. Interest is also credited to the participant’s plan account. A participant becomes fully vested in the plan after three years, and may take a lump sum distribution upon termination of employment or retirement. Certain collectively bargained and grandfathered employees continue to accrue benefits through career pay or final pay formulas.
	Other Postretirement Benefit Plans
	We and certain of our U.S. subsidiaries provide other postretirement benefits (OPEB), including medical benefits for closed groups of retired employees and certain grandfathered employees and their dependents, and limited postretirement life insurance benefits for retired employees. Medical benefits for these closed groups of retirees may be subject to deductibles, co-payment provisions, dollar caps and other limitations on the amount of employer costs, and we reserve the right to change these benefits. Effective January 1, 2014, the plan was amended to provide a fixed subsidy to post-age 65 Medicare eligible participants to purchase coverage through a retiree Medicare exchange.
	Additionally, our subsidiary SFPP has incurred certain liabilities for postretirement benefits to certain current and former employees, their covered dependents, and their beneficiaries. However, the net periodic benefit costs, contributions and liability amounts associated with the SFPP postretirement benefit plan are not material to our consolidated income statements or balance sheets.
	Benefit Obligation, Plan Assets and Funded Status. The following table provides information about our pension and OPEB plans as of and for each of the years ended December 31, 2014 and 2013 (in millions):
		Pension Benefits								OPEB
		2014				2013				2014				2013
	Change in benefit obligation:
	Benefit obligation at beginning of period	$	2,563			$	2,792			$	631			$	720
	Service cost	21				25				—				—
	Interest cost	112				92				25				23
	Actuarial loss (gain)	294				(132		)		15				(38		)
	Benefits paid	(186		)		(239		)		(52		)		(54		)
	Participant contributions	—				—				3				11
	Medicare Part D subsidy receipts	—				—				2				6
	Plan amendments	—				25				—				(37		)
	Benefit obligation at end of period	2,804				2,563				624				631
	Change in plan assets:
	Fair value of plan assets at beginning of period	2,333				2,240				380				341
	Actual return on plan assets	180				254				32				40
	Employer contributions	50				78				26				42
	Participant contributions	—				—				3				11
	Benefits paid	(186		)		(239		)		(52		)		(54		)
	Fair value of plan assets at end of period	2,377				2,333				389				380
	Funded status - net liability at December 31,	$	(427	)		$	(230	)		$	(235	)		$	(251	)
_______
Components of Funded Status. The following table details the amounts recognized in our balance sheet at December 31, 2014 and 2013 related to our pension and OPEB plans (in millions):
	Pension Benefits								OPEB
	2014				2013				2014				2013
Non-current benefit asset	$	—			$	—			$	173			$	224
Current benefit liability	—				—				(22		)		(32		)
Non-current benefit liability	(427		)		(230		)		(386		)		(443		)
Funded status - net liability at December 31,	$	(427	)		$	(230	)		$	(235	)		$	(251	)
Components of Accumulated Other Comprehensive Income (Loss). The following table details the amounts of pre-tax accumulated other comprehensive income (loss) at December 31, 2014 and 2013 related to our pension and OPEB plans which are included on our accompanying consolidated balance sheets, including the portion attributable to our noncontrolling interests, (in millions):
	Pension Benefits								OPEB
	2014				2013				2014				2013
Unrecognized net actuarial loss	$	(296	)		$	(10	)		$	(27	)		$	(17	)
Unrecognized prior service (cost) credit	(4		)		(5		)		20				21
Accumulated other comprehensive (loss) income	$	(300	)		$	(15	)		$	(7	)		$	4
We anticipate that approximately $2 million of pre-tax accumulated other comprehensive loss will be recognized as part of our net periodic benefit cost in 2015, including approximately $3 million of unrecognized net actuarial loss and approximately $1 million of unrecognized prior service credit.
Our accumulated benefit obligation for our pension plans was $2,719 million and $2,516 million at December 31, 2014 and 2013, respectively.
Our accumulated postretirement benefit obligation for our OPEB plans, whose accumulated postretirement benefit obligations exceeded the fair value of plan assets, was $553 million and $534 million at December 31, 2014 and 2013, respectively. The fair value of these plans’ assets was approximately $145 million and $60 million at December 31, 2014 and 2013, respectively.
Plan Assets. The investment policies and strategies for the assets of each of the pension and OPEB plans are established by the Fiduciary Committee (the “Committee”), which is responsible for investment decisions and management oversight of each plan. The stated philosophy of the Committee is to manage these assets in a manner consistent with the purpose for which the plans were established and the time frame over which the plans’ obligations need to be met. The objectives of the investment management program are to (1) meet or exceed plan actuarial earnings assumptions over the long term and (2) provide a reasonable return on assets within established risk tolerance guidelines and to maintain the liquidity needs of the plans with the goal of paying benefit and expense obligations when due. In seeking to meet these objectives, the Committee recognizes that prudent investing requires taking reasonable risks in order to raise the likelihood of achieving the targeted investment returns. In order to reduce portfolio risk and volatility, the Committee has adopted a strategy of using multiple asset classes.
As of December 31, 2014, the allowable range for target asset allocations in effect for the pension plan were 34% to 58%, equity, 40% to 50% fixed income, 0% to 5% cash, 0% to 2% alternative investments and 0% to 10% company securities (KMI Class P common stock).  As of December 31, 2014, the target asset allocations in effect for the retiree medical and retiree life insurance plans were 70% equity and 30% fixed income.
Below are the details of our pension and OPEB plan assets classified by level and a description of the valuation methodologies used for assets measured at fair value.
•	Level 1 assets’ fair values are based on quoted market prices for the instruments in actively traded markets. Included in this level are cash, dollar-denominated money market funds, common and preferred stock, exchange traded mutual funds and limited partnerships. These investments are valued at the closing price reported on the active market on which the individual securities are traded.
•	Level 2 assets’ fair values are primarily based on pricing data representative of quoted prices for similar assets in active markets (or identical assets in less active markets). Included in this level are money market funds, common/collective trust funds, mutual funds, limited partnerships, trusts, fixed income and other securities. Money market funds are valued at amortized cost, which approximates fair value. The common/collective trust funds’, mutual funds’, limited partnerships’ and trusts’ fair values are based on the net asset value as reported by the issuer, which is determined based on the fair value of the underlying securities as of the valuation date. The fixed income securities’ fair values are primarily based on an evaluated price which is based on a compilation of primarily observable market information or a broker quote in a non-active market.
•	Level 3 assets’ fair values are calculated using valuation techniques that require inputs that are both significant to the fair value measurement and are unobservable, or are similar to Level 2 assets and are also subject to certain restrictions associated with the timing of redemption which extend beyond 90 days as of December 31. Included in this level are insurance contracts, mutual funds with significant redemption restrictions, limited partnerships and private equity. Insurance contracts are valued at contract value, which approximates fair value. The mutual funds’ fair values are primarily based on the net asset value as reported by the issuer, which is determined based on the fair value of the underlying securities as of the valuation date. The limited partnerships’ and private equity investments’ fair values are primarily based on the securities’ value as reported by the issuer, which may be determined utilizing discounted present value.
Listed below are the fair values of our pension and OPEB plans’ assets that are recorded at fair value classified in each level at December 31, 2014 and 2013 (in millions):
	Pension Assets
	2014																2013
	Level 1				Level 2				Level 3				Total				Level 1				Level 2				Level 3		Total
Cash and money market funds	$	5			$	91			$	—			$	96			$	—			$	20			$	—	$	20
Common/collective trusts(a)	—				863				—				863				—				920				—		920
Insurance contracts	—				—				15				15				—				—				15		15
Mutual funds(b)	71				198				—				269				92				134				—		226
Common and preferred stocks(c)	459				—				—				459				498				—				—		498
Corporate bonds	—				247				—				247				—				220				—		220
U.S. government securities	—				190				—				190				—				120				—		120
Asset backed securities	—				28				—				28				—				29				—		29
Limited partnerships	—				—				16				16				—				—				28		28
Equity trusts	—				199				—				199				—				235				—		235
Private equity	—				—				10				10				—				—				9		9
Other	—				(15		)		—				(15		)		—				13				—		13
Total asset fair value(c)	$	535			$	1,801			$	41			$	2,377			$	590			$	1,691			$	52	$	2,333
_______
(a)	For 2014, this category includes common/collective trust funds which are invested in approximately 47% fixed income and 53% equity. For 2013, this category includes common/collective trusts funds which are invested in approximately 36% fixed income, 62% equity and 2% short term securities.
(b)	For 2014, this category includes mutual funds which are invested in approximately 74% fixed income and 26% equity. For 2013, this category includes mutual funds which are invested in approximately 60% fixed income, 40% equity and other investments.
(c)	Plan assets include $252 million and $229 million of KMI Class P common stock for 2014 and 2013, respectively.
	OPEB Assets
	2014																2013
	Level 1				Level 2				Level 3				Total				Level 1				Level 2				Level 3		Total
Cash and money market funds	$	23			$	—			$	—			$	23			$	—			$	—			$	—	$	—
Domestic equity securities	25				—				—				25				13				—				—		13
Common/collective trusts(a)	—				71				—				71				—				85				—		85
Fixed income trusts	—				63				—				63				65				—				—		65
Limited partnerships	76				79				—				155				92				72				—		164
Insurance contracts	—				—				49				49				—				—				46		46
Mutual funds	3				—				—				3				7				—				—		7
Total asset fair value	$	127			$	213			$	49			$	389			$	177			$	157			$	46	$	380
_______
(a)	For 2014, this category includes common/collective trust funds which are invested in approximately 67% equity and 33% fixed income securities. For 2013, this category includes common/collective trust funds which are invested in approximately 70% equity and 30% fixed income securities.
The following tables present the changes in our pension and OPEB plans’ assets included in Level 3 for the years ended December 31, 2014 and 2013 (in millions):
	Pension Assets
	Balance at Beginning of Period				Transfers In (Out)				Realized and Unrealized Gains (Losses), net				Purchases (Sales), net				Balance at End of Period
2014
Insurance contracts	$	15			$	—			$	—			$	—			$	15
Limited partnerships	28				—				5				(17		)		16
Private equity	9				—				2				(1		)		10
Total	$	52			$	—			$	7			$	(18	)		$	41
2013
Insurance contracts	$	14			$	—			$	—			$	1			$	15
Mutual funds	40				—				—				(40		)		—
Limited partnerships	24				—				3				1				28
Private equity	9				—				1				(1		)		9
Total	$	87			$	—			$	4			$	(39	)		$	52
_______
	OPEB Assets
	Balance at Beginning of Period				Transfers In (Out)				Realized and Unrealized Gains (Losses), net				Purchases (Sales), net				Balance at End of Period
2014
Insurance contracts	$	46			$	—			$	(3	)		$	6			$	49
Total	$	46			$	—			$	(3	)		$	6			$	49
2013
Insurance contracts	$	44			$	—			$	—			$	2			$	46
Total	$	44			$	—			$	—			$	2			$	46
_______
Changes in the underlying value of Level 3 assets due to the effect of changes of fair value were immaterial for the years ended December 31, 2014 and 2013.
Expected Payment of Future Benefits and Employer Contributions. As of December 31, 2014, we expect to make the following benefit payments under our plans (in millions):
Fiscal year		Pension Benefits				OPEB(a)
2015		$	190			$	46
2016		193				46
2017		193				45
2018		195				45
2019		195				44
2020-2024		965				209
_______
(a)	Includes a reduction of approximately $2 million in each of the years 2015 - 2019 and approximately $12 million in aggregate for 2020 - 2024 for an expected subsidy related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003.
In 2015, we expect to contribute $50 million to our pension plan and approximately $14 million, net of anticipated subsidies, to our OPEB plan.
Actuarial Assumptions and Sensitivity Analysis. Benefit obligations and net benefit cost are based on actuarial estimates and assumptions. The following table details the weighted-average actuarial assumptions used in determining our benefit obligation and net benefit costs of our pension and OPEB plans for 2014, 2013 and 2012:
		Pension Benefits									OPEB
		2014			2013			2012			2014			2013			2012
Assumptions related to benefit obligations:
Discount rate		3.66	%		4.45	%		3.4	%		3.56	%		4.34	%		3.34	%
Rate of compensation increase		4.5	%		3.5	%		3	%		n/a			n/a			n/a
Assumptions related to benefit costs:
Discount rate(a)		4.45	%		3.4	%		4.22	%		4.34	%		3.62	%		4.11	%
Expected return on plan assets(b)(c)		7.5	%		8	%		8.44	%		7.43	%		7.35	%		8.21	%
Rate of compensation increase		3.5	%		3	%		3.5	%		n/a			n/a			n/a
_______
(a)	The discount rate related to pension benefit cost was 4.50% for the period from January 1, 2012 to May 24, 2012, and 4.03% for the period from May 25, 2012 to December 31, 2012 (the period subsequent to the EP acquisition). The discount rate related to other postretirement benefit cost was 3.34% for the period from January 1, 2013 to July 31, 2013 (the period prior to an OPEB plan amendment that resulted in a remeasurement) and 4.00% for the period from August 1, 2013 to December 31, 2013, and 4.25% for the period from January 1, 2012 to May 24, 2012 and 4.01% for the period from May 25, 2012 to December 31, 2012.
(b)	The expected return on plan assets related to pension cost was 8.90% for the period from January 1, 2012 to May 24, 2012, and 8.11% for the period from May 25, 2012 to December 31, 2012 (the period subsequent to the EP acquisition). The expected return on plan assets related to other postretirement benefit cost was 8.90% for the period from January 1, 2012 to May 24, 2012, and 7.72% for the period from May 25, 2012 to December 31, 2012.
(c)	The expected return on plan assets listed in the table above is a pre-tax rate of return based on our targeted portfolio of investments. For the assumed EP OPEB plans, we utilize an after-tax expected return on plan assets to determine our benefit costs, which is based on unrelated business income taxes at a rate of 21% and 24% for 2014 and 2013, respectively.
The expected long-term rates of return on plan assets were determined by combining a review of the historical returns realized within the portfolio, the investment strategy included in the plans’ investment policy, and capital market projections for the asset classes in which the portfolio is invested and the target weightings of each asset class.
Actuarial estimates for our OPEB plans assumed a weighted-average annual rate of increase in the per capita cost of covered health care benefits of 7.00%, gradually decreasing to 4.50% by the year 2031. Assumed health care cost trends have a significant effect on the amounts reported for OPEB plans. A one-percentage point change in assumed health care cost trends would have the following effects as of December 31, 2014 and 2013 (in millions):
		2014				2013
One-percentage point increase:
Aggregate of service cost and interest cost		$	2			$	2
Accumulated postretirement benefit obligation		47				45
One-percentage point decrease:
Aggregate of service cost and interest cost		$	(2	)		$	(1	)
Accumulated postretirement benefit obligation		(40		)		(39		)
Components of Net Benefit Cost and Other Amounts Recognized in Other Comprehensive Income. For each of the years ended December 31, the components of net benefit cost and other amounts (including amounts associated with the EP Pension and OPEB plans since the May 25, 2012 acquisition date) recognized in pre-tax other comprehensive income related to our pension and OPEB plans are as follows (in millions):
		Pension Benefits												OPEB
		2014				2013				2012				2014				2013				2012
Components of net benefit cost:
Service cost		$	21			$	25			$	18			$	—			$	—			$	—
Interest cost		112				92				67				25				23				18
Expected return on assets		(171		)		(175		)		(110		)		(24		)		(22		)		(15		)
Amortization of prior service (credit) cost		—				—				(1		)		(2		)		(1		)		(1		)
Amortization of net actuarial loss (gain)		—				—				10				(1		)		3				4
Curtailment and settlement gain		—				(3		)		(2		)		—				—				(1		)
Net benefit (credit) cost		(38		)		(61		)		(18		)		(2		)		3				5
Other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss:
Net (gain) loss arising during period		285				(211		)		85				10				(50		)		25
Prior service cost (credit) arising during period		—				25				(17		)		—				(18		)		(4		)
Amortization or settlement recognition of net actuarial gain (loss)		—				3				(10		)		—				(3		)		(5		)
Amortization of prior service credit		—				—				1				1				1				1
Total recognized in total other comprehensive income loss		285				(183		)		59				11				(70		)		17
Total recognized in net benefit (credit) cost and other comprehensive (income) loss		$	247			$	(244	)		$	41			$	9			$	(67	)		$	22
Other Plans
Plans Associated with Foreign Operations
Two of our subsidiaries, Kinder Morgan Canada Inc. and Trans Mountain Pipeline Inc. (as general partner of Trans Mountain Pipeline L.P.) are sponsors of pension plans for eligible Trans Mountain pipeline system employees.  The plans include registered defined benefit pension plans, supplemental unfunded arrangements (which provide pension benefits in excess of statutory limits) and defined contributory plans.  These subsidiaries also provide postretirement benefits other than pensions for retired employees. Our combined net periodic benefit costs for these Trans Mountain pension and other postretirement benefit plans for the years ended December 31, 2014, 2013 and 2012 was $10 million, $11 million and $11 million, respectively, recognized ratably over each year.  As of December 31, 2014, we estimate the overall net periodic pension and other postretirement benefit costs for these plans for the year 2015 will be approximately $14 million, although this estimate could change if there is a significant event, such as a plan amendment or a plan curtailment, which would require a remeasurement of liabilities.  Furthermore, we expect to contribute approximately $11 million to these benefit plans in 2015.
Multiemployer Plans
As a result of acquiring several terminal operations, primarily the acquisition of Kinder Morgan Bulk Terminals, Inc. effective July 1, 1998, we participate in several multi-employer pension plans for the benefit of employees who are union members.  We do not administer these plans and contribute to them in accordance with the provisions of negotiated labor contracts.  Other benefits include a self-insured health and welfare insurance plan and an employee health plan where employees may contribute for their dependents’ health care costs.  Amounts charged to expense for these plans were approximately $13 million, $11 million and $11 million for the years ended December 31, 2014, 2013 and 2012, respectively. We consider the overall multi-employer pension plan liability exposure to be minimal in relation to the value of its total consolidated assets and net income.

Stockholders_Equity_Notes

Stockholders' Equity (Notes)	12 Months Ended
	Dec. 31, 2014
Stockholders' Equity Note [Abstract]
Shareholders' Equity	Stockholders’ Equity
	Kinder Morgan, Inc. – Equity Interests
	Common Equity
	During the years 2012 through 2014, as authorized by our board of directors under various repurchase programs, we repurchased shares and warrants. As of December 31, 2014, we had $2 million available for repurchases under the 2014 repurchase program. During the years ended December 31, 2014, 2013 and 2012, we paid a total of $98 million, $465 million and $157 million, respectively, for the repurchase of warrants. During the years ended December 31, 2014 and 2013, we repurchased $94 million and $172 million respectively, of our Class P shares.
	The following table sets forth the changes in our outstanding shares:
		Class P			Class A			Class B			Class C
	Balance at December 31, 2011	170,921,140			535,972,387			94,132,596			2,318,258
	Shares issued for EP acquisition (see Note 3)	330,154,610			—			—			—
	Shares issued with conversions of EP Trust I Preferred securities	562,521			—			—			—
	Shares converted	535,972,387			(535,972,387	)		(94,132,596	)		(2,318,258	)
	Shares canceled	(2,049,615	)		—			—			—
	Restricted shares vested	107,553			—			—			—
	Balance at December 31, 2012	1,035,668,596			—			—			—
	Shares issued for EP acquisition(a)	53
	Shares repurchased and canceled	(5,175,055	)
	Shares issued with conversions of EP Trust I Preferred securities	77,442
	Shares issued for exercised warrants	16,886
	Restricted shares vested	89,154
	Balance at December 31, 2013	1,030,677,076
	Shares issued for Merger Transactions	1,096,910,451
	Shares repurchased and canceled	(2,780,337	)
	Shares issued with conversions of EP Trust I Preferred securities	2,820
	Shares issued for exercised warrants	12,402
	Restricted shares vested	324,704
	Balance at December 31, 2014	2,125,147,116
	_______
	(a) Represents Class P shares issued upon the settlement of an EP dissenter. The settlement of the dissenter’s 128 EP shares was determined based on the same conversion of EP shares into cash, KMI Class P shares and KMI warrants that was received by other EP shareholders at the time of the acquisition.
	As of January 1, 2012, the “Investors” (as defined hereinafter) owned all of our outstanding Class A shares, Class B shares and Class C shares, which are sometimes referred to in this report as the “investor retained stock.”  The Investors were Richard D. Kinder, our Chairman and Chief Executive Officer; the Sponsor Investors; Fayez Sarofim, one of our directors, and investment entities affiliated with him, and an investment entity affiliated with Michael C. Morgan, another of our directors and William V. Morgan, one of our founders, whom we refer to collectively as the “Original Stockholders”; and a number of other members of our management, who are referred to collectively as “Other Management.” Our Class A shares represented the total capital contributed by the Investors (and a notional amount of capital allocated to the contribution of the holders of the Class C shares) at the time of a 2007 going private transaction. The Class B shares and Class C shares represented incentive compensation that were held by members of our management, including Mr. Kinder only in the case of the Class B shares.
	During the year ended December 31, 2012, certain of the Sponsor Investors (the Selling Stockholders) completed underwritten public offerings (the Offerings) of an aggregate of 198,996,921 shares of our Class P common stock (including 8,700,000 shares that were the subject of an underwriters’ option to purchase additional shares). Neither we nor our management sold any shares of common stock in the Offerings, and we did not receive any of the proceeds from the Offerings of shares by the Selling Stockholders. As a result of these offerings, the Sponsor Investors advised by or affiliated with Goldman Sachs & Co., The Carlyle Group, and Riverstone Holdings LLC no longer own any of our shares, and representatives of these Sponsor Investors are no longer on our board.
	On December 26, 2012, the remaining series of the Class A, Class B and Class C shares held by the Investors automatically converted into shares of Class P common stock upon the election of the holders of at least two-thirds of the shares of each such series of Class A common stock and the holders of at least two-thirds of the shares of each such series of Class B common stock. Subsequent to these conversions, all our Class A, Class B and Class C shares were fully converted and as a result, only our Class P common stock was outstanding as of December 31, 2012. Additionally, as Class A, Class B and Class C shares converted, certain holders of Class P shares were paid out in cash and their Class P shares were immediately canceled. During the year ended December 31, 2012 approximately 2 million Class P shares were canceled resulting in payments totaling approximately $71 million to the holders of those shares.
	Equity Issuances Subsequent to December 31, 2014
	On December 19, 2014, we entered into an equity distribution agreement with UBS Securities LLC, referred to as UBS, with Citigroup Global Markets Inc., Credit Suisse Securities (U.S.A.) LLC, Deutsche Bank Securities Inc., J.P. Morgan Securities LLC and Mitsubishi UFJ Securities (U.S.A.), Inc. (each a “Manager” and, collectively, the “Managers”). We propose to issue and sell through or to the Managers, as sales agents and/or principals, shares of the our Class P common stock, par value $0.01 per share having an aggregate offering price of up to $5,000 million from time to time during the term of this Agreement. Subsequent to December 31, 2014, we had equity issuances of 20,363,204 shares of our Class P common stock.
	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:
		Year Ended December 31,
		2014				2013				2012
	Per common share cash dividend declared for the period	$	1.74			$	1.6			$	1.4
	Per common share cash dividend paid in the period	1.7				1.56				1.34
	_______
	On January 21, 2015, our board of directors declared a cash dividend of $0.45 per share for the quarterly period ended December 31, 2014. This dividend was paid on February 17, 2015 to shareholders of record as of February 2, 2015. Since this dividend was declared after the end of the quarter, no amount is shown in our accompanying December 31, 2014 consolidated balance sheet as a dividend payable.
	Warrants
	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 table below sets forth the changes in our outstanding warrants:
		Warrants
		2014			2013			2012
	Beginning balance	347,933,107			439,809,442			—
	Warrants issued in EP acquisition(a)	—			81			504,598,883
	Warrants issued with conversions of EP Trust I Preferred securities(b)	4,315			118,377			859,796
	Warrants exercised	(18,040	)		(21,208	)		—
	Warrants repurchased and canceled	(49,783,406	)		(91,973,585	)		(65,649,237	)
	Ending balance	298,135,976			347,933,107			439,809,442
	_______
	(a)	See Note 3. 2013 amount represents warrants issued upon the settlement of an EP dissenter. The settlement of the dissenter’s 128 EP shares was determined based on the same conversion of EP shares into cash, KMI Class P shares and KMI warrants that was received by other EP shareholders at the time of the acquisition.
	(b)	See Note 8.
	Noncontrolling Interests
	The caption “Noncontrolling interests” in our accompanying consolidated balance sheets consists of interests that we do not own in the following subsidiaries (in millions):
		December 31,
		2014				2013
	KMP	$	—			$	7,642
	EPB	—				4,122
	KMR	—				3,142
	Other	350				286
		$	350			$	15,192
	_______
	At December 31, 2014, as a result of the Merger Transactions, we owned all of the outstanding common units of KMP and EPB and all of the outstanding shares of KMR that we or our subsidiaries did not already own.
At December 31, 2013, we owned, directly, and indirectly in the form of i-units corresponding to the number of shares of KMR we owned, approximately 43 million limited partner units of KMP.  These units, which consisted of 22 million common units, 5 million Class B units and 16 million i-units, represented approximately 9.8% of the total outstanding limited partner interests of KMP.  In addition, we indirectly own all the common equity of the general partner of KMP, which holds an effective 2% interest in KMP and its operating partnerships.  Together, at December 31, 2013, our limited partner and general partner interests represented approximately 11.6% of KMP’s total equity interests and represented an approximate 50% economic interest in KMP.  This difference resulted from the existence of incentive distribution rights (IDRs) previously held by KMGP, the general partner of KMP.
As of December 31, 2013, we owned approximately 90 million limited partner units of EPB, representing approximately 41% of the total equity interests of EPB. In addition, we were the sole owner of the general partner of EPB, which held an effective 2% interest in EPB.
At December 31, 2013, we owned approximately 16 million KMR shares representing approximately 13.0% of KMR’s outstanding shares.
Contributions
Prior to the completion of the Merger Transactions on November 26, 2014, contributions from our noncontrolling interests consisted primarily of equity issuances by KMP, EPB and KMR. Each of these subsidiaries had an equity distribution agreement in place which allowed the subsidiary to sell its equity interests from time to time through a designated sales agent. The terms of each agreement were substantially similar. Sales of the subsidiary’s equity interests were made by means of ordinary brokers’ transactions on the NYSE at market prices, in block transactions or as otherwise agreed between the subsidiary equity issuer and its sales agent. The subsidiary equity issuer could also sell its equity interests to its sales agent as principal for the sales agent’s own account at a price agreed upon at the time of the sale.  Any sale of the subsidiary’s equity interests to the sales agent as principal would be pursuant to the terms of a separate agreement between the subsidiary equity issuer and its sales agent. The equity distribution agreement provided the subsidiary with the right, but not the obligation to offer and sell its equity units or shares, at prices to be determined by market conditions. The subsidiary retained at all times complete control over the amount and the timing of sales under its respective equity distribution agreement, and it designated the maximum number of equity units or shares to be sold through its sales agent, on a daily basis or otherwise as the subsidiary equity issuer and its sales agent agreed.
The table below shows significant issuances to the public of common units or shares, the net proceeds from the issuances and the use of the proceeds during the years ended December 31, 2014 and 2013 by KMP, EPB and KMR (dollars in millions and shares in thousands):
	Issuances		Common units/shares			Net proceeds				Use of proceeds
			(in thousands)			(in millions)
KMP
Issued under Equity Distribution Agreement(a)
	2014		5,513			$	441			Reduced borrowings under KMP’s commercial paper program
	2013		10,814			$	900			Reduced borrowings under KMP’s commercial paper program
Other issuances
	Feb-14		7,935			$	603			Reduced borrowings under KMP’s commercial paper program that were used to fund KMP’s APT acquisition in January 2014
	Feb-13		4,600			$	385			Issued to pay a portion of the purchase price for the March 2013 drop-down transaction
	May-13		43,371			$	—		(b)	Issued to Copano unitholders as KMP’s purchase price for Copano
EPB
Issued under Equity Distribution Agreement(c)
	2014		7,314			$	275			General partnership purposes
	2013		2,038			$	85			General partnership purposes
Other issuances
	May-14		7,820			$	242			Issued to pay a portion of the purchase price for the May 2014 drop-down transaction
KMR
Issued under Equity Distribution Agreement(d)
	2014		1,735			$	134			Purchased additional KMP i-units; KMP then used proceeds to reduce borrowings under its commercial paper program
	2013		2,640			$	210			Purchased additional KMP i-units; KMP then used proceeds to reduce borrowings under its commercial paper program
_______
(a)	Prior to the completion of the Merger Transactions on November 26, 2014, KMP was a party to two equity distribution agreements with UBS Securities LLC (UBS), one of which allowed the aggregate offering price of KMP’s common units of up to $2.175 billion, and a second separate equity distribution agreement which allowed the aggregate offering price of up to $1.9 billion.
(b)	KMP valued these units at $3,733 million based on the $86.08 closing market price of a KMP common unit on the NYSE on May 1, 2013.
(c)	Prior to the completion of the Merger Transactions on November 26, 2014, EPB was a party to an equity distribution agreement with Citigroup. Pursuant to the provisions of EPB’s equity distribution agreement, EPB could sell from time to time through Citigroup, as its sales agent, EPB’s common units representing limited partner interests having an aggregate offering price of up to $500 million.
(d)	Prior to the completion of the Merger Transactions on November 26, 2014, KMR was a party to an equity distribution agreement with Credit Suisse Securities (U.S.A.) LLC (Credit Suisse). Pursuant to the provisions of KMR’s equity distribution agreement, it could sell from time to time through Credit Suisse, as its sales agent, KMR shares having an aggregate offering price of up to $500 million.
The above equity issuances by KMP, EPB and KMR during the periods ended November 25, 2014 and December 31, 2013 had the associated effects of increasing our (i) noncontrolling interests by $1,640 million and $5,059 million, respectively; (ii) accumulated deferred income taxes by $19 million and $93 million, respectively; and (iii) additional paid-in capital by $36 million and $161 million, respectively.
Distributions
The following table provides information about distributions from our noncontrolling interests (in millions except per unit and i-unit distribution amounts):
	Year Ended December 31,
	2014				2013				2012
KMP(a)
Per unit cash distribution declared for the period	$	4.17			$	5.33			$	4.98
Per unit cash distribution paid in the period	$	5.53			$	5.26			$	4.85
Cash distributions paid in the period to the public	$	1,654			$	1,372			$	1,081
EPB(a)(b)
Per unit cash distribution declared for the period	$	1.95			$	2.55			$	1.74
Per unit cash distribution paid in the period	$	2.6			$	2.51			$	1.13
Cash distributions paid in the period to the public	$	347			$	318			$	137
KMR(a)(c)
Share distributions paid in the period to the public	7,794,183				6,588,477				5,586,579
_______
(a)	As a result of the Merger Transactions, no distribution was declared for the fourth quarter of 2014.
(b)	Represents distribution information since the May 2012 EP acquisition.
(c)	KMR’s distributions were paid in the form of additional shares or fractions thereof calculated by dividing the KMP cash distribution per common unit by the average of the market closing prices of a KMR share determined for a ten-trading day period ending on the trading day immediately prior to the ex-dividend date for the shares.  Represents share distributions made in the period to noncontrolling interests and excludes 1,127,712, 976,723 and 902,367 of shares distributed in 2014, 2013 and 2012, respectively, on KMR shares we directly and indirectly owned.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions
	Affiliated Balances
	The following table summarizes our balance sheet affiliate balances (in millions):
		December 31,
		2014		2013
	Balance sheet location
	Accounts receivable, net	$	31	$	19
	Other current assets	3		3
	Deferred charges and other assets	46		47
		$	80	$	69
	Current portion of debt(a)	$	6	$	6
	Accounts payable	22		9
	Long-term debt(a)	172		169
		$	200	$	184
	_______
	(a)	Includes financing obligations payable to WYCO (See Note 8).
	Notes Receivable
	Plantation
	We and ExxonMobil have a term loan agreement covering a note receivable due from Plantation. We own a 51.17% equity interest in Plantation and our proportionate share of the outstanding principal amount of the note receivable was $47 million and $48 million as of December 31, 2014 and 2013, respectively. The note bears interest at the rate of 4.25% per annum and provides for semiannual payments of principal and interest on December 31 and June 30 each year, with a final principal payment of $45 million (for our portion of the note) due on July 20, 2016. We included $1 million of the note receivable balance within “Other current assets” and we included the remaining outstanding balance within “Deferred charges and other assets” on our accompanying consolidated balance sheets as of both December 31, 2014 and 2013.
	Gulf LNG Holdings Group, LLC
	In conjunction with the acquisition of EP, KMI acquired a long-term note receivable, bearing interest at 12% per annum, that was due from Gulf LNG Holdings Group, LLC, a 50% equity investee, with a remaining principal amount of $85 million. Subsequent to the EP acquisition and through the end of 2012, we received payments on this note totaling $75 million. We received payments for the remaining note balance of $10 million during the first quarter of 2013.
	Subsequent Event
	MEP
	On February 3, 2015 we renewed our loan agreement for an additional one-year term with MEP, our 50%-owned equity investee. The loan agreement allows us, at our sole option, to make loans from time to time to MEP to fund its working capital needs and for other LLC purposes. Each individual loan must be in an amount not less than $2 million, and the aggregate loan balance outstanding must not exceed $40 million. Borrowings under the loan agreement bear interest at a rate of one month LIBOR plus 1.75%, and all borrowings can be prepaid before maturity without penalty or premium. As of both December 31, 2014 and 2013 there was no amount outstanding pursuant to this loan agreement.

Commitments_and_Contingent_Lia

Commitments and Contingent Liabilities (Notes)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Disclosure [Text Block]	Commitments and Contingent Liabilities
	Leases and Rights-of-Way Obligations
	The table below depicts future gross minimum rental commitments under our operating leases and rights-of-way obligations as of December 31, 2014 (in millions):
	Year	Commitment
	2015	$	97
	2016	85
	2017	75
	2018	67
	2019	65
	Thereafter	289
	Total minimum payments	$	678
	_______
	The remaining terms on our operating leases, including probable elections to exercise renewal options, range from one to thirty-nine years. Total lease and rental expenses were $114 million, $126 million and $94 million for the years ended December 31, 2014, 2013 and 2012, respectively. The amount of capital leases included within “Property, plant and equipment, net” in our accompanying consolidated balance sheets as of December 31, 2014 and 2013 is not material to our consolidated balance sheets.
	Commitments
	Capital Contributions for Elba Liquefaction Project
	In January 2013, SLC, our subsidiary, and Shell U.S. Gas and Power, LLC (Shell G&P), a subsidiary of Royal Dutch Shell plc (Shell), formed ELC, an equity method investment, to develop and own a natural gas liquefaction plant at SLNG’s existing Elba Island LNG terminal. In connection with the formation of ELC, SLC and Shell G&P entered into a LLC agreement in which SLC owns 51% of ELC and Shell G&P owns the remaining membership interest. Under the terms of the LLC agreement, SLC and Shell G&P are both obligated to make certain capital contributions in proportion to their membership interests in ELC to fund the construction of the liquefaction facilities. Our investment at the terminal, including both the liquefaction facilities and SLNG ancillary facilities, is estimated to be approximately $1.3 billion.
	Contingent Debt
	Our contingent debt disclosures pertain to certain types of guarantees or indemnifications we have made and cover certain types of guarantees included within debt agreements, even if the likelihood of requiring our performance under such guarantee is remote.
	As of December 31, 2014 and 2013, our contingent debt obligations, as well as our obligations with respect to related letters of credit, totaled $1,069 million and $74 million, respectively. The December 31, 2014 amount is primarily represented by our proportional share of the debt obligations of two equity investees. Under such guarantees we are severally liable for our percentage ownership share of these equity investees’ debt issued in the event of their non-performance. Also included in our contingent debt obligations is a guarantee of the debt obligations of our 50%-owned investee, Cortez Pipeline Company (we are severally liable for its percentage ownership share (50%) of the Cortez Pipeline Company debt and 100% of the debt issued by one of its subsidiaries in the event of their non-performance) which has a $200 million credit facility to fund an expansion project.
	Guarantees and Indemnifications
	We are involved in joint ventures and other ownership arrangements that sometimes require financial and performance guarantees. In a financial guarantee, we are obligated to make payments if the guaranteed party fails to make payments under, or violates the terms of, the financial arrangement. In a performance guarantee, we provide assurance that the guaranteed party will execute on the terms of the contract. If they do not, we are required to perform on their behalf. We also periodically provide indemnification arrangements related to assets or businesses we have sold. These arrangements include, but are not limited to, indemnifications for income taxes, the resolution of existing disputes and environmental matters.
	Our potential exposure under guarantee and indemnification agreements can range from a specified to an unlimited dollar amount, depending on the nature of the claim and the particular transaction. While many of these agreements may specify a maximum potential exposure, or a specified duration to the indemnification obligation, there are circumstances where the amount and duration are unlimited. Those arrangements with a specified dollar amount have a maximum stated value of approximately $688 million, which primarily represents indemnification agreements associated with EP’s prior discontinued and foreign operations. We are unable to estimate a maximum exposure for our guarantee and indemnification agreements that do not provide for limits on the amount of future payments due to the uncertainty of these exposures.

Risk_Management_Notes

Risk Management (Notes)	12 Months Ended
	Dec. 31, 2014
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 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.
	As part of the EP acquisition, we acquired power forward and swap contracts. We have entered into offsetting positions that eliminate the price risks associated with our power contracts.
	As of December 31, 2014, we discontinued hedge accounting on certain of our crude derivative contracts as we do 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 December 31, 2014, 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	(10.9	)	MMBbl
	Crude oil basis	(10.8	)	MMBbl
	Natural gas fixed price	(27.2	)	Bcf
	Natural gas basis	(8.0	)	Bcf
	Derivatives not designated as hedging contracts
	Crude oil fixed price	(14.9	)	MMBbl
	Natural gas fixed price	2		Bcf
	Natural gas basis	6.5		Bcf
	NGL fixed price	(2.1	)	MMBbl
	_______
	As of December 31, 2014, 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 through December 2018.
	Interest Rate Risk Management
	As of December 31, 2014 and 2013, we had a combined notional principal amount of $9,200 million and $5,400 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 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 December 31, 2014, 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 February 2014, we entered into four separate fixed-to-variable interest rate swap agreements having a combined notional principal amount of $500 million. These agreements effectively convert a portion of the interest expense associated with our 3.50% senior notes due March 1, 2021, from a fixed rate to a variable rate. In September 2014, we entered into five 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 4.25% senior notes due September 1, 2024, from a fixed rate to a variable rate. Additionally, in November 2014, we entered into twenty-one separate fixed-to-variable interest rate swap agreements having a combined notional principal amount of $3,000 million. These agreements effectively convert a portion of the interest expense associated with our 4.30% senior notes due June 1, 2025 and 3.05% senior notes due December 1, 2019, from a fixed rate to a variable rate.
	Fair Value of Derivative Contracts
	The following table summarizes the fair values of our derivative contracts included on our accompanying consolidated balance sheets (in millions):
	Fair Value of Derivative Contracts
				Asset derivatives								Liability derivatives
				December 31,								December 31,
				2014				2013				2014				2013
		Balance sheet location		Fair value								Fair value
	Derivatives designated as hedging contracts
	Natural gas and crude derivative contracts	Other current assets/(Other current liabilities)		$	309			$	18			$	(34	)		$	(33	)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		6				58				—				(30		)
	Subtotal			315				76				(34		)		(63		)
	Interest rate swap agreements	Other current assets/(Other current liabilities)		143				87				—				—
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		260				172				(53		)		(116		)
	Subtotal			403				259				(53		)		(116		)
	Total			718				335				(87		)		(179		)
	Derivatives not designated as hedging contracts
	Natural gas, crude and NGL derivative contracts	Other current assets/(Other current liabilities)		73				4				(2		)		(5		)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		196				—				—				—
	Subtotal			269				4				(2		)		(5		)
	Power derivative contracts	Other current assets/(Other current liabilities)		10				7				(57		)		(54		)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		—				11				(16		)		(73		)
	Subtotal			10				18				(73		)		(127		)
	Total			279				22				(75		)		(132		)
	Total derivatives			$	997			$	357			$	(162	)		$	(311	)
	_______
	Debt Fair Value Adjustments
	The offsetting entry to adjust the carrying value of the debt securities whose fair value was being hedged is included within “Debt fair value adjustments” on our accompanying consolidated balance sheets. Our “Debt fair value adjustments” also include all unamortized debt discount/premium amounts, purchase accounting on our debt balances, and any unamortized portion of proceeds received from the early termination of interest rate swap agreements.  As of December 31, 2014 and 2013, these fair value adjustments to our debt balances included (i) $1,221 million and $1,379 million, respectively, associated with fair value adjustments to our debt previously recorded in purchase accounting; (ii) $347 million and $143 million, respectively, associated with the offsetting entry for hedged debt; (iii) $454 million and $517 million respectively, associated with unamortized premium from the termination of interest rate swap agreements; and offset by (iv) $88 million and $62 million, respectively, associated with unamortized debt discount amounts. As of December 31, 2014, the weighted-average amortization period of the unamortized premium from the termination of the interest rate swaps was approximately 16 years.
	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
					Year Ended December 31,
					2014				2013				2012
	Interest rate swap agreements		Interest expense		$	207			$	(425	)		$	55
	Total				$	207			$	(425	)		$	55
	Fixed rate debt		Interest expense		$	(204	)		$	425			$	(55	)
	Total				$	(204	)		$	425			$	(55	)
	_______
	Derivatives in cash flow hedging relationships		Amount of gain/(loss) recognized in OCI on derivative (effective portion)(a)												Location of gain/(loss) reclassified from Accumulated OCI into income (effective portion)		Amount of gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)									Location of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	Amount of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)
			Year Ended														Year Ended										Year Ended
			December 31,														December 31,										December 31,
			2014				2013				2012						2014			2013			2012				2014		2013		2012
	Energy commodity derivative contracts		$	423			$	(45	)		$	87			Revenues—Natural gas sales		$	(1	)	$	—		$	4		Revenues—Natural gas sales	$	—	$	—	$	—
														Revenues—Product sales and other		26			(13		)	(15		)	Revenues—Product sales and other	11		3		(11		)
														Costs of sales		4			—			17			Costs of sales	—		—		—
Interest rate swap agreements		(15		)		7				(5		)		Interest expense		(4		)	2			2			Interest expense	—		—		—
Total		$	408			$	(38	)		$	82			Total		$	25		$	(11	)	$	8		Total	$	11	$	3	$	(11	)
_______
(a)	We expect to reclassify an approximate $208 million gain associated with energy commodity price risk management activities included in our accumulated other comprehensive loss balance as of December 31, 2014 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
				Year Ended December 31,
				2014				2013				2012
Energy commodity derivative contracts		Revenues—Natural gas sales		$	(7	)		$	—			$	1
		Revenues—Product sales and other		20				(10		)		(4		)
		Costs of sales		—				2				—
		Other expense (income)		(2		)		(2		)		—
Total				$	11			$	(10	)		$	(3	)
Credit Risks
We have counterparty credit risk as a result of our use of financial derivative contracts.  Our counterparties consist primarily of financial institutions, major energy companies, natural gas and electric utilities and local distribution companies.  This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions.
We maintain credit policies with regard to our counterparties that we believe minimize our overall credit risk.  These policies include (i) an evaluation of potential counterparties’ financial condition (including credit ratings); (ii) collateral requirements under certain circumstances; and (iii) the use of standardized agreements which allow for netting of positive and negative exposure associated with a single counterparty.  Based on our policies, exposure, credit and other reserves, our management does not anticipate a material adverse effect on our financial position, results of operations, or cash flows as a result of counterparty performance.
Our OTC swaps and options are entered into with counterparties outside central trading organizations such as futures, options or stock exchanges.  These contracts are with a number of parties, all of which have investment grade credit ratings.  While we enter into derivative transactions with investment grade counterparties and actively monitor their ratings, it is nevertheless possible that from time to time losses will result from counterparty credit risk in the future.
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 December 31, 2014 and 2013, we had $20 million and $167 million, respectively, of outstanding letters of credit supporting our commodity price risks associated with the sale of power.
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 December 31, 2014, we estimate that if our credit rating was downgraded one or two notches, we would be required to post no additional collateral to our counterparties.
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
	hedge derivatives				adjustments				liability adjustments				income/(loss)
Balance as of December 31, 2011	$	(20	)		$	37			$	(132	)		$	(115	)
Other comprehensive income before reclassifications	32				14				(53		)		(7		)
Amounts reclassified from accumulated other comprehensive loss	(5		)		—				9				4
Net current-period other comprehensive income	27				14				(44		)		(3		)
Balance as of December 31, 2012	7				51				(176		)		(118		)
Other comprehensive income before reclassifications	(14		)		(49		)		151				88
Amounts reclassified from accumulated other comprehensive loss	4				—				2				6
Net current-period other comprehensive income	(10		)		(49		)		153				94
Balance as of December 31, 2013	(3		)		2				(23		)		(24		)
Other comprehensive income before reclassifications	254				(68		)		(212		)		(26		)
Amounts reclassified from accumulated other comprehensive loss	(22		)		—				(1		)		(23		)
Impact of Merger Transactions (See Note 1)	98				(42		)		—				56
Net current-period other comprehensive income	330				(110		)		(213		)		7
Balance as of December 31, 2014	$	327			$	(108	)		$	(236	)		$	(17	)

Fair_Value_Notes

Fair Value (Notes)	12 Months Ended
	Dec. 31, 2014
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 and (ii) interest rate swap agreements, based on the three levels established by the Codification (in millions). Certain of our derivative contracts are subject to master netting agreements.
		Balance sheet asset fair value measurements using												Amounts not offset in the balance sheet
		Level 1			Level 2			Level 3			Gross amount			Financial instruments			Cash collateral held(b)			Net amount
	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
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	4		$	46		$	48		$	98		$	(62	)	$	—		$	36
	Interest rate swap agreements	$	—		$	259		$	—		$	259		$	(28	)	$	—		$	231
	_______
		Balance sheet liability												Amounts not offset in the balance sheet
		fair value measurements using
		Level 1			Level 2			Level 3			Gross amount			Financial instruments			Cash collateral posted(c)			Net amount
	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	)
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	(6	)	$	(31	)	$	(158	)	$	(195	)	$	62		$	17		$	(116	)
	Interest rate swap agreements	$	—		$	(116	)	$	—		$	(116	)	$	28		$	—		$	(88	)
	_______
	(a)	Level 1 consists primarily of NYMEX natural gas futures.  Level 2 consists primarily of OTC 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)
		Year Ended December 31,
		2014			2013
	Derivatives-net asset (liability)
	Beginning of period	$	(110	)	$	(155	)
	Transfers out(a)	(88		)	—
	Total gains or (losses)
	Included in earnings	22			(5		)
	Included in other comprehensive loss	78			(1		)
	Purchases(b)	—			17
	Settlements	37			34
	End of period	$	(61	)	$	(110	)
	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		$	(8	)
	_______
	(a) On December 31, 2014, we transferred WTI options from Level 3 to Level 2 due to increased observability of significant inputs in their valuations.
	(b) 2013 amount represents the purchase of Level 3 energy commodity derivative contracts associated with our May 1, 2013 Copano acquisition.
	As of December 31, 2014, 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):
		December 31, 2014						December 31, 2013
		Carrying			Estimated			Carrying			Estimated
		value			fair value			value			fair value
	Total debt	$	42,963		$	43,582		$	36,193		$	36,248
	_______
	We used Level 2 input values to measure the estimated fair value of our outstanding debt balance as of both December 31, 2014 and 2013.

Reportable_Segments_Notes

Reportable Segments (Notes)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Reportable Segments	Reportable Segments
	We divide our operations into the following reportable business segments.  These segments and their principal sources of revenues are as follows:
	•	Natural Gas Pipelines—(i) the ownership and operation of major interstate and intrastate natural gas pipeline and storage systems; (ii) the ownership and/or operation of associated natural gas and crude oil gathering systems and natural gas processing and treating facilities; and (iii) the ownership and/or operation of NGL fractionation facilities and transportation systems;
	•	CO2—(i) the production, transportation and marketing of CO2 to oil fields that use CO2 as a flooding medium for recovering crude oil from mature oil fields to increase production; (ii) ownership interests in and/or operation of oil fields and gas processing plants in West Texas; and (iii) the ownership and operation of a crude oil pipeline system in West Texas;
	•	Terminals—(i) the ownership and/or operation of liquids and bulk terminal facilities and rail transloading and materials handling facilities located throughout the U.S. and portions of Canada that transload and store refined petroleum products, crude oil, condensate, and bulk products, including coal, petroleum coke, cement, alumina, salt and other bulk chemicals and (ii) the ownership and operation of our Jones Act tankers;
	•	Products Pipelines—the ownership and operation of refined petroleum products and crude oil and condensate pipelines that deliver refined petroleum products (gasoline, diesel fuel and jet fuel), NGL, crude oil, condensate and bio-fuels to various markets, plus the ownership and/or operation of associated product terminals and petroleum pipeline transmix facilities;
	•	Kinder Morgan Canada—the ownership and operation of the Trans Mountain pipeline system that transports crude oil and refined petroleum products from Edmonton, Alberta, Canada to marketing terminals and refineries in British Columbia, Canada and the state of Washington, plus the Jet Fuel aviation turbine fuel pipeline that serves the Vancouver (Canada) International Airport; and
	•	Other—primarily includes other miscellaneous assets and liabilities purchased in our 2012 EP acquisition including (i) our corporate headquarters in Houston, Texas; (ii) several physical natural gas contracts with power plants associated with EP’s legacy trading activities; and (iii) other miscellaneous EP assets and liabilities.
	We evaluate performance principally based on each segment’s EBDA (including amortization of excess cost of equity investments), which excludes general and administrative expenses, third-party debt costs and interest expense, unallocable interest income, and unallocable income tax expense.  Our reportable segments are strategic business units that offer different products and services, and they are structured based on how our chief operating decision makers organize their operations for optimal performance and resource allocation.  Each segment is managed separately because each segment involves different products and marketing strategies.
	We consider each period’s earnings before all non-cash DD&A expenses to be an important measure of business segment performance for our reporting segments.  We account for intersegment sales at market prices, while we account for asset transfers at either market value or, in some instances, book value.
	During 2014, 2013 and 2012, we did not have revenues from any single external customer that exceeded 10% of our consolidated revenues.
	Financial information by segment follows (in millions):
		Year Ended December 31,
		2014			2013			2012
	Revenues
	Natural Gas Pipelines(a)
	Revenues from external customers	$	10,153		$	8,613		$	5,230
	Intersegment revenues	15			4			—
	CO2	1,960			1,857			1,677
	Terminals
	Revenues from external customers	1,717			1,408			1,356
	Intersegment revenues	1			2			3
	Products Pipelines	2,068			1,853			1,370
	Kinder Morgan Canada	291			302			311
	Other	1			1			(6		)
	Total segment revenues	16,206			14,040			9,941
	Other revenues(b)	36			36			35
	Less: Total intersegment revenues	(16		)	(6		)	(3		)
	Total consolidated revenues	$	16,226		$	14,070		$	9,973
		Year Ended December 31,
		2014			2013			2012
	Operating expenses(c)
	Natural Gas Pipelines(a)	$	6,241		$	5,235		$	3,111
	CO2	494			439			381
	Terminals	746			657			685
	Products Pipelines	1,258			1,295			759
	Kinder Morgan Canada	106			110			103
	Other	24			30			5
	Total segment operating expenses	8,869			7,766			5,044
	Other operating expenses	—			—			4
	Less: Total intersegment operating expenses	(16		)	(6		)	(3		)
	Total consolidated operating expenses	$	8,853		$	7,760		$	5,045
		Year Ended December 31,
		2014			2013			2012
	Other expense (income)
	Natural Gas Pipelines(a)	$	5		$	(24	)	$	14
	CO2(d)	243			—			(7		)
	Terminals	29			(74		)	(14		)
	Products Pipelines	(3		)	6			(5		)
	Other	1			(7		)	(1		)
	Total consolidated other expense (income)	$	275		$	(99	)	$	(13	)
		Year Ended December 31,
		2014			2013			2012
	DD&A
	Natural Gas Pipelines(a)	$	897		$	797		$	478
	CO2	570			533			494
	Terminals	337			247			236
	Products Pipelines	166			155			143
	Kinder Morgan Canada	51			54			56
	Other	19			20			12
	Total consolidated DD&A	$	2,040		$	1,806		$	1,419
		Year Ended December 31,
		2014			2013			2012
	Earnings from equity investments
Natural Gas Pipelines(a)(e)	$	318		$	232		$	52
CO2	25			24			25
Terminals	18			22			21
Products Pipelines	44			45			39
Kinder Morgan Canada	—			4			5
Other	1			—			11
Total consolidated equity earnings	$	406		$	327		$	153
	Year Ended December 31,
	2014			2013			2012
Amortization of excess cost of equity investments
Natural Gas Pipelines(a)	$	39		$	32		$	17
CO2	(1		)	2			2
Products Pipelines	7			5			4
Total consolidated amortization of excess cost of equity investments	$	45		$	39		$	23
	Year Ended December 31,
	2014			2013			2012
Interest income
Natural Gas Pipelines	$	1		$	—		$	18
Products Pipelines	2			2			2
Kinder Morgan Canada	—			3			14
Other	6			8			3
Total segment interest income	9			13			37
Unallocated interest income	—			2			(9		)
Total consolidated interest income	$	9		$	15		$	28
	Year Ended December 31,
	2014			2013			2012
Other, net-income (expense)
Natural Gas Pipelines(f)	$	24		$	578		$	4
CO2	—			—			(1		)
Terminals	12			1			2
Products Pipelines	(1		)	1			9
Kinder Morgan Canada(g)	15			246			3
Other	30			9			2
Total consolidated other, net-income (expense)	$	80		$	835		$	19
	Year Ended December 31,
	2014			2013			2012
Income tax benefit (expense)
Natural Gas Pipelines	$	(6	)	$	(9	)	$	(5	)
CO2	(8		)	(7		)	(5		)
Terminals	(29		)	(14		)	(3		)
Products Pipelines	(2		)	2			2
Kinder Morgan Canada	(18		)	(21		)	(1		)
Total segment income tax expense	(63		)	(49		)	(12		)
Unallocated income tax expense	(585		)	(693		)	(127		)
Total consolidated income tax expense	$	(648	)	$	(742	)	$	(139	)
	Year Ended December 31,
	2014			2013			2012
Segment EBDA(h)
Natural Gas Pipelines(a)	$	4,259		$	4,207		$	2,174
CO2	1,240			1,435			1,322
Terminals	944			836			708
Products Pipelines	856			602			668
Kinder Morgan Canada	182			424			229
Other	13			(5		)	7
Total segment EBDA	7,494			7,499			5,108
Total segment DD&A	(2,040		)	(1,806		)	(1,419		)
Total segment amortization of excess cost of equity investments	(45		)	(39		)	(23		)
Other revenues	36			36			35
General and administrative expenses(i)	(610		)	(613		)	(929		)
Interest expense, net of unallocable interest income(j)	(1,807		)	(1,688		)	(1,441		)
Unallocable income tax expense	(585		)	(693		)	(127		)
Loss from discontinued operations, net of tax(k)	—			(4		)	(777		)
Total consolidated net income	$	2,443		$	2,692		$	427
	Year Ended December 31,
	2014			2013			2012
Capital expenditures
Natural Gas Pipelines(a)	$	935		$	1,085		$	499
CO2	792			667			453
Terminals	1,049			1,108			707
Products Pipelines	680			416			307
Kinder Morgan Canada	156			77			16
Other	5			16			40
Total consolidated capital expenditures	$	3,617		$	3,369		$	2,022
	2014			2013
Investments at December 31
Natural Gas Pipelines(a)	5,174			$	5,130
CO2	17			12
Terminals	219			196
Products Pipelines	624			611
Kinder Morgan Canada	1			1
Other	1			1
Total consolidated investments	$	6,036		$	5,951
	2014			2013
Assets at December 31
Natural Gas Pipelines	$	52,523		$	52,357
CO2	5,227			4,708
Terminals	8,850			6,888
Products Pipelines	7,179			6,648
Kinder Morgan Canada	1,593			1,677
Other	459			568
Total segment assets	75,831			72,846
Corporate assets(l)	7,311			2,339
Assets held for sale	56			—
Total consolidated assets	$	83,198		$	75,185
_______
(a)	The Copano acquisition was effective May 1, 2013 and the EP acquisition was effective May 25, 2012 (see Note 3).
(b)	Includes a management fee for services we perform for NGPL Holdco LLC.
(c)	Includes natural gas purchases and other costs of sales, operations and maintenance expenses, and taxes, other than income taxes.
(d)	2014 amount includes an impairment charge of $235 million primarily related to the Katz Strawn unit.
(e)	2013 and 2012 amounts include impairment charges of $65 million and $200 million, respectively, to reduce the carrying value of our equity investment in NGPL Holdco LLC.
(f)	2013 amount includes a $558 million gain from the remeasurement of our previously held 50% equity interest in Eagle Ford to fair value (See Note 3).
(g)	2013 amount includes a $224 million pre-tax gain from the sale of our equity and debt investments in the Express pipeline system (See Note 3).
(h)	Includes revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income).
(i)	2012 amount includes $366 million of pre-tax expense associated with the EP acquisition and EP Energy sale.
(j)	Includes (i) interest expense and (ii) miscellaneous other income and expenses not allocated to business segments. 2012 amount includes $108 million of expense for capitalized financing fees associated with the EP acquisition financing that were written-off (primarily due to debt repayments) or amortized.
(k)	Represents loss from sale of the FTC Natural Gas Pipelines disposal group and other, net of tax (see Note 3).
(l)	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.
We do not attribute interest and debt expense to any of our reportable business segments.  For each of the years ended December 31, 2014, 2013 and 2012, we reported total consolidated interest expense of $1,807 million, $1,690 million, and $1,427 million, respectively.
Following is geographic information regarding the revenues and long-lived assets of our business segments (in millions):
	Year Ended December 31,
	2014			2013			2012
Revenues from external customers
U.S.	$	15,605		$	13,656		$	9,488
Canada	437			398			407
Mexico	184			16			78
Total consolidated revenues from external customers	$	16,226		$	14,070		$	9,973
_______
	2014			2013			2012
Long-lived assets at December 31(a)
U.S.	$	50,141		$	42,080		$	37,651
Canada	2,268			2,214			2,035
Mexico	81			81			82
Total consolidated long-lived assets	$	52,490		$	44,375		$	39,768
_______
(a) Long-lived assets exclude goodwill and other intangibles, net.

Litigation_Environmental_and_O

Litigation, Environmental and Other Contingencies (Notes)	12 Months Ended
	Dec. 31, 2014
Loss Contingency, Information about Litigation Matters [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 $100 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. Accordingly, SFPP filed with the CPUC a request to eliminate the 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. A decision from the CPUC is expected in the first quarter of 2015.
	Other Commercial Matters
	Union Pacific Railroad Company Easements
	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. UPRR is expected to seek further appellate review by the U.S. Supreme Court. We believe we have recorded a right-of-way liability consistent with the Court of Appeals’ decision and sufficient to cover our potential liability for back rent.
	By notice dated October 25, 2013, UPRR demanded the payment of $22.25 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.
	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 expense (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.
	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, 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 have been consolidated into one proceeding. 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 on the remaining claims. Trial was held in late 2014 and a decision is expected during the first half of 2015. Motions to dismiss have been filed in Brinckerhoff III and Brinckerhoff IV. Defendants 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. Plaintiff filed a notice of appeal to the Delaware Supreme Court, which will hear oral argument on February 25, 2015.
	Price Reporting Litigation
	Beginning in 2003, several lawsuits were filed against El Paso Marketing L.P. (EPM) alleging that EP, EPM and other energy companies 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. A petition for certiorari was granted by the U.S. Supreme Court. Oral argument was heard on January 12, 2015 and the matter is stayed pending appeal. 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 alleges 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.
	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 December 31, 2014 and 2013, our total reserve for legal matters was $400 million and $624 million, respectively. The reserve primarily relates to various claims from regulatory proceedings arising from our products pipeline and natural gas pipeline transportation rates. The overall decrease in the reserve from December 31, 2013 was primarily due to the settlement refunds associated with our SFPP rate proceedings.
	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 an allocation process to determine each party’s respective share of the cleanup costs. This is a non-judicial allocation process. 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 process to conclude in 2015. We also expect the LWG to complete the RI/FS process 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. Our motion to dismiss the suit was denied on August 19, 2014 and we have filed an answer to the Second Amended Complaint.
	Paulsboro, New Jersey Liquids Terminal Consent Judgment
	On June 25, 2007, the New Jersey Department of Environmental Protection (NJDEP) and the Administrator of the New Jersey Spill Compensation Fund, referred to collectively as the plaintiffs, filed a complaint in Gloucester County, New Jersey against ExxonMobil and KMLT, formerly known as GATX Terminals Corporation, alleging natural resource damages related to historic contamination at the Paulsboro, New Jersey liquids terminal owned by ExxonMobil from the mid-1950s through November 1989, by GATX Terminals Corporation from 1989 through September 2000, and later owned by Support Terminals and Pacific Atlantic Terminals, LLC. The terminal is now owned by Plains Products, which was also joined as a party to the lawsuit.
	In mid 2011, KMLT and Plains Products entered into a settlement agreement and subsequent Consent Judgment with the NJDEP which resolved the state’s alleged natural resource damages claim. The natural resource damage settlement includes a monetary award of $1 million and a series of remediation and restoration activities at the terminal site. KMLT and Plains Products have joint responsibility for this settlement. Simultaneously, KMLT and Plains Products entered into an agreement that settled each party’s relative share of responsibility (50/50) to the NJDEP under the Consent Judgment noted above. The Consent Judgment is now entered with the Court and the settlement is final. According to the agreement, Plains will conduct remediation activities at the site and KMLT will provide oversight and 50% of the costs. We are awaiting approval from the NJDEP in order to begin remediation activities.
	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.
	On May 7, 2013, the City of San Diego petitioned the California Superior Court for a writ of mandamus seeking an order setting aside the RWQCB’s approval of an amendment to our permit request to increase the discharge of water from our groundwater treatment system to the City of San Diego’s municipal storm sewer system. On October 10, 2014, the court ruled that the City’s petition was moot and dismissed the case because the amendment to the permit was no longer required and had been rescinded by the RWQCB at the request of SFPP upon SFPP’s completion of soil and groundwater remediation at the City’s stadium property site.
	Uranium Mines in Vicinity of Cameron, Arizona
	In the 1950s and 1960s, Rare Metals Inc., a historical subsidiary of EPNG, operated 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.
	PHMSA Inspection of Carteret Terminal, Carteret, New Jersey
	On April 4, 2013, the PHMSA, Office of Pipeline Safety issued a Notice of Probable Violation, Proposed Civil Penalty and Proposed Compliance Order (NOPV) arising from an inspection at the KMLT, Carteret, New Jersey location on March 15, 2011 following a release and fire that occurred during maintenance activity on March 14, 2011. On July 17, 2013, KMLT entered into a Consent Agreement and Order with the PHMSA, pursuant to which KMLT paid a penalty of $63,100 and is required to complete ongoing pipeline integrity testing and other corrective measures by November 30, 2015.
	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 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 of approximately 70 cooperating parties (CPG) 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 CPG 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 September 10, 2013, the SLFPA filed a motion to remand the case to the state district court for Orleans Parish. The Court denied the remand motion on June 27, 2014. Louisiana Act 544 (the Act) went into effect on June 6, 2014 and specified the political entities authorized to institute litigation for environmental damage in the coastal zone. Under the Act, which was specifically made retroactive, we contend the SLFPA is not a valid plaintiff, whereas the SLFPA contends the Act is unconstitutional. The parties filed numerous cross motions seeking a ruling on the enforceability of the Act and other potentially dispositive legal issues. On February 13, 2015, the Court granted defendants’ motion to dismiss the suit for failure to state a claim, and issued an order dismissing plaintiffs’ claims with prejudice.
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. On January 14, 2014, the plaintiff filed a motion to remand the case to state court. On August 11, 2014, the court entered an order suspending a ruling on the remand motion and administratively closing the case, pending a ruling on plaintiff’s remand motion in another substantially similar case in the same federal court to which TGP is not a party. On December 1, 2014, the remand motion in the substantially similar case was granted. On February 3, 2015, TGP and other defendants filed a motion to re-open its case for the purpose of further proceedings, including the court’s consideration of whether remand is required. 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 we await Kinetica’s response to TGP’s tender.
Pennsylvania Department of Environmental Protection Notice of Alleged Violations
The Pennsylvania Department of Environmental Protection (PADEP) notified TGP of alleged violations of certain conditions to the construction permits issued to TGP for the construction of TGP’s 300 Line Project in 2011. The alleged violations arise from field inspections performed by county conservation districts, as delegates of the PADEP, during construction. The PADEP alleges that TGP failed to implement and maintain best practices to achieve sufficient erosion and sediment controls, stabilization of the right-of-way, and prevention of potential discharge of sediment into the waters of the Commonwealth of Pennsylvania during construction, before placing the line into service, and in connection with the occurrence of 100 year storm events. On December 22, 2014, TGP entered into a consent order and agreement with the PADEP pursuant to which TGP agreed to pay a civil penalty of $210,000, $50,000 in costs, and $540,000 to fund community environmental programs in Pike, Potter, Susquehanna, and Wayne counties in Pennsylvania to generally improve water quality in such counties and help restore third party dump sites unrelated to TGP’s construction or other activities.
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 December 31, 2014 and 2013, we have accrued a total reserve for environmental liabilities in the amount of $340 million and $378 million, respectively. In addition, as of both December 31, 2014 and 2013, we have recorded a receivable of $14 million, for expected cost recoveries that have been deemed probable.

Guarantee_of_Securities_of_Sub

Guarantee of Securities of Subsidiaries (Notes)	12 Months Ended
	Dec. 31, 2014
Guarantee of Securities of Subsidiaries [Abstract]
Guarantees [Text Block]	Guarantee of Securities of Subsidiaries
	KMI, along with its direct and indirect subsidiaries KMP, EPB 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, Copano and EPB, 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, Copano or EPB 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.
	Excluding fair value adjustments, as of December 31, 2014, Parent Issuer and Guarantor, Subsidiary Issuer and Guarantor-KMP, Subsidiary Issuer and Guarantor-Copano, Subsidiary Issuer and Guarantor-EPB and Subsidiary Guarantors had $12,674 million, $17,800 million, $332 million, $2,860 million and $6,463 million of Guaranteed Notes outstanding, respectively.   Included in the Subsidiary Guarantors debt balance as presented in the accompanying December 31, 2014 condensed consolidating balance sheet is approximately $178 million 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 Issuer and Guarantor-EPB, 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 KMI Transactions close date, KMR was dissolved and its assets merged into KMI.  Therefore, for all periods presented KMR’s financial statement balances and activities are reflected within the Parent Issuer and Guarantor column.
	On January 1, 2015, EPB and its subsidiary, EPPOC merged with and into KMP and were dissolved. As a result of such merger, all of the subsidiaries of EPPOC are wholly owned subsidiaries of KMP and effective January 1, 2015, EPPOC is no longer a Subsidiary Issuer and Guarantor.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Income Tax Uncertainties, Policy [Policy Text Block]	We recognize the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities, based not only on the technical merits of the tax position based on tax law, but also the past administrative practices and precedents of the taxing authority.  The tax benefits recognized in the financial statements from such a position are measured based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate resolution.
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]	Impairments
	We review long-lived assets for impairment whenever events or changes in circumstances indicate that our carrying amount of an asset may not be recoverable.  We recognize impairment losses when estimated future cash flows expected to result from our use of the asset and its eventual disposition is less than its carrying amount.
	We evaluate our oil and gas producing properties for impairment of value on a field-by-field basis or, in certain instances, by logical grouping of assets if there is significant shared infrastructure, using undiscounted future cash flows based on total proved and risk-adjusted probable and possible reserves.  For the purpose of impairment testing, adjustments for the inclusion of risk-adjusted probable and possible reserves, as well as forward curve pricing, will cause impairment calculation cash flows to differ from the amounts presented in our supplemental information on oil and gas producing activities disclosed in “Supplemental Information on Oil and Gas Producing Activities (Unaudited).”
	Oil and gas producing properties deemed to be impaired are written down to their fair value, as determined by discounted future cash flows based on total proved and risk-adjusted probable and possible reserves or, if available, comparable market values.  Unproved oil and gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment.
Basis of Accounting, Policy [Policy Text Block]	Basis of Presentation
	Our reporting currency is U.S. dollars, and all references to dollars are U.S. dollars.
	Our accompanying consolidated financial statements have been prepared under the rules and regulations of the 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.
Use of Estimates, Policy [Policy Text Block]	Use of Estimates
	Certain amounts included in or affecting our financial statements and related disclosures must be estimated, requiring us to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time our financial statements are prepared. These estimates and assumptions affect the amounts we report for assets and liabilities, our revenues and expenses during the reporting period, and our disclosure of contingent assets and liabilities at the date of our financial statements. We evaluate these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods we consider reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from our estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known.
	In addition, we believe that certain accounting policies are of more significance in our financial statement preparation process than others, and set out below are the principal accounting policies we apply in the preparation of our consolidated financial statements.
Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy [Policy Text Block]	Cash Equivalents and Restricted Deposits
	We define cash equivalents as all highly liquid short-term investments with original maturities of three months or less.
	Restricted cash of $118 million and $75 million as of December 31, 2014 and 2013, respectively is included in “Other current assets.”
Receivables, Policy [Policy Text Block]	Accounts Receivable
	The amounts reported as “Accounts receivable, net” on our accompanying consolidated balance sheets as of December 31, 2014 and 2013 primarily consist of amounts due from customers.
	Our policy for determining an appropriate allowance for doubtful accounts varies according to the type of business being conducted and the customers being served.  Generally, we make periodic reviews and evaluations of the appropriateness of the allowance for doubtful accounts based on a historical analysis of uncollected amounts, and we record adjustments as necessary for changed circumstances and customer-specific information.  When specific receivables are determined to be uncollectible, the reserve and receivable are relieved.
Inventory, Policy [Policy Text Block]	Inventories
	Our inventories consist of materials and supplies and products such as, NGL, crude oil, condensate, refined petroleum products, transmix and natural gas. We report these assets at the lower of weighted-average cost or market. We report materials and supplies inventories at cost, and periodically review for physical deterioration and obsolescence.
Gas Balancing Arrangements, Policy [Policy Text Block]	Gas Imbalances
	We value gas imbalances due to or due from interconnecting pipelines at the lower of cost or market or index prices. As of December 31, 2014 and 2013, our gas imbalance receivables—including both trade and related party receivables—totaled $103 million and $83 million, respectively, and we included these amounts within “Other current assets” on our accompanying consolidated balance sheets. As of December 31, 2014 and 2013, our gas imbalance payables—consisting of only trade payables—totaled $36 million and $34 million, respectively, and we included these amounts within “Other current liabilities” on our accompanying consolidated balance sheets.
Property, Plant and Equipment, Policy [Policy Text Block]	Property, Plant and Equipment
	Capitalization, Depreciation and Depletion and Disposals
	We report property, plant and equipment at its acquisition cost. We expense costs for routine maintenance and repairs in the period incurred.
	We generally compute depreciation using either the straight-line method based on estimated economic lives or, for certain depreciable assets, we employ the composite depreciation method, applying a single depreciation rate for a group of assets. Generally, we apply composite depreciation rates to functional groups of property having similar economic characteristics. The rates range from 0.9% to 23.0% excluding certain short-lived assets such as vehicles. For FERC-regulated entities, the FERC-accepted composite depreciation rate is applied to the total cost of the composite group until the net book value equals the salvage value. For other entities, depreciation estimates are based on various factors, including age (in the case of acquired assets), manufacturing specifications, technological advances and historical data concerning useful lives of similar assets. Uncertainties that impact these estimates included changes in laws and regulations relating to restoration and abandonment requirements, economic conditions, and supply and demand in the area. When assets are put into service, we make estimates with respect to useful lives (and salvage values where appropriate) that we believe are reasonable. Subsequent events could cause us to change our estimates, thus impacting the future calculation of depreciation and amortization expense. Historically, adjustments to useful lives have not had a material impact on our aggregate depreciation levels from year to year.
	Our oil and gas producing activities are accounted for under the successful efforts method of accounting. Under this method costs that are incurred to acquire leasehold and subsequent development costs are capitalized. Costs that are associated with the drilling of successful exploration wells are capitalized if proved reserves are found. Costs associated with the drilling of exploratory wells that do not find proved reserves, geological and geophysical costs, and costs of certain non-producing leasehold costs are expensed as incurred. The capitalized costs of our producing oil and gas properties are depreciated and depleted by the units-of-production method. Other miscellaneous property, plant and equipment are depreciated over the estimated useful lives of the asset.
	We engage in enhanced recovery techniques in which CO2 is injected into certain producing oil reservoirs. In some cases, the acquisition cost of the CO2 associated with enhanced recovery is capitalized as part of our development costs when it is injected. The acquisition cost associated with pressure maintenance operations for reservoir management is expensed when it is injected. When CO2 is recovered in conjunction with oil production, it is extracted and re-injected, and all of the associated costs are expensed as incurred. Proved developed reserves are used in computing units of production rates for drilling and development costs, and total proved reserves are used for depletion of leasehold costs. The units-of-production rate is determined by field.
	A gain on the sale of property, plant and equipment used in our oil and gas producing activities or in our bulk and liquids terminal activities is calculated as the difference between the cost of the asset disposed of, net of depreciation, and the sales proceeds received. A gain on an asset disposal is recognized in income in the period that the sale is closed. A loss on the sale of property, plant and equipment is calculated as the difference between the cost of the asset disposed of, net of depreciation, and the sales proceeds received or the market value if the asset is being held for sale. A loss is recognized when the asset is sold or when the net cost of an asset held for sale is greater than the market value of the asset. For our pipeline system assets under the composite method of depreciation, we generally charge the original cost of property sold or retired to accumulated depreciation and amortization, net of salvage and cost of removal. Gains and losses are booked for operating unit sales and land sales and are recorded to income or expense accounts in accordance with regulatory accounting guidelines. In those instances where we receive recovery in tariff rates related to losses on dispositions of operating units, we record a regulatory asset for the estimated recoverable amount.
Asset Retirement Obligations, Policy [Policy Text Block]	Asset Retirement Obligations
	We record liabilities for obligations related to the retirement and removal of long-lived assets used in our businesses.  We record, as liabilities, the fair value of asset retirement obligations on a discounted basis when they are incurred, which is typically at the time the assets are installed or acquired.  Amounts recorded for the related assets are increased by the amount of these obligations.  Over time, the liabilities increase due to the change in their present value, and the initial capitalized costs are depreciated over the useful lives of the related assets.  The liabilities are eventually extinguished when the asset is taken out of service.
Equity Method Investments, Policy [Policy Text Block]
	Equity method of accounting
	We account for investments—which we do not control, but do have the ability to exercise significant influence—by the equity method of accounting. Under this method, our equity investments are carried originally at our acquisition cost, increased by our proportionate share of the investee’s net income and by contributions made, and decreased by our proportionate share of the investee’s net losses and by distributions received.
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	Goodwill
	Goodwill represents the excess of the cost of an acquisition price over the fair value of the acquired net assets, and such amounts are reported separately on our consolidated balance sheets.  As of December 31, 2014 and 2013 our total goodwill was $24,654 million and $24,504 million, respectively.  Goodwill is not amortized, but instead is tested for impairment annually or on an interim basis if events or circumstances indicate that the fair value of the asset has decreased below its carrying value. We perform our goodwill impairment test on May 31 of each year.  There were no impairment charges resulting from our May 31, 2014 or 2013 impairment testing, and no event indicating an impairment has occurred subsequent to May 31, 2014 other than as described below.
	If a significant portion of one of our business segments is disposed of (that also constitutes a business), we allocate goodwill based on the relative fair values of the portion of the segment being disposed of and the portion of the segment remaining.
Revenue Recognition, Policy [Policy Text Block]	Revenue Recognition Policies
	We recognize revenues as services are rendered or goods are delivered and, if applicable, title has passed.  We recognize natural gas sales revenues and NGL sales revenue when the natural gas or NGL is sold to a purchaser at a fixed or determinable price, delivery has occurred and title has transferred, and collectability of the revenue is reasonably assured. Our sales and purchases of natural gas and NGL are primarily accounted for on a gross basis as natural gas sales or product sales, as applicable, and cost of sales.
	In addition to storing and transporting a significant portion of the natural gas volumes we purchase and resell, we provide various types of natural gas storage and transportation services for third-party customers.  Under these contracts, the natural gas remains the property of these customers at all times. In many cases, generally described as firm service, the customer pays a two-part rate that includes (i) a fixed fee reserving the right to transport or store natural gas in our facilities and (ii) a per-unit rate for volumes actually transported or injected into/withdrawn from storage.  The fixed-fee component of the overall rate is recognized as revenue in the period the service is provided.  The per-unit charge is recognized as revenue when the volumes are delivered to the customers’ agreed upon delivery point, or when the volumes are injected into/withdrawn from our storage facilities.
	In other cases, generally described as interruptible service, there is no fixed fee associated with the services because the customer accepts the possibility that service may be interrupted at our discretion in order to serve customers who have purchased firm service.  In the case of interruptible service, revenue is recognized in the same manner utilized for the per-unit rate for volumes actually transported under firm service agreements.
	We provide crude oil and refined petroleum products transportation and storage services to customers.  Revenues are recorded when products are delivered and services have been provided, and adjusted according to terms prescribed by the toll settlements with shippers and approved by regulatory authorities.
	We recognize bulk terminal transfer service revenues based on volumes loaded and unloaded.  We recognize liquids terminal tank rental revenue ratably over the contract period. We recognize liquids terminal throughput revenue based on volumes received and volumes delivered.  We recognize transmix processing revenues based on volumes processed or sold, and if applicable, when title has passed.  We recognize energy-related product sales revenues based on delivered quantities of product.
	Revenues from the sale of crude oil, NGL, CO2 and natural gas production within the CO2 business segment are recorded using the entitlement method.  Under the entitlement method, revenue is recorded when title passes based on our net interest.  We record our entitled share of revenues based on entitled volumes and contracted sales prices. Since there is a ready market for oil and gas production, we sell the majority of our products soon after production at various locations, at which time title and risk of loss pass to the buyer.
Regulatory Environmental Costs, Policy [Policy Text Block]	Environmental Matters
	We capitalize or expense, as appropriate, environmental expenditures.  We capitalize certain environmental expenditures required in obtaining rights-of-way, regulatory approvals or permitting as part of the construction. We accrue and expense environmental costs that relate to an existing condition caused by past operations, which do not contribute to current or future revenue generation.  We generally do not discount environmental liabilities to a net present value, and we record environmental liabilities when environmental assessments and/or remedial efforts are probable and we can reasonably estimate the costs.  Generally, our recording of these accruals coincides with our completion of a feasibility study or our commitment to a formal plan of action.  We recognize receivables for anticipated associated insurance recoveries when such recoveries are deemed to be probable. We record at fair value, where appropriate, environmental liabilities assumed in a business combination.
	We routinely conduct reviews of potential environmental issues and claims that could impact our assets or operations.  These reviews assist us in identifying environmental issues and estimating the costs and timing of remediation efforts.  We also routinely adjust our environmental liabilities to reflect changes in previous estimates.  In making environmental liability estimations, we consider the material effect of environmental compliance, pending legal actions against us, and potential third-party liability claims.  Often, as the remediation evaluation and effort progresses, additional information is obtained, requiring revisions to estimated costs.  These revisions are reflected in our income in the period in which they are reasonably determinable.
Pension and Other Postretirement Plans, Policy [Policy Text Block]	ensions and Other Postretirement Benefits
	We recognize the differences between the fair value of each of our and our consolidated subsidiaries’ pension and other postretirement benefit plans’ assets and the benefit obligations as either assets or liabilities on our balance sheet. We record deferred plan costs and income—unrecognized losses and gains, unrecognized prior service costs and credits, and any remaining unamortized transition obligations—in “Accumulated other comprehensive loss” or as a regulatory asset or liability for certain of our regulated operations, until they are amortized to be recognized as a component of benefit expense.
Consolidation, Subsidiaries or Other Investments, Consolidated Entities, Policy [Policy Text Block]	Noncontrolling Interests
	Noncontrolling interests represents the outstanding ownership interests in our consolidated subsidiaries that are not owned by us.  In our accompanying consolidated income statements, the noncontrolling interest in the net income (or loss) of our consolidated subsidiaries is shown as an allocation of our consolidated net income and is presented separately as “Net income attributable to noncontrolling interests.”  In our accompanying consolidated balance sheets, noncontrolling interests represents the ownership interests in our consolidated subsidiaries’ net assets held by parties other than us.  It is presented separately as “Noncontrolling interests” within “Stockholders’ Equity.”
Income Tax, Policy [Policy Text Block]	Income Taxes
	Income tax expense is recorded based on an estimate of the effective tax rate in effect or to be in effect during the relevant periods.  Deferred income tax assets and liabilities are recognized for temporary differences between the basis of assets and liabilities for financial reporting and tax purposes.  Changes in tax legislation are included in the relevant computations in the period in which such changes are effective.  Deferred tax assets are reduced by a valuation allowance for the amount of any tax benefit we do not expect to be realized.
Foreign Currency Transactions and Translations Policy [Policy Text Block]	Foreign Currency Transactions and Translation
	Foreign currency transaction gains or losses result from a change in exchange rates between (i) the functional currency, for example the Canadian dollar for a Canadian subsidiary and (ii) the currency in which a foreign currency transaction is denominated, for example the U.S. dollar for a Canadian subsidiary.  In our accompanying consolidated statements of income, gains and losses from our foreign currency transactions are included within “Other Income (Expense)—Other, net.”
	Foreign currency translation is the process of expressing, in U.S. dollars, amounts recorded in a local functional currency other than U.S. dollars, for example the Canadian dollar for a Canadian subsidiary.  We translate the assets and liabilities of each of our consolidated foreign subsidiaries that have a local functional currency to U.S. dollars at year-end exchange rates.  Income and expense items are translated at weighted-average rates of exchange prevailing during the year and stockholders’ equity accounts are translated by using historical exchange rates.  The cumulative translation adjustments balance is reported as a component of “Accumulated other comprehensive loss.”
Comprehensive Income, Policy [Policy Text Block]	Comprehensive Income
	For each of the years ended December 31, 2014, 2013 and 2012, the difference between our net income and our comprehensive income resulted from (i) unrealized gains or losses on derivative contracts accounted for as cash flow hedges; (ii) foreign currency translation adjustments; and (iii) unrealized gains or losses related to changes in pension and other postretirement benefit plan liabilities. For more information on our risk management activities, see Note 13.
Derivatives, Policy [Policy Text Block]	Risk Management Activities
	We utilize energy commodity derivative contracts for the purpose of mitigating our risk resulting from fluctuations in the market price of natural gas, NGL and crude oil.  In addition, we enter into interest rate swap agreements for the purpose of hedging the interest rate risk associated with our debt obligations. We measure our derivative contracts at fair value and we report them on our balance sheet as either an asset or liability.  If the derivative transaction qualifies for and is designated as a normal purchase and sale, it is exempted from fair value accounting and is accounted for using traditional accrual accounting.
	Furthermore, changes in our derivative contracts’ fair values are recognized currently in earnings unless hedge accounting is applied.  If a derivative contract meets specific accounting criteria, the contract’s gains and losses are allowed to offset related results on the hedged item in our income statement, and we may formally designate the derivative contract as a hedge and document and assess the effectiveness of the contract associated with the transaction that receives hedge accounting.  Only designated qualifying items that are effectively offset by changes in fair value or cash flows during the term of the hedge are eligible to use the special accounting for hedging.
	Our derivative contracts that hedge our energy commodity price risks involve our normal business activities, which include the purchase and sale of natural gas, NGL and crude oil, and we may designate these derivative contracts as cash flow hedges—derivative contracts that hedge exposure to variable cash flows of forecasted transactions—and the effective portion of these derivative contracts’ gain or loss is initially reported as a component of other comprehensive income (outside earnings) and subsequently reclassified into earnings when the forecasted transactions affect earnings.  The ineffective portion of the gain or loss is reported in earnings immediately.
Public Utilities, Policy [Policy Text Block]	Regulatory Assets and Liabilities
	Regulatory assets and liabilities represent probable future revenues or expenses associated with certain charges and credits that will be recovered from or refunded to customers through the ratemaking process.  We included the amounts of our regulatory assets and liabilities within “Other current assets,” “Deferred charges and other assets,” “Other current liabilities” and “Other long-term liabilities and deferred credits,” respectively, in our accompanying consolidated balance sheets. As of December 31, 2014, the recovery period for these regulatory assets was approximately one year to forty-two years.
	The following table summarizes our regulatory asset and liability balances as of December 31, 2014 and 2013 (in millions):
		December 31,
		2014				2013
	Current regulatory assets	$	81			$	91
	Non-current regulatory assets	406				446
	Total regulatory assets	$	487			$	537
	Current regulatory liabilities	$	189			$	135
	Non-current regulatory liabilities	290				397
	Total regulatory liabilities	$	479			$	532
	_______
	On July 26, 2012, TGP filed an application with the FERC seeking authority to abandon by sale certain natural gas facilities located offshore in the Gulf of Mexico and onshore in the state of Louisiana, as well as a related offer of settlement that addressed the proposed rate and accounting treatment associated with the sale. The offer of settlement provided for a rate adjustment to TGP’s maximum tariff rates upon the transfer of the assets and established a regulatory asset for a portion of the unrecovered net book value of the facilities to be sold. Effective September 1, 2013, following the FERC’s approval of both the requested abandonment authorization and the offer of settlement, TGP sold these assets, and in 2013, TGP recognized both a $93 million increase in regulatory assets and a $36 million gain from the sale of assets.
Transfer of net assets between entities under common control [Policy Text Block]	Transfer of Net Assets Between Entities Under Common Control
	We account for the transfer of net assets between entities under common control by carrying forward the net assets recognized in the balance sheets of each combining entity to the balance sheet of the combined entity, and no other assets or liabilities are recognized as a result of the combination.  Transfers of net assets between entities under common control do not affect the historical income statement or balance sheet of the combined entity.
Earnings Per Share, Policy [Policy Text Block]	Earnings per Share
	For the years ended December 31, 2014 and 2013, earnings per share was calculated 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 table sets forth the allocation of net income available to shareholders for Class P shares and for participating securities (in millions):
		Year Ended December 31,
		2014				2013
	Class P	$	1,015			$	1,187
	Participating securities(a)	11				6
	Net Income Attributable to Kinder Morgan, Inc.	$	1,026			$	1,193
	_______
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
	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):
		Year Ended December 31,
		2014			2013
	Unvested restricted stock awards	7			4
	Outstanding warrants to purchase our Class P shares(a)	312			401
	Convertible trust preferred securities	10			10
	_______
	(a)	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.
	On December 26, 2012, the remaining series of our Class A, Class B, and Class C shares were fully-converted and as a result, only our Class P common stock was outstanding as of December 31, 2012 (see Note 10).
	For the year ended December 31, 2012, earnings per share was calculated using the two-class method.  Earnings were allocated to each class of common stock based on the amount of dividends paid in the current period for each class of stock 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.  For the investor retained stock, the allocation of undistributed earnings or excess distributions over earnings was in direct proportion to the maximum number of Class P shares into which it could convert.
	For the Class P diluted earnings per share computations, total net income attributable to Kinder Morgan, Inc. was divided by the adjusted weighted-average shares outstanding during the period, including all potential common stock equivalents.  This included, for the periods prior to December 26, 2012, the Class P shares into which the investor retained stock (collectively, our Class A, Class B and Class C common stocks) was convertible.  The number of Class P shares on a fully-converted basis was the same before and after any conversion of our investor retained stock.  Each time one Class P share was issued upon conversion of investor retained stock, the number of Class P shares went up by one, and the number of Class P shares into which the investor retained stock was convertible went down by one.  Accordingly, there was no difference between Class P basic and diluted earnings per share because the conversion of Class A, Class B, and Class C shares into Class P shares did not impact the number of Class P shares on a fully-converted basis.  Commencing with the acquisition of EP, potential common stock equivalents also included the Class P shares issuable in connection with the warrants and the trust preferred securities (see Note 10).  As no securities were convertible into Class A shares, the basic and diluted earnings per share computations for Class A shares were the same. For the year ended December 31, 2012, the following potential Class P common stock equivalents were antidilutive and, accordingly, were excluded from the determination of diluted earnings per share; (i) 451 million related to outstanding warrants to purchase our Class P shares; and (ii) 11 million related to convertible trust preferred securities.
	The following tables set forth the computation of basic and diluted earnings per share from continuing operations for the year ending December 31, 2012 (in millions, except per share amounts):
		Year ended December 31, 2012
		Income from Continuing Operations Available to Shareholders
		Class P				Class A			Participating			Total
									Securities(a)
	Income from continuing operations											$	1,204
	Less: income from continuing operations attributable to noncontrolling interests											(696		)
	Income from continuing operations attributable to KMI											508
	Dividends paid in the period	$	601			$	542		$	41		(1,184		)
	Excess distributions over earnings	(344		)		(331		)	(1		)	$	(676	)
	Income from continuing operations attributable to shareholders	$	257			$	211		$	40		$	508
	Basic earnings per share from continuing operations
	Basic weighted-average number of shares outstanding	461				446			N/A
	Basic earnings per common share from continuing operations(b)	$	0.56			$	0.47		N/A
	Diluted earnings per share from continuing operations
	Income from continuing operations attributable to shareholders and assumed conversions(c)	$	508			$	211		N/A
	Diluted weighted-average number of shares	908				446			N/A
	Diluted earnings per common share from continuing operations(b)	$	0.56			$	0.47		N/A
	_______
	The following tables set forth the computation of basic and diluted earnings per share for the year ended December 31, 2012 (in millions, except per share amounts):
		Year ended December 31, 2012
		Net Income Available to Shareholders
		Class P				Class A			Participating			Total
									Securities(a)
	Net income attributable to KMI											$	315
	Dividends paid in the period	$	601			$	542		$	41		(1,184		)
	Excess distributions over earnings	(441		)		(426		)	(2		)	$	(869	)
	Net income attributable to shareholders	$	160			$	116		$	39		$	315
	Basic earnings per share
	Basic weighted-average number of shares outstanding	461				446			N/A
	Basic earnings per common share(b)	$	0.35			$	0.26		N/A
	Diluted earnings per share
	Net income attributable to shareholders and assumed conversions(c)	$	315			$	116		N/A
	Diluted weighted-average number of shares	908				446			N/A
	Diluted earnings per common share(b)	$	0.35			$	0.26		N/A
	_______
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalents payments.
	(b)	The Class A shares earnings per share as compared to the Class P shares earnings per share were reduced due to the sharing of economic benefits (including dividends) amongst the Class A, B, and C shares.  Class A, B and C shares owned by Richard Kinder, the sponsor investors, the original shareholders, and other management were referred to as “investor retained stock,” and were convertible into a fixed number of Class P shares.  In the aggregate, our investor retained stock was entitled to receive a dividend per share on a fully-converted basis equal to the dividend per share on our common stock.  The conversion of shares of investor retained stock into Class P shares did not increase our total fully-converted shares outstanding, impact the aggregate dividends we paid or the dividends we paid per share on our Class P common stock.
	(c)	For the diluted earnings per share calculation, total net income attributable to each class of common stock was divided by the adjusted weighted-average shares outstanding during the period, including all potential common stock equivalents.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Regulatory Assets and Liabilities [Text Block]	The following table summarizes our regulatory asset and liability balances as of December 31, 2014 and 2013 (in millions):
		December 31,
		2014			2013
	Current regulatory assets	$	81		$	91
	Non-current regulatory assets	406			446
	Total regulatory assets	$	487		$	537
	Current regulatory liabilities	$	189		$	135
	Non-current regulatory liabilities	290			397
	Total regulatory liabilities	$	479		$	532
	_______
Schedule of Net Income for Shareholders and Participating Securities [Table Text Block]	The following table sets forth the allocation of net income available to shareholders for Class P shares and for participating securities (in millions):
		Year Ended December 31,
		2014			2013
	Class P	$	1,015		$	1,187
	Participating securities(a)	11			6
	Net Income Attributable to Kinder Morgan, Inc.	$	1,026		$	1,193
	_______
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalent payments.
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]	The following tables set forth the computation of basic and diluted earnings per share from continuing operations for the year ending December 31, 2012 (in millions, except per share amounts):
		Year ended December 31, 2012
		Income from Continuing Operations Available to Shareholders
		Class P			Class A			Participating			Total
								Securities(a)
	Income from continuing operations										$	1,204
	Less: income from continuing operations attributable to noncontrolling interests										(696		)
	Income from continuing operations attributable to KMI										508
	Dividends paid in the period	$	601		$	542		$	41		(1,184		)
	Excess distributions over earnings	(344		)	(331		)	(1		)	$	(676	)
	Income from continuing operations attributable to shareholders	$	257		$	211		$	40		$	508
	Basic earnings per share from continuing operations
	Basic weighted-average number of shares outstanding	461			446			N/A
	Basic earnings per common share from continuing operations(b)	$	0.56		$	0.47		N/A
	Diluted earnings per share from continuing operations
	Income from continuing operations attributable to shareholders and assumed conversions(c)	$	508		$	211		N/A
	Diluted weighted-average number of shares	908			446			N/A
	Diluted earnings per common share from continuing operations(b)	$	0.56		$	0.47		N/A
	_______
	The following tables set forth the computation of basic and diluted earnings per share for the year ended December 31, 2012 (in millions, except per share amounts):
		Year ended December 31, 2012
		Net Income Available to Shareholders
		Class P			Class A			Participating			Total
								Securities(a)
	Net income attributable to KMI										$	315
	Dividends paid in the period	$	601		$	542		$	41		(1,184		)
	Excess distributions over earnings	(441		)	(426		)	(2		)	$	(869	)
	Net income attributable to shareholders	$	160		$	116		$	39		$	315
	Basic earnings per share
	Basic weighted-average number of shares outstanding	461			446			N/A
	Basic earnings per common share(b)	$	0.35		$	0.26		N/A
	Diluted earnings per share
	Net income attributable to shareholders and assumed conversions(c)	$	315		$	116		N/A
	Diluted weighted-average number of shares	908			446			N/A
	Diluted earnings per common share(b)	$	0.35		$	0.26		N/A
	_______
	(a)	Participating securities are unvested restricted stock awards issued to management employees that contain non-forfeitable rights to dividend equivalents payments.
	(b)	The Class A shares earnings per share as compared to the Class P shares earnings per share were reduced due to the sharing of economic benefits (including dividends) amongst the Class A, B, and C shares.  Class A, B and C shares owned by Richard Kinder, the sponsor investors, the original shareholders, and other management were referred to as “investor retained stock,” and were convertible into a fixed number of Class P shares.  In the aggregate, our investor retained stock was entitled to receive a dividend per share on a fully-converted basis equal to the dividend per share on our common stock.  The conversion of shares of investor retained stock into Class P shares did not increase our total fully-converted shares outstanding, impact the aggregate dividends we paid or the dividends we paid per share on our Class P common stock.
	(c)	For the diluted earnings per share calculation, total net income attributable to each class of common stock was divided by the adjusted weighted-average shares outstanding during the period, including all potential common stock equivalents.

Acquisitions_Tables

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Schedule of Business Acquisitions, by Acquisition [Table Text Block]
				Assignment of Purchase Price
	Ref.	Date	Acquisition	Purchase			Current		Property		Deferred		Goodwill		Long-term debt			Other liabilities			Non-controlling interest			Previously held equity interest
				price			assets		plant &		charges
									equipment		& other
	-1	14-Nov	Pennsylvania and Florida Jones Act Tankers	$	270		$	—	$	270	$	8	$	25	$	—		$	(33	)	$	—		$	—
	-2	14-Jan	American Petroleum Tankers and State Class Tankers	961			6		951		6		64		—			(66		)	—			—
	-3	13-Jun	Goldsmith-Landreth Field Unit	280			—		298		—		—		—			(18		)	—			—
	-4	13-May	Copano	3,733			218		2,788		1,973		963		(1,252		)	(236		)	(17		)	(704		)
	-5	12-May	EP	22,928			7,175		12,921		5,718		18,562		(13,417		)	(4,234		)	(3,797		)	—
Business Acquisition, Pro Forma Information [Table Text Block]	The following summarized unaudited pro forma consolidated income statement information for the years ended December 31, 2014 and 2013, assumes that the Crowley, APT, Copano and the Goldsmith Landreth field unit acquisitions had occurred as of January 1, 2013. We prepared the following summarized unaudited pro forma financial results for comparative purposes only. The summarized unaudited pro forma financial results may not be indicative of the results that would have occurred if these acquisitions had been completed as of January 1, 2013 or the results that will be attained in the future. Amounts presented below are in millions, except for the per share amounts:
			Pro Forma
			Year Ended December 31,
			2014			2013
			(Unaudited)
	Revenues		$	16,260		$	14,911
	Income from continuing operations		2,448			2,665
	Income from discontinued operations, net of tax		—			(4		)
	Net income		2,448			2,661
	Net income attributable to noncontrolling interests		(1,419		)	(1,490		)
	Net income attributable to Kinder Morgan, Inc.		1,029			1,171
	Diluted earnings per common share
	Class P shares		$	0.9		$	1.12
KMP’s FTC Natural Gas Pipelines [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	Summarized financial information for the FTC Natural Gas Pipelines disposal group is as follows (in millions):
		Year Ended
		December 31, 2012(a)
	Operating revenues	$	227
	Operating expenses	(131		)
	Depreciation and amortization	(7		)
	Other expense	(1		)
	Earnings from equity investments	70
	Interest income and Other, net	2
	Income from operations of the FTC Natural Gas Pipelines disposal group	$	160
	_______
	(a)	2012 amounts represent financial information for the ten month period ended October 31, 2012. We sold the FTC Natural Gas Pipelines disposal group effective November 1, 2012.

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Operating Loss Carryforwards [Line Items]
Schedule of Unrecognized Tax Benefits Roll Forward [Table Text Block]	A reconciliation of our gross unrecognized tax benefit excluding interest and penalties is as follows (in millions):
		Year Ended December 31,
		2014			2013				2012
	Balance at beginning of period	$	209		$	269			$	57
	Uncertain tax positions of EP	—			4				289
	Subtotal	209			273				346
	Additions based on current year tax positions	12			11				11
	Additions based on prior year tax positions	—			26				1
	Reductions based on prior year tax positions	(3		)	—				—
	Reductions based on settlements with taxing authority	(24		)	(86		)		(55		)
	Reductions due to lapse in statute of limitations	(5		)	(15		)		(34		)
	Balance at end of period	$	189		$	209			$	269
Schedule of Income before Income Tax, Domestic and Foreign [Table Text Block]	The components of “Income from Continuing Operations Before Income Taxes” are as follows (in millions):
		Year Ended December 31,
		2014			2013				2012
	U.S.	$	2,941		$	3,107			$	1,246
	Foreign	150			331				97
	Total Income from Continuing Operations Before Income Taxes	$	3,091		$	3,438			$	1,343
Schedule of Components of Income Tax Expense (Benefit)	Components of the income tax provision applicable to continuing operations for federal, foreign and state taxes are as follows (in millions):
		Year Ended December 31,
		2014			2013				2012
	Current tax expense
	Federal	$	(16	)	$	57			$	48
	State	36			36				34
	Foreign	13			9				10
	Total	33			102				92
	Deferred tax expense
	Federal	572			612				49
	State	14			—				4
	Foreign	29			28				(6		)
	Total	615			640				47
	Total tax provision	$	648		$	742			$	139
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	The difference between the statutory federal income tax rate and our effective income tax rate is summarized as follows (in millions, except percentages):
		Year Ended December 31,
		2014						2013						2012
	Federal income tax	$	1,082		35	%		$	1,203			35	%	$	470		35	%
	Increase (decrease) as a result of:
	State deferred tax rate change	—			—	%		(21		)		(0.6	)%	20			1.5	%
	Taxes on foreign earnings	40			1.3	%		112				3.3	%	(6		)	(0.5	)%
	Net effects of consolidating KMP’s and EPB’s U.S. income tax provision	(433		)	(14.0	)%		(488		)		(14.2	)%	(288		)	(21.5	)%
	State income tax, net of federal benefit	37			1.2	%		45				1.3	%	21			1.6	%
	Dividend received deduction	(50		)	(1.6	)%		(54		)		(1.6	)%	(32		)	(2.4	)%
	Adjustments to uncertain tax positions	(5		)	(0.2	)%		(87		)		(2.5	)%	(72		)	(5.3	)%
	Valuation allowance on Investment in NGPL	61			2	%		—				—	%	—			—	%
	Disposition of certain international holdings	(112		)	(3.6	)%		—				—	%	—			—	%
	Other	28			0.9	%		32				0.9	%	26			1.9	%
	Total	$	648		21	%		$	742			21.6	%	$	139		10.3	%
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	Deferred tax assets and liabilities result from the following (in millions):
		December 31,
		2014			2013
	Deferred tax assets
	Employee benefits	$	329		$	238
	Accrued expenses	123			136
	Net operating loss, capital loss, tax credit carryforwards	778			673
	Derivative instruments and interest rate and currency swaps	43			68
	Debt fair value adjustment	102			112
	Investments	4,858			—
	Other	31			43
	Valuation allowances	(154		)	(95		)
	Total deferred tax assets	6,110			1,175
	Deferred tax liabilities
	Property, plant and equipment	373			351
	Investments	—			4,888
	Other	30			20
	Total deferred tax liabilities	403			5,259
	Net deferred tax assets (liabilities)	$	5,707		$	(4,084	)
	Current deferred tax asset	$	56		$	567
	Non-current deferred tax assets (liabilities)	5,651			(4,651		)
	Net deferred tax assets (liabilities)	$	5,707		$	(4,084	)
	_______
	Deferred Tax Assets and Valuation Allowances: As a result of the Merger Transactions, we acquired directly or indirectly all of the equity interests of KMP, KMR and EPB that we and our subsidiaries did not already own. In exchange for their interests in KMP and EPB, we paid stock and cash with a fair market value of approximately $64 billion to the limited partner unit holders. This represents a taxable exchange for which we received a step-up in tax basis in the underlying assets acquired (our investment in KMP and EPB). A deferred tax asset of approximately $10.3 billion related to the book tax basis difference in this investment has been recorded, computed as $64 billion tax basis in excess of $36 billion book basis at our statutory tax rate of 36.48%.
	In accordance with ASC 810-10-45-23, if changes in a parent’s ownership interest do not result in a change in its controlling financial interest in its subsidiary, those changes should be accounted for as equity transactions. No gain or loss is recognized in consolidated net income or comprehensive income. The carrying amount of the noncontrolling interest is adjusted to reflect the change in ownership interest in the subsidiary. Any difference between the fair value of the consideration received or paid and the amount by which the noncontrolling interest is adjusted is recognized in equity attributable to the parent. Therefore, because the transaction conforms to the conditions set forth in ASC 810-10-45-23, we have concluded that the increase in the deferred tax assets should be recorded with the offset to equity rather than the income statement.
	The step-up in tax basis results in a deferred tax asset of approximately $4.9 billion primarily related to our investment in KMP and EPB. As book earnings from our investment in KMP and EPB are projected to exceed taxable income (primarily as a result of the partnership’s tax depreciation in excess of book depreciation), the deferred tax asset related to our investment in KMP and EPB is expected to be fully realized.
	We recorded a full valuation allowance of $61 million against the deferred tax asset related to our investment in NGPL as we no longer have viable means by which we reasonably expect to recover this asset.
	We have deferred tax assets of $466 million related to net operating loss carryovers, $312 million related to alternative minimum and foreign tax credits, and $93 million of valuation allowances related to deferred tax assets at December 31, 2014. As of December 31, 2013, we had deferred tax assets of $354 million related to net operating loss carryovers, $11 million related to capital loss carryovers, $308 million related to alternative minimum and foreign tax credits, and valuation allowances related to deferred tax assets of $95 million. We expect to generate taxable income beginning in 2016 and utilize all federal net operating loss carryforwards and alternative minimum tax carryforwards by the end of 2018.
	Expiration Periods for Deferred Tax Assets: As of December 31, 2014, we have U.S. federal net operating loss carryforwards of $906 million, which will expire from 2018 - 2034; state losses of $1.9 billion which will expire from 2014 - 2034; and foreign losses of $213 million, of which approximately $124 million carries over indefinitely and $89 million expires from 2028 - 2035. We also have $300 million of federal alternative minimum tax credits which do not expire; and approximately $11 million of foreign tax credits, the majority of which will expire from 2016 - 2024. Use of our U.S. federal carryforwards is subject to the limitations provided under Sections 382 and 383 of the Internal Revenue Code as well as the separate return limitation rules of Internal Revenue Service regulations.
	Unrecognized Tax Benefits: We recognize the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities, based not only on the technical merits of the tax position based on tax law, but also the past administrative practices and precedents of the taxing authority.  The tax benefits recognized in the financial statements from such a position are measured based on the largest benefit that has a greater than 50% likelihood of being realized upon ultimate resolution.

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment [Table Text Block]	As of December 31, 2014 and 2013, our property, plant and equipment consisted of the following (in millions):
		December 31,
		2014			2013
	Natural gas, liquids, crude oil and CO2 pipelines	$	18,119		$	17,399
	Natural gas, liquids, CO2, and terminals station equipment	21,233			17,960
	Natural gas, liquids (including linefill), and transmix processing	520			259
	Other	3,964			3,656
	Accumulated depreciation, depletion and amortization	(8,369		)	(6,757		)
		35,467			32,517
	Land and land rights-of-way	1,324			1,158
	Construction work in process	1,773			2,172
	Property, plant and equipment, net	$	38,564		$	35,847

Investments_Tables

Investments (Tables)	12 Months Ended
	Dec. 31, 2014										Dec. 31, 2013
Investments [Abstract]
Schedule of earnings from equity investments [Table Text Block]	Our earnings (losses) from equity investments were as follows (in millions):
		Year Ended December 31,
		2014			2013			2012
	Citrus Corporation(a)	$	97		$	84		$	53
	Fayetteville Express Pipeline LLC	55			55			55
	Gulf LNG Holdings Group, LLC(a)	48			47			22
	Midcontinent Express Pipeline LLC	45			40			42
	Red Cedar Gathering Company	33			31			32
	Plantation Pipe Line Company	29			35			32
	Cortez Pipeline Company	25			24			25
	Fort Union Gas Gathering L.L.C.(b)	16			11			—
	Ruby Pipeline Holding Company, L.L.C.(a)	15			(6		)	(5		)
	Watco Companies, LLC	13			13			13
	Parkway Pipeline LLC	8			1			—
	Sierrita Pipeline LLC	3			—			—
	NGPL Holdco LLC(c)	—			(66		)	(198		)
	Double Eagle Pipeline LLC(b)	(1		)	1			—
	EagleHawk	(7		)	9			11
	All others	27			48			71
	Total	$	406		$	327		$	153
	Amortization of excess costs	$	(45	)	$	(39	)	$	(23	)
	_______
	(a)	2012 amounts are for the period from May 25, 2012 through December 31, 2012.
	(b)	2013 amounts are for the period from May 1, 2013 through December 31, 2013.
	(c)	2013 and 2012 amounts include non-cash investment impairment charges, which we recorded in the amount of $65 million and $200 million (pre-tax), respectively.
Schedule of Equity Method Investments [Table Text Block]	Our investments primarily consist of equity investments where we hold significant influence over investee actions and which we account for under the equity method of accounting. As of December 31, 2014 and 2013 our investments consisted of the following (in millions):
		December 31,
		2014			2013
	Citrus Corporation	$	1,805		$	1,875
	Ruby Pipeline Holding Company, L.L.C.	1,123			1,153
	Midcontinent Express Pipeline LLC	748			602
	Gulf LNG Holdings Group, LLC	547			578
	EagleHawk	337			272
	Plantation Pipe Line Company	303			307
	Red Cedar Gathering Company	184			176
	Double Eagle Pipeline LLC	150			144
	Parkway Pipeline LLC	144			131
	Fayetteville Express Pipeline LLC	130			144
	Watco Companies, LLC	103			103
	Fort Union Gas Gathering L.L.C.	70			161
	Sierrita Pipeline LLC	63			19
	Cortez Pipeline Company	17			12
	All others	304			266
	Total equity investments	6,028			5,943
	Bond investments	8			8
	Total investments	$	6,036		$	5,951
Summarized financial info of significant equity investment [Table Text Block]											Summarized combined financial information for our significant equity investments (listed or described above) is reported below (in millions; amounts represent 100% of investee financial information):
												Year Ended December 31,
											Income Statement	2014		2013		2012
											Revenues	$	3,829	$	3,615	$	3,681
											Costs and expenses	3,063		2,803		3,194
											Net income (loss)	$	766	$	812	$	487
											_______
												December 31,
											Balance Sheet	2014		2013
											Current assets	$	943	$	950
											Non-current assets	20,630		20,782
											Current liabilities	1,643		1,451
											Non-current liabilities	10,841		11,351
											Partners’/owners’ equity	9,089		8,930

Goodwill_and_Other_Intangibles1

Goodwill and Other Intangibles (Tables)	12 Months Ended
	Dec. 31, 2014
Goodwill [Line Items]
Schedule of Goodwill [Table Text Block]	Changes in the gross amounts of our goodwill and accumulated impairment losses for each of the years ended December 31, 2014 and 2013 are summarized as follows (in millions):
		Natural Gas Pipelines			CO2		Products Pipelines			Terminals			Kinder			Total
													Morgan
													Canada
	Historical Goodwill	$	22,276		$	1,528	$	2,129		$	1,484		$	626		$	28,043
	Accumulated impairment losses	(2,090		)	—		(1,267		)	(677		)	(377		)	(4,411		)
	Balance as of December 31, 2012	20,186			1,528		862			807			249			23,632
	Acquisitions(a)	888			—		—			—			—			888
	Currency translation adjustments	—			—		—			—			(16		)	(16		)
	Balance as of December 31, 2013	21,074			1,528		862			807			233			24,504
	Acquisitions(a)(b)	82			—		—			89			—			171
	Currency translation adjustments	—			—		—			—			(19		)	(19		)
	Impairment	—			—		—			(2		)	—			(2		)
	Balance as of December 31, 2014	$	21,156		$	1,528	$	862		$	894		$	214		$	24,654
	_______
	(a)	2014 and 2013 Natural Gas Pipelines acquisition amounts include $82 million and $881 million, respectively, relating to the May 1, 2013 Copano acquisition as discussed in Note 3. 2013 Natural Gas Pipelines acquisition amount also includes $7 million relating to other EP acquisition assets.
	(b)	2014 Terminals acquisition amount includes $64 million related to the January 17, 2014 APT acquisition and $25 million related to the November 5, 2014 Crowley acquisition.

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments [Table Text Block]	The table amounts exclude all debt fair value adjustments, including debt discounts and premiums (in millions):
		December 31,
		2014				2013
	KMI and Subsidiaries
	Senior term loan facilities, variable rate, due May 24, 2015 and May 6, 2017(a)	$	—			$	1,528
	Senior notes and debentures, 2.00% through 8.25%, due 2014 through 2098(b)(c)(d)	11,438				5,645
	Credit facility due November 26, 2019(e)(f)	850				175
	Commercial paper borrowings(e)(f)	386				—
	KMP
	Senior notes, 2.65% through 9.00%, due 2014 through 2044(b)	17,800				15,600
	Commercial paper borrowings(g)(h)	—				979
	Credit facility due May 1, 2018(g)	—				—
	TGP senior notes, 7.00% through 8.375%, due 2016 through 2037(b)	1,790				1,790
	EPNG senior notes, 5.95% through 8.625%, due 2017 through 2032(b)	1,115				1,115
	Copano senior notes, 7.125% due April 1, 2021(b)	332				332
	EPB
	EPPOC senior notes, 4.10% through 7.50%, due 2015 through 2042(b)(i)	2,860				2,260
	Credit facility due May 27, 2016(g)	—				—
	CIG, senior notes, 5.95% through 6.85%, due 2015 through 2037(b)(j)	475				475
	SLNG senior notes, 9.50% through 9.75%, due 2014 through 2016(b)(k)	—				135
	SNG notes, 4.40% through 8.00%, due 2017 through 2032(b)(l)	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(b)	1,636				1,636
	EPC Building, LLC, promissory note, 3.967%, due 2014 through 2035	453				461
	Preferred securities, 4.75%, due March 31, 2028(d)(m)	280				280
	KMGP, $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock(n)	100				100
	Other miscellaneous debt(o)	303				494
	Total debt – KMI and Subsidiaries	41,029				34,216
	Less: Current portion of debt(p)	2,717				2,306
	Total long-term debt – KMI and Subsidiaries(q)	$	38,312			$	31,910
	_______
	(a)	The senior secured term loan facility, due May 24, 2015, was repaid and replaced in May 2014 with a new unsecured senior term loan facility due May 6, 2017. The unsecured senior term loan facility was repaid in November 2014 (see “—Credit Facilities and Restrictive Covenants” below).
	(b)	Notes provide for the redemption at any time at a price equal to 100% of the principal amount of the notes plus accrued interest to the redemption date plus a make whole premium.
	(c)	Includes $6.0 billion of senior notes issued on November 26, 2014 as a result of the Merger Transactions (see “—Debt Issuances and Repayments” below).
	(d)	On June 30, 2014, El Paso Issuing Corporation, a wholly-owned subsidiary of El Paso Holdco LLC and the corporate co-issuer under certain guaranteed notes, merged with and into El Paso Holdco LLC, a wholly-owned subsidiary of KMI, and immediately thereafter, El Paso Holdco LLC merged with and into KMI pursuant to an internal restructuring transaction. KMI succeeded El Paso Holdco LLC as issuer with respect to these debt obligations. Consequently, El Paso Holdco LLC ceased to be an obligor with respect to approximately $3.6 billion of outstanding senior notes.
	(e)	As of December 31, 2014 and 2013, the weighted average interest rates on our credit facility borrowings, including commercial paper borrowings in 2014, were 1.54% and 2.67%, respectively.
	(f)	On November 26, 2014, we entered into a $4 billion replacement credit facility and a commercial paper program of up to $4 billion of unsecured notes (see “—Credit Facilities and Restrictive Covenants” below).
	(g)	On November 26, 2014, in conjunction with the Merger Transactions, KMP’s and EPB’s credit facility and KMP’s commercial paper program were terminated.
	(h)	As of December 31, 2013, the average interest rate on KMP’s outstanding commercial paper borrowings was 0.28%. The borrowings under KMP’s commercial paper program were used principally to finance the acquisitions and capital expansions it made during 2014 and 2013.
	(i)	EPPOC’s operating assets are its investments in WIC, CIG, SLNG, Elba Express, SNG, SLC, CPG, EP Ruby, LLC, Southern Gulf LNG Company, L.L.C. and CIG Gas Storage Company LLC. There are no significant restrictions on EPPOC’s ability to access the net assets or cash flows related to its controlling interests in the operating companies either through dividend or loan. The restrictive covenants under these debt obligations are no more restrictive than the restrictive covenants under our credit facility. (See also “—Debt Issuances and Repayments” below.)
	(j)	CIG is subject to a number of restrictions and covenants under its debt obligation. The most restrictive of these include limitations on the incurrence of liens and limitations on sale-leaseback transactions.
	(k)	The SLNG senior notes were repaid on November 26, 2014.
	(l)	Under its indentures, SNG is subject to a number of restrictions and covenants. The most restrictive of these include limitations on the incurrence of liens. Southern Natural Issuing Corporation (SNIC) is a wholly owned finance subsidiary of SNG and is the co-issuer of certain of SNG’s outstanding debt securities. SNIC has no material assets, operations, revenues or cash flows other than those related to its service as a co-issuer of the debt securities. Accordingly, it has no ability to service obligations on the debt securities.
	(m)	Capital Trust I (Trust I), is a 100%-owned business trust that as of December 31, 2014, had $5.6 million of 4.75% trust convertible preferred securities outstanding (referred to as the EP Trust I Preferred Securities). Trust I exists for the sole purpose of issuing preferred securities and investing the proceeds in 4.75% convertible subordinated debentures, which are due 2028. Trust I’s sole source of income is interest earned on these debentures. This interest income is used to pay distributions on the preferred securities. We provide a full and unconditional guarantee of the EP Trust I Preferred Securities. There are no significant restrictions from these securities on our ability to obtain funds from our subsidiaries by distribution, dividend or loan. The EP Trust I Preferred Securities are non-voting (except in limited circumstances), pay quarterly distributions at an annual rate of 4.75%, carry a liquidation value of $50 per security plus accrued and unpaid distributions and are convertible at any time prior to the close of business on March 31, 2028, at the option of the holder, into the following mixed consideration: (i) 0.7197 of a share of our Class P common stock; (ii) $25.18 in cash without interest; and (iii) 1.100 warrants to purchase a share of our Class P common stock. We have the right to redeem these Trust I Preferred Securities at any time. Because of the substantive conversion rights of the securities into the mixed consideration, we bifurcated the fair value of the EP Trust I Preferred Securities into debt and equity components and as of December 31, 2014, the outstanding balance of $280 million (of which $141 million is classified as current) was bifurcated between debt ($248 million) and equity ($32 million). During the years ended December 31, 2014 and 2013, 3,923 and 107,618 EP Trust I Preferred Securities had been converted into (i) 2,820 and 77,442 shares of our Class P common stock; (ii) approximately $99,000 and $3 million in cash; and (iii) 4,315 and 118,377 in warrants, respectively.
	(n)	As of December 31, 2014, KMGP had outstanding 100,000 shares of its $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock due 2057.  Since August 18, 2012, dividends on the preferred stock accumulate at a floating rate of the 3-month LIBOR plus 3.8975% and are payable quarterly in arrears, when and if declared by KMGP’s board of directors, on February 18, May 18, August 18 and November 18 of each year, beginning November 18, 2012.  The preferred stock has approval rights over a commencement of or filing of voluntary bankruptcy by KMP or its SFPP or Calnev subsidiaries (see “—KMGP Preferred Shares” below).
	(o)	In conjunction with the construction of the Totem Gas Storage facility (Totem) and the High Plains pipeline (High Plains), CIG’s joint venture partner in WYCO funded 50% of the construction costs. EPB reflected the payments made by their joint venture partner as other long-term liabilities on the balance sheet during construction and upon project completion, the advances were converted into a financing obligation to WYCO. Upon placing these projects in service, EPB transferred its title in the projects to WYCO and leased the assets back. Although EPB transferred the title in these projects to WYCO, the transfer did not qualify for sale leaseback accounting because of EPB’s continuing involvement through its equity investment in WYCO. As such, the costs of the facilities remain on our balance sheets and the advanced payments received from EPB’s 50% joint venture partner were converted into a financing obligation due to WYCO. As of December 31, 2014, the principal amounts of the Totem and High Plains financing obligations were $73 million and $100 million, respectively, which will be paid in monthly installments through 2039 based on the initial lease term. At the expiration of the initial lease term, the lease agreement shall be extended automatically for the term of related firm service agreements. The interest rate on these obligations is 15.5%, payable on a monthly basis.
	(p)	Includes commercial paper borrowings.
	(q)	Excludes debt fair value adjustments. As of December 31, 2014 and December 31, 2013, our total “Debt fair value adjustments” increased our combined debt carrying amounts by $1,934 million and $1,977 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. For further information about our debt fair value adjustments, see Note 13.
Schedule of Significant Long-Term Debt Issuances and Payments [Table Text Block]	Apart from the assumption of the Copano debt discussed above, following are significant long-term debt issuances and repayments made during 2014 and 2013:
			2014		2013
	Issuances		$650 million senior term loan facility due 2017		$750 million 5.00% notes due 2021
			$500 million 2.00% notes due 2017(b)		$750 million 5.625% notes due 2023
			$1,500 million 3.05% notes due 2019(b)		$251 million EPC Building, LLC 3.967% promissory notes(a)
			$1,500 million 4.30% notes due 2025(b)		$600 million 3.50% notes due 2023
			$750 million 5.30% notes due 2034(b)		$700 million 5.00% notes due 2043
			$1,750 million 5.55% notes due 2045(b)		$800 million 2.65% notes due 2019
			$750 million 3.50% notes due 2021		$650 million 4.15% notes due 2024
			$750 million 5.50% notes due 2044
			$650 million 4.25% notes due 2024
			$550 million 5.40% notes due 2044
			$600 million 4.30% notes due 2024
	Repayments		$500 million 5.125% notes due 2014		$500 million 5.00% notes due 2013
			$1,528 million senior term loan facility due 2015		$1,186 million senior term loan facility due 2015
			$650 million senior term loan facility due 2017(b)		$88 million 8.00% notes due 2013
			$207 million 6.875% notes due 2014		$249 million 7.75% notes due 2018(c)
					$178 million portion of 7.125% notes due 2021(d)
	________
	(a)	In December 2012, our subsidiary, EPC Building, LLC had issued $468 million of 3.967% amortizing promissory notes with payments due 2013 through 2035, of which $217 million was issued to third parties and the remaining $251 million was held by KMI until they were sold to third parties in April of 2013.
	(b) Debt issued or repaid associated with the Merger Transactions.
	(c) KMP paid $259 million (based on a price of 103.875% of the principal amount) to fully redeem and retire the 7.75% series of senior notes in accordance with the terms and conditions of the indenture governing the notes.
Schedule of preferred share distributions [Table Text Block]	The following table provides information about KMGP’s distributions on 100,000 shares of its Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock:
			Year Ended December 31,
			2014				2013
	Per share cash distribution declared for the period(a)		$	41.86			$	42.101
	Per share cash distribution paid in the period		$	41.877			$	42.169
	_______
	(a)	On January 21, 2015, KMGP declared a distribution for the three months ended December 31, 2014, of $10.553 per share, which was paid on February 18, 2015 to shareholders of record as of February 2, 2015.
Schedule of Maturities of Long-term Debt [Table Text Block]	The scheduled maturities of the outstanding debt balances, excluding debt fair value adjustments as of December 31, 2014, are summarized as follows (in millions):
	Year		Total
	2015		$	2,717
	2016		1,684
	2017		3,059
	2018		2,328
	2019		2,819
	Thereafter		28,422
	Total		$	41,029

Sharebased_Compensation_and_Em1

Share-based Compensation and Employee Benefits Share-based Compensation and Employee Benefits (Tables)	12 Months Ended
	Dec. 31, 2014
Share-based Compensation [Abstract]
Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]	The following table sets forth a summary of activity and related balances of our restricted stock excluding that issued to non-employee directors (in millions, except share amounts):
		Year Ended							Year Ended							Year Ended
		December 31, 2014							December 31, 2013							December 31, 2012
		Shares			Weighted Average				Shares			Weighted Average				Shares			Weighted Average
					Grant Date							Grant Date							Grant Date
					Fair Value							Fair Value							Fair Value
	Outstanding at beginning of period	6,382,885			$	239			2,154,022			$	69			1,163,090			$	33
	Granted	1,694,668			61				4,563,495			181				1,463,388			51
	Vested	(460,032	)		(14		)		(83,444	)		(3		)		(102,033	)		(3		)
	Forfeited	(244,227	)		(9		)		(251,188	)		(8		)		(370,423	)		(12		)
	Outstanding at end of period	7,373,294			$	277			6,382,885			$	239			2,154,022			$	69
	Intrinsic value of restricted stock vested during the period				$	17						$	3						$	4
Schedule of Share-based Compensation Arrangement by Share-based Payment Award, Restricted Stock Units, Vested and Expected to Vest [Table Text Block]
	Year		Vesting of Restricted Shares
	2015		713,675
	2016		1,337,884
	2017		1,653,507
	2018		1,111,830
	2019		1,720,568
	2020		580,759
	2021		199,725
	2023		55,346
	Total Outstanding		7,373,294
Schedule of Defined Benefit Plans Disclosures [Table Text Block]	Benefit Obligation, Plan Assets and Funded Status. The following table provides information about our pension and OPEB plans as of and for each of the years ended December 31, 2014 and 2013 (in millions):
		Pension Benefits								OPEB
		2014				2013				2014				2013
	Change in benefit obligation:
	Benefit obligation at beginning of period	$	2,563			$	2,792			$	631			$	720
	Service cost	21				25				—				—
	Interest cost	112				92				25				23
	Actuarial loss (gain)	294				(132		)		15				(38		)
	Benefits paid	(186		)		(239		)		(52		)		(54		)
	Participant contributions	—				—				3				11
	Medicare Part D subsidy receipts	—				—				2				6
	Plan amendments	—				25				—				(37		)
	Benefit obligation at end of period	2,804				2,563				624				631
	Change in plan assets:
	Fair value of plan assets at beginning of period	2,333				2,240				380				341
	Actual return on plan assets	180				254				32				40
	Employer contributions	50				78				26				42
	Participant contributions	—				—				3				11
	Benefits paid	(186		)		(239		)		(52		)		(54		)
	Fair value of plan assets at end of period	2,377				2,333				389				380
	Funded status - net liability at December 31,	$	(427	)		$	(230	)		$	(235	)		$	(251	)
	_______
Schedule of Net Funded Status [Table Text Block]	Components of Funded Status. The following table details the amounts recognized in our balance sheet at December 31, 2014 and 2013 related to our pension and OPEB plans (in millions):
		Pension Benefits								OPEB
		2014				2013				2014				2013
	Non-current benefit asset	$	—			$	—			$	173			$	224
	Current benefit liability	—				—				(22		)		(32		)
	Non-current benefit liability	(427		)		(230		)		(386		)		(443		)
	Funded status - net liability at December 31,	$	(427	)		$	(230	)		$	(235	)		$	(251	)
Schedule of Defined Benefit Plan Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block]	Components of Accumulated Other Comprehensive Income (Loss). The following table details the amounts of pre-tax accumulated other comprehensive income (loss) at December 31, 2014 and 2013 related to our pension and OPEB plans which are included on our accompanying consolidated balance sheets, including the portion attributable to our noncontrolling interests, (in millions):
		Pension Benefits								OPEB
		2014				2013				2014				2013
	Unrecognized net actuarial loss	$	(296	)		$	(10	)		$	(27	)		$	(17	)
	Unrecognized prior service (cost) credit	(4		)		(5		)		20				21
	Accumulated other comprehensive (loss) income	$	(300	)		$	(15	)		$	(7	)		$	4
Fair value of Pension and OPEB assets by level of assets [Table Text Block]	Listed below are the fair values of our pension and OPEB plans’ assets that are recorded at fair value classified in each level at December 31, 2014 and 2013 (in millions):
		Pension Assets
		2014																2013
		Level 1				Level 2				Level 3				Total				Level 1				Level 2				Level 3		Total
	Cash and money market funds	$	5			$	91			$	—			$	96			$	—			$	20			$	—	$	20
	Common/collective trusts(a)	—				863				—				863				—				920				—		920
	Insurance contracts	—				—				15				15				—				—				15		15
	Mutual funds(b)	71				198				—				269				92				134				—		226
	Common and preferred stocks(c)	459				—				—				459				498				—				—		498
	Corporate bonds	—				247				—				247				—				220				—		220
	U.S. government securities	—				190				—				190				—				120				—		120
	Asset backed securities	—				28				—				28				—				29				—		29
	Limited partnerships	—				—				16				16				—				—				28		28
	Equity trusts	—				199				—				199				—				235				—		235
	Private equity	—				—				10				10				—				—				9		9
	Other	—				(15		)		—				(15		)		—				13				—		13
	Total asset fair value(c)	$	535			$	1,801			$	41			$	2,377			$	590			$	1,691			$	52	$	2,333
	_______
	(a)	For 2014, this category includes common/collective trust funds which are invested in approximately 47% fixed income and 53% equity. For 2013, this category includes common/collective trusts funds which are invested in approximately 36% fixed income, 62% equity and 2% short term securities.
	(b)	For 2014, this category includes mutual funds which are invested in approximately 74% fixed income and 26% equity. For 2013, this category includes mutual funds which are invested in approximately 60% fixed income, 40% equity and other investments.
	(c)	Plan assets include $252 million and $229 million of KMI Class P common stock for 2014 and 2013, respectively.
		OPEB Assets
		2014																2013
		Level 1				Level 2				Level 3				Total				Level 1				Level 2				Level 3		Total
	Cash and money market funds	$	23			$	—			$	—			$	23			$	—			$	—			$	—	$	—
	Domestic equity securities	25				—				—				25				13				—				—		13
	Common/collective trusts(a)	—				71				—				71				—				85				—		85
	Fixed income trusts	—				63				—				63				65				—				—		65
	Limited partnerships	76				79				—				155				92				72				—		164
	Insurance contracts	—				—				49				49				—				—				46		46
	Mutual funds	3				—				—				3				7				—				—		7
	Total asset fair value	$	127			$	213			$	49			$	389			$	177			$	157			$	46	$	380
	_______
	(a)	For 2014, this category includes common/collective trust funds which are invested in approximately 67% equity and 33% fixed income securities. For 2013, this category includes common/collective trust funds which are invested in approximately 70% equity and 30% fixed income securities.
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block]	The following tables present the changes in our pension and OPEB plans’ assets included in Level 3 for the years ended December 31, 2014 and 2013 (in millions):
		Pension Assets
		Balance at Beginning of Period				Transfers In (Out)				Realized and Unrealized Gains (Losses), net				Purchases (Sales), net				Balance at End of Period
	2014
	Insurance contracts	$	15			$	—			$	—			$	—			$	15
	Limited partnerships	28				—				5				(17		)		16
	Private equity	9				—				2				(1		)		10
	Total	$	52			$	—			$	7			$	(18	)		$	41
	2013
	Insurance contracts	$	14			$	—			$	—			$	1			$	15
	Mutual funds	40				—				—				(40		)		—
	Limited partnerships	24				—				3				1				28
	Private equity	9				—				1				(1		)		9
	Total	$	87			$	—			$	4			$	(39	)		$	52
	_______
		OPEB Assets
		Balance at Beginning of Period				Transfers In (Out)				Realized and Unrealized Gains (Losses), net				Purchases (Sales), net				Balance at End of Period
	2014
	Insurance contracts	$	46			$	—			$	(3	)		$	6			$	49
	Total	$	46			$	—			$	(3	)		$	6			$	49
	2013
	Insurance contracts	$	44			$	—			$	—			$	2			$	46
	Total	$	44			$	—			$	—			$	2			$	46
Schedule of Expected Benefit Payments [Table Text Block]	Expected Payment of Future Benefits and Employer Contributions. As of December 31, 2014, we expect to make the following benefit payments under our plans (in millions):
	Fiscal year		Pension Benefits				OPEB(a)
	2015		$	190			$	46
	2016		193				46
	2017		193				45
	2018		195				45
	2019		195				44
	2020-2024		965				209
	_______
	(a)	Includes a reduction of approximately $2 million in each of the years 2015 - 2019 and approximately $12 million in aggregate for 2020 - 2024 for an expected subsidy related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003.
Schedule or Description of Weighted Average Discount Rate [Table Text Block]	Actuarial Assumptions and Sensitivity Analysis. Benefit obligations and net benefit cost are based on actuarial estimates and assumptions. The following table details the weighted-average actuarial assumptions used in determining our benefit obligation and net benefit costs of our pension and OPEB plans for 2014, 2013 and 2012:
			Pension Benefits									OPEB
			2014			2013			2012			2014			2013			2012
	Assumptions related to benefit obligations:
	Discount rate		3.66	%		4.45	%		3.4	%		3.56	%		4.34	%		3.34	%
	Rate of compensation increase		4.5	%		3.5	%		3	%		n/a			n/a			n/a
	Assumptions related to benefit costs:
	Discount rate(a)		4.45	%		3.4	%		4.22	%		4.34	%		3.62	%		4.11	%
	Expected return on plan assets(b)(c)		7.5	%		8	%		8.44	%		7.43	%		7.35	%		8.21	%
	Rate of compensation increase		3.5	%		3	%		3.5	%		n/a			n/a			n/a
	_______
	(a)	The discount rate related to pension benefit cost was 4.50% for the period from January 1, 2012 to May 24, 2012, and 4.03% for the period from May 25, 2012 to December 31, 2012 (the period subsequent to the EP acquisition). The discount rate related to other postretirement benefit cost was 3.34% for the period from January 1, 2013 to July 31, 2013 (the period prior to an OPEB plan amendment that resulted in a remeasurement) and 4.00% for the period from August 1, 2013 to December 31, 2013, and 4.25% for the period from January 1, 2012 to May 24, 2012 and 4.01% for the period from May 25, 2012 to December 31, 2012.
	(b)	The expected return on plan assets related to pension cost was 8.90% for the period from January 1, 2012 to May 24, 2012, and 8.11% for the period from May 25, 2012 to December 31, 2012 (the period subsequent to the EP acquisition). The expected return on plan assets related to other postretirement benefit cost was 8.90% for the period from January 1, 2012 to May 24, 2012, and 7.72% for the period from May 25, 2012 to December 31, 2012.
	(c)	The expected return on plan assets listed in the table above is a pre-tax rate of return based on our targeted portfolio of investments. For the assumed EP OPEB plans, we utilize an after-tax expected return on plan assets to determine our benefit costs, which is based on unrelated business income taxes at a rate of 21% and 24% for 2014 and 2013, respectively.
Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates [Table Text Block]	Actuarial estimates for our OPEB plans assumed a weighted-average annual rate of increase in the per capita cost of covered health care benefits of 7.00%, gradually decreasing to 4.50% by the year 2031. Assumed health care cost trends have a significant effect on the amounts reported for OPEB plans. A one-percentage point change in assumed health care cost trends would have the following effects as of December 31, 2014 and 2013 (in millions):
			2014				2013
	One-percentage point increase:
	Aggregate of service cost and interest cost		$	2			$	2
	Accumulated postretirement benefit obligation		47				45
	One-percentage point decrease:
	Aggregate of service cost and interest cost		$	(2	)		$	(1	)
	Accumulated postretirement benefit obligation		(40		)		(39		)
Schedule of Net Benefit Costs [Table Text Block]	Components of Net Benefit Cost and Other Amounts Recognized in Other Comprehensive Income. For each of the years ended December 31, the components of net benefit cost and other amounts (including amounts associated with the EP Pension and OPEB plans since the May 25, 2012 acquisition date) recognized in pre-tax other comprehensive income related to our pension and OPEB plans are as follows (in millions):
			Pension Benefits												OPEB
			2014				2013				2012				2014				2013				2012
	Components of net benefit cost:
	Service cost		$	21			$	25			$	18			$	—			$	—			$	—
	Interest cost		112				92				67				25				23				18
	Expected return on assets		(171		)		(175		)		(110		)		(24		)		(22		)		(15		)
	Amortization of prior service (credit) cost		—				—				(1		)		(2		)		(1		)		(1		)
	Amortization of net actuarial loss (gain)		—				—				10				(1		)		3				4
	Curtailment and settlement gain		—				(3		)		(2		)		—				—				(1		)
	Net benefit (credit) cost		(38		)		(61		)		(18		)		(2		)		3				5
	Other changes in plan assets and benefit obligations recognized in other comprehensive (income) loss:
	Net (gain) loss arising during period		285				(211		)		85				10				(50		)		25
	Prior service cost (credit) arising during period		—				25				(17		)		—				(18		)		(4		)
	Amortization or settlement recognition of net actuarial gain (loss)		—				3				(10		)		—				(3		)		(5		)
	Amortization of prior service credit		—				—				1				1				1				1
	Total recognized in total other comprehensive income loss		285				(183		)		59				11				(70		)		17
	Total recognized in net benefit (credit) cost and other comprehensive (income) loss		$	247			$	(244	)		$	41			$	9			$	(67	)		$	22

Stockholders_Equity_Tables

Stockholders Equity (Tables)	12 Months Ended
	Dec. 31, 2014
Stockholders' Equity Note [Abstract]
Schedule of Common Stock Outstanding Roll Forward	The following table sets forth the changes in our outstanding shares:
		Class P			Class A			Class B			Class C
	Balance at December 31, 2011	170,921,140			535,972,387			94,132,596			2,318,258
	Shares issued for EP acquisition (see Note 3)	330,154,610			—			—			—
	Shares issued with conversions of EP Trust I Preferred securities	562,521			—			—			—
	Shares converted	535,972,387			(535,972,387	)		(94,132,596	)		(2,318,258	)
	Shares canceled	(2,049,615	)		—			—			—
	Restricted shares vested	107,553			—			—			—
	Balance at December 31, 2012	1,035,668,596			—			—			—
	Shares issued for EP acquisition(a)	53
	Shares repurchased and canceled	(5,175,055	)
	Shares issued with conversions of EP Trust I Preferred securities	77,442
	Shares issued for exercised warrants	16,886
	Restricted shares vested	89,154
	Balance at December 31, 2013	1,030,677,076
	Shares issued for Merger Transactions	1,096,910,451
	Shares repurchased and canceled	(2,780,337	)
	Shares issued with conversions of EP Trust I Preferred securities	2,820
	Shares issued for exercised warrants	12,402
	Restricted shares vested	324,704
	Balance at December 31, 2014	2,125,147,116
	_______
	(a) Represents Class P shares issued upon the settlement of an EP dissenter. The settlement of the dissenter’s 128 EP shares was determined based on the same conversion of EP shares into cash, KMI Class P shares and KMI warrants that was received by other EP shareholders at the time of the acquisition.
Schedule of Dividends Payable [Table Text Block]	The following table provides information about our per share dividends:
		Year Ended December 31,
		2014				2013				2012
	Per common share cash dividend declared for the period	$	1.74			$	1.6			$	1.4
	Per common share cash dividend paid in the period	1.7				1.56				1.34
Schedule of Warrants Outstanding Roll Forward [Table Text Block]	The table below sets forth the changes in our outstanding warrants:
		Warrants
		2014			2013			2012
	Beginning balance	347,933,107			439,809,442			—
	Warrants issued in EP acquisition(a)	—			81			504,598,883
	Warrants issued with conversions of EP Trust I Preferred securities(b)	4,315			118,377			859,796
	Warrants exercised	(18,040	)		(21,208	)		—
	Warrants repurchased and canceled	(49,783,406	)		(91,973,585	)		(65,649,237	)
	Ending balance	298,135,976			347,933,107			439,809,442
	_______
	(a)	See Note 3. 2013 amount represents warrants issued upon the settlement of an EP dissenter. The settlement of the dissenter’s 128 EP shares was determined based on the same conversion of EP shares into cash, KMI Class P shares and KMI warrants that was received by other EP shareholders at the time of the acquisition.
	(b)	See Note 8.
Schedule of Noncontrolling Interest [Table Text Block]	The caption “Noncontrolling interests” in our accompanying consolidated balance sheets consists of interests that we do not own in the following subsidiaries (in millions):
		December 31,
		2014				2013
	KMP	$	—			$	7,642
	EPB	—				4,122
	KMR	—				3,142
	Other	350				286
		$	350			$	15,192
Schedule of noncontrolling interest contributions text block [Table Text Block]	The table below shows significant issuances to the public of common units or shares, the net proceeds from the issuances and the use of the proceeds during the years ended December 31, 2014 and 2013 by KMP, EPB and KMR (dollars in millions and shares in thousands):
		Issuances		Common units/shares			Net proceeds				Use of proceeds
				(in thousands)			(in millions)
	KMP
	Issued under Equity Distribution Agreement(a)
		2014		5,513			$	441			Reduced borrowings under KMP’s commercial paper program
		2013		10,814			$	900			Reduced borrowings under KMP’s commercial paper program
	Other issuances
		Feb-14		7,935			$	603			Reduced borrowings under KMP’s commercial paper program that were used to fund KMP’s APT acquisition in January 2014
		Feb-13		4,600			$	385			Issued to pay a portion of the purchase price for the March 2013 drop-down transaction
		May-13		43,371			$	—		(b)	Issued to Copano unitholders as KMP’s purchase price for Copano
	EPB
	Issued under Equity Distribution Agreement(c)
		2014		7,314			$	275			General partnership purposes
		2013		2,038			$	85			General partnership purposes
	Other issuances
		May-14		7,820			$	242			Issued to pay a portion of the purchase price for the May 2014 drop-down transaction
	KMR
	Issued under Equity Distribution Agreement(d)
		2014		1,735			$	134			Purchased additional KMP i-units; KMP then used proceeds to reduce borrowings under its commercial paper program
		2013		2,640			$	210			Purchased additional KMP i-units; KMP then used proceeds to reduce borrowings under its commercial paper program
	_______
	(a)	Prior to the completion of the Merger Transactions on November 26, 2014, KMP was a party to two equity distribution agreements with UBS Securities LLC (UBS), one of which allowed the aggregate offering price of KMP’s common units of up to $2.175 billion, and a second separate equity distribution agreement which allowed the aggregate offering price of up to $1.9 billion.
	(b)	KMP valued these units at $3,733 million based on the $86.08 closing market price of a KMP common unit on the NYSE on May 1, 2013.
	(c)	Prior to the completion of the Merger Transactions on November 26, 2014, EPB was a party to an equity distribution agreement with Citigroup. Pursuant to the provisions of EPB’s equity distribution agreement, EPB could sell from time to time through Citigroup, as its sales agent, EPB’s common units representing limited partner interests having an aggregate offering price of up to $500 million.
	(d)	Prior to the completion of the Merger Transactions on November 26, 2014, KMR was a party to an equity distribution agreement with Credit Suisse Securities (U.S.A.) LLC (Credit Suisse). Pursuant to the provisions of KMR’s equity distribution agreement, it could sell from time to time through Credit Suisse, as its sales agent, KMR shares having an aggregate offering price of up to $500 million.
Schedule of Distributions by Noncontrolling Interests [Table Text Block]	The following table provides information about distributions from our noncontrolling interests (in millions except per unit and i-unit distribution amounts):
		Year Ended December 31,
		2014				2013				2012
	KMP(a)
	Per unit cash distribution declared for the period	$	4.17			$	5.33			$	4.98
	Per unit cash distribution paid in the period	$	5.53			$	5.26			$	4.85
	Cash distributions paid in the period to the public	$	1,654			$	1,372			$	1,081
	EPB(a)(b)
	Per unit cash distribution declared for the period	$	1.95			$	2.55			$	1.74
	Per unit cash distribution paid in the period	$	2.6			$	2.51			$	1.13
	Cash distributions paid in the period to the public	$	347			$	318			$	137
	KMR(a)(c)
	Share distributions paid in the period to the public	7,794,183				6,588,477				5,586,579
	_______
	(a)	As a result of the Merger Transactions, no distribution was declared for the fourth quarter of 2014.
	(b)	Represents distribution information since the May 2012 EP acquisition.
	(c)	KMR’s distributions were paid in the form of additional shares or fractions thereof calculated by dividing the KMP cash distribution per common unit by the average of the market closing prices of a KMR share determined for a ten-trading day period ending on the trading day immediately prior to the ex-dividend date for the shares.  Represents share distributions made in the period to noncontrolling interests and excludes 1,127,712, 976,723 and 902,367 of shares distributed in 2014, 2013 and 2012, respectively, on KMR shares we directly and indirectly owned.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Schedule of Related Party Transactions [Table Text Block]	The following table summarizes our balance sheet affiliate balances (in millions):
		December 31,
		2014		2013
	Balance sheet location
	Accounts receivable, net	$	31	$	19
	Other current assets	3		3
	Deferred charges and other assets	46		47
		$	80	$	69
	Current portion of debt(a)	$	6	$	6
	Accounts payable	22		9
	Long-term debt(a)	172		169
		$	200	$	184
	_______
	(a)	Includes financing obligations payable to WYCO (See Note 8).

Commitments_and_Contingent_Lia1

Commitments and Contingent Liabilities (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	The table below depicts future gross minimum rental commitments under our operating leases and rights-of-way obligations as of December 31, 2014 (in millions):
	Year	Commitment
	2015	$	97
	2016	85
	2017	75
	2018	67
	2019	65
	Thereafter	289
	Total minimum payments	$	678
	_______

Risk_Management_Tables

Risk Management (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative [Line Items]
Schedule of Derivative Instruments [Table Text Block]	As of December 31, 2014, 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	(10.9	)	MMBbl
	Crude oil basis	(10.8	)	MMBbl
	Natural gas fixed price	(27.2	)	Bcf
	Natural gas basis	(8.0	)	Bcf
	Derivatives not designated as hedging contracts
	Crude oil fixed price	(14.9	)	MMBbl
	Natural gas fixed price	2		Bcf
	Natural gas basis	6.5		Bcf
	NGL fixed price	(2.1	)	MMBbl
	_______
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table summarizes the fair values of our derivative contracts included on our accompanying consolidated balance sheets (in millions):
	Fair Value of Derivative Contracts
				Asset derivatives								Liability derivatives
				December 31,								December 31,
				2014				2013				2014				2013
		Balance sheet location		Fair value								Fair value
	Derivatives designated as hedging contracts
	Natural gas and crude derivative contracts	Other current assets/(Other current liabilities)		$	309			$	18			$	(34	)		$	(33	)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		6				58				—				(30		)
	Subtotal			315				76				(34		)		(63		)
	Interest rate swap agreements	Other current assets/(Other current liabilities)		143				87				—				—
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		260				172				(53		)		(116		)
	Subtotal			403				259				(53		)		(116		)
	Total			718				335				(87		)		(179		)
	Derivatives not designated as hedging contracts
	Natural gas, crude and NGL derivative contracts	Other current assets/(Other current liabilities)		73				4				(2		)		(5		)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		196				—				—				—
	Subtotal			269				4				(2		)		(5		)
	Power derivative contracts	Other current assets/(Other current liabilities)		10				7				(57		)		(54		)
		Deferred charges and other assets/(Other long-term liabilities and deferred credits)		—				11				(16		)		(73		)
	Subtotal			10				18				(73		)		(127		)
	Total			279				22				(75		)		(132		)
	Total derivatives			$	997			$	357			$	(162	)		$	(311	)
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
					Year Ended December 31,
					2014				2013				2012
	Interest rate swap agreements		Interest expense		$	207			$	(425	)		$	55
	Total				$	207			$	(425	)		$	55
	Fixed rate debt		Interest expense		$	(204	)		$	425			$	(55	)
	Total				$	(204	)		$	425			$	(55	)
	_______
	Derivatives in cash flow hedging relationships		Amount of gain/(loss) recognized in OCI on derivative (effective portion)(a)												Location of gain/(loss) reclassified from Accumulated OCI into income (effective portion)		Amount of gain/(loss) reclassified from Accumulated OCI into income (effective portion)(b)									Location of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)	Amount of gain/(loss) recognized in income on derivative (ineffective portion and amount excluded from effectiveness testing)
			Year Ended														Year Ended										Year Ended
			December 31,														December 31,										December 31,
			2014				2013				2012						2014			2013			2012				2014		2013		2012
	Energy commodity derivative contracts		$	423			$	(45	)		$	87			Revenues—Natural gas sales		$	(1	)	$	—		$	4		Revenues—Natural gas sales	$	—	$	—	$	—
															Revenues—Product sales and other		26			(13		)	(15		)	Revenues—Product sales and other	11		3		(11		)
															Costs of sales		4			—			17			Costs of sales	—		—		—
	Interest rate swap agreements		(15		)		7				(5		)		Interest expense		(4		)	2			2			Interest expense	—		—		—
	Total		$	408			$	(38	)		$	82			Total		$	25		$	(11	)	$	8		Total	$	11	$	3	$	(11	)
	_______
	(a)	We expect to reclassify an approximate $208 million gain associated with energy commodity price risk management activities included in our accumulated other comprehensive loss balance as of December 31, 2014 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
					Year Ended December 31,
					2014				2013				2012
	Energy commodity derivative contracts		Revenues—Natural gas sales		$	(7	)		$	—			$	1
			Revenues—Product sales and other		20				(10		)		(4		)
			Costs of sales		—				2				—
			Other expense (income)		(2		)		(2		)		—
	Total				$	11			$	(10	)		$	(3	)
Schedule of Accumulated Other Comprehensive Income (Loss) [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
		hedge derivatives				adjustments				liability adjustments				income/(loss)
	Balance as of December 31, 2011	$	(20	)		$	37			$	(132	)		$	(115	)
	Other comprehensive income before reclassifications	32				14				(53		)		(7		)
	Amounts reclassified from accumulated other comprehensive loss	(5		)		—				9				4
	Net current-period other comprehensive income	27				14				(44		)		(3		)
	Balance as of December 31, 2012	7				51				(176		)		(118		)
	Other comprehensive income before reclassifications	(14		)		(49		)		151				88
	Amounts reclassified from accumulated other comprehensive loss	4				—				2				6
	Net current-period other comprehensive income	(10		)		(49		)		153				94
	Balance as of December 31, 2013	(3		)		2				(23		)		(24		)
	Other comprehensive income before reclassifications	254				(68		)		(212		)		(26		)
	Amounts reclassified from accumulated other comprehensive loss	(22		)		—				(1		)		(23		)
	Impact of Merger Transactions (See Note 1)	98				(42		)		—				56
	Net current-period other comprehensive income	330				(110		)		(213		)		7
	Balance as of December 31, 2014	$	327			$	(108	)		$	(236	)		$	(17	)

Fair_Value_Tables

Fair Value (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value, by Balance Sheet Grouping	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):
		December 31, 2014						December 31, 2013
		Carrying			Estimated			Carrying			Estimated
		value			fair value			value			fair value
	Total debt	$	42,963		$	43,582		$	36,193		$	36,248
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)
		Year Ended December 31,
		2014			2013
	Derivatives-net asset (liability)
	Beginning of period	$	(110	)	$	(155	)
	Transfers out(a)	(88		)	—
	Total gains or (losses)
	Included in earnings	22			(5		)
	Included in other comprehensive loss	78			(1		)
	Purchases(b)	—			17
	Settlements	37			34
	End of period	$	(61	)	$	(110	)
	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		$	(8	)
	_______
	(a) On December 31, 2014, we transferred WTI options from Level 3 to Level 2 due to increased observability of significant inputs in their valuations.
	(b) 2013 amount represents the purchase of Level 3 energy commodity derivative contracts associated with our May 1, 2013 Copano acquisition.
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 and (ii) interest rate swap agreements, based on the three levels established by the Codification (in millions). Certain of our derivative contracts are subject to master netting agreements.
		Balance sheet asset fair value measurements using												Amounts not offset in the balance sheet
		Level 1			Level 2			Level 3			Gross amount			Financial instruments			Cash collateral held(b)			Net amount
	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
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	4		$	46		$	48		$	98		$	(62	)	$	—		$	36
	Interest rate swap agreements	$	—		$	259		$	—		$	259		$	(28	)	$	—		$	231
	_______
		Balance sheet liability												Amounts not offset in the balance sheet
		fair value measurements using
		Level 1			Level 2			Level 3			Gross amount			Financial instruments			Cash collateral posted(c)			Net amount
	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	)
	As of December 31, 2013
	Energy commodity derivative contracts(a)	$	(6	)	$	(31	)	$	(158	)	$	(195	)	$	62		$	17		$	(116	)
	Interest rate swap agreements	$	—		$	(116	)	$	—		$	(116	)	$	28		$	—		$	(88	)
	_______
	(a)	Level 1 consists primarily of NYMEX natural gas futures.  Level 2 consists primarily of OTC 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.

Reportable_Segments_Tables

Reportable Segments (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Schedule of Revenue from External Customers Attributed to Foreign Countries by Geographic Area [Table Text Block]	Following is geographic information regarding the revenues and long-lived assets of our business segments (in millions):
		Year Ended December 31,
		2014			2013			2012
	Revenues from external customers
	U.S.	$	15,605		$	13,656		$	9,488
	Canada	437			398			407
	Mexico	184			16			78
	Total consolidated revenues from external customers	$	16,226		$	14,070		$	9,973
	_______
		2014			2013			2012
	Long-lived assets at December 31(a)
	U.S.	$	50,141		$	42,080		$	37,651
	Canada	2,268			2,214			2,035
	Mexico	81			81			82
	Total consolidated long-lived assets	$	52,490		$	44,375		$	39,768
	_______
	(a) Long-lived assets exclude goodwill and other intangibles, net.
Schedule of Segment Reporting Information, by Segment	Financial information by segment follows (in millions):
		Year Ended December 31,
		2014			2013			2012
	Revenues
	Natural Gas Pipelines(a)
	Revenues from external customers	$	10,153		$	8,613		$	5,230
	Intersegment revenues	15			4			—
	CO2	1,960			1,857			1,677
	Terminals
	Revenues from external customers	1,717			1,408			1,356
	Intersegment revenues	1			2			3
	Products Pipelines	2,068			1,853			1,370
	Kinder Morgan Canada	291			302			311
	Other	1			1			(6		)
	Total segment revenues	16,206			14,040			9,941
	Other revenues(b)	36			36			35
	Less: Total intersegment revenues	(16		)	(6		)	(3		)
	Total consolidated revenues	$	16,226		$	14,070		$	9,973
		Year Ended December 31,
		2014			2013			2012
	Operating expenses(c)
	Natural Gas Pipelines(a)	$	6,241		$	5,235		$	3,111
	CO2	494			439			381
	Terminals	746			657			685
	Products Pipelines	1,258			1,295			759
	Kinder Morgan Canada	106			110			103
	Other	24			30			5
	Total segment operating expenses	8,869			7,766			5,044
	Other operating expenses	—			—			4
	Less: Total intersegment operating expenses	(16		)	(6		)	(3		)
	Total consolidated operating expenses	$	8,853		$	7,760		$	5,045
		Year Ended December 31,
		2014			2013			2012
	Other expense (income)
	Natural Gas Pipelines(a)	$	5		$	(24	)	$	14
	CO2(d)	243			—			(7		)
	Terminals	29			(74		)	(14		)
	Products Pipelines	(3		)	6			(5		)
	Other	1			(7		)	(1		)
	Total consolidated other expense (income)	$	275		$	(99	)	$	(13	)
		Year Ended December 31,
		2014			2013			2012
	DD&A
	Natural Gas Pipelines(a)	$	897		$	797		$	478
	CO2	570			533			494
	Terminals	337			247			236
	Products Pipelines	166			155			143
	Kinder Morgan Canada	51			54			56
	Other	19			20			12
	Total consolidated DD&A	$	2,040		$	1,806		$	1,419
		Year Ended December 31,
		2014			2013			2012
	Earnings from equity investments
	Natural Gas Pipelines(a)(e)	$	318		$	232		$	52
	CO2	25			24			25
	Terminals	18			22			21
	Products Pipelines	44			45			39
	Kinder Morgan Canada	—			4			5
	Other	1			—			11
	Total consolidated equity earnings	$	406		$	327		$	153
		Year Ended December 31,
		2014			2013			2012
	Amortization of excess cost of equity investments
	Natural Gas Pipelines(a)	$	39		$	32		$	17
CO2	(1		)	2			2
Products Pipelines	7			5			4
Total consolidated amortization of excess cost of equity investments	$	45		$	39		$	23
	Year Ended December 31,
	2014			2013			2012
Interest income
Natural Gas Pipelines	$	1		$	—		$	18
Products Pipelines	2			2			2
Kinder Morgan Canada	—			3			14
Other	6			8			3
Total segment interest income	9			13			37
Unallocated interest income	—			2			(9		)
Total consolidated interest income	$	9		$	15		$	28
	Year Ended December 31,
	2014			2013			2012
Other, net-income (expense)
Natural Gas Pipelines(f)	$	24		$	578		$	4
CO2	—			—			(1		)
Terminals	12			1			2
Products Pipelines	(1		)	1			9
Kinder Morgan Canada(g)	15			246			3
Other	30			9			2
Total consolidated other, net-income (expense)	$	80		$	835		$	19
	Year Ended December 31,
	2014			2013			2012
Income tax benefit (expense)
Natural Gas Pipelines	$	(6	)	$	(9	)	$	(5	)
CO2	(8		)	(7		)	(5		)
Terminals	(29		)	(14		)	(3		)
Products Pipelines	(2		)	2			2
Kinder Morgan Canada	(18		)	(21		)	(1		)
Total segment income tax expense	(63		)	(49		)	(12		)
Unallocated income tax expense	(585		)	(693		)	(127		)
Total consolidated income tax expense	$	(648	)	$	(742	)	$	(139	)
	Year Ended December 31,
	2014			2013			2012
Segment EBDA(h)
Natural Gas Pipelines(a)	$	4,259		$	4,207		$	2,174
CO2	1,240			1,435			1,322
Terminals	944			836			708
Products Pipelines	856			602			668
Kinder Morgan Canada	182			424			229
Other	13			(5		)	7
Total segment EBDA	7,494			7,499			5,108
Total segment DD&A	(2,040		)	(1,806		)	(1,419		)
Total segment amortization of excess cost of equity investments	(45		)	(39		)	(23		)
Other revenues	36			36			35
General and administrative expenses(i)	(610		)	(613		)	(929		)
Interest expense, net of unallocable interest income(j)	(1,807		)	(1,688		)	(1,441		)
Unallocable income tax expense	(585		)	(693		)	(127		)
Loss from discontinued operations, net of tax(k)	—			(4		)	(777		)
Total consolidated net income	$	2,443		$	2,692		$	427
	Year Ended December 31,
	2014			2013			2012
Capital expenditures
Natural Gas Pipelines(a)	$	935		$	1,085		$	499
CO2	792			667			453
Terminals	1,049			1,108			707
Products Pipelines	680			416			307
Kinder Morgan Canada	156			77			16
Other	5			16			40
Total consolidated capital expenditures	$	3,617		$	3,369		$	2,022
	2014			2013
Investments at December 31
Natural Gas Pipelines(a)	5,174			$	5,130
CO2	17			12
Terminals	219			196
Products Pipelines	624			611
Kinder Morgan Canada	1			1
Other	1			1
Total consolidated investments	$	6,036		$	5,951
	2014			2013
Assets at December 31
Natural Gas Pipelines	$	52,523		$	52,357
CO2	5,227			4,708
Terminals	8,850			6,888
Products Pipelines	7,179			6,648
Kinder Morgan Canada	1,593			1,677
Other	459			568
Total segment assets	75,831			72,846
Corporate assets(l)	7,311			2,339
Assets held for sale	56			—
Total consolidated assets	$	83,198		$	75,185
_______
(a)	The Copano acquisition was effective May 1, 2013 and the EP acquisition was effective May 25, 2012 (see Note 3).
(b)	Includes a management fee for services we perform for NGPL Holdco LLC.
(c)	Includes natural gas purchases and other costs of sales, operations and maintenance expenses, and taxes, other than income taxes.
(d)	2014 amount includes an impairment charge of $235 million primarily related to the Katz Strawn unit.
(e)	2013 and 2012 amounts include impairment charges of $65 million and $200 million, respectively, to reduce the carrying value of our equity investment in NGPL Holdco LLC.
(f)	2013 amount includes a $558 million gain from the remeasurement of our previously held 50% equity interest in Eagle Ford to fair value (See Note 3).
(g)	2013 amount includes a $224 million pre-tax gain from the sale of our equity and debt investments in the Express pipeline system (See Note 3).
(h)	Includes revenues, earnings from equity investments, allocable interest income, and other, net, less operating expenses, allocable income taxes, and other expense (income).
(i)	2012 amount includes $366 million of pre-tax expense associated with the EP acquisition and EP Energy sale.
(j)	Includes (i) interest expense and (ii) miscellaneous other income and expenses not allocated to business segments. 2012 amount includes $108 million of expense for capitalized financing fees associated with the EP acquisition financing that were written-off (primarily due to debt repayments) or amortized.
(k)	Represents loss from sale of the FTC Natural Gas Pipelines disposal group and other, net of tax (see Note 3).
(l)	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.

General_Details

General (Details) (USD $)	0 Months Ended	12 Months Ended	11 Months Ended
In Billions, except Share data, unless otherwise specified	Nov. 25, 2014	Dec. 31, 2014	Nov. 25, 2014	Nov. 26, 2014
Entity Information [Line Items]
Enterprise Market Value		$125
Miles Of Pipeline		80,000
Number Of Pipeline Terminals Owned Interest In And Or Operated		180
Other Significant Noncash Transaction, Value of Consideration Given	77
KMP [Member]
Entity Information [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]
Entity Information [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%
KMI members [Member] | KMP and EPB [Member]
Entity Information [Line Items]
Subsidiary or Equity Method Investee, Cumulative Proceeds Received on All Transactions	$3.90
Merger Transactions [Member] | KMI members [Member] | KMR [Member]
Entity Information [Line Items]
Shares, Issued				2.4849
Merger Transactions [Member] | KMI members [Member] | KMP [Member]
Entity Information [Line Items]
Shares, Issued				2.1931
Business Combination Cash Consideration For Transferred Equity Interest				10.77
Merger Transactions [Member] | KMI members [Member] | EPB [Member]
Entity Information [Line Items]
Shares, Issued				0.9451
Business Combination Cash Consideration For Transferred Equity Interest				4.65

Summary_of_Significant_Account3

Summary of Significant Accounting Policies Cash Equivalents and Restricted Deposits (Details) (Other Assets [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Other Assets [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted Cash and Cash Equivalents, Current	$118	$75

Summary_of_Significant_Account4

Summary of Significant Accounting Policies Gas Imbalances (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Gas Balancing Asset (Liability)	$103	$83
Gas Balancing Payable, Current	$36	$34

Summary_of_Significant_Account5

Summary of Significant Accounting Policies Regulatory Assets and Liabilities (Details) (USD $)	12 Months Ended	0 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Sep. 03, 2013	Dec. 31, 2013
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	81		$91
Regulatory Assets, Noncurrent	406		446
Regulatory Assets	487		537
Regulatory Liability, Current	189		135
Regulatory Liability, Noncurrent	290		397
Regulatory Liabilities	479		532
Minimum [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets Recovery Period	1 year
Maximum [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets Recovery Period	42 years
Federal Energy Regulatory Commission [Member] | TGP's Sale of Production Area Facilities [Member] | TGP [Member]
Regulatory Assets and Liabilities [Line Items]
Increase (Decrease) in Other Regulatory Assets		93
Gain (Loss) on Disposition of Oil and Gas and Timber Property		$36

Summary_of_Significant_Account6

Summary of Significant Accounting Policies Earnings per share (Details) (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Class of Warrant or Right, Exercise Price of Warrants or Rights	$40
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	$2,443	$2,696	$1,204
Net income attributable to KMI	1,026	1,193	315
Income (Loss) from Continuing Operations Attributable to Noncontrolling Interest			-696
Income (Loss) from Continuing Operations Attributable to Parent			508
Dividends, Common Stock, Cash	-1,760	-1,622	-1,184
Remaining Undistributed Earnings, Continuing Operations			-676
Undistributed Earnings, Basic			-869
Net Income (Loss) Available to Common Stockholders, Basic	1,026	1,193	315
income (Loss) from Continuing Operations Attributable to Shareholders			508
Class P [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Dividends			601
Net Income (Loss) Available to Common Stockholders And Assumed Conversion			315
Remaining Undistributed Earnings, Continuing Operations			-344
Undistributed Earnings, Basic			-441
Net Income (Loss) Available to Common Stockholders, Basic	1,015	1,187	160
income (Loss) from Continuing Operations Attributable to Shareholders			257
Basic Weighted-Average Number of Shares Outstanding	1,137	1,036	461
Income (Loss) from Continuing Operations, Per Basic Share			$0.56
Net Income (Loss) From Continuing Operation Available to Common Stockholders And Assumed Conversion			508
Diluted Weighted-Average Number of Shares Outstanding	1,137	1,036	908
Income (Loss) from Continuing Operations, Per Diluted Share			$0.56
Earnings Per Share, Diluted			$0.35
Earnings Per Share, Basic			$0.35
Common Class A [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Dividends			542
Net Income (Loss) Available to Common Stockholders And Assumed Conversion			116
Remaining Undistributed Earnings, Continuing Operations			-331
Undistributed Earnings, Basic			-426
Net Income (Loss) Available to Common Stockholders, Basic			116
income (Loss) from Continuing Operations Attributable to Shareholders			211
Basic Weighted-Average Number of Shares Outstanding			446
Income (Loss) from Continuing Operations, Per Basic Share			$0.47
Net Income (Loss) From Continuing Operation Available to Common Stockholders And Assumed Conversion			211
Diluted Weighted-Average Number of Shares Outstanding			446
Income (Loss) from Continuing Operations, Per Diluted Share			$0.47
Earnings Per Share, Diluted			$0.26
Earnings Per Share, Basic			$0.26
Participating Securities [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Dividends			41
Remaining Undistributed Earnings, Continuing Operations			-1
Undistributed Earnings, Basic			-2
Net Income (Loss) Available to Common Stockholders, Basic	11	6	39
income (Loss) from Continuing Operations Attributable to Shareholders			40
Warrant [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	312	401	451
Restricted Stock [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	7	4
Convertible Preferred Stock [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	10	10	11
Retained Earnings [Member]
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Net income attributable to KMI	1,026	1,193	315
Dividends, Common Stock, Cash	($1,760)	($1,622)	($1,184)

Summary_of_Significant_Account7

Summary of Significant Accounting Policies Goodwill (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Goodwill [Line Items]
Asset Impairment Charges	$272,000,000	$0	$0
Goodwill, Impairment Loss	2,000,000
Goodwill	24,654,000,000	24,504,000,000	23,632,000,000
Goodwill, Impaired, Accumulated Impairment Loss	0		4,411,000,000
Terminals [Member]
Goodwill [Line Items]
Goodwill, Impairment Loss	2,000,000
Goodwill	894,000,000	807,000,000	807,000,000
Goodwill, Impaired, Accumulated Impairment Loss			677,000,000
Watco Companies LLC [Member] | Terminals [Member]
Goodwill [Line Items]
Asset Impairment Charges	$29,000,000

Summary_of_Significant_Account8

Summary of Significant Accounting Policies Property, Plant and Equipment (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Line Items]
Goodwill	$24,654	$24,504	$23,632
Composite depreciation rate, low	0.90%
Composite depreciation rate, high	23.00%

Acquisitions_Business_Combinat

Acquisitions Business Combinations and Acquisitions of Investments (Details) (USD $)	0 Months Ended
In Millions, unless otherwise specified	Nov. 05, 2014	Jan. 17, 2014	Jun. 02, 2013	3-May-13	25-May-12	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	31-May-13	Apr. 30, 2013
Business Acquisition [Line Items]
Goodwill						$24,654	$24,504	$23,632
Crowley Maritime Tankers [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest	270
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets	0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	270
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets	8
Goodwill	25
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt	0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Liabilities	33
Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value	0
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value	0
American Petroleum Tankers and State Class Tankers [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest		961
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets		6
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment		951
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets		6
Goodwill		64
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt		0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Liabilities		66
Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value		0
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value		0
Goldsmith-Landreth Field Unit [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest									280
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets									0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment									298
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets									0
Goodwill									0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt									0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Liabilities									18
Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value									0
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value			0
Copano Energy, L.L.C. [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest										3,733
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets										218
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment										2,788
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets										1,973
Goodwill										963
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt										1,252
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Liabilities										236
Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value										17
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value				704
El Paso Corporation [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest					22,928
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets					7,175
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment					12,921
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets					5,718
Goodwill					18,562
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt					13,417
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Liabilities					4,234
Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value					3,797
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value					$0

Acquisitions_1_Crowley_Maritim

Acquisitions (1) Crowley Maritime Tankers (Details) (Crowley Maritime Tankers [Member], USD $)	0 Months Ended
In Millions, unless otherwise specified	Nov. 05, 2014
	bbl
Crowley Maritime Tankers [Member]
Business Acquisition [Line Items]
Number of Vessels	2
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest	$270
Increase (Decrease) in Deferred Income Taxes	8
Business Combination, Contingent Consideration, Liability	8
Unfavorable Customer Contracts	$25
Tanker Capacity	0

Acquisitions_2_American_Petrol

Acquisitions (2) American Petroleum Tankers and State Class Tankers (Details) (USD $)	0 Months Ended
In Millions, unless otherwise specified	Jan. 17, 2014
American Petroleum Tankers and State Class Tankers [Member]
Business Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest	$961
Increase (Decrease) in Deferred Income Taxes	6
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other	61
American Petroleum Tankers [Member]
Business Acquisition [Line Items]
Number of Vessels	5
Tanker Capacity	330,000
Vessel Time Charter, Operating Remaining contract term	4 years
Vessel Time Charter, Operating Renewal Term	2 years
Dynamics NASSCO shipyard [Member] | State Class Tankers [Member]
Business Acquisition [Line Items]
Number of Vessels	4
Tanker Capacity	330,000
Vessel Time Charter, Operating Remaining contract term	5 years
Vessel Time Charter, Operating Renewal Term	3 years
Long-term Purchase Commitment, Amount	$276

Acquisitions_3_Goldsmith_Landr

Acquisitions (3) Goldsmith Landreth Field Unit (Details) (Legado Resources [Member], Goldsmith-Landreth Field Unit [Member], USD $)	0 Months Ended
In Millions, unless otherwise specified	Jun. 02, 2013	31-May-13
		acre
		MMcf
Legado Resources [Member] | Goldsmith-Landreth Field Unit [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred	$298
Payments to Acquire Businesses, Gross	280
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities		18
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Long-Term Asset Retirement Obligations		$12
Gas and Oil Area, Total		6,000
Oil and Gas Delivery Commitments and Contracts, Remaining Contractual Volume Per Day		150

Acquisitions_4_Copano_Details

Acquisitions (4) Copano (Details) (USD $)	12 Months Ended			0 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	3-May-13	1-May-13
Business Acquisition [Line Items]
Equity Method Investments	$6,028	$5,943
Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Gain (Loss), Net	0	558	0
Copano Energy, L.L.C. [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred				5,200
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable, Percent of Transaction Unit for Unit					100.00%
Common Units [Member] | Copano Energy, L.L.C. [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable,Unit for Unit Exchange Ratio					0.4563
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares				43,371,210
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable				3,733
Business Acquisition, Share Price					86.08
Eagle Ford Gathering LLC [Member] | Copano Energy, L.L.C. [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired					50.00%
Business Combination, Step Acquisition, Equity Interest in Acquiree, Percentage					50.00%
Equity Method Investments					704
Eagle Ford Gathering LLC [Member] | KMP Acquisiton of Copano Energy LLC [Member]
Business Acquisition [Line Items]
Equity Method Investments, Fair Value Disclosure					146
Gain on remeasurement of previously held equity investments to fair value [Member] | Eagle Ford Gathering LLC [Member] | Copano Energy, L.L.C. [Member]
Business Acquisition [Line Items]
Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Gain (Loss), Net		$558

Acquisitions_5_EP_Details

Acquisitions (5) EP (Details) (USD $)	12 Months Ended			0 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	25-May-12
Business Acquisition [Line Items]
Noncash compensation expense on settlement of EP stock awards	$0	$0	$87
Class of Warrant or Right, Exercise Price of Warrants or Rights	$40
Proceeds from Divestiture of Businesses	0	0	1,791
Write off of Deferred Debt Issuance Cost			108
El Paso Corporation [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred				22,900
Noncash compensation expense on settlement of EP stock awards				87
Class of Warrant or Right, Exercise Price of Warrants or Rights				$40
Class of Warrant or Right, Term				5 years
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets				5,718
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Liabilities				4,234
Business Combination, Acquisition Related Costs			463
Write off of Deferred Debt Issuance Cost			108
Business Combination, Integration Related Costs			160
Share-based Compensation Arrangement by Share-based Payment Award Accelerated Compensation Cost			87
El Paso Corporation [Member] | Class P [Member]
Business Acquisition [Line Items]
Payments to Acquire Businesses, Gross				11,600
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares				330,000,000
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable				10,600
Business Acquisition, Share Price				$32.11
Warrant [Member] | El Paso Corporation [Member]
Business Acquisition [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares				505,000,000
Business Acquisition, Equity Interest Issued or Issuable, Value Assigned				863
Business Acquisition, Share Price				$1.71
Advisory Fees [Member] | El Paso Corporation [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs			37
Legal fees and expenses [Member] | El Paso Corporation [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs			68
Pension Costs [Member] | El Paso Corporation [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition Related Costs			($29)

Acquisitions_Pro_Forma_Informa

Acquisitions Pro Forma Information (Details) (EP, Copano and the Goldsmith Landreth Unit acquisitions occurred as of January 1, 2012 [Member], USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Revenue	$16,260	$14,911
Business Acquisition, Pro Forma Income (Loss) from Continuing Operations before Changes in Accounting and Extraordinary Items, Net of Tax	2,448	2,665
Business Acquisition, Pro Forma Income (Loss) from Discontinued Operations before Changes in Accounting and Extraordinary Items, Net of Tax	0	-4
Business Acquisition, Pro Forma Net Income (Loss)	2,448	2,661
Pro Forma Income Attributable to Noncontrolling Interests	-1,419	-1,490
Class P [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Earnings Per Share, Diluted	$0.90	$1.12
Kinder Morgan, Inc. [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro-forma, Net income (loss) attributable to parent	$1,029	$1,171

Acquisitions_Acquisitions_Subs

Acquisitions Acquisitions Subsequent to December 31, 2014 (Details) (USD $)	12 Months Ended			0 Months Ended	3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Feb. 13, 2015	Mar. 31, 2015	Feb. 09, 2015
						acre
						bbl
Business Acquisition [Line Items]
Repayments of Debt	$17,801	$12,393	$14,755
Subsequent Event [Member] | Hiland Partners, LP [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred				3,058
Payments to Acquire Businesses, Gross				1,715
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities				1,343
Subsequent Event [Member] | KMI's acquisition of Royal Vopak assets [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred					158
Number of terminals					3
Number of Real Estate Properties					1
Area of Real Estate Property						36
Storage Capacity						1,069,500
Bridge Loan [Member] | Subsequent Event [Member]
Business Acquisition [Line Items]
Repayments of Debt				$368
North Carolina [Member] | Subsequent Event [Member] | KMI's acquisition of Royal Vopak assets [Member]
Business Acquisition [Line Items]
Number of terminals					2
North Wilmington, North Carolina [Member] | Subsequent Event [Member] | KMI's acquisition of Royal Vopak assets [Member]
Business Acquisition [Line Items]
Number of terminals					1
South Wilmington, North Carolina [Member] | Subsequent Event [Member] | KMI's acquisition of Royal Vopak assets [Member]
Business Acquisition [Line Items]
Number of terminals					1

Acquisitions_Dropdown_Assets_D

Acquisitions Drop-down Assets (Details)	Aug. 01, 2012	Mar. 01, 2013	Aug. 02, 2012	2-May-14
Drop-Down of EPNG and TGP Part 1 to KMP [Member] | Kinder Morgan Energy Partners, L.P. [Member] | TGP [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage	100.00%
Drop-Down of EPNG and TGP Part 1 to KMP [Member] | Kinder Morgan Energy Partners, L.P. [Member] | EPNG [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage		50.00%	50.00%
Drop-Down of Assets to EPB [Member] | El Paso Pipeline Partners, L.P. [Member] | Ruby Pipeline Holding Company LLC [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage				50.00%
Drop-Down of Assets to EPB [Member] | El Paso Pipeline Partners, L.P. [Member] | Gulf LNG Holdings Group LLC [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage				50.00%
Drop-Down of Assets to EPB [Member] | El Paso Pipeline Partners, L.P. [Member] | Young Gas Storage [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage				47.50%

Acquisitions_KMP_Previously_He

Acquisitions KMP Previously Held Investment in El Paso Midstream Investment, LLC (Details) (USD $)	0 Months Ended
	Jun. 01, 2012	Jun. 02, 2013	Dec. 31, 2014	Dec. 31, 2013
Business Acquisition [Line Items]
Other Assets, Noncurrent			$2,239,000,000	$2,577,000,000
El Paso Midstream [Member]
Business Acquisition [Line Items]
Goodwill, Gross	248,000,000
Kinder Morgan Energy Partners, L.P. [Member] | Kohlberg Kravis Roberts & Co. L.P. [Member] | El Paso Midstream Investment Company, LLC. [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds	289,000,000
Kinder Morgan subsidiaries [Member] | El Paso Midstream Investment Company, LLC. [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Kinder Morgan, Inc. [Member] | El Paso Midstream Investment Company, LLC. [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage	100.00%
Gain (Loss) on Sale of Equity Investments	0
Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds	578,000,000
Customer Relationships [Member] | El Paso Midstream [Member]
Business Acquisition [Line Items]
Other Assets, Noncurrent	$50,000,000
Change in Estimated Useful Life		10 years

Acquisitions_Income_Tax_Impact

Acquisitions Income Tax Impact of the Drop-Down of EP Assets to KMP (Details) (USD $)	5 Months Ended	12 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Aug. 02, 2012	Mar. 04, 2013
Business Acquisition [Line Items]
Income tax expense from deferred charges that arose from drop-down transactions	$7	$18	$20
Drop-Down of EPNG and TGP Part 1 to KMP [Member]
Business Acquisition [Line Items]
Deferred Tax Assets, Deferred Income		456			448
EPNG Part 2 and EP Midstream Assets Part 2 Drop Downs [Member]
Business Acquisition [Line Items]
Deferred Tax Assets, Deferred Income						$53
TGP and EPNG [Member]
Business Acquisition [Line Items]
Public Utilities, Property, Plant and Equipment, Equipment, Useful Life				25 years

Acquisitions_The_FTC_Natural_G

Acquisitions The FTC Natural Gas Pipelines Disposal Group – Discontinued Operations (Details) (USD $)	12 Months Ended			3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2012	Mar. 31, 2012
Business Acquisition [Line Items]
Proceeds from Divestiture of Businesses	$0	$0	$1,791
Income from operations of the FTC Natural Gas Pipelines disposal group and other, net of tax	0	0	160
FTC Natural Gas Pipeline Disposal Group [Member]
Business Acquisition [Line Items]
Proceeds from Divestiture of Businesses				1,791
Selling expenses on sale of assets held for sale				78
Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Loss		4
KMP’s FTC Natural Gas Pipelines [Member]
Business Acquisition [Line Items]
Disposal Group, Including Discontinued Operation, Revenue			227
Impairment of Long-Lived Assets to be Disposed of					937
Disposal Group, Including Discontinued Operation, Operating Expense			131
Disposal Group, Including Discontinued Operation, Depreciation and Amortization			7
Disposal group, Including Discontinued Operation, Other Expenses			1
Disposal Group, Including Discontinued Operation, Earnings From Equity Investments			70
Disposal Group, Including Discontinued Operation, Interest Income and Other, Net			2
Income from operations of the FTC Natural Gas Pipelines disposal group and other, net of tax			$160

Acquisitions_Express_Pipeline_

Acquisitions Express Pipeline System (Details) (USD $)	12 Months Ended			0 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 14, 2013	Mar. 31, 2015
Business Acquisition [Line Items]
Proceeds from Sale of Equity Method Investments	$0	$490	$0
Income Tax Expense (Benefit)	648	742	139
Equity Method Investments	6,028	5,943
KMP Sale of Express Pipeline System [Member] | Express Pipeline System [Member]
Business Acquisition [Line Items]
Equity Method Investment, Realized Gain (Loss) on Disposal		224
Income Tax Expense (Benefit)		84
KMP Sale of Express Pipeline System [Member] | Equity method investment & Suboordinated debt investment [Member] | Express Pipeline System [Member] | Spectra Energy Corp. [Member]
Business Acquisition [Line Items]
Proceeds from Sale of Equity Method Investments				402
Kinder Morgan Canada [Member]
Business Acquisition [Line Items]
Income Tax Expense (Benefit)	18	21	1
Equity Method Investments				67
Express Pipeline System [Member]
Business Acquisition [Line Items]
Notes Receivable, Related Parties				$110
Express Pipeline System [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage		33.33%		33.33%
Subsequent Event [Member] | KMI's acquisition of Royal Vopak assets [Member]
Business Acquisition [Line Items]
Number of Real Estate Properties					1

Income_Taxes_Details

Income Taxes (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Loss Carryforwards [Line Items]
Deferred Tax Assets, Operating Loss Carryfowards, net	$778,000,000	$673,000,000
Income from Continuing Operations Before Income Taxes
U.S.	2,941,000,000	3,107,000,000	1,246,000,000
Foreign	150,000,000	331,000,000	97,000,000
Income from Continuing Operations Before Income Taxes	3,091,000,000	3,438,000,000	1,343,000,000
Components of Income Tax Expense (Benefit), Continuing Operations [Abstract]
Total tax provision	648,000,000	742,000,000	139,000,000
Current tax expense
Federal	-16,000,000	57,000,000	48,000,000
State	36,000,000	36,000,000	34,000,000
Foreign	13,000,000	9,000,000	10,000,000
Federal	572,000,000	612,000,000	49,000,000
Current Income Tax Expense (Benefit)	33,000,000	102,000,000	92,000,000
Effective Income Tax Rate Reconciliation [Abstract]
Federal income tax	1,082,000,000	1,203,000,000	470,000,000
Federal income tax	35.00%	35.00%	35.00%
Taxes on foreign earnings	40,000,000	112,000,000	-6,000,000
Taxes on foreign earnings	1.30%	3.30%	-0.50%
Net effects of consolidating KMP’s and EPB’s U.S. income tax provision	-433,000,000	-488,000,000	-288,000,000
Net effects of consolidating KMP’s and EPB’s U.S. income tax provision	-14.00%	-14.20%	-21.50%
State income tax, net of federal benefit	37,000,000	45,000,000	21,000,000
State income tax, net of federal benefit	1.20%	1.30%	1.60%
Dividend received deduction	-50,000,000	-54,000,000	-32,000,000
Dividend received deduction	-1.60%	-1.60%	-2.40%
Adjustments to uncertain tax positions	-5,000,000	-87,000,000	-72,000,000
Adjustments to uncertain tax positions	-0.20%	-2.50%	-5.30%
Effective Income Tax Rate Reconciliation, Disposition of Certain International Holdings, Amount	-112,000,000	0	0
Effective Income Tax Rate Reconciliation, Disposition of Certain International Holdings, Percent	-3.60%	0.00%	0.00%
Other	28,000,000	32,000,000	26,000,000
Other	0.90%	0.90%	1.90%
Total	21.00%	21.60%	10.30%
Deferred tax expense
State	14,000,000	0	4,000,000
Foreign	29,000,000	28,000,000	-6,000,000
Deferred Income Tax Expense (Benefit)	615,000,000	640,000,000	47,000,000
Deferred tax assets
Employee benefits	329,000,000	238,000,000
Accrued expenses	123,000,000	136,000,000
Derivative instruments and interest rate and currency swaps	43,000,000	68,000,000
Debt fair value adjustment	102,000,000	112,000,000
Deferred Tax Assets, Investments	4,858,000,000	0
Other	31,000,000	43,000,000
Total deferred tax assets	6,110,000,000	1,175,000,000
Deferred Tax Assets, Alternative Minimum, Foreign Tax Credits	312,000,000
Deferred tax liabilities
Property, plant and equipment	373,000,000	351,000,000
Investments	0	4,888,000,000
Other	30,000,000	20,000,000
Total deferred tax liabilities	403,000,000	5,259,000,000
Deferred Tax Assets, Net	5,707,000,000
Net deferred tax assets (liabilities)		-4,084,000,000
Current deferred tax asset	56,000,000	567,000,000
Deferred Tax Assets, Net, Noncurrent	5,651,000,000	0
Non-current deferred tax assets (liabilities)	0	-4,651,000,000
Deferred Tax Assets, Tax Credit Carryovers, Alt Min, Gen Bus and Foreign		308,000,000
Deferred Tax Assets, Valuation Allowance	-154,000,000	-95,000,000
Deferred Tax Assets, Operating Loss Carryforwards	466,000,000	354,000,000
Deferred Tax Assets, Capital Loss Carryforwards		11,000,000
Required minimum likelihood for benefits to be recognized in the financial statements	50.00%
Deferred Tax Assets, Equity Method Investments	10,300,000,000
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Unrecognized Tax Benefits, Subtotal	209,000,000		273,000,000	346,000,000
Unrecognized Tax Benefits	209,000,000	269,000,000	57,000,000
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions	-3,000,000	0	0
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions	12,000,000	11,000,000	11,000,000
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions	0	26,000,000	1,000,000
Reductions based on settlements with taxing authority	-24,000,000	-86,000,000	-55,000,000
Reductions due to lapse in statute of limitations	-5,000,000	-15,000,000	-34,000,000
Unrecognized Tax Benefits	189,000,000	209,000,000	269,000,000	57,000,000
Unrecognized Tax Benefits, Interest on Income Taxes Accrued	28,000,000	29,000,000	28,000,000
Unrecognized Tax Benefits, Income Tax Penalties Accrued	2,000,000	2,000,000	2,000,000
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued	189,000,000
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	1,000,000
Unrecognized tax benefits, income tax penalties and interest accruing next year	190,000,000
Income from Continuing Operations Before Income Taxes
U.S.	2,941,000,000	3,107,000,000	1,246,000,000
Foreign	150,000,000	331,000,000	97,000,000
Income from Continuing Operations Before Income Taxes	3,091,000,000	3,438,000,000	1,343,000,000
Components of Income Tax Expense (Benefit), Continuing Operations [Abstract]
Total tax provision	648,000,000	742,000,000	139,000,000
Current tax expense
Federal	-16,000,000	57,000,000	48,000,000
State	36,000,000	36,000,000	34,000,000
Foreign	13,000,000	9,000,000	10,000,000
Federal	572,000,000	612,000,000	49,000,000
Current Income Tax Expense (Benefit)	33,000,000	102,000,000	92,000,000
Effective Income Tax Rate Reconciliation [Abstract]
Federal income tax	1,082,000,000	1,203,000,000	470,000,000
Federal income tax	35.00%	35.00%	35.00%
Taxes on foreign earnings	40,000,000	112,000,000	-6,000,000
Taxes on foreign earnings	1.30%	3.30%	-0.50%
Net effects of consolidating KMP’s and EPB’s U.S. income tax provision	-433,000,000	-488,000,000	-288,000,000
Net effects of consolidating KMP’s and EPB’s U.S. income tax provision	-14.00%	-14.20%	-21.50%
State income tax, net of federal benefit	37,000,000	45,000,000	21,000,000
State income tax, net of federal benefit	1.20%	1.30%	1.60%
Dividend received deduction	-50,000,000	-54,000,000	-32,000,000
Dividend received deduction	-1.60%	-1.60%	-2.40%
Adjustments to uncertain tax positions	-5,000,000	-87,000,000	-72,000,000
Adjustments to uncertain tax positions	-0.20%	-2.50%	-5.30%
Effective Income Tax Rate Reconciliation, Disposition of Certain International Holdings, Amount	-112,000,000	0	0
Effective Income Tax Rate Reconciliation, Disposition of Certain International Holdings, Percent	-3.60%	0.00%	0.00%
Other	28,000,000	32,000,000	26,000,000
Other	0.90%	0.90%	1.90%
Total	21.00%	21.60%	10.30%
Deferred tax expense
State	14,000,000	0	4,000,000
Foreign	29,000,000	28,000,000	-6,000,000
Deferred Income Tax Expense (Benefit)	615,000,000	640,000,000	47,000,000
Deferred tax assets
Employee benefits	329,000,000	238,000,000
Accrued expenses	123,000,000	136,000,000
Derivative instruments and interest rate and currency swaps	43,000,000	68,000,000
Debt fair value adjustment	102,000,000	112,000,000
Deferred Tax Assets, Investments	4,858,000,000	0
Other	31,000,000	43,000,000
Total deferred tax assets	6,110,000,000	1,175,000,000
Deferred Tax Assets, Alternative Minimum, Foreign Tax Credits	312,000,000
Deferred tax liabilities
Property, plant and equipment	373,000,000	351,000,000
Investments	0	4,888,000,000
Other	30,000,000	20,000,000
Total deferred tax liabilities	403,000,000	5,259,000,000
Deferred Tax Assets, Net	5,707,000,000
Net deferred tax assets (liabilities)		-4,084,000,000
Current deferred tax asset	56,000,000	567,000,000
Deferred Tax Assets, Net, Noncurrent	5,651,000,000	0
Non-current deferred tax assets (liabilities)	0	-4,651,000,000
Deferred Tax Assets, Tax Credit Carryovers, Alt Min, Gen Bus and Foreign		308,000,000
Deferred Tax Assets, Valuation Allowance	-154,000,000	-95,000,000
Deferred Tax Assets, Operating Loss Carryforwards	466,000,000	354,000,000
Deferred Tax Assets, Capital Loss Carryforwards		11,000,000
Required minimum likelihood for benefits to be recognized in the financial statements	50.00%
Deferred Tax Assets, Equity Method Investments	10,300,000,000
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Unrecognized Tax Benefits, Subtotal	209,000,000		273,000,000	346,000,000
Unrecognized Tax Benefits	209,000,000	269,000,000	57,000,000
Unrecognized Tax Benefits, Decrease Resulting from Prior Period Tax Positions	-3,000,000	0	0
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions	12,000,000	11,000,000	11,000,000
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions	0	26,000,000	1,000,000
Reductions based on settlements with taxing authority	-24,000,000	-86,000,000	-55,000,000
Reductions due to lapse in statute of limitations	-5,000,000	-15,000,000	-34,000,000
Unrecognized Tax Benefits	189,000,000	209,000,000	269,000,000	57,000,000
Unrecognized Tax Benefits, Interest on Income Taxes Accrued	28,000,000	29,000,000	28,000,000
Unrecognized Tax Benefits, Income Tax Penalties Accrued	2,000,000	2,000,000	2,000,000
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued	189,000,000
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	1,000,000
Unrecognized tax benefits, income tax penalties and interest accruing next year	190,000,000
State and Local Jurisdiction [Member]
Effective Income Tax Rate Reconciliation [Abstract]
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, State, Amount	0	-21,000,000	20,000,000
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, State, Percent	0.00%	-0.60%	1.50%
Effective Income Tax Rate Reconciliation [Abstract]
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, State, Amount	0	-21,000,000	20,000,000
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, State, Percent	0.00%	-0.60%	1.50%
General Business Tax Credit Carryforward [Member] | Foreign Tax Authority [Member]
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Operating Loss Carryforwards, Foreign	213,000,000
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Operating Loss Carryforwards, Foreign	213,000,000
2018 - 2034 [Member] | General Business Tax Credit Carryforward [Member] | Domestic Tax Authority [Member]
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	906,000,000
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	906,000,000
Does Not Expire [Member] | General Business Tax Credit Carryforward [Member]
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Tax Credit Carryforwards, Alternative Minimum Tax	300,000,000
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Tax Credit Carryforwards, Alternative Minimum Tax	300,000,000
Does Not Expire [Member] | General Business Tax Credit Carryforward [Member] | Foreign Tax Authority [Member]
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Operating Loss Carryforwards, Not Subject to Expiration	124,000,000
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Operating Loss Carryforwards, Not Subject to Expiration	124,000,000
Expires from 2028 - 2035 [Member] | General Business Tax Credit Carryforward [Member] | Foreign Tax Authority [Member]
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	89,000,000
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	89,000,000
Majority expire from 2016 - 2024 [Member] | General Business Tax Credit Carryforward [Member]
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Tax Credit Carryforwards, Foreign	11,000,000
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Tax Credit Carryforwards, Foreign	11,000,000
Natural Gas Pipelines [Member]
Effective Income Tax Rate Reconciliation [Abstract]
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	61,000,000	0	0
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Percent	2.00%	0.00%	0.00%
Deferred tax liabilities
Deferred Tax Assets, Valuation Allowance	-61,000,000
Effective Income Tax Rate Reconciliation [Abstract]
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	61,000,000	0	0
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Percent	2.00%	0.00%	0.00%
Deferred tax liabilities
Deferred Tax Assets, Valuation Allowance	-61,000,000
KMP and EPB [Member]
Effective Income Tax Rate Reconciliation [Abstract]
Total	36.48%
Deferred tax liabilities
Deferred Tax Assets, Valuation Allowance	-4,900,000,000
Business Combination, Consideration Transferred	64,000,000,000
Tax Basis of Investments, Cost for Income Tax Purposes	64,000,000,000
Book basis of investment	36,000,000,000
Effective Income Tax Rate Reconciliation [Abstract]
Total	36.48%
Deferred tax liabilities
Deferred Tax Assets, Valuation Allowance	-4,900,000,000
Business Combination, Consideration Transferred	64,000,000,000
Tax Basis of Investments, Cost for Income Tax Purposes	64,000,000,000
Book basis of investment	36,000,000,000
KMI's Acquisition of EP [Member] | El Paso LLC [Member]
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Unrecognized Tax Benefits, Increase Resulting from Acquisition	0		4,000,000	289,000,000
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Unrecognized Tax Benefits, Increase Resulting from Acquisition	0		4,000,000	289,000,000
State and Local Jurisdiction [Member] | Expires from 2014 - 2034 [Member] | General Business Tax Credit Carryforward [Member] | Domestic Tax Authority [Member]
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	1,900,000,000
Reconciliation of Gross Unrecognized Tax Benefits, Excluding Interest and Penalties
Deferred Tax Assets, Operating Loss Carryforwards, Subject to Expiration	1,900,000,000
KMI members [Member]
Deferred tax liabilities
Deferred Tax Assets, Valuation Allowance	-93,000,000
Deferred tax liabilities
Deferred Tax Assets, Valuation Allowance	($93,000,000)

Property_Plant_and_Equipment_C

Property, Plant and Equipment Classes and Depreciation (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	($8,369)	($6,757)
Public Utilities, Property, Plant and Equipment, Equipment	35,467	32,517
Land and land rights-of-way	1,324	1,158
Construction in Progress, Gross	1,773	2,172
Net depreciable property plant and equipment	38,564	35,847
Public Utilities, Property, Plant and Equipment, Common	15,026	14,957
Depreciation, depletion and amortization	2,040	1,806	1,419
Asset Retirement Obligation	192	204
Asset Retirement Obligation, Current	7	25
Asset Impairment Charges	272	0	0
Charged against PPE [Member]
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]
Depreciation, depletion and amortization	1,862	1,663	1,324
Gas Transmission Equipment [Member]
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]
Public Utilities, Property, Plant and Equipment, Transmission	18,119	17,399
Gas, Transmission and Distribution Equipment [Member]
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]
Public Utilities, Property, Plant and Equipment, Transmission and Distribution	21,233	17,960
Gas Gathering and Processing Equipment [Member]
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]
Public Utilities, Property, Plant and Equipment, Generation or Processing	520	259
Property, Plant and Equipment, Other Types [Member]
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]
Other depreciable property plant and equipment	3,964	3,656
CO2 [Member]
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]
Depreciation, depletion and amortization	570	533	494
CO2 [Member] | Katz Strawn [Member]
Public Utilities, Property, Plant and Equipment, Transmission and Distribution [Abstract]
Asset Impairment Charges	$235

Property_Plant_and_Equipment_A

Property, Plant and Equipment Asset Retirement Obligations (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Property, Plant and Equipment [Abstract]
Asset Retirement Obligation	$192	$204
Asset Retirement Obligation, Current	$7	$25

Property_Plant_and_Equipment_I

Property, Plant and Equipment Impairment (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Impairment [Abstract]
Asset Impairment Charges	$272	$0	$0
CO2 [Member] | Katz Strawn [Member]
Impairment [Abstract]
Asset Impairment Charges	$235

Investments_Details

Investments (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Schedule of Equity Method Investments [Line Items]
Miles Of Pipeline	80,000
Percent of investee information represented	100.00%
Total Equity Investments	$6,028	$5,943
Bond Investments	8	8
Long-term Investments	6,036	5,951
Earnings from equity investments	406	327	153
Amortization of excess costs	-45	-39	-23
Equity Method Investment, Summarized Financial Information, Revenue	3,829	3,615	3,681
Equity Method Investment, Summarized Financial Information, Cost of Sales	3,063	2,803	3,194
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	766	812	487
Equity Method Investment, Summarized Financial Information, Current Assets	943	950
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	20,630	20,782
Equity Method Investment, Summarized Financial Information, Current Liabilities	1,643	1,451
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities	10,841	11,351
Equity Method Investment, Summarized Financial Information, Equity or Capital	9,089	8,930
Citrus Corporation [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Miles Of Pipeline	5,300
Total Equity Investments	1,805	1,875
Earnings from equity investments	97	84	53
Ruby Pipeline Holding Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Total Equity Investments	1,123	1,153
Earnings from equity investments	15	-6	-5
Midcontinent Express Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Total Equity Investments	748	602
Earnings from equity investments	45	40	42
Gulf LNG Holdings Group LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Total Equity Investments	547	578
Earnings from equity investments	48	47	22
Plantation Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	51.17%
Total Equity Investments	303	307
Earnings from equity investments	29	35	32
EagleHawk Field Services [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	25.00%
Total Equity Investments	337	272
Earnings from equity investments	-7	9	11
Red Cedar Gathering company [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	49.00%
Total Equity Investments	184	176
Earnings from equity investments	33	31	32
Double Eagle Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Total Equity Investments	150	144
Earnings from equity investments	-1	1	0
Parkway Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Total Equity Investments	144	131
Earnings from equity investments	8	1	0
Fayetteville Express [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Total Equity Investments	130	144
Earnings from equity investments	55	55	55
Watco Companies LLC [Member]
Schedule of Equity Method Investments [Line Items]
Preferred Stock, Value, Issued (Share)	100,000
Quarterly preferred distribution rate	3.25%
Profit participation rate	0.50%
Total Equity Investments	103	103
Earnings from equity investments	13	13	13
Fort Union Gas Gathering L.L.C.
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	37.04%
Total Equity Investments	70	161
Earnings from equity investments	16	11	0
Sierrita Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	35.00%
Total Equity Investments	63	19
Earnings from equity investments	3	0	0
Cortez Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Total Equity Investments	17	12
Earnings from equity investments	25	24	25
NGPL Holdco LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	20.00%
Equity Method Investment, Other than Temporary Impairment		65	200
Earnings from equity investments	0	-66	-198
All Others [Member]
Schedule of Equity Method Investments [Line Items]
Total Equity Investments	304	266
Earnings from equity investments	$27	$48	$71
Energy Transfers Partners LP [Member] | Citrus Corporation [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Energy Transfers Partners LP [Member] | Fayetteville Express [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
ONEOK Parftners [Member] | Fort Union Gas Gathering L.L.C.
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	37.04%
WPX Energy Rocky Mountain, LLC [Member] | Fort Union Gas Gathering L.L.C.
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	11.11%
Western Gas Partners [Member] | Fort Union Gas Gathering L.L.C.
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	14.81%
PEMEX [Member] | Sierrita Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	35.00%
Mitsui [Member] | Sierrita Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	30.00%
Veresen Inc. [Member] | Ruby Pipeline Holding Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Regency Energy Partners LP [Member] | Midcontinent Express Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
GE Financial Services [Member] | Gulf LNG Holdings Group LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
BHP Billiton [Member] | EagleHawk Field Services [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	75.00%
Southern Ute Indian Tribe [Member] | Red Cedar Gathering company [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	51.00%
Magellan Midstream Partners [Member] | Double Eagle Pipeline LLC
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Valero Energy Corp. [Member] | Parkway Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Exxon Mobil Corporation [Member] | Cortez Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	37.00%
Cortez Vickers Pipeline Company [Member] | Cortez Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	13.00%

Goodwill_and_Other_Intangibles2

Goodwill and Other Intangibles Goodwill and Excess Investment Cost (Details) (USD $)	12 Months Ended			0 Months Ended	3 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	31-May-13	Mar. 31, 2014	Nov. 05, 2014
Goodwill [Line Items]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	19 years
Goodwill, Impairment Loss	($2,000,000)
Goodwill [Roll Forward]
Historical goodwill including accumulated activities except impairments			28,043,000,000
Goodwill, Impaired, Accumulated Impairment Loss	0		-4,411,000,000
Goodwill	24,504,000,000	23,632,000,000			24,504,000,000
Goodwill arising from acquisitions	171,000,000	888,000,000
Goodwill, Translation Adjustments	-19,000,000	-16,000,000
Goodwill	24,654,000,000	24,504,000,000	23,632,000,000
Asset Impairment Charges	272,000,000	0	0
Reporting unit [Member]
Goodwill [Line Items]
Goodwill, Impairment Loss				0
Natural Gas Pipelines [Member]
Goodwill [Line Items]
Goodwill, Impairment Loss	0
Goodwill [Roll Forward]
Historical goodwill including accumulated activities except impairments			22,276,000,000
Goodwill, Impaired, Accumulated Impairment Loss			-2,090,000,000
Goodwill	21,074,000,000	20,186,000,000			21,074,000,000
Goodwill arising from acquisitions	82,000,000	888,000,000
Goodwill, Translation Adjustments	0	0
Goodwill	21,156,000,000	21,074,000,000
CO2 [Member]
Goodwill [Line Items]
Goodwill, Impairment Loss	0
Goodwill [Roll Forward]
Historical goodwill including accumulated activities except impairments			1,528,000,000
Goodwill, Impaired, Accumulated Impairment Loss			0
Goodwill	1,528,000,000	1,528,000,000			1,528,000,000
Goodwill arising from acquisitions	0	0
Goodwill, Translation Adjustments	0	0
Goodwill	1,528,000,000	1,528,000,000
Products Pipelines [Member]
Goodwill [Line Items]
Goodwill, Impairment Loss	0
Goodwill [Roll Forward]
Historical goodwill including accumulated activities except impairments			2,129,000,000
Goodwill, Impaired, Accumulated Impairment Loss			-1,267,000,000
Goodwill	862,000,000	862,000,000			862,000,000
Goodwill arising from acquisitions	0	0
Goodwill, Translation Adjustments	0	0
Goodwill	862,000,000	862,000,000
Kinder Morgan Canada [Member]
Goodwill [Line Items]
Goodwill, Impairment Loss	0
Goodwill [Roll Forward]
Historical goodwill including accumulated activities except impairments			626,000,000
Goodwill, Impaired, Accumulated Impairment Loss			-377,000,000
Goodwill	233,000,000	249,000,000			233,000,000
Goodwill arising from acquisitions	0	0
Goodwill, Translation Adjustments	-19,000,000	-16,000,000
Goodwill	214,000,000	233,000,000
Terminals [Member]
Goodwill [Line Items]
Goodwill, Impairment Loss	-2,000,000
Goodwill [Roll Forward]
Historical goodwill including accumulated activities except impairments			1,484,000,000
Goodwill, Impaired, Accumulated Impairment Loss			-677,000,000
Goodwill	807,000,000	807,000,000			807,000,000
Goodwill arising from acquisitions	89,000,000	0
Goodwill, Translation Adjustments	0	0
Goodwill	894,000,000	807,000,000
APT and SCT [Member] | Terminals [Member]
Goodwill [Roll Forward]
Goodwill arising from acquisitions					64,000,000
KMP Acquisiton of Copano Energy LLC [Member] | Natural Gas Pipelines [Member]
Goodwill [Roll Forward]
Goodwill arising from acquisitions		881,000,000			82,000,000
KMI's Acquisition of El Paso Corporation [Member] | Natural Gas Pipelines [Member]
Goodwill [Roll Forward]
Goodwill arising from acquisitions		7,000,000
Crowley Maritime Tankers [Member]
Goodwill [Roll Forward]
Goodwill						25,000,000
Goodwill						25,000,000
Crowley Maritime Tankers [Member] | Terminals [Member]
Goodwill [Roll Forward]
Goodwill arising from acquisitions					25,000,000
Amortized [Member]
Goodwill [Roll Forward]
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	746,000,000	809,000,000
Unamortization [Member]
Goodwill [Roll Forward]
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	138,000,000	138,000,000
unamortized excess cost over underlying fair value of net assets acquired [Member]
Goodwill [Roll Forward]
Asset Impairment Charges	$0
Change in Estimated Useful Life	0 years
May 31st [Member]
Goodwill [Line Items]
Number of reporting units	7
May 31, 2013 [Member] | Natural Gas Pipelines Non-Regulated & Natural Gas Pipelines Regulated [Member] | KMP Acquisiton of Copano Energy LLC [Member]
Goodwill [Line Items]
Number of reportable segments for impairment testing	2

Goodwill_and_Other_Intangibles3

Goodwill and Other Intangibles Other Intangibles (Details) (USD $)	12 Months Ended			3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2014
Finite-Lived Intangible Assets [Line Items]
Goodwill arising from acquisitions	$171	$888
Intangible Assets, Gross (Excluding Goodwill)	2,302	2,438
Intangible Assets, Net (Excluding Goodwill)	2,302	2,438
Amortization of Intangible Assets	143	125	86
Finite-Lived Intangible Assets, Amortization Expense, Year Two	133
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months	142
Finite-Lived Intangible Assets, Amortization Expense, Year Three	129
Finite-Lived Intangible Assets, Amortization Expense, Year Four	126
Finite-Lived Intangible Assets, Amortization Expense, after Year Five	125
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life	19 years
Terminals [Member]
Finite-Lived Intangible Assets [Line Items]
Goodwill arising from acquisitions	89	0
Terminals [Member] | Crowley Maritime Tankers [Member]
Finite-Lived Intangible Assets [Line Items]
Goodwill arising from acquisitions				$25

Debt_Details

Debt (Details) (USD $)	12 Months Ended			0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jan. 14, 2015	Nov. 26, 2014	Jun. 29, 2014
Debt Instrument [Line Items]
Long-term Debt, Current Maturities	2,717,000,000	$2,306,000,000
Preferred stock	0	0
Debt, Weighted Average Interest Rate	5.02%	5.08%
Preferred Stock, Liquidation Preference Per Share	50
Value of preferred securities value assigned to debt	248,000,000
Value of preferred securities value assigned to equity	32,000,000
Preferred stock, shares outstanding (in shares)	0	0
Preferred stock, par value (in dollars per share)	0.01	$0.01
Debt fair value adjustments	1,934,000,000	1,977,000,000
Kinder Morgan, Inc. [Member]
Debt Instrument [Line Items]
Senior Notes					6,000,000,000
Line of Credit Facility, Amount Outstanding	850,000,000	175,000,000
Commercial Paper	386,000,000	0			4,000,000,000
Redemption price of debt as a percentage of face amount	100.00%
Line of Credit Facility, Current Borrowing Capacity	4,000,000,000				4,000,000,000
Class of Warrant or Right, Number of Securities Called by Warrants or Rights	1.1
Kinder Morgan, Inc. [Member] | Commercial Paper [Member]
Debt Instrument [Line Items]
Commercial Paper	386,000,000
Kinder Morgan Energy Partners, L.P. [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	0	0
Commercial Paper	0	979,000,000
Kinder Morgan Energy Partners, L.P. [Member] | Commercial Paper [Member]
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate		0.28%
El Paso Pipeline Partners Operating Company, L.L.C. [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	0	0
Colorado Interstate Gas Company, L.L.C. [Member]
Debt Instrument [Line Items]
Construction Costs Funded	50.00%
Kinder Morgan G.P., Inc. [Member]
Debt Instrument [Line Items]
Preferred stock, shares outstanding (in shares)	100,000
Preferred Stock, Dividend Rate, Percentage	3.90%
Kinder Morgan, Inc and Subsidiaries [Member]
Debt Instrument [Line Items]
Long-term Debt	41,029,000,000	34,216,000,000
Long-term Debt, Excluding Current Maturities	38,312,000,000	31,910,000,000
Capital Trust [Member]
Debt Instrument [Line Items]
Equity Method Investment, Ownership Percentage	100.00%
Senior unsecured term loan facility, variable, due May 6, 2017 [Member] | Kinder Morgan, Inc. [Member]
Debt Instrument [Line Items]
Senior Notes	0
Senior Notes and debentures, 2.00% through 8.25%, due 2014 through 2098 [Member] | Kinder Morgan, Inc. [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	2.00%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.25%
Senior Notes	11,438,000,000	5,645,000,000
Senior secured term loan facility, variable, due May 24, 2015 [Member] | Kinder Morgan, Inc. [Member]
Debt Instrument [Line Items]
Senior Notes		1,528,000,000
KMP Senior notes, 2.65% through 9.00%, due 2014 through 2044 [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	2.65%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	9.00%
Senior Notes	17,800,000,000	15,600,000,000
KMP Senior notes, 7.00% through 8.375%, due 2016 through 2037 [Member] | TGP [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	7.00%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.38%
Senior Notes	1,790,000,000	1,790,000,000
KMP 5.95% through 8.625%, due 2017 through 2032 [Member] [Member] | EPNG [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.95%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.63%
Senior Notes	1,115,000,000	1,115,000,000
KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member] | Copano Energy, L.L.C. [Member]
Debt Instrument [Line Items]
Senior Notes	332,000,000	332,000,000
Interest rate, stated percentage	7.13%	7.13%
EPB Notes, 4.10% through 7.50%, due 2015 through 2042 [Member] [Member] | El Paso Pipeline Partners Operating Company, L.L.C. [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	4.10%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	7.50%
Senior Notes	2,860,000,000	2,260,000,000
EPB Notes, 5.95% through 6.85%, due 2015 through 2037 [Member] | Colorado Interstate Gas Company, L.L.C. [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.95%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	6.85%
Senior Notes	475,000,000	475,000,000
EPB Senior notes, 9.50% and 9.75%, due 2014 and 2016 [Member] | Southern LNG Company, L.L.C.(SLNG) [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	9.50%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	9.75%
Senior Notes	0	135,000,000
EPB Notes, 4.40% through 8.00%, due 2017 through 2032 [Member] | SNG [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	4.40%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.00%
Notes Payable	1,211,000,000	1,211,000,000
KMI 5.70% through 6.40% series, due 2016 through 2036 [Member] | Kinder Morgan Finance Company, LLC [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.70%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	6.40%
Senior Notes	1,636,000,000	1,636,000,000
KMI Promissory note 3.967%, due 2014 through 2035 [Member] [Member] | EPC Building LLC [Member]
Debt Instrument [Line Items]
Notes Payable	453,000,000	461,000,000
Interest rate, stated percentage	3.97%
KMI EP Capital Trust I 4.75%, due 2028 [Member]
Debt Instrument [Line Items]
Interest rate, stated percentage	4.75%
Debt Instrument, Face Amount	5,600,000
Value of cash issued in debt conversion	99,000	3,000,000
KMI EP Capital Trust I 4.75%, due 2028 [Member] | Capital Trust I [Member]
Debt Instrument [Line Items]
Senior Notes	280,000,000	280,000,000
Long-term Debt, Current Maturities	141,000,000
Interest rate, stated percentage	4.75%
KMI $1,000 Liquidation Value Series A Fixed-to-Floating Rate Term Cumulative Preferred Stock [Member] | Kinder Morgan G.P., Inc. [Member]
Debt Instrument [Line Items]
Preferred stock	100,000,000	100,000,000
Preferred stock, par value (in dollars per share)	1,000
Other Miscellaneous Subsidiary Debt [Member] | KMI, KMP and EPB [Member]
Debt Instrument [Line Items]
Notes Payable	303,000,000	494,000,000
KMI Credit Facility [Member] | Kinder Morgan, Inc. [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	1.54%	2.67%
Capital Trust [Member]
Debt Instrument [Line Items]
Conversion of Stock, Shares Converted	3,923	107,618
Totem [Member] | El Paso Pipeline Partners, L.P. [Member]
Debt Instrument [Line Items]
Capital Lease Obligations	73,000,000
High Plains [Member] | El Paso Pipeline Partners, L.P. [Member]
Debt Instrument [Line Items]
Capital Lease Obligations	100,000,000
Totem and High Plains [Member]
Debt Instrument [Line Items]
Interest rate, stated percentage	15.50%
Class P [Member]
Debt Instrument [Line Items]
Preferred Stock, Conversion, Shares	0.7197
Debt Instrument, Convertible, Conversion Price	25.18
Stock Issued During Period, Shares, Conversion of Convertible Securities			535,972,387
Class P [Member] | KMI EP Capital Trust I 4.75%, due 2028 [Member]
Debt Instrument [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities			562,521
Class P [Member] | Capital Trust [Member]
Debt Instrument [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities	2,820	77,442
Warrant [Member] | Capital Trust [Member]
Debt Instrument [Line Items]
Debt Conversion, Converted Instrument, Warrants or Options Issued	4,315	118,377
WYCO Development L.L.C. [Member] | El Paso Pipeline Partners, L.P. [Member]
Debt Instrument [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Financial Guarantee [Member] | El Paso Holdco [Member]
Debt Instrument [Line Items]
Indemnified by parent of subsidiary debt						3,600,000,000
Subsequent Event [Member] | KMI EP Capital Trust I 4.75%, due 2028 [Member]
Debt Instrument [Line Items]
Value of cash issued in debt conversion				$24,000,000
Subsequent Event [Member] | Capital Trust [Member]
Debt Instrument [Line Items]
Conversion of Stock, Shares Converted				969,117
Subsequent Event [Member] | Class P [Member] | Capital Trust [Member]
Debt Instrument [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities				697,473
Subsequent Event [Member] | Warrant [Member] | Capital Trust [Member]
Debt Instrument [Line Items]
Debt Conversion, Converted Instrument, Warrants or Options Issued				1,066,028

Credit_Facilities_and_Restrict

Credit Facilities and Restrictive Covenants (Details) (USD $)	12 Months Ended	0 Months Ended	2 Months Ended
	Dec. 31, 2014	Feb. 04, 2015	Feb. 22, 2015	Nov. 26, 2014	Dec. 31, 2013	Feb. 23, 2015
Kinder Morgan, Inc. [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Term	5 years
Line of Credit Facility, Current Borrowing Capacity	$4,000,000,000			$4,000,000,000
Line of Credit Facility, Maximum Borrowing Capacity Increase				5,000,000,000
Commercial Paper	386,000,000			4,000,000,000	0
Line of Credit Facility, Amount Outstanding	850,000,000				175,000,000
Letters of Credit Outstanding, Amount	223,000,000
Remaining borrowing capacity	2,541,000,000
Kinder Morgan, Inc. [Member] | Secured Debt [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Amount Outstanding	850,000,000
Kinder Morgan, Inc. [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper	386,000,000
Federal Funds Rate [Member] | Kinder Morgan, Inc. [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	0.50%
London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member] | Kinder Morgan, Inc. [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.13%
London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member] | Kinder Morgan, Inc. [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.00%
LIBOR Alternate Base Rate [Member] | Kinder Morgan, Inc. [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.00%
LIBOR Alternate Base Rate [Member] | Minimum [Member] | Kinder Morgan, Inc. [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	0.13%
LIBOR Alternate Base Rate [Member] | Maximum [Member] | Kinder Morgan, Inc. [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.00%
For the Period Ended on or prior to December 31, 2017 [Member] | Kinder Morgan, Inc. [Member] | Restrictive covenant [Member]
Line of Credit Facility [Line Items]
Consolidated Leverage Ratio	6.5
For the Period Ended After December 31, 2017 and on or prior to December 31, 2018 [Member] | Kinder Morgan, Inc. [Member] | Restrictive covenant [Member]
Line of Credit Facility [Line Items]
Consolidated Leverage Ratio	6.25
For the Period Ended After December 31,2018 [Member] | Kinder Morgan, Inc. [Member] | Restrictive covenant [Member]
Line of Credit Facility [Line Items]
Consolidated Leverage Ratio	6
Subsequent Event [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Term		6 months
Subsequent Event [Member] | Bridge Loan [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Amount Outstanding During Period			1,641,000,000
Line of Credit Facility, Fair Value of Amount Outstanding						$1,516,000,000

Debt_Copano_Debt_AcquiredDetai

Debt Copano Debt Acquired(Details) (Copano Energy, L.L.C. [Member], USD $)	Dec. 31, 2013	1-May-13	Dec. 31, 2014
In Millions, unless otherwise specified
7.75% unsecured senior notes due June 1, 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.75%	7.75%
KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.13%		7.13%
KMP Acquisiton of Copano Energy LLC [Member] | 7.75% unsecured senior notes due June 1, 2018 [Member]
Debt Instrument [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt		249
KMP Acquisiton of Copano Energy LLC [Member] | KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]
Debt Instrument [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt		510
Debt Instrument, Interest Rate, Stated Percentage		7.13%
KMP Acquisiton of Copano Energy LLC [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt		404

Debt_Debt_Issuances_and_Repaym

Debt Debt Issuances and Repayments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Apr. 30, 2013	1-May-13
Debt Instrument [Line Items]
Repayments of Debt	$17,801	$12,393	$14,755
3.05% Senior Notes due December 1, 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.05%
4.30% Senior Notes due June1, 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.30%
EPC Building LLC [Member] | KMI Promissory note 3.967%, due 2014 through 2035 [Member] [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.97%
EPC Building LLC [Member] | KMI Promissory note 3.967%, due 2013 through 2035 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.97%
Debt Instrument, Face Amount			468
EPC Building LLC [Member] | Third parties [Member] | KMI Promissory note 3.967%, due 2013 through 2035 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt		0
Debt Instrument, Face Amount			217	251
Kinder Morgan, Inc. [Member] | Senior unsecured term loan facility, variable, due May 6, 2017 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Long-term Debt	650
Repayments of Debt	650
Kinder Morgan, Inc. [Member] | 6.875% Senior Notes due June 15,2014 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.88%
Repayments of Debt	207
Kinder Morgan, Inc. [Member] | KMI 5% Senior Notes due February 15, 2021 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.00%
Proceeds from Issuance of Long-term Debt		750
Kinder Morgan, Inc. [Member] | 2% Senior Notes Due 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	2.00%
Proceeds from Issuance of Long-term Debt	500
Kinder Morgan, Inc. [Member] | KMI 5.625% Senior Notes due November 15, 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.63%
Proceeds from Issuance of Long-term Debt		750
Kinder Morgan, Inc. [Member] | 3.05% Senior Notes due December 1, 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.05%
Proceeds from Issuance of Long-term Debt	1,500
Kinder Morgan, Inc. [Member] | 4.30% Senior Notes due June1, 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.30%
Proceeds from Issuance of Long-term Debt	1,500
Kinder Morgan, Inc. [Member] | 5.30% Senior Notes due December 1, 2034 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.30%
Proceeds from Issuance of Long-term Debt	750
Kinder Morgan, Inc. [Member] | 5.55% Senior Notes due June 1, 2045 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.50%
Proceeds from Issuance of Long-term Debt	1,750
Kinder Morgan Energy Partners, L.P. [Member] | KMP 3.50% Senior Notes due March 1, 2021 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.50%
Proceeds from Issuance of Long-term Debt	750
Kinder Morgan Energy Partners, L.P. [Member] | KMP 3.50% Senior Notes due September 1, 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.50%
Proceeds from Issuance of Long-term Debt		600
Kinder Morgan Energy Partners, L.P. [Member] | KMP 5.50% Senior Notes due March 1, 2044 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.50%
Proceeds from Issuance of Long-term Debt	750
Kinder Morgan Energy Partners, L.P. [Member] | KMP 5% Senior Notes due March 1, 2043 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.00%
Proceeds from Issuance of Long-term Debt		700
Kinder Morgan Energy Partners, L.P. [Member] | KMP 4.25% Senior Notes due September 1, 2024 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.25%
Proceeds from Issuance of Long-term Debt	650
Kinder Morgan Energy Partners, L.P. [Member] | 2.65% Senior Notes due February 1, 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		2.65%
Proceeds from Issuance of Long-term Debt		800
Kinder Morgan Energy Partners, L.P. [Member] | KMP 5.40% Senior Notes due September 1, 2044 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.40%
Proceeds from Issuance of Long-term Debt	550
Kinder Morgan Energy Partners, L.P. [Member] | 4.15% Senior Notes due February 1, 2024 [Member] [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		4.15%
Proceeds from Issuance of Long-term Debt		650
Kinder Morgan Energy Partners, L.P. [Member] | 5.125% senior notes due November 15, 2014 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.13%
Repayments of Debt	500
Kinder Morgan Energy Partners, L.P. [Member] | KMP 5% Senior Notes due December 15, 2013 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.00%
Repayments of Debt		500
El Paso Pipeline Partners Operating Company, L.L.C. [Member] | EPB 4.30% Senior Notes due May 1, 2024 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.30%
Proceeds from Issuance of Long-term Debt	600
El Paso Pipeline Partners Operating Company, L.L.C. [Member] | EPB Notes, 4.10% through 8.00%, due 2013 through 2042 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.00%
Repayments of Debt		88
Copano Energy, L.L.C. [Member] | 7.75% unsecured senior notes due June 1, 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.75%			7.75%
Repayments of Debt		249
Debt Instrument, Repurchase Amount		259
Debt Instrument, Redemption Price, Percentage		103.88%
Copano Energy, L.L.C. [Member] | KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.13%	7.13%
Repayments of Debt		178
Debt Instrument, Repurchase Amount		191
Senior secured term loan credit facility, due May 24, 2015 [Member] | Kinder Morgan, Inc. [Member]
Debt Instrument [Line Items]
Repayments of Debt	$1,528	$1,186

Debt_Kinder_Morgan_GP_Inc_Pref

Debt Kinder Morgan G.P., Inc. Preferred Shares (Details) (USD $)	12 Months Ended		0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Jan. 21, 2015
Debt Instrument [Line Items]
Preferred stock, shares outstanding (in shares)	0	0
Kinder Morgan G.P., Inc. [Member]
Debt Instrument [Line Items]
Preferred stock, shares outstanding (in shares)	100,000
Preferred Stock, Dividends Per Share, Declared	$41.86	$42.10
Preferred Stock, Dividends, Per Share, Cash Paid	$41.88	$42.17
Subsequent Event [Member] | Kinder Morgan G.P., Inc. [Member]
Debt Instrument [Line Items]
Preferred Stock, Dividends Per Share, Declared			$10.55

Debt_Maturities_of_Debt_Detail

Debt Maturities of Debt (Details) (Kinder Morgan, Inc. [Member], USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Kinder Morgan, Inc. [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$2,717
Long-term Debt, Maturities, Repayments of Principal in Year Two	1,684
Long-term Debt, Maturities, Repayments of Principal in Year Three	3,059
Long-term Debt, Maturities, Repayments of Principal in Year Four	2,328
Long-term Debt, Maturities, Repayments of Principal in Year Five	2,819
Long-term Debt, Maturities, Repayments of Principal after Year Five	28,422
Total debt outstanding	$41,029

Debt_Interest_Rates_Interest_R

Debt Interest Rates, Interest Rate Swaps and Contingent Debt (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Debt, Weighted Average Interest Rate	5.02%	5.08%
Preferred stock, par value (in dollars per share)	0.01	$0.01
KMI EP Capital Trust I 4.75%, due 2028 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	4.75%
Kinder Morgan, Inc. [Member] | Senior Notes and debentures, 2.00% through 8.25%, due 2014 through 2098 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	2.00%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.25%
Kinder Morgan Finance Company, LLC [Member] | KMI 5.70% through 6.40% series, due 2016 through 2036 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.70%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	6.40%
EPC Building LLC [Member] | KMI Promissory note 3.967%, due 2014 through 2035 [Member] [Member]
Debt Instrument [Line Items]
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]
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 stock, par value (in dollars per share)	1,000
Kinder Morgan Energy Partners, L.P. [Member] | KMP Senior notes, 2.65% through 9.00%, due 2014 through 2044 [Member]
Debt Instrument [Line Items]
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]
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] [Member]
Debt Instrument [Line Items]
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] | KMP 7.125% Senior Notes due April 1, 2021 (Copano) [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	7.13%	7.13%
El Paso Pipeline Partners Operating Company, L.L.C. [Member] | EPB Notes, 4.10% through 7.50%, due 2015 through 2042 [Member] [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	4.10%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	7.50%
Colorado Interstate Gas Company, L.L.C. [Member] | EPB Notes, 5.95% through 6.85%, due 2015 through 2037 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.95%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	6.85%
Southern LNG Company, L.L.C.(SLNG) [Member] | EPB Senior notes, 9.50% and 9.75%, due 2014 and 2016 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	9.50%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	9.75%
SNG [Member] | EPB Notes, 4.40% through 8.00%, due 2017 through 2032 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	4.40%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	8.00%

Debt_Subsequent_Event_Details

Debt Subsequent Event (Details) (USD $)	12 Months Ended		0 Months Ended		12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Feb. 04, 2015	Jan. 14, 2015	Dec. 31, 2012
Capital Trust [Member]
Debt Instrument [Line Items]
Conversion of Stock, Shares Converted	3,923	107,618
KMI EP Capital Trust I 4.75%, due 2028 [Member]
Debt Instrument [Line Items]
Value of cash issued in debt conversion	99,000	3,000,000
Subsequent Event [Member]
Debt Instrument [Line Items]
Debt Instrument, Term			6 months
Subsequent Event [Member] | Capital Trust [Member]
Debt Instrument [Line Items]
Conversion of Stock, Shares Converted				969,117
Subsequent Event [Member] | KMI EP Capital Trust I 4.75%, due 2028 [Member]
Debt Instrument [Line Items]
Value of cash issued in debt conversion				24,000,000
Class P [Member]
Debt Instrument [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities					535,972,387
Class P [Member] | Capital Trust [Member]
Debt Instrument [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities	2,820	77,442
Class P [Member] | KMI EP Capital Trust I 4.75%, due 2028 [Member]
Debt Instrument [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities					562,521
Class P [Member] | Subsequent Event [Member] | Capital Trust [Member]
Debt Instrument [Line Items]
Stock Issued During Period, Shares, Conversion of Convertible Securities				697,473
Warrant [Member] | Capital Trust [Member]
Debt Instrument [Line Items]
Debt Conversion, Converted Instrument, Warrants or Options Issued	4,315	118,377
Warrant [Member] | Subsequent Event [Member] | Capital Trust [Member]
Debt Instrument [Line Items]
Debt Conversion, Converted Instrument, Warrants or Options Issued				1,066,028

Kinder_Morgan_Inc_Equity_Inter

Kinder Morgan, Inc.- Equity Interests (Details) (USD $)	12 Months Ended			2 Months Ended	0 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Feb. 22, 2015	Jan. 21, 2015	Dec. 31, 2011	Dec. 19, 2014	25-May-12
Class of Stock [Line Items]
Stock Repurchase Program, Remaining Authorized Repurchase Amount	$2
Payments for Repurchase of Warrants	98	465	157
Payments for Repurchase of Common Stock	94	172
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	460,032	83,444	102,033
Share Settlement of Dissenter		128
Dividends Per Common Share Declared for the Period	$1.74	$1.60	$1.40
Common Stock, Dividends, Per Share, Cash Paid	$1.70	$1.56	$1.34
Debt Instrument, Convertible, Conversion Ratio	1
Class of Warrant or Right, Exercise Price of Warrants or Rights	$40
Class of Warrant or Right, Outstanding	298,135,976	347,933,107	439,809,442			0
Warrants Exercised, Number of Warrants	-18,040	-21,208	0
Number of warrants repurchased	-49,783,406	-91,973,585	-65,649,237
Class P [Member]
Class of Stock [Line Items]
Payments for Repurchase of Common Stock	94	172	71
Balance at (in shares)	2,125,147,116	1,030,677,076	1,035,668,596			170,921,140
Shares converted (in shares)			-535,972,387
Shares canceled (in shares)			-2,049,615
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	324,704	89,154	107,553
Stock Repurchased and Retired During Period, Shares	-2,780,337	-5,175,055
Shares Issued During Period for Exercised Warrants	12,402	16,886
Shares Issued During Period, Shares, Merger Transactions	1,096,910,451
Common stock, par value (in dollars per share)	$0.01	$0.01
Value of Stock Available for Sale Under Equity Distribution Agreement							$5,000
Class P [Member] | KMI EP Capital Trust I 4.75%, due 2028 [Member]
Class of Stock [Line Items]
Shares converted (in shares)			-562,521
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	2,820	77,442
Common Class A [Member]
Class of Stock [Line Items]
Balance at (in shares)			0			535,972,387
Shares converted (in shares)			-535,972,387
Shares canceled (in shares)			0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period			0
Common Class B [Member]
Class of Stock [Line Items]
Balance at (in shares)			0			94,132,596
Shares converted (in shares)			-94,132,596
Shares canceled (in shares)			0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period			0
Common Class C [Member]
Class of Stock [Line Items]
Balance at (in shares)			0			2,318,258
Shares converted (in shares)			-2,318,258
Shares canceled (in shares)			0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period			0
KMI's Acquisition of EP [Member]
Class of Stock [Line Items]
Warrants issued during the period	0	81	504,598,883
El Paso Corporation [Member]
Class of Stock [Line Items]
Class of Warrant or Right, Exercise Price of Warrants or Rights								$40
El Paso Corporation [Member] | Class P [Member]
Class of Stock [Line Items]
Share issued (in shares)		53	330,154,610
El Paso Corporation [Member] | Common Class A [Member]
Class of Stock [Line Items]
Share issued (in shares)			0
El Paso Corporation [Member] | Common Class B [Member]
Class of Stock [Line Items]
Share issued (in shares)			0
El Paso Corporation [Member] | Common Class C [Member]
Class of Stock [Line Items]
Share issued (in shares)			0
KMI EP Capital Trust I 4.75%, due 2028 [Member] | Common Class A [Member]
Class of Stock [Line Items]
Shares converted (in shares)			0
KMI EP Capital Trust I 4.75%, due 2028 [Member] | Common Class B [Member]
Class of Stock [Line Items]
Shares converted (in shares)			0
KMI EP Capital Trust I 4.75%, due 2028 [Member] | Common Class C [Member]
Class of Stock [Line Items]
Shares converted (in shares)			0
Subsequent Event [Member] | Class P [Member]
Class of Stock [Line Items]
Share issued (in shares)				20,363,204
Dividend Declared [Member]
Class of Stock [Line Items]
Dividends Per Common Share Declared for the Period					$0.45
Kinder Morgan, Inc. [Member] | Warrant [Member] | El Paso Corporation [Member]
Class of Stock [Line Items]
Class of Warrant or Right, Exercise Price of Warrants or Rights	$40
Sponsor investors [Member] | Class P [Member]
Class of Stock [Line Items]
Share issued (in shares)			198,996,921
Investor retained stock sold in overallotment to public offering			8,700,000
Conversion of Class A, B and C shares to P shares [Member] | Class P [Member]
Class of Stock [Line Items]
Shares canceled (in shares)			-2,000,000
Conversion of EP Trust I Preferred Securities [Member]
Class of Stock [Line Items]
Warrants issued during the period	4,315	118,377	859,796

Sharebased_Compensation_and_Em2

Share-based Compensation and Employee Benefits Share-based Compensation (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Stock Compensation Plan for Non-Employee Directors [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	6 months
Restricted Stock and Long-term Incentive Retention Award Plan [Abstract]
Stock Issued During Period, Shares, Restricted Stock Award, Gross	1,694,668	4,563,495	1,463,388
Stock Issued During Period, Value, Restricted Stock Award, Gross	$61,000,000	$181,000,000	$51,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	-460,032	-83,444	-102,033
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value	-14,000,000	-3,000,000	-3,000,000
Stock Issued During Period, Shares, Restricted Stock Award, Forfeited	-244,227	-251,188	-370,423
Stock Issued During Period, Value, Restricted Stock Award, Forfeitures	-9,000,000	-8,000,000	-12,000,000
Intrinsic Value of Restricted Stock During Period	17,000,000	3,000,000	4,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Share-based Awards Other than Options	170,000,000	177,000,000
Share based compensation, amount vested, percent	100.00%
Allocated Share-based Compensation Expense		2,000,000	7,000,000
Class P [Member]
Restricted Stock and Long-term Incentive Retention Award Plan [Abstract]
Balance at (in shares)	1,030,677,076	1,035,668,596	170,921,140
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	-324,704	-89,154	-107,553
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Restricted Stock or Unit Expense	57,000,000	35,000,000	14,000,000
Restricted Stock [Member]
Restricted Stock and Long-term Incentive Retention Award Plan [Abstract]
Balance at (in shares)				1,163,090
Common Stock, Value, Outstanding	277,000,000	239,000,000	69,000,000	33,000,000
Restricted Stock [Member] | Minimum [Member] | Variable Vesting Periods [Member]
Stock Compensation Plan for Non-Employee Directors [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	1 year
Restricted Stock [Member] | Maximum [Member] | Variable Vesting Periods [Member]
Stock Compensation Plan for Non-Employee Directors [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	10 years
Restricted Stock Compensation Program [Member] | Restricted Stock [Member] | Variable Vesting Periods [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	7,373,294
Restricted Stock Compensation Program [Member] | Year 2014 [Member] | Restricted Stock [Member] | Variable Vesting Periods [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	713,675
Restricted Stock Compensation Program [Member] | Year 2016 [Member] | Restricted Stock [Member] | Variable Vesting Periods [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,337,884
Restricted Stock Compensation Program [Member] | Year 2017 [Member] | Restricted Stock [Member] | Variable Vesting Periods [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,653,507
Restricted Stock Compensation Program [Member] | Year 2018 [Member] | Restricted Stock [Member] | Variable Vesting Periods [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,111,830
Restricted Stock Compensation Program [Member] | Year 2019 [Member] | Restricted Stock [Member] | Variable Vesting Periods [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,720,568
Restricted Stock Compensation Program [Member] | Year 2020 [Member] | Restricted Stock [Member] | Variable Vesting Periods [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	580,759
Restricted Stock Compensation Program [Member] | Year 2021 [Member] | Restricted Stock [Member] | Variable Vesting Periods [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	199,725
Restricted Stock Compensation Program [Member] | Year 2023 [Member] | Restricted Stock [Member] | Variable Vesting Periods [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	55,346
Kinder Morgan Energy Partners, L.P. Common Unit Compensation Plan for Non-Employee Directors [Member] | Restricted Stock [Member] | Six Month Vesting Period [Member]
Stock Compensation Plan for Non-Employee Directors [Abstract]
Restricted stock vested, percent	100.00%
Kinder Morgan, Inc. [Member] | Class P [Member]
Stock Compensation Plan for Non-Employee Directors [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	250,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Net of Forfeitures	6,210	5,710	5,520
Stock Issued During Period, Value, Share-based Compensation, Net of Forfeitures	$220,000	$210,000	$185,000

Noncontrolling_Interests_Detai

Noncontrolling Interests (Details) (USD $)	11 Months Ended	12 Months Ended			1 Months Ended				0 Months Ended
	Nov. 25, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Feb. 28, 2014	Feb. 28, 2013	31-May-14	31-May-13	3-May-13	1-May-13
Noncontrolling Interest [Line Items]
Noncontrolling interests		$350,000,000	$15,192,000,000
Adjustments to Additional Paid in Capital, Reallocation of Noncontrolling Interest	1,640,000,000		5,059,000,000
Income Tax Effects Allocated Directly to Equity, Equity Transactions	19,000,000		93,000,000
Adjustments to Additional Paid in Capital, Other	36,000,000		161,000,000
Subsidiary Share Distribution, Shares Distributed to Parent		1,127,712	976,723	902,367
Kinder Morgan Energy Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Noncontrolling interests		0	7,642,000,000
Investment Owned, Balance, Shares			43,000,000
Economic interest, percent			50.00%
Noncontrolling Interest, Shares or Equity Units Issued					7,935,000	4,600,000
Adjustments to Additional Paid in Capital, Reallocation of Noncontrolling Interest					603,000,000	385,000,000
Value Of Units Available For Sale Under Fourth Amendment Of Equity Distribution Agreement With UBS	2,175,000,000
Value of units available for sale under third amendment of equity distribution agreement with UBS	1,900,000,000
Distribution Made to Limited Partner, Distributions Declared, Per Unit		$4.17	$5.33	4.98
Distribution Made to Limited Partner, Distributions Paid, Per Unit		$5.53	$5.26	4.85
Cash distributions paid to public unitholders		1,654,000,000	1,372,000,000	1,081,000,000
El Paso Pipeline Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Noncontrolling interests		0	4,122,000,000
Noncontrolling Interest, Shares or Equity Units Issued							7,820,000
Adjustments to Additional Paid in Capital, Reallocation of Noncontrolling Interest							242,000,000
Value of units available for sale under equity distribution agreement	500,000,000
Distribution Made to Limited Partner, Distributions Declared, Per Unit		$1.95	$2.55	1.74
Distribution Made to Limited Partner, Distributions Paid, Per Unit		$2.60	$2.51	1.13
Cash distributions paid to public unitholders		347,000,000	318,000,000	137,000,000
Kinder Morgan Management, LLC [Member]
Noncontrolling Interest [Line Items]
Noncontrolling interests		0	3,142,000,000
Value of units available for sale under equity distribution agreement	500,000,000
Common Stock Dividends, Shares		7,794,183	6,588,477	5,586,579
Other noncontrolling interests [Member]
Noncontrolling Interest [Line Items]
Noncontrolling interests		350,000,000	286,000,000
KMP Acquisiton of Copano Energy LLC [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Noncontrolling Interest, Shares or Equity Units Issued								43,371,000
Adjustments to Additional Paid in Capital, Reallocation of Noncontrolling Interest								0
KMP Acquisiton of Copano Energy LLC [Member] | Common Units [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable									3,733,000,000
Business Acquisition, Share Price										$86.08
Common Units [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Investment Owned, Balance, Shares			22,000,000
B Units [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Investment Owned, Balance, Shares			5,000,000
I-Units [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Investment Owned, Balance, Shares			16,000,000
Limited partner units [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Equity Method Investment, Ownership Percentage			9.80%
Limited partner units [Member] | El Paso Pipeline Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Equity Method Investment, Ownership Percentage			41.00%
General Partner [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest			2.00%
General Partner [Member] | El Paso Pipeline Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest			2.00%
General Partner and Limited Partner interests [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Equity Method Investment, Ownership Percentage			11.60%
Common Stock [Member] | El Paso Pipeline Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Investment Owned, Balance, Shares			90,000,000
Common Stock [Member] | Kinder Morgan Management, LLC [Member]
Noncontrolling Interest [Line Items]
Investment Owned, Balance, Shares			16,000,000
Equity Method Investment, Ownership Percentage			13.00%
Equity distribution agreement [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Noncontrolling Interest, Shares or Equity Units Issued		5,513,000	10,814,000
Adjustments to Additional Paid in Capital, Reallocation of Noncontrolling Interest		441,000,000	900,000,000
Equity distribution agreement [Member] | El Paso Pipeline Partners, L.P. [Member]
Noncontrolling Interest [Line Items]
Noncontrolling Interest, Shares or Equity Units Issued		7,314,000	2,038,000
Adjustments to Additional Paid in Capital, Reallocation of Noncontrolling Interest		275,000,000	85,000,000
Equity distribution agreement [Member] | Kinder Morgan Management, LLC [Member]
Noncontrolling Interest [Line Items]
Noncontrolling Interest, Shares or Equity Units Issued		1,735,000	2,640,000
Adjustments to Additional Paid in Capital, Reallocation of Noncontrolling Interest		$134,000,000	$210,000,000

Sharebased_Compensation_and_Em3

Share-based Compensation and Employee Benefits Pensions and Other Postretirement Benefit Plans (Details) (USD $)	5 Months Ended		7 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	23-May-12	Jul. 31, 2013	Dec. 31, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets					$380
Defined Benefit Plan, Fair Value of Plan Assets	380				389	380
Components of Accumulated Other Comprehensive Income (Loss) [Abstract]
Unrecognized net actuarial loss					3
Unrecognized prior service credit					1
Actuarial Assumptions and Sensitivity Analysis [Abstract]
discount rate, post aquistion through year end				4.01%
Per capita cost of covered health care benefits rate by year 2019					4.50%
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components					2	2
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation					47	45
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components					-2	-1
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation					-40	-39
Savings plan [Member]
Savings Plan [Abstract]
Defined Contribution Plan, Employer Matching Contribution, Percent					5.00%
Defined Contribution Plan, Cost Recognized					42	40	32
United States Pension Plan of US Entity [Member]
Pension Plans [Abstract]
Defined Benefit Plan,Vesting Period					3 years
Limited Partnership [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	164				155	164
Mutual funds investment type [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	7				3	7
Insurance Contract, Rights and Obligations [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	46				49	46
Common collective trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	85				71	85
Fixed Income Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	65				63	65
Money Market Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				23	0
Domestic Equity Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	13				25	13
Kinder Morgan, Inc. [Member]
Components of Accumulated Other Comprehensive Income (Loss) [Abstract]
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Gains (Losses), before Tax					2
Kinder Morgan, Inc. [Member] | 2015 - 2019 [Member]
Expected Payment of Future Benefits and Employer Contributions [Abstract]
Medicare prescription drug, improvement and modernization act, annual subsidy					2
Kinder Morgan, Inc. [Member] | 2020 - 2024 [Member]
Expected Payment of Future Benefits and Employer Contributions [Abstract]
Medicare prescription drug, improvement and modernization act, annual subsidy					12
Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	177				127	177
Fair Value, Inputs, Level 1 [Member] | Limited Partnership [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	92				76	92
Fair Value, Inputs, Level 1 [Member] | Mutual funds investment type [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	7				3	7
Fair Value, Inputs, Level 1 [Member] | Insurance Contract, Rights and Obligations [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 1 [Member] | Common collective trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 1 [Member] | Fixed Income Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	65				0	65
Fair Value, Inputs, Level 1 [Member] | Money Market Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				23	0
Fair Value, Inputs, Level 1 [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	13				25	13
Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	157				213	157
Fair Value, Inputs, Level 2 [Member] | Limited Partnership [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	72				79	72
Fair Value, Inputs, Level 2 [Member] | Mutual funds investment type [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 2 [Member] | Insurance Contract, Rights and Obligations [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 2 [Member] | Common collective trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	85				71	85
Fair Value, Inputs, Level 2 [Member] | Fixed Income Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				63	0
Fair Value, Inputs, Level 2 [Member] | Money Market Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 2 [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	46				49	46
Fair Value, Inputs, Level 3 [Member] | Limited Partnership [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 3 [Member] | Mutual funds investment type [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 3 [Member] | Insurance Contract, Rights and Obligations [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	46				49	46
Fair Value, Inputs, Level 3 [Member] | Common collective trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 3 [Member] | Fixed Income Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 3 [Member] | Money Market Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Fair Value, Inputs, Level 3 [Member] | Domestic Equity Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
January 1, 2014 [Member]
Other Postretirement Benefit Plans [Abstract]
Purchase of Medical Coverage through Medicare Exchange Participant, Age					65
United States Pension Plan of US Entity [Member]
Savings Plan [Abstract]
Defined Benefit Plan, Percent of Employees Covered					100.00%
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation			2,792		2,563	2,792
Defined Benefit Plan, Service Cost					21	25	18
Defined Benefit Plan, Interest Cost					112	92	67
Defined Benefit Plan, Actuarial Gain (Loss)					294	-132
Defined Benefit Plan, Benefits Paid					-186	-239
Defined Benefit Plan, Contributions by Plan Participants					0	0
Defined Benefit Plan, Gross Prescription Drug Subsidy Receipts Received					0	0
Defined Benefit Plan, Plan Amendments					0	25
Defined Benefit Plan, Benefit Obligation	2,563			2,792	2,804	2,563	2,792
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets			2,240		2,333	2,240
Defined Benefit Plan, Actual Return on Plan Assets					180	254
Defined Benefit Plan, Contributions by Employer					50	78
Defined Benefit Plan, Fair Value of Plan Assets	2,333			2,240	2,377	2,333	2,240
Defined Benefit Plan, Funded Status of Plan	-230				-427	-230
Components of Funded Status [Abstract]
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	0				0	0
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	0				0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	-230				-427	-230
Components of Accumulated Other Comprehensive Income (Loss) [Abstract]
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Gains (Losses), before Tax	-10				-296	-10
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax	-5				-4	-5
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	-15				-300	-15
Expected Payment of Future Benefits and Employer Contributions [Abstract]
Defined Benefit Plan, Expected Future Benefit Payments, 2014					190
Defined Benefit Plan, Expected Future Benefit Payments, 2015					193
Defined Benefit Plan, Expected Future Benefit Payments, 2016					193
Defined Benefit Plan, Expected Future Benefit Payments, 2017					195
Defined Benefit Plan, Expected Future Benefit Payments, 2018					195
Defined Benefit Plan, Expected Future Benefit Payments, 2019-2023					965
Defined Benefit Plan, Expected Future Benefit Payments, Remainder of Fiscal Year					50
Actuarial Assumptions and Sensitivity Analysis [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.45%			3.40%	3.66%	4.45%	3.40%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	3.50%			3.00%	4.50%	3.50%	3.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate		4.50%		4.03%	4.45%	3.40%	4.22%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets		8.90%		8.11%	7.50%	8.00%	8.44%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase					3.50%	3.00%	3.50%
Components of Net Benefit Cost and Other Amounts Recognized in Other Comprehensive Income [Abstract]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)					0	0	-1
Defined Benefit Plan, Future Amortization of Gain (Loss)					0	0	10
Defined Benefit Plan, Expected Return on Plan Assets					171	175	110
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements and Curtailments					0	-3	-2
Defined Benefit Plan, Net Periodic Benefit Cost					-38	-61	-18
Other comprehensive income defined benefit plan net loss gain arising during period					285	-211	85
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost (Credit) Arising During Period, before Tax					0	25	-17
Other comprehensive income defined benefit plan amortization of net actuarial gain loss					0	3	-10
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax					0	0	1
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Gain (Loss), before Tax					285	-183	59
Total Net benefit cost and other comprehensive income (loss) recognized					247	-244	41
Pension Plans, Defined Benefit [Member] | Other Assets [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	13				-15	13
Pension Plans, Defined Benefit [Member] | Private Equity Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	9				10	9
Pension Plans, Defined Benefit [Member] | Equity Trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	235				199	235
Pension Plans, Defined Benefit [Member] | Limited Partnership [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	28				16	28
Pension Plans, Defined Benefit [Member] | Asset-backed Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	29				28	29
Pension Plans, Defined Benefit [Member] | US Government Agencies Debt Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	120				190	120
Pension Plans, Defined Benefit [Member] | Corporate Bond Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	220				247	220
Pension Plans, Defined Benefit [Member] | Common and preferred stock [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	498				459	498
Pension Plans, Defined Benefit [Member] | Mutual funds investment type [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	226				269	226
Pension Plans, Defined Benefit [Member] | Insurance Contract, Rights and Obligations [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	15				15	15
Pension Plans, Defined Benefit [Member] | Common collective trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets					920
Defined Benefit Plan, Fair Value of Plan Assets	920				863	920
Pension Assets At Fair Value Classified in each Level [Abstract]
Percent of funds invested in fixed income securities					47.00%	36.00%
Percent of funds invested in equity securities					53.00%	62.00%
Percent of funds invested in short-term securities						2.00%
Pension Plans, Defined Benefit [Member] | Money Market Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	20				96	20
Pension Plans, Defined Benefit [Member] | Mutual funds [Member]
Pension Assets At Fair Value Classified in each Level [Abstract]
Percent of funds invested in fixed income securities					74.00%	60.00%
Percent of fund invested in equity and other investments					26.00%	40.00%
Pension Plans, Defined Benefit [Member] | Class P [Member]
Pension Assets At Fair Value Classified in each Level [Abstract]
Amount of plan assets invested in parent company common stock					252	229
Pension Plans, Defined Benefit [Member] | Kinder Morgan, Inc. [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation	2,516				2,719	2,516
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	590				535	590
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Other Assets [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Private Equity Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Limited Partnership [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Asset-backed Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | US Government Agencies Debt Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Corporate Bond Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Common and preferred stock [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	498				459	498
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Mutual funds investment type [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	92				71	92
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Insurance Contract, Rights and Obligations [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Common collective trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Money Market Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				5	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	1,691				1,801	1,691
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Other Assets [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	13				-15	13
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Private Equity Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0					0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	235				199	235
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Limited Partnership [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Asset-backed Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	29				28	29
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | US Government Agencies Debt Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	120				190	120
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Corporate Bond Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	220				247	220
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Common and preferred stock [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Mutual funds investment type [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	134				198	134
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Insurance Contract, Rights and Obligations [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Common collective trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	920				863	920
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Money Market Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	20				91	20
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets			87		52	87
Defined Benefit Plan, Fair Value of Plan Assets	52				41	52
Changes in Pension and OPEB Assets [Abstract]
Defined Benefit Plan, Transfers Between Measurement Levels					0	0
Gain (Loss) on Investments					7	4
Defined Benefit Plan, Purchases, Sales, and Settlements					-18	-39
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Other Assets [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Private Equity Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets			9		9	9
Defined Benefit Plan, Fair Value of Plan Assets	9				10	9
Changes in Pension and OPEB Assets [Abstract]
Defined Benefit Plan, Transfers Between Measurement Levels					0	0
Gain (Loss) on Investments					2	1
Defined Benefit Plan, Purchases, Sales, and Settlements					-1	-1
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Limited Partnership [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets			24		28	24
Defined Benefit Plan, Fair Value of Plan Assets	28				16	28
Changes in Pension and OPEB Assets [Abstract]
Defined Benefit Plan, Transfers Between Measurement Levels					0	0
Gain (Loss) on Investments					5	3
Defined Benefit Plan, Purchases, Sales, and Settlements					-17	1
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Asset-backed Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | US Government Agencies Debt Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Corporate Bond Securities [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Common and preferred stock [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Mutual funds investment type [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets			40			40
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Changes in Pension and OPEB Assets [Abstract]
Defined Benefit Plan, Transfers Between Measurement Levels						0
Gain (Loss) on Investments						0
Defined Benefit Plan, Purchases, Sales, and Settlements						-40
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Insurance Contract, Rights and Obligations [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets			14		15	14
Defined Benefit Plan, Fair Value of Plan Assets	15				15	15
Changes in Pension and OPEB Assets [Abstract]
Defined Benefit Plan, Transfers Between Measurement Levels					0	0
Gain (Loss) on Investments					0	0
Defined Benefit Plan, Purchases, Sales, and Settlements					0	1
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Common collective trusts [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Money Market Funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets	0				0	0
Pension Plans, Defined Benefit [Member] | Private Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets					0
Other Postretirement Benefit Plan [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation			720		631	720
Defined Benefit Plan, Service Cost					0	0	0
Defined Benefit Plan, Interest Cost					25	23	18
Defined Benefit Plan, Actuarial Gain (Loss)					15	-38
Defined Benefit Plan, Benefits Paid					-52	-54
Defined Benefit Plan, Contributions by Plan Participants					3	11
Defined Benefit Plan, Gross Prescription Drug Subsidy Receipts Received					2	6
Defined Benefit Plan, Plan Amendments					0	-37
Defined Benefit Plan, Benefit Obligation	631			720	624	631	720
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets			341		380	341
Defined Benefit Plan, Actual Return on Plan Assets					32	40
Defined Benefit Plan, Contributions by Employer					26	42
Defined Benefit Plan, Fair Value of Plan Assets	380			341	389	380	341
Defined Benefit Plan, Funded Status of Plan	-251				-235	-251
Components of Funded Status [Abstract]
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	224				173	224
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	-32				-22	-32
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	-443				-386	-443
Components of Accumulated Other Comprehensive Income (Loss) [Abstract]
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Gains (Losses), before Tax	-17				-27	-17
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax	21				20	21
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	4				-7	4
Expected Payment of Future Benefits and Employer Contributions [Abstract]
Defined Benefit Plan, Expected Future Benefit Payments, 2014					46
Defined Benefit Plan, Expected Future Benefit Payments, 2015					46
Defined Benefit Plan, Expected Future Benefit Payments, 2016					45
Defined Benefit Plan, Expected Future Benefit Payments, 2017					45
Defined Benefit Plan, Expected Future Benefit Payments, 2018					44
Defined Benefit Plan, Expected Future Benefit Payments, 2019-2023					209
Defined Benefit Plan, Expected Future Benefit Payments, Remainder of Fiscal Year					14
Actuarial Assumptions and Sensitivity Analysis [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.34%			3.34%	3.56%	4.34%	3.34%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.00%		3.34%		4.34%	3.62%	4.11%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets		8.90%		7.72%	7.43%	7.35%	8.21%
discount rate, prior to aquisition		4.25%
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year					7.00%
Components of Net Benefit Cost and Other Amounts Recognized in Other Comprehensive Income [Abstract]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)					-2	-1	-1
Defined Benefit Plan, Future Amortization of Gain (Loss)					-1	3	4
Defined Benefit Plan, Expected Return on Plan Assets					24	22	15
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements and Curtailments					0	0	-1
Defined Benefit Plan, Net Periodic Benefit Cost					-2	3	5
Other comprehensive income defined benefit plan net loss gain arising during period					10	-50	25
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost (Credit) Arising During Period, before Tax					0	-18	-4
Other comprehensive income defined benefit plan amortization of net actuarial gain loss					0	-3	-5
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax					1	1	1
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Gain (Loss), before Tax					11	-70	17
Total Net benefit cost and other comprehensive income (loss) recognized					9	-67	22
Other Postretirement Benefit Plan [Member] | Equity Securities [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations	70.00%				67.00%	70.00%
Other Postretirement Benefit Plan [Member] | Fixed Income Securities [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations	30.00%				33.00%	30.00%
Other Postretirement Benefit Plan [Member] | Kinder Morgan, Inc. [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation	534				553	534
Components of Accumulated Other Comprehensive Income (Loss) [Abstract]
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets	60				145	60
Other Postretirement Benefit Plan [Member] | El Paso LLC [Member]
Actuarial Assumptions and Sensitivity Analysis [Abstract]
After-tax expected return on plan assets, used to determine benefit cost	24.00%				21.00%	24.00%
Other Postretirement Benefit Plan [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets			44		46	44
Defined Benefit Plan, Fair Value of Plan Assets	46				49	46
Changes in Pension and OPEB Assets [Abstract]
Defined Benefit Plan, Transfers Between Measurement Levels					0	0
Gain (Loss) on Investments					-3	0
Defined Benefit Plan, Purchases, Sales, and Settlements					6	2
Other Postretirement Benefit Plan [Member] | Fixed Income Securities [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					30.00%
Other Postretirement Benefit Plan [Member] | Equity Securities [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					70.00%
Other Postretirement Benefit Plan [Member] | Insurance Contract, Rights and Obligations [Member] | Fair Value, Inputs, Level 3 [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets			44		46	44
Defined Benefit Plan, Fair Value of Plan Assets	46				49	46
Changes in Pension and OPEB Assets [Abstract]
Defined Benefit Plan, Transfers Between Measurement Levels					0	0
Gain (Loss) on Investments					-3	0
Defined Benefit Plan, Purchases, Sales, and Settlements					$6	$2
Minimum [Member] | Pension Plans, Defined Benefit [Member] | Cash [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					0.00%
Minimum [Member] | Pension Plans, Defined Benefit [Member] | Other Investments [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					0.00%
Minimum [Member] | Pension Plans, Defined Benefit [Member] | Alternative investments [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					0.00%
Minimum [Member] | Pension Plans, Defined Benefit [Member] | Fixed Income Securities [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					40.00%
Minimum [Member] | Pension Plans, Defined Benefit [Member] | Equity Securities [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					34.00%
Maximum [Member] | Pension Plans, Defined Benefit [Member] | Cash [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					5.00%
Maximum [Member] | Pension Plans, Defined Benefit [Member] | Other Investments [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					2.00%
Maximum [Member] | Pension Plans, Defined Benefit [Member] | Alternative investments [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					10.00%
Maximum [Member] | Pension Plans, Defined Benefit [Member] | Fixed Income Securities [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					50.00%
Maximum [Member] | Pension Plans, Defined Benefit [Member] | Equity Securities [Member]
Plan Assets [Abstract]
Defined Benefit Plan, Actual Plan Asset Allocations					58.00%

Sharebased_Compensation_and_Em4

Share-based Compensation and Employee Benefits Other Plans (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Kinder Morgan Energy Partners, L.P. [Domain]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Multi-employer pension plan expense	$13	$11	$11
Trans Mountain Pipeline [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost	10	11	11
Defined Benefit Plan, Net Periodic Benefit Cost, next twelve months	14
Expected Defined Benefit Pension and OPEB contribution, next twelve months	$11

Related_Party_Transactions_Aff

Related Party Transactions Affiliated Balances (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
RELATED PARTY ASSETS
Other current assets	$746	$436
Deferred charges and other assets	2,239	2,577
Affiliated Entity [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	31
RELATED PARTY ASSETS
Accounts receivable, net		19
Other current assets	3	3
Deferred charges and other assets	46	47
Total Assets	80	69
RELATED PARTY LIABILITIES [Abstract]
Notes Payable, Related Parties, Current	6	6
Accounts Payable, Related Parties, Current	22	9
Notes Payable, Related Parties, Noncurrent	172	169
Due to Related Parties	$200	$184

Related_Party_Transactions_Not1

Related Party Transactions Notes Receivable (Details) (USD $)	3 Months Ended	7 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Mar. 14, 2013	Dec. 31, 2014	25-May-12
Express Pipeline System [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Related Party Transaction [Line Items]
Equity Method Investment, Ownership Percentage			33.33%	33.33%
ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member] | Plantation Pipeline Company [Member]
Related Party Transaction [Line Items]
Notes Receivable, Related Parties			48
Notes Receivable, Related Parties, Current			1
ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member] | ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member] | Plantation Pipeline Company [Member]
Related Party Transaction [Line Items]
Equity Method Investment, Ownership Percentage					51.17%
KMI's Acquisition of El Paso Corporation [Member] | Gulf LNG Holdings Group LLC [Member] | Gulf LNG Holdings Group LLC long-term note receivable [Member] | El Paso LLC [Member]
Related Party Transaction [Line Items]
Equity Method Investment, Ownership Percentage						50.00%
KMI's Acquisition of El Paso Corporation [Member] | KMI's Acquisition of EP [Member] | El Paso LLC [Member]
Related Party Transaction [Line Items]
Notes Receivable, Related Parties						85
Fixed Income Securities [Member] | KMI's Acquisition of El Paso Corporation [Member] | Gulf LNG Holdings Group LLC [Member] | El Paso LLC [Member]
Related Party Transaction [Line Items]
Proceeds from Related Party Debt	10	75
ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member] | ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member] | Plantation Pipeline Company [Member]
Related Party Transaction [Line Items]
Notes Receivable, Related Parties					47
ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member] | Notes Receivable [Member] | ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member] | Plantation Pipeline Company [Member]
Related Party Transaction [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					4.25%
Notes Receivable, Balloon Payment, Related Parties					45
Gulf LNG Holdings Group LLC long-term note receivable [Member] | Notes Receivable [Member] | KMI's Acquisition of EP [Member] | Gulf LNG Holdings Group LLC [Member]
Related Party Transaction [Line Items]
Debt Instrument, Interest Rate, Stated Percentage						12.00%

Related_Party_Transactions_Sub

Related Party Transactions Subsequent Event (Details) (USD $)	3 Months Ended	7 Months Ended	12 Months Ended
	Mar. 31, 2013	Dec. 31, 2012	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	25-May-12	Feb. 03, 2015	Dec. 23, 2014
Totem [Member] | EPB financing obligations payable to WYCO [Member]
Related Party Transaction [Line Items]
Notes Receivable, Related Parties, Current				$1,000,000
Plantation Pipeline Company [Member] | ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member]
Related Party Transaction [Line Items]
Notes Receivable, Related Parties, Current					1,000,000
Notes Receivable, Related Parties					48,000,000
ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member] | Plantation Pipeline Company [Member] | ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member]
Related Party Transaction [Line Items]
Notes Receivable, Related Parties				47,000,000
Midcontinent Express Pipeline LLC [Member]
Related Party Transaction [Line Items]
Equity Method Investment, Ownership Percentage				50.00%
Line of Credit [Member] | Kinder Morgan, Inc. [Member] | Midcontinent Express Pipeline LLC [Member] | Midcontinent Express Pipeline LLC [Member] | KMI loan agreement with MEP [Member]
Related Party Transaction [Line Items]
Line of Credit Facility, Fair Value of Amount Outstanding					0
Notes Receivable [Member] | Gulf LNG Holdings Group LLC long-term note receivable [Member] | Gulf LNG Holdings Group LLC [Member] | KMI's Acquisition of EP [Member]
Related Party Transaction [Line Items]
Debt Instrument, Interest Rate, Stated Percentage						12.00%
Notes Receivable [Member] | ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member] | Plantation Pipeline Company [Member] | ExxonMobile and Kinder Morgan term loan agreement with Plantation. [Member]
Related Party Transaction [Line Items]
Debt Instrument, Periodic Payment Terms, Balloon Payment to be Paid				45,000,000
Debt Instrument, Interest Rate, Stated Percentage				4.25%
KMI's Acquisition of El Paso Corporation [Member] | El Paso LLC [Member] | KMI's Acquisition of EP [Member]
Related Party Transaction [Line Items]
Notes Receivable, Related Parties						85,000,000
Gulf LNG Holdings Group LLC long-term note receivable [Member] | KMI's Acquisition of El Paso Corporation [Member] | El Paso LLC [Member] | Gulf LNG Holdings Group LLC [Member]
Related Party Transaction [Line Items]
Equity Method Investment, Ownership Percentage						50.00%
Fixed Income Securities [Member] | KMI's Acquisition of El Paso Corporation [Member] | El Paso LLC [Member] | Gulf LNG Holdings Group LLC [Member]
Related Party Transaction [Line Items]
Repayment of Notes Receivable from Related Parties	10,000,000	75,000,000
Subsequent Event [Member] | KMI loan agreement with MEP [Member] | Midcontinent Express Pipeline LLC [Member] | KMI loan agreement with MEP [Member]
Related Party Transaction [Line Items]
Renewal Term			1 year
Subsequent Event [Member] | Line of Credit [Member] | Kinder Morgan, Inc. [Member] | Midcontinent Express Pipeline LLC [Member] | Midcontinent Express Pipeline LLC [Member] | KMI loan agreement with MEP [Member]
Related Party Transaction [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity							40,000,000
Line of Credit Facility, Fair Value of Amount Outstanding				0
Subsequent Event [Member] | Line of Credit [Member] | Minimum [Member] | Kinder Morgan, Inc. [Member] | Midcontinent Express Pipeline LLC [Member] | Midcontinent Express Pipeline LLC [Member] | KMI loan agreement with MEP [Member]
Related Party Transaction [Line Items]
Line of Credit Facility, Current Borrowing Capacity							$2,000,000
Subsequent Event [Member] | KMI loan agreement with MEP [Member] | Midcontinent Express Pipeline LLC [Member] | KMI loan agreement with MEP [Member]
Related Party Transaction [Line Items]
Equity Method Investment, Ownership Percentage								50.00%

Commitments_and_Contingent_Lia2

Commitments and Contingent Liabilities Leases (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating Leased Assets [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$97
Operating Leases, Future Minimum Payments, Due in Two Years	85
Operating Leases, Future Minimum Payments, Due in Three Years	75
Operating Leases, Future Minimum Payments, Due in Four Years	67
Operating Leases, Future Minimum Payments, Due in Five Years	65
Operating Leases, Future Minimum Payments, Due Thereafter	289
Operating Leases, Future Minimum Payments Due	678
Operating Leases, Rent Expense	$114	$126	$94
Minimum [Member]
Operating Leased Assets [Line Items]
Lessee Leasing Arrangements, Operating Leases, Term of Contract	1 year
Maximum [Member]
Operating Leased Assets [Line Items]
Lessee Leasing Arrangements, Operating Leases, Term of Contract	39 years

Commitments_and_Contingent_Lia3

Commitments and Contingent Liabilities Commitments (Details) (USD $)	12 Months Ended
In Billions, unless otherwise specified	Dec. 31, 2014
Oil and Gas Delivery Commitments and Contracts [Line Items]
Share of capital expenditures including ancillary facilities	$1.30
Elba Liquification Company LLC [Member]
Oil and Gas Delivery Commitments and Contracts [Line Items]
Equity Method Investment, Ownership Percentage	51.00%

Commitments_and_Contingent_Lia4

Commitments and Contingent Liabilities Contingent Debt (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Cortez Pipeline Company [Member]
Guarantor Obligations [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Cortez Expansion Capital Corp [Member]
Guarantor Obligations [Line Items]
Percentage of Debt Guaranteed	100.00%
Letter of Credit [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	1,069	$74
Revolving Credit Facility [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	200

Commitments_and_Contingent_Lia5

Commitments and Contingent Liabilities Guarantees and Indemnifications (Details) (El Paso LLC [Member], USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
El Paso LLC [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$688

Energy_Commodity_Price_Risk_Ma

Energy Commodity Price Risk Managment (Details) (Energy Related Derivative [Member])	Dec. 31, 2014
	MMBbls
Designated as Hedging Instrument [Member] | Crude Oil Basis [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	-10.8
Designated as Hedging Instrument [Member] | Natural Gas Basis [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	-8
Designated as Hedging Instrument [Member] | Crude Oil Fixed Price [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	-10.9
Designated as Hedging Instrument [Member] | Natural Gas Fixed Price [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	-27.2
Not Designated as Hedging Instrument [Member] | Natural Gas Basis [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	6.5
Not Designated as Hedging Instrument [Member] | Crude Oil Fixed Price [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	-14.9
Not Designated as Hedging Instrument [Member] | Natural Gas Fixed Price [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	2
Not Designated as Hedging Instrument [Member] | Natural Gas Liquids Fixed Price [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	-2.1

Interest_Rate_Risk_Managment_D

Interest Rate Risk Managment (Details) (USD $)	1 Months Ended
In Millions, unless otherwise specified	Nov. 30, 2014	Sep. 30, 2014	Feb. 28, 2014	Dec. 31, 2014	Dec. 31, 2013	Sep. 29, 2014
Derivative [Line Items]
Debt fair value adjustments				$1,934	$1,977
Number of Fixed-to-Variable Interest Rate Swap Agreements Entered Into	21	5	4
3.50% Senior Notes due March 1, 2021 [Member]
Derivative [Line Items]
Interest rate, stated percentage				3.50%
4.25% Senior Notes due September 1, 2024 [Member]
Derivative [Line Items]
Interest rate, stated percentage				4.25%
4.30% Senior Notes due June1, 2025 [Member]
Derivative [Line Items]
Interest rate, stated percentage				4.30%
3.05% Senior Notes due December 1, 2019 [Member]
Derivative [Line Items]
Interest rate, stated percentage				3.05%
Interest Rate Swap [Member]
Derivative [Line Items]
Derivative, Notional Amount				9,200	5,400
Interest Rate Swap [Member] | 3.50% Senior Notes due March 1, 2021 [Member]
Derivative [Line Items]
Derivative, Notional Amount			500
Interest Rate Swap [Member] | 4.25% Senior Notes due September 1, 2024 [Member]
Derivative [Line Items]
Derivative, Notional Amount						600
Interest Rate Swap [Member] | 4.30% Senior Notes due June 1, 2025 and 3.05% Senior Notes due December 1, 2019 [Member]
Derivative [Line Items]
Derivative, Notional Amount	3,000

Risk_Management_Fair_Value_of_

Risk Management Fair Value of Derivative Contracts (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	$359	$231
Liability derivatives	-9	-88
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	997	357
Liability derivatives	-162	-311
Not Designated as Hedging Instrument [Member] | Energy Related Derivative [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	269	4
Liability derivatives	-2	-5
Not Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	73	4
Not Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives	-2	-5
Not Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Deferred charges and other assets/(Other long-term liabilities and deferred credits) [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	196	0
Not Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Non Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives	0	0
Not Designated as Hedging Instrument [Member] | Power Derivative Contract [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	10	18
Liability derivatives	-73	-127
Not Designated as Hedging Instrument [Member] | Power Derivative Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	10	7
Not Designated as Hedging Instrument [Member] | Power Derivative Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives	-57	-54
Not Designated as Hedging Instrument [Member] | Power Derivative Contract [Member] | Deferred charges and other assets/(Other long-term liabilities and deferred credits) [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	0	11
Not Designated as Hedging Instrument [Member] | Power Derivative Contract [Member] | Non Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives	-16	-73
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	279	22
Liability derivatives	-75	-132
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	718	335
Liability derivatives	-87	-179
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	315	76
Liability derivatives	-34	-63
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	309	18
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives	-34	-33
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Deferred charges and other assets/(Other long-term liabilities and deferred credits) [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	6	58
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Non Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives	0	-30
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	403	259
Liability derivatives	-53	-116
Designated as Hedging Instrument [Member] | Fair Value Hedging [Member] | Interest Rate Swap [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	143	87
Designated as Hedging Instrument [Member] | Fair Value Hedging [Member] | Interest Rate Swap [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives	0	0
Designated as Hedging Instrument [Member] | Fair Value Hedging [Member] | Interest Rate Swap [Member] | Deferred charges and other assets/(Other long-term liabilities and deferred credits) [Member]
Derivatives, Fair Value [Line Items]
Asset derivatives	260	172
Designated as Hedging Instrument [Member] | Fair Value Hedging [Member] | Interest Rate Swap [Member] | Non Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability derivatives	($53)	($116)

Risk_Management_Debt_Fair_Valu

Risk Management Debt Fair Value Adjustments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Derivative [Line Items]
Amortization Period of Deferred Gain (Loss) on Discontinuation of Interest Rate Fair Value Hedge	16 years
Deferred Gain (Loss) on Discontinuation of Interest Rate Fair Value Hedge	$454	$517
Amount the adjustment to fair value of debt was increased by related to the fair value of interest rate swaps	347	143
Debt fair value adjustments	1,934	1,977
Purchase Accounting [Member]
Derivative [Line Items]
Debt fair value adjustments	1,221	1,379
Unamortized Debt Discount Amounts [Member]
Derivative [Line Items]
Debt fair value adjustments	$88	$62

Effect_of_Derivative_Contracts

Effect of Derivative Contracts on the Income Statement (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Debt fair value adjustments	$1,934	$1,977
Energy Related Derivative [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	11	-10	-3
Energy Related Derivative [Member] | Revenues—Natural gas sales
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-7	0	1
Energy Related Derivative [Member] | Revenues—Product sales and other
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	20	-10	-4
Energy Related Derivative [Member] | Costs of sales
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0	2	0
Energy Related Derivative [Member] | Other expense (income) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-2	-2	0
Purchase Accounting [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Debt fair value adjustments	1,221	1,379
Designated as Hedging Instrument [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	408	-38	82
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)	25	-11	8
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	11	3	-11
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	-15	7	-5
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Interest expense | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Income, Net	207	-425	55
Designated as Hedging Instrument [Member] | Interest Rate Swap [Member] | Interest expense | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	-4	2	2
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0	0	0
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	208
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Other Comprehensive Income (Loss) [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net	423	-45	87
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Revenues—Natural gas sales | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	-1	0	4
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0	0	0
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Revenues—Product sales and other | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	26	-13	-15
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	11	3	-11
Designated as Hedging Instrument [Member] | Energy Related Derivative [Member] | Costs of sales | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain/(loss)reclassified fromAccumulated OCIinto income(effective portion)	4	0	17
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	0	0	0
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Interest expense | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Income, Net	($204)	$425	($55)

Credit_Risks_Details

Credit Risks (Details) (Energy Related Derivative [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013
Energy Related Derivative [Member]
Credit Derivatives [Line Items]
Letters of Credit Outstanding, Amount	$20,000,000	$167,000,000
Additional Collateral, Aggregate Fair Value	$0

Risk_Management_Risk_Managemen

Risk Management Risk Management Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
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	($3)	$7	($20)
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	2	51	37
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	23	176	132
Accumulated other comprehensive loss	-24	-118	-115
Other Comprehensive Income Unrealized Gain Loss On Derivatives Arising During Period Net Of Tax Portion Attributable To Parent	254	-14	32
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Adjustment, Net of Tax, Before Reclassifications, Portion Attributable to Parent	-68	-49	14
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Reclassification Adjustments, Net of Tax	-212	151	-53
Other Comprehensive Income Reclassification Adjustment On Derivatives Included In Net Income Net Of Tax Portion Attributable To Parent	-22	4	-5
Other Comprehensive Income (Loss), Foreign Currency Transaction and Translation Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Net of Tax	0	0	0
Other Comprehensive Income Loss Reclassification Adjustment From AOCI Pension And Other Postretiremen Benefit Plans Net Of Tax Portion Attributable To Parent	-1	2	9
Other Comprehensive Income Impact of Merger Transactions on Derivatives Arising During Period Net Of Tax Portion Attributable To Parent	98
Other Comprehensive Income (Loss), Foreign Currency adjustment on Impact of Merger Transactions, Net of Tax	-42
Other Comprehensive (Income) Loss, Impact of Merger Transactions on Pension and Other Postretirement Benefit Plans, Adjustment, before Reclassification Adjustments, Net of Tax	0
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent	330	-10	27
Foreign currency translation adjustments (net of tax benefit (expense) of $41, $22, and $(8), respectively)	-110	-49	14
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	-213	153	-44
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	7	94	-3
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	327	-3	7
Accumulated Other Comprehensive Income (Loss), Foreign Currency Translation Adjustment, Net of Tax	-108	2	51
Accumulated Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	236	23	176
Accumulated other comprehensive loss	-17	-24	-118
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	-26	88	-7
Other comprehensive income (loss), Impact of Merger Transactions before reclassifications, net of tax, portion attributable to parent	56
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	($23)	$6	$4

Fair_Value_of_Derivative_Contr

Fair Value of Derivative Contracts (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	($110)	($155)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers out of Level 3	-88	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Liability Net, Gain (Loss) Included in Earnings	22	-5
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Gain (Loss) Included in Other Comprehensive Income (Loss)	78	-1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases	0	17
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Liability Net, Settlements	37	34
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	-61	-110
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	1	-8
Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset fair value, derivative	594	98
Liability fair value, derivative	-109	-195
Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset fair value, derivative	403	259
Liability fair value, derivative	-53	-116
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]
Asset fair value, derivative	49	4
Liability fair value, derivative	-25	-6
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]
Asset fair value, derivative	0	0
Liability fair value, derivative	0	0
Fair Value, Inputs, Level 2 [Member] | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset fair value, derivative	533	46
Liability fair value, derivative	-11	-31
Fair Value, Inputs, Level 2 [Member] | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset fair value, derivative	403	259
Liability fair value, derivative	-53	-116
Significant unobservable inputs (Level 3) [Member] | Energy Related Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset fair value, derivative	12	48
Liability fair value, derivative	-73	-158
Significant unobservable inputs (Level 3) [Member] | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset fair value, derivative	0	0
Liability fair value, derivative	0	0
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	-46	-62
Net Liability Adjustment for Financial Instruments Subject to Master Netting Agreement but Presented Gross	46	62
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	-44	-28
Net Liability Adjustment for Financial Instruments Subject to Master Netting Agreement but Presented Gross	44	28
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	535	36
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	-16	-116
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	359	231
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	-9	-88
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	-13	0
Derivative, Collateral, Right to Reclaim Cash	47	17
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

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total debt	$42,963	$36,193
Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total debt	$43,582	$36,248

Reportable_Segments_Revenues_D

Reportable Segments Revenues (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Revenues from external customers	$16,226	$14,070	$9,973
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	10,153	8,613	5,230
Natural Gas Pipelines [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	15	4	0
CO2 [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	1,960	1,857	1,677
Terminals [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	1,717	1,408	1,356
Terminals [Member] | Intersegment Revenues [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	1	2	3
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	2,068	1,853	1,370
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	291	302	311
Other Segments [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	1	1	-6
Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	16,206	14,040	9,941
Unallocated [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	36	36	35
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues from external customers	($16)	($6)	($3)

Reportable_Segments_Operating_

Reportable Segments Operating expenses (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	$8,853	$7,760	$5,045
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	6,241	5,235	3,111
CO2 [Member]
Segment Reporting Information [Line Items]
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	494	439	381
Terminals [Member]
Segment Reporting Information [Line Items]
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	746	657	685
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	1,258	1,295	759
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	106	110	103
Other Segments [Member]
Segment Reporting Information [Line Items]
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	24	30	5
Total segments [Member]
Segment Reporting Information [Line Items]
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	8,869	7,766	5,044
Unallocated [Member]
Segment Reporting Information [Line Items]
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	0	0	4
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Cost of Goods Sold, Operations and Maintenance Expense and Taxes Other Than Income Taxes	($16)	($6)	($3)

Reportable_Segments_Other_expe

Reportable Segments Other expense (income) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Other Cost and Expense, Operating	$275	($99)	($13)
CO2 [Member]
Segment Reporting Information [Line Items]
Other Cost and Expense, Operating	243	0	-7
Terminals [Member]
Segment Reporting Information [Line Items]
Other Cost and Expense, Operating	29	-74	-14
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Other Cost and Expense, Operating	-3	6	-5
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Other Cost and Expense, Operating	5	-24	14
Other Segments [Member]
Segment Reporting Information [Line Items]
Other Cost and Expense, Operating	$1	($7)	($1)

Reportable_Segments_Depreciati

Reportable Segments Depreciation, depletion and amortization (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Depreciation, depletion and amortization	$2,040	$1,806	$1,419
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Depreciation, depletion and amortization	897	797	478
CO2 [Member]
Segment Reporting Information [Line Items]
Depreciation, depletion and amortization	570	533	494
Terminals [Member]
Segment Reporting Information [Line Items]
Depreciation, depletion and amortization	337	247	236
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Depreciation, depletion and amortization	166	155	143
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Depreciation, depletion and amortization	51	54	56
Other Segments [Member]
Segment Reporting Information [Line Items]
Depreciation, depletion and amortization	$19	$20	$12

Reportable_Segments_Earnings_l

Reportable Segments Earnings (loss) from equity investments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Asset Impairment Charges	$272	$0	$0
Earnings from equity investments	406	327	153
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Earnings from equity investments	318	232	52
CO2 [Member]
Segment Reporting Information [Line Items]
Earnings from equity investments	25	24	25
Terminals [Member]
Segment Reporting Information [Line Items]
Earnings from equity investments	18	22	21
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Earnings from equity investments	44	45	39
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Earnings from equity investments	0	4	5
Other Segments [Member]
Segment Reporting Information [Line Items]
Earnings from equity investments	1	0	11
NGPL Holdco LLC [Member] | Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Asset Impairment Charges		$65	$200

Reportable_Segments_Amortizati

Reportable Segments Amortization of excess cost of equity investments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Other Depreciation and Amortization	$45	$39	$23
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Other Depreciation and Amortization	39	32	17
CO2 [Member]
Segment Reporting Information [Line Items]
Other Depreciation and Amortization	-1	2	2
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Other Depreciation and Amortization	$7	$5	$4

Reportable_Segments_Interest_i

Reportable Segments Interest income (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Interest income	$9	$15	$28
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Interest income	1	0	18
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Interest income	2	2	2
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Interest income	0	3	14
Other Segments [Member]
Segment Reporting Information [Line Items]
Interest income	6	8	3
Total segments [Member]
Segment Reporting Information [Line Items]
Interest income	9	13	37
Unallocated [Member]
Segment Reporting Information [Line Items]
Interest income	$0	$2	($9)

Reportable_Segments_Other_neti

Reportable Segments Other, net-income(expense) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Other Income	$80	$835	$19
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Other Income	24	578	4
CO2 [Member]
Segment Reporting Information [Line Items]
Other Income	0	0	-1
Terminals [Member]
Segment Reporting Information [Line Items]
Other Income	12	1	2
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Other Income	-1	1	9
Other Segments [Member]
Segment Reporting Information [Line Items]
Other Income	30	9	2
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Other Income	$15	$246	$3

Reportable_Segments_Income_tax

Reportable Segments Income tax benefit (expense) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Income Tax Expense (Benefit)	($648)	($742)	($139)
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Income Tax Expense (Benefit)	-6	-9	-5
CO2 [Member]
Segment Reporting Information [Line Items]
Income Tax Expense (Benefit)	-8	-7	-5
Terminals [Member]
Segment Reporting Information [Line Items]
Income Tax Expense (Benefit)	-29	-14	-3
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Income Tax Expense (Benefit)	-2	2	2
Total segments [Member]
Segment Reporting Information [Line Items]
Income Tax Expense (Benefit)	-63	-49	-12
Unallocated [Member]
Segment Reporting Information [Line Items]
Income Tax Expense (Benefit)	-585	-693	-127
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Income Tax Expense (Benefit)	($18)	($21)	($1)

Reportable_Segments_Segment_ea

Reportable Segments Segment earnings before depreciation, depletion, amortization and amortization of excess cost of equity investments (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Depreciation, Depletion and Amortization	($2,040)	($1,806)	($1,419)
Amortization of excess cost of equity investments	-45	-39	-23
Product sales and other	4,461	3,788	2,449
General and Administrative Expense	-610	-613	-929
Unallocable Interest Expense Net Of Interest Income	-1,807	-1,688	-1,441
Income Tax Expense (Benefit)	-648	-742	-139
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	0	-4	-777
Net Income	2,443	2,692	427
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	4,259	4,207	2,174
Depreciation, Depletion and Amortization	-897	-797	-478
Amortization of excess cost of equity investments	-39	-32	-17
Income Tax Expense (Benefit)	-6	-9	-5
CO2 [Member]
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	1,240	1,435	1,322
Depreciation, Depletion and Amortization	-570	-533	-494
Amortization of excess cost of equity investments	1	-2	-2
Income Tax Expense (Benefit)	-8	-7	-5
Terminals [Member]
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	944	836	708
Depreciation, Depletion and Amortization	-337	-247	-236
Income Tax Expense (Benefit)	-29	-14	-3
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	856	602	668
Depreciation, Depletion and Amortization	-166	-155	-143
Amortization of excess cost of equity investments	-7	-5	-4
Income Tax Expense (Benefit)	-2	2	2
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	182	424	229
Depreciation, Depletion and Amortization	-51	-54	-56
Income Tax Expense (Benefit)	-18	-21	-1
Other Segments [Member]
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	13	-5	7
Depreciation, Depletion and Amortization	-19	-20	-12
Total segments [Member]
Segment Reporting Information [Line Items]
Segment Earnings Before Depreciation Depletion And Amortization	7,494	7,499	5,108
Income Tax Expense (Benefit)	-63	-49	-12
Unallocated [Member]
Segment Reporting Information [Line Items]
Product sales and other	36	36	35
Income Tax Expense (Benefit)	($585)	($693)	($127)

Reportable_Segments_Capital_ex

Reportable Segments Capital expenditures (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Payments to Acquire Property, Plant, and Equipment	$3,617	$3,369	$2,022
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Payments to Acquire Property, Plant, and Equipment	935	1,085	499
CO2 [Member]
Segment Reporting Information [Line Items]
Payments to Acquire Property, Plant, and Equipment	792	667	453
Terminals [Member]
Segment Reporting Information [Line Items]
Payments to Acquire Property, Plant, and Equipment	1,049	1,108	707
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Payments to Acquire Property, Plant, and Equipment	680	416	307
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Payments to Acquire Property, Plant, and Equipment	156	77	16
Other Segments [Member]
Segment Reporting Information [Line Items]
Payments to Acquire Property, Plant, and Equipment	$5	$16	$40

Reportable_Segments_Investment

Reportable Segments Investments (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Segment Reporting Information [Line Items]
Long-term Investments	$6,036	$5,951
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Long-term Investments	5,174	5,130
CO2 [Member]
Segment Reporting Information [Line Items]
Long-term Investments	17	12
Terminals [Member]
Segment Reporting Information [Line Items]
Long-term Investments	219	196
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Long-term Investments	624	611
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Long-term Investments	1	1
Other Segments [Member]
Segment Reporting Information [Line Items]
Long-term Investments	$1	$1

Reportable_Segments_Assets_Det

Reportable Segments Assets (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Segment Reporting Information [Line Items]
Assets	$83,198	$75,185
Assets held for sale	56	0
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Assets	52,523	52,357
CO2 [Member]
Segment Reporting Information [Line Items]
Assets	5,227	4,708
Terminals [Member]
Segment Reporting Information [Line Items]
Assets	8,850	6,888
Products Pipelines [Member]
Segment Reporting Information [Line Items]
Assets	7,179	6,648
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Assets	1,593	1,677
Other Segments [Member]
Segment Reporting Information [Line Items]
Assets	459	568
Operating Segments [Member]
Segment Reporting Information [Line Items]
Assets	75,831	72,846
Corporate Segment [Member]
Segment Reporting Information [Line Items]
Assets	$7,311	$2,339

Reportable_Segments_Other_Deta

Reportable Segments Other (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 14, 2013
Segment Reporting Information [Line Items]
Revenues	$16,226	$14,070	$9,973
Asset Impairment Charges	272	0	0
Write off of Deferred Debt Issuance Cost			108
Interest Expense	1,807	1,690	1,427
Revenues from External Customers [Member]
Segment Reporting Information [Line Items]
Concentration Risk, Percentage	10.00%	10.00%	10.00%
Express Pipeline System [Member] | Kinder Morgan Energy Partners, L.P. [Member]
Segment Reporting Information [Line Items]
Equity Method Investment, Ownership Percentage		33.33%		33.33%
Natural Gas Pipelines [Member]
Segment Reporting Information [Line Items]
Revenues	10,153	8,613	5,230
Natural Gas Pipelines [Member] | NGPL Holdco LLC [Member]
Segment Reporting Information [Line Items]
Asset Impairment Charges		65	200
Natural Gas Pipelines [Member] | Eagle Ford Gathering LLC [Member]
Segment Reporting Information [Line Items]
Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Loss		558
Equity Method Investment, Ownership Percentage		50.00%
CO2 [Member]
Segment Reporting Information [Line Items]
Revenues	1,960	1,857	1,677
CO2 [Member] | Katz Strawn [Member]
Segment Reporting Information [Line Items]
Asset Impairment Charges	235
Kinder Morgan Canada [Member]
Segment Reporting Information [Line Items]
Revenues	291	302	311
Kinder Morgan Canada [Member] | Express Pipeline System [Member]
Segment Reporting Information [Line Items]
Gain (Loss) on Sale of Investments		224
Unallocated [Member]
Segment Reporting Information [Line Items]
Revenues	36	36	35
Unallocated [Member] | Certain items [Member]
Segment Reporting Information [Line Items]
Business Combination, Acquisition Related Costs			366
Single customer exceeding 10% of total [Member]
Segment Reporting Information [Line Items]
Revenues	$0	$0	$0

Reportable_Segments_Geographic

Reportable Segments Geographical information (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Revenues	$16,226	$14,070	$9,973
Long-Lived Assets	52,490	44,375	39,768
UNITED STATES
Segment Reporting Information [Line Items]
Revenues	15,605	13,656	9,488
Long-Lived Assets	50,141	42,080	37,651
CANADA
Segment Reporting Information [Line Items]
Revenues	437	398	407
Long-Lived Assets	2,268	2,214	2,035
MEXICO
Segment Reporting Information [Line Items]
Revenues	184	16	78
Long-Lived Assets	$81	$81	$82

Litigation_Environmental_and_O1

Litigation, Environmental and Other Contingencies Federal Energy Regulatory Commission Proceedings (Details) (Regulated Operation [Member], Federal Energy Regulatory Commission [Member], Various Shippers [Member], Unfavorable Regulatory Action [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
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	100
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

Litigation_Environmental_and_O2

Litigation, Environmental and Other Contingencies California Public Utilities Commission Proceedings (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Loss Contingencies [Line Items]
Accrued contingencies	$383	$584
Regulated Operation [Member] | Revenue Subject to Refund [Member] | California Public Utilities Commission [Member] | Various Shippers [Member] | SFPP [Member] | Unfavorable Regulatory Action [Member] | Settled Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	319
Letter of Credit [Member] | California Public Utilities Commission [Member] | SFPP [Member]
Loss Contingencies [Line Items]
Accrued contingencies	$100

Litigation_Environmental_and_O3

Litigation, Environmental and Other Contingencies Other Commercial Matters (Details) (USD $)	0 Months Ended	12 Months Ended		9 Months Ended	1 Months Ended
In Millions, unless otherwise specified	Oct. 25, 2013	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Mar. 31, 2011
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
Pending Litigation [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]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value	$22.25
Pending Litigation [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] | Loss on Long-term Purchase Commitment [Member]
Loss Contingencies [Line Items]
Loss Contingency, Initial Award Amount, Annual Rent Payable		14
Pending Litigation [Member] | SFPP, L.P. vs. UPRR on relocation costs [Member] | SFPP L.P. [Member]
Loss Contingencies [Line Items]
Loss contingency, settlement tentative by court, value		42.5
Pending Litigation [Member] | Price Reporting Litigation [Member] | Kinder Morgan Bulk Terminals, Inc. [Member] | Price Reporting Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value			140
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
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] | Pending Litigation [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]
Loss Contingencies [Line Items]
Lessee Leasing Arrangements, Operating Leases, Term of Contract	10 years

Litigation_Environmental_and_O4

Litigation, Environmental and Other Contingencies General (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Loss Contingencies [Line Items]
Estimated Litigation Liability	$400	$624

Litigation_Environmental_and_O5

Litigation, Environmental and Other Contingencies Environmental Matters (Details) (USD $)	240 Months Ended	0 Months Ended		6 Months Ended	1 Months Ended	12 Months Ended	0 Months Ended		1 Months Ended	12 Months Ended
	Dec. 31, 1969	Jul. 24, 2013	Nov. 08, 2013	Jun. 30, 2013	Dec. 31, 2000	Dec. 31, 2014	Oct. 25, 2013	Aug. 06, 2013	Aug. 31, 2007	Dec. 31, 2010	Dec. 31, 2013
					Terminals	Terminals
						Parties
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies						340,000,000					$378,000,000
Recorded Third-Party Environmental Recoveries Receivable						14,000,000					14,000,000
Rare Metals Inc. [Member]
Loss Contingencies [Line Items]
Number of Uranium Mines	20
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
Bastian Bay, Buras, Empire and Fort Jackson oil and gas fields of Plaquemines Parish [Member] | Plaquemines Parish, Louisiana (Docket No. 60-999) [Member] | Parish of Plaquemines, Louisiana [Member] | TGP [Member]
Loss Contingencies [Line Items]
Loss Contingency, Number of Defendants			17
Environmental Issue [Member] | Carteret Terminal, Carteret, NJ [Member] | PHMSA Inspection of Carteret Terminal [Member] | PHMSA [Member] | Kinder Morgan Liquids Terminals, LLC [Member]
Loss Contingencies [Line Items]
Litigation Settlement, Amount				63,100
Regulated Operation [Member] | Portland Harbor Superfund Site, Willamette River, Portland, Oregon [Member] | Portland Harbor Superfund Site, Willamette River, Portland, Oregon [Member] | Environmental Protection Agency [Member] | GATX Terminals Corporation (n/k/a KMLT) [Member]
Loss Contingencies [Line Items]
Number of Liquid Terminals					2	4
Number of Parties Involoved In Site Cleanup						90
Pending Litigation [Member] | Lower Passaic River Study Area [Member]
Loss Contingencies [Line Items]
Number of Facilities						100
Number of Parties at a Joint Defense Group						70
Pending Litigation [Member] | SFPP L.P. [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]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value							22,250,000
Pending Litigation [Member] | SFPP Phoenix Terminal [Member] | GATX Terminals Corporation (n/k/a KMLT) [Member] | Paulsboro, New Jersey Liquids Terminal [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value						1,000,000
Litigation, Environmental Settlement Amount, Percentage of Cost						50.00%
Pending Litigation [Member] | SFPP Phoenix Terminal [Member] | KMEP and SFPP [Member] | Unfavorable Regulatory Action [Member] | Roosevelt Irrigation District v. Kinder Morgan G.P., Inc., Kinder Morgan Energy Partners, L.P. , U.S. District Court, Arizona [Member]
Loss Contingencies [Line Items]
Loss Contingency, Number of Defendants						70		26
Loss Contingency, Damages Sought, Value						175,000,000
Pending Litigation [Member] | Mission Valley Terminal Facility [Member] | Kinder Morgan Energy Partners, L.P. [Member] | United States District Court, Southern District of California, case number 07CV1883WCAB [Member]
Loss Contingencies [Line Items]
Loss Contingency, Damages Sought, Value									170,000,000	365,000,000
Settled Litigation [Member] | Community Environmental Program Fund [Member] | TGP [Member] | Pennsylvania Department of Environmental Protection [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense						540,000
Settled Litigation [Member] | Civil Penalty [Member] | TGP [Member] | Pennsylvania Department of Environmental Protection [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense						210,000
Settled Litigation [Member] | Environmental Restoration Costs [Member] | TGP [Member] | Pennsylvania Department of Environmental Protection [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense						50,000
Minimum [Member] | Pending Litigation [Member] | Lower Passaic River Study Area [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense						365,000,000
Maximum [Member] | Pending Litigation [Member] | Lower Passaic River Study Area [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense						3,200,000,000
Preferred alternative [Member] | Pending Litigation [Member] | Lower Passaic River Study Area [Member]
Loss Contingencies [Line Items]
Environmental Remediation Expense						1,700,000,000

Reconciliation_of_Significant_

Reconciliation of Significant Asset and Liabilities Balances (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Reconciliation of Significant Asset and Liability Balances [Line Items]
Cash and cash equivalents	$315	$598	$714	$411
Property, plant and equipment, net	38,564	35,847
Goodwill	24,654	24,504	23,632
Outstanding	$38,212	$31,810

Guarantee_of_Securities_of_Sub1

Guarantee of Securities of Subsidiaries Income Statement and Comprehensive Income (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Guarantor Obligations [Line Items]
Revenues	$16,226	$14,070	$9,973
Depreciation, depletion and amortization	2,040	1,806	1,419
Other Operating Income (Expense), Net	3	-99	-13
Total Operating Costs, Expenses and Other	11,778	10,080	7,380
Operating Income	4,448	3,990	2,593
Earnings from equity investments	406	327	153
Interest Income (Expense), Net	-1,798	-1,675	-1,399
Nonoperating Income (Expense)	-1,357	-552	-1,250
Income from Continuing Operations Before Income Taxes	3,091	3,438	1,343
Income Tax Expense (Benefit)	-648	-742	-139
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	2,443	2,692	427
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	-49	94	-3
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	0	-4	-777
Net Income Attributable to Noncontrolling Interests	-1,417	-1,499	-112
Income from Continuing Operations	2,443	2,696	1,204
Net Income Attributable to Kinder Morgan, Inc.	1,026	1,193	315
Other Nonoperating Income (Expense)	80	53	19
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	-20	-40	-71
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,463	2,732	498
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	-1,486	-1,445	-186
Total comprehensive income	977	1,287	312
Parent Company [Member]
Guarantor Obligations [Line Items]
Revenues	36	36	35
Cost of Sales	0	0	0
Depreciation, depletion and amortization	21	20	19
Other Operating Income (Expense), Net	30	22	295
Total Operating Costs, Expenses and Other	51	42	314
Operating Income	-15	-6	-279
Earnings from equity investments	0	0	0
Interest Income (Expense), Net	-493	-539	-630
Income from Continuing Operations Before Income Taxes	1,440	1,479	-68
Income Tax Expense (Benefit)	-166	-41	392
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	1,274	1,438	310
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			12
Net Income Attributable to Noncontrolling Interests	-248	-245	5
Income from Continuing Operations		1,438	324
Net Income Attributable to Kinder Morgan, Inc.	1,026	1,193	315
Other Nonoperating Income (Expense)	0	-1	-1
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	24	-81
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	1,250	1,519	322
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	-273	-232	-10
Total comprehensive income	977	1,287	312
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		0	-14
Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Revenues	14,310	12,511	8,651
Cost of Sales	5,737	4,739	2,761
Depreciation, depletion and amortization	1,655	1,466	1,091
Other Operating Income (Expense), Net	2,927	2,325	2,172
Total Operating Costs, Expenses and Other	10,319	8,530	6,024
Operating Income	3,991	3,981	2,627
Earnings from equity investments	407	323	206
Interest Income (Expense), Net	-1,040	-949	-757
Income from Continuing Operations Before Income Taxes	5,604	5,890	2,870
Income Tax Expense (Benefit)	-183	50	98
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	5,421	5,936	2,966
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			200
Net Income Attributable to Noncontrolling Interests	-211	-236	-168
Income from Continuing Operations		5,940	2,968
Net Income Attributable to Kinder Morgan, Inc.	5,210	5,700	2,798
Other Nonoperating Income (Expense)	-13	549	-21
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	-386	145
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	5,807	5,791	3,166
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	-203	-237	-174
Total comprehensive income	5,604	5,554	2,992
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		-4	-2
Non-Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Revenues	1,886	1,512	1,265
Cost of Sales	499	468	271
Depreciation, depletion and amortization	364	320	309
Other Operating Income (Expense), Net	514	663	438
Total Operating Costs, Expenses and Other	1,377	1,451	1,018
Operating Income	509	61	247
Earnings from equity investments	-1	4	-53
Interest Income (Expense), Net	-89	-35	16
Income from Continuing Operations Before Income Taxes	1,587	2,034	1,694
Income Tax Expense (Benefit)	-292	-740	-620
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	1,295	1,294	313
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			96
Net Income Attributable to Noncontrolling Interests	0	0	0
Income from Continuing Operations		1,294	1,074
Net Income Attributable to Kinder Morgan, Inc.	1,295	1,294	313
Other Nonoperating Income (Expense)	48	249	18
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	168	172
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	1,127	1,122	409
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0	0	0
Total comprehensive income	1,127	1,122	409
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		0	-761
Consolidation, Eliminations [Member]
Guarantor Obligations [Line Items]
Revenues	-6	11	22
Cost of Sales	42	46	25
Depreciation, depletion and amortization	0	0	0
Other Operating Income (Expense), Net	-48	-35	-3
Total Operating Costs, Expenses and Other	-6	11	22
Operating Income	0	0	0
Earnings from equity investments	0	0	0
Interest Income (Expense), Net	0	0	0
Income from Continuing Operations Before Income Taxes	-9,528	-9,939	-4,910
Income Tax Expense (Benefit)	0	0	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	-9,528	-9,939	-4,910
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			-412
Net Income Attributable to Noncontrolling Interests	-958	-1,018	51
Income from Continuing Operations		-9,939	-4,910
Net Income Attributable to Kinder Morgan, Inc.	-10,486	-10,957	-4,859
Other Nonoperating Income (Expense)	0	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	451	-411
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	-9,979	-9,528	-5,322
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	-1,010	-976	-2
Total comprehensive income	-10,989	-10,504	-5,324
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		0	0
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]
Guarantor Obligations [Line Items]
Revenues	16,226	14,070	9,973
Cost of Sales	6,278	5,253	3,057
Depreciation, depletion and amortization	2,040	1,806	1,419
Other Operating Income (Expense), Net	3,460	3,021	2,904
Total Operating Costs, Expenses and Other	11,778	10,080	7,380
Operating Income	4,448	3,990	2,593
Earnings from equity investments	406	327	153
Interest Income (Expense), Net	-1,798	-1,675	-1,399
Income from Continuing Operations Before Income Taxes	3,091	3,438	1,343
Income Tax Expense (Benefit)	-648	-742	-139
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	2,443	2,692	427
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			71
Net Income Attributable to Noncontrolling Interests	-1,417	-1,499	-112
Income from Continuing Operations		2,696	1,204
Net Income Attributable to Kinder Morgan, Inc.	1,026	1,193	315
Other Nonoperating Income (Expense)	35	796	-4
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	-20	-40
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,463	2,732	498
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	-1,486	-1,445	-186
Total comprehensive income	977	1,287	312
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		-4	-777
Subsidiaries [Member] | Parent Company [Member]
Guarantor Obligations [Line Items]
Earnings from equity investments	1,948	2,025	842
Subsidiaries [Member] | Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Earnings from equity investments	2,259	1,986	815
Subsidiaries [Member] | Non-Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Earnings from equity investments	1,120	1,755	1,466
Subsidiaries [Member] | Consolidation, Eliminations [Member]
Guarantor Obligations [Line Items]
Earnings from equity investments	-9,528	-9,939	-4,910
Subsidiaries [Member] | Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]
Guarantor Obligations [Line Items]
Earnings from equity investments	0	0	0
EPB [Member] | Subsidiary Issuer and Guarantor [Member]
Guarantor Obligations [Line Items]
Revenues	0	0	0
Cost of Sales	0	0	0
Depreciation, depletion and amortization	0	0	0
Other Operating Income (Expense), Net	5	8	2
Total Operating Costs, Expenses and Other	5	8	2
Operating Income	-5	-8	-2
Earnings from equity investments	0	0	0
Interest Income (Expense), Net	-171	-157	-69
Income from Continuing Operations Before Income Taxes	566	594	365
Income Tax Expense (Benefit)	0	0	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	566	594	365
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			10
Net Income Attributable to Noncontrolling Interests	0	0	0
Income from Continuing Operations		594	365
Net Income Attributable to Kinder Morgan, Inc.	566	594	365
Other Nonoperating Income (Expense)	0	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	10	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	556	594	375
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0	0	0
Total comprehensive income	556	594	375
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		0	0
EPB [Member] | Subsidiaries [Member] | Subsidiary Issuer and Guarantor [Member]
Guarantor Obligations [Line Items]
Earnings from equity investments	742	759	436
Copano Energy, L.L.C. [Member] | Subsidiary Issuer and Guarantor [Member]
Guarantor Obligations [Line Items]
Revenues	0	0	0
Cost of Sales	0	0	0
Depreciation, depletion and amortization	0	0	0
Other Operating Income (Expense), Net	32	38	0
Total Operating Costs, Expenses and Other	32	38	0
Operating Income	-32	-38	0
Earnings from equity investments	0	0	0
Interest Income (Expense), Net	-46	-36	0
Income from Continuing Operations Before Income Taxes	146	88	0
Income Tax Expense (Benefit)	0	0	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	146	88	0
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			0
Net Income Attributable to Noncontrolling Interests	0	0	0
Income from Continuing Operations		88	0
Net Income Attributable to Kinder Morgan, Inc.	146	88	0
Other Nonoperating Income (Expense)	0	-1	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	146	88	0
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0	0	0
Total comprehensive income	146	88	0
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		0	0
Copano Energy, L.L.C. [Member] | Subsidiaries [Member] | Subsidiary Issuer and Guarantor [Member]
Guarantor Obligations [Line Items]
Earnings from equity investments	224	163	0
KMP [Member] | Subsidiary Issuer and Guarantor [Member]
Guarantor Obligations [Line Items]
Revenues	0	0	0
Cost of Sales	0	0	0
Depreciation, depletion and amortization	0	0	0
Other Operating Income (Expense), Net	0	0	0
Total Operating Costs, Expenses and Other	0	0	0
Operating Income	0	0	0
Earnings from equity investments	0	0	0
Interest Income (Expense), Net	41	41	41
Income from Continuing Operations Before Income Taxes	3,276	3,292	1,392
Income Tax Expense (Benefit)	-7	-11	-9
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	3,269	3,281	1,383
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			165
Net Income Attributable to Noncontrolling Interests	0	0	0
Income from Continuing Operations		3,281	1,383
Net Income Attributable to Kinder Morgan, Inc.	3,269	3,281	1,383
Other Nonoperating Income (Expense)	0	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	-287	135
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	3,556	3,146	1,548
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0	0	0
Total comprehensive income	3,556	3,146	1,548
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax		0	0
KMP [Member] | Subsidiaries [Member] | Subsidiary Issuer and Guarantor [Member]
Guarantor Obligations [Line Items]
Earnings from equity investments	$3,235	$3,251	$1,351

Guarantee_of_Securities_of_Sub2

Guarantee of Securities of Subsidiaries Balance Sheet (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
ASSETS
Cash and cash equivalents	$315	$598	$714	$411
All other current assets	746	436
Property, plant and equipment, net	38,564	35,847
Long-term Investments	6,036	5,951
Goodwill	24,654	24,504	23,632
Deferred Tax Assets, Net, Noncurrent	5,651	0
Deferred charges and other assets	2,239	2,577
Total Assets	83,198	75,185
LIABILITIES AND STOCKHOLDERS’ EQUITY
Long-term Debt, Current Maturities	2,717	2,306
Deferred income taxes	0	4,651
Liabilities	48,772	46,900
Stockholders' Equity Attributable to Parent	34,076	13,093
Stockholders' Equity Attributable to Noncontrolling Interest	350	15,192
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	34,426	28,285	24,100	8,568
Total Liabilities and Stockholders’ Equity	83,198	75,185
Long-term Debt and Capital Lease Obligations	40,246	33,887
Parent Company [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Long-term Debt	12,674
ASSETS
Cash and cash equivalents	4	83	48	2
All other current assets	397	657
Property, plant and equipment, net	263	284
Long-term Investments	16	17
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	31,364	13,618
Goodwill	15,087	15,099
Due from Affiliate, Noncurrent	4,459	0
Deferred Tax Assets, Net, Noncurrent	0
Deferred charges and other assets	287	455
Total Assets	53,747	30,500
LIABILITIES AND STOCKHOLDERS’ EQUITY
Long-term Debt, Current Maturities	1,486	575
Other Liabilities, Current	318	72
Long-term Debt, Excluding Current Maturities	11,862	7,775
Due to Affiliate, Noncurrent	2,619	1,993
Deferred income taxes	2,094	2,022
Other Liabilities, Noncurrent	583	384
Liabilities	19,671	13,200
Stockholders' Equity Attributable to Parent	34,076	13,093
Stockholders' Equity Attributable to Noncontrolling Interest	0	4,207
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	34,076	17,300
Total Liabilities and Stockholders’ Equity	53,747	30,500
Subsidiary Issuer and Guarantor [Member] | KMP [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Long-term Debt	17,800
ASSETS
Cash and cash equivalents	15	10	95	1
All other current assets	151	136
Property, plant and equipment, net	0	0
Long-term Investments	0	0
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	27,264	26,555
Goodwill	0	0
Due from Affiliate, Noncurrent	19,824	17,284
Deferred Tax Assets, Net, Noncurrent	0
Deferred charges and other assets	341	233
Total Assets	48,927	44,969
LIABILITIES AND STOCKHOLDERS’ EQUITY
Long-term Debt, Current Maturities	324	1,504
Other Liabilities, Current	463	394
Long-term Debt, Excluding Current Maturities	18,197	15,644
Due to Affiliate, Noncurrent	153	0
Deferred income taxes	0	0
Other Liabilities, Noncurrent	78	173
Liabilities	31,141	28,168
Stockholders' Equity Attributable to Parent	17,786	16,801
Stockholders' Equity Attributable to Noncontrolling Interest	0	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	17,786	16,801
Total Liabilities and Stockholders’ Equity	48,927	44,969
Subsidiary Issuer and Guarantor [Member] | Copano Energy, L.L.C. [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Long-term Debt	332
ASSETS
Cash and cash equivalents	0	1	0	0
All other current assets	3	2
Property, plant and equipment, net	5	170
Long-term Investments	0	0
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	1,911	4,430
Goodwill	920	813
Due from Affiliate, Noncurrent	0	0
Deferred Tax Assets, Net, Noncurrent	0
Deferred charges and other assets	0	0
Total Assets	2,850	5,416
LIABILITIES AND STOCKHOLDERS’ EQUITY
Long-term Debt, Current Maturities	0	0
Other Liabilities, Current	12	41
Long-term Debt, Excluding Current Maturities	386	393
Due to Affiliate, Noncurrent	753	907
Deferred income taxes	2	2
Other Liabilities, Noncurrent	2	0
Liabilities	1,270	1,398
Stockholders' Equity Attributable to Parent	1,580	4,018
Stockholders' Equity Attributable to Noncontrolling Interest	0	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	1,580	4,018
Total Liabilities and Stockholders’ Equity	2,850	5,416
Subsidiary Issuer and Guarantor [Member] | EPB [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Long-term Debt	2,860
ASSETS
Cash and cash equivalents	0	78	110	0
All other current assets	1	0
Property, plant and equipment, net	0	0
Long-term Investments	1	0
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	6,150	4,445
Goodwill	22	22
Due from Affiliate, Noncurrent	8	0
Deferred Tax Assets, Net, Noncurrent	0
Deferred charges and other assets	19	20
Total Assets	6,202	4,583
LIABILITIES AND STOCKHOLDERS’ EQUITY
Long-term Debt, Current Maturities	375	0
Other Liabilities, Current	34	30
Long-term Debt, Excluding Current Maturities	2,478	2,253
Due to Affiliate, Noncurrent	1,206	1,143
Deferred income taxes	0	0
Other Liabilities, Noncurrent	0	0
Liabilities	4,116	3,445
Stockholders' Equity Attributable to Parent	2,086	1,138
Stockholders' Equity Attributable to Noncontrolling Interest	0	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	2,086	1,138
Total Liabilities and Stockholders’ Equity	6,202	4,583
Guarantor Subsidiaries [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Long-term Debt	6,463
ASSETS
Cash and cash equivalents	17	17	28	10
All other current assets	2,547	2,184
Property, plant and equipment, net	29,490	26,698
Long-term Investments	5,910	5,822
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	16,387	3,584
Goodwill	5,419	5,317
Due from Affiliate, Noncurrent	3,621	3,087
Deferred Tax Assets, Net, Noncurrent	9,251
Deferred charges and other assets	3,782	3,866
Total Assets	87,999	61,567
LIABILITIES AND STOCKHOLDERS’ EQUITY
Long-term Debt, Current Maturities	381	77
Other Liabilities, Current	1,814	1,728
Long-term Debt, Excluding Current Maturities	6,609	7,101
Due to Affiliate, Noncurrent	22,437	15,599
Deferred income taxes	0	1,142
Other Liabilities, Noncurrent	987	1,023
Liabilities	33,781	27,493
Stockholders' Equity Attributable to Parent	54,218	31,025
Stockholders' Equity Attributable to Noncontrolling Interest	0	3,049
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	54,218	34,074
Total Liabilities and Stockholders’ Equity	87,999	61,567
Long-term Debt and Capital Lease Obligations	178
Non-Guarantor Subsidiaries [Member]
ASSETS
Cash and cash equivalents	279	409	433	398
All other current assets	358	302
Property, plant and equipment, net	8,806	8,695
Long-term Investments	109	112
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	3,337	3,839
Goodwill	3,206	3,253
Due from Affiliate, Noncurrent	496	511
Deferred Tax Assets, Net, Noncurrent	0
Deferred charges and other assets	112	441
Total Assets	17,106	17,782
LIABILITIES AND STOCKHOLDERS’ EQUITY
Long-term Debt, Current Maturities	151	150
Other Liabilities, Current	1,024	1,515
Long-term Debt, Excluding Current Maturities	714	721
Due to Affiliate, Noncurrent	1,240	1,240
Deferred income taxes	1,504	1,485
Other Liabilities, Noncurrent	514	707
Liabilities	6,013	6,357
Stockholders' Equity Attributable to Parent	11,093	11,478
Stockholders' Equity Attributable to Noncontrolling Interest	0	-53
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	11,093	11,425
Total Liabilities and Stockholders’ Equity	17,106	17,782
Consolidation, Eliminations [Member]
ASSETS
Cash and cash equivalents	0	0	0	0
All other current assets	-20	-11
Property, plant and equipment, net	0	0
Long-term Investments	0	0
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	-86,413	-56,471
Goodwill	0	0
Due from Affiliate, Noncurrent	-28,408	-20,882
Deferred Tax Assets, Net, Noncurrent	-3,600
Deferred charges and other assets	0	0
Total Assets	-133,633	-89,632
LIABILITIES AND STOCKHOLDERS’ EQUITY
Long-term Debt, Current Maturities	0	0
Other Liabilities, Current	-20	-11
Long-term Debt, Excluding Current Maturities	0	0
Due to Affiliate, Noncurrent	-28,408	-20,882
Deferred income taxes	-3,600	0
Other Liabilities, Noncurrent	0	0
Liabilities	-47,220	-33,161
Stockholders' Equity Attributable to Parent	-86,763	-64,460
Stockholders' Equity Attributable to Noncontrolling Interest	350	7,989
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	-86,413	-56,471
Total Liabilities and Stockholders’ Equity	-133,633	-89,632
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]
ASSETS
Cash and cash equivalents	315	598	714	411
All other current assets	3,437	3,270
Property, plant and equipment, net	38,564	35,847
Long-term Investments	6,036	5,951
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	0	0
Goodwill	24,654	24,504
Due from Affiliate, Noncurrent	0	0
Deferred Tax Assets, Net, Noncurrent	5,651
Deferred charges and other assets	4,541	5,015
Total Assets	83,198	75,185
LIABILITIES AND STOCKHOLDERS’ EQUITY
Long-term Debt, Current Maturities	2,717	2,306
Other Liabilities, Current	3,645	3,769
Long-term Debt, Excluding Current Maturities	40,246	33,887
Due to Affiliate, Noncurrent	0	0
Deferred income taxes	0	4,651
Other Liabilities, Noncurrent	2,164	2,287
Liabilities	48,772	46,900
Stockholders' Equity Attributable to Parent	34,076	13,093
Stockholders' Equity Attributable to Noncontrolling Interest	350	15,192
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	34,426	28,285
Total Liabilities and Stockholders’ Equity	83,198	75,185
Affiliated Entity [Member]
ASSETS
All other current assets	3	3
Deferred charges and other assets	46	47
Affiliated Entity [Member] | Parent Company [Member]
ASSETS
All other current assets	1,870	287
LIABILITIES AND STOCKHOLDERS’ EQUITY
Other Liabilities, Current	709	379
Affiliated Entity [Member] | Subsidiary Issuer and Guarantor [Member] | KMP [Member]
ASSETS
All other current assets	1,332	751
LIABILITIES AND STOCKHOLDERS’ EQUITY
Other Liabilities, Current	11,926	10,453
Affiliated Entity [Member] | Subsidiary Issuer and Guarantor [Member] | Copano Energy, L.L.C. [Member]
ASSETS
All other current assets	11	0
LIABILITIES AND STOCKHOLDERS’ EQUITY
Other Liabilities, Current	115	55
Affiliated Entity [Member] | Subsidiary Issuer and Guarantor [Member] | EPB [Member]
ASSETS
All other current assets	1	18
LIABILITIES AND STOCKHOLDERS’ EQUITY
Other Liabilities, Current	23	19
Affiliated Entity [Member] | Guarantor Subsidiaries [Member]
ASSETS
All other current assets	11,575	10,992
LIABILITIES AND STOCKHOLDERS’ EQUITY
Other Liabilities, Current	1,553	823
Affiliated Entity [Member] | Non-Guarantor Subsidiaries [Member]
ASSETS
All other current assets	403	220
LIABILITIES AND STOCKHOLDERS’ EQUITY
Other Liabilities, Current	866	539
Affiliated Entity [Member] | Consolidation, Eliminations [Member]
ASSETS
All other current assets	-15,192	-12,268
LIABILITIES AND STOCKHOLDERS’ EQUITY
Other Liabilities, Current	-15,192	-12,268
Affiliated Entity [Member] | Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]
ASSETS
All other current assets	0	0
LIABILITIES AND STOCKHOLDERS’ EQUITY
Other Liabilities, Current	$0	$0

Guarantee_of_Securities_of_Sub3

Guarantee of Securities of Subsidiaries Cash Flows (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	$4,467	$4,122	$2,808
Payments to Acquire Businesses, Net of Cash Acquired	0	0
Capital expenditures	-3,617	-3,369	-2,022
Sale or casualty of property, plant and equipment, and other net assets net of removal costs	5	87	154
Proceeds from Sale of Equity Method Investments	0	490	0
Proceeds from disposal of discontinued operations	0	0	1,791
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	182	185	200
Contributions to investments	-389	-217	-192
Other, net	-3	-6	25
Net Cash Provided by (Used in) Investing Activities	-5,210	-3,122	-5,097
Proceeds from Issuance of Debt	24,573	13,581	18,148
Repayments of Debt	-17,801	-12,393	-14,755
Debt issue costs	-89	-38	-111
Payments of Dividends	-1,760	-1,622	-1,184
Repurchases of shares and warrants	-192	-637	-157
Cash consideration of Merger Transactions (Note 1)	-3,937	0	0
Merger Transactions costs	-74	0	0
Repurchases of Warrants	-98	-465	-157
Contributions from noncontrolling interests	1,767	1,706	1,939
Distributions to noncontrolling interests	-2,013	-1,692	-1,219
Other, net	-3	0	-77
Net Cash Provided by (Used in) Financing Activities	471	-1,095	2,584
Effect of Exchange Rate on Cash and Cash Equivalents	-11	-21	8
Cash and Cash Equivalents, Period Increase (Decrease)	-283	-116	303
Cash and Cash Equivalents, at Carrying Value	315	598	714	411
El Paso Holdco and Finance Corp [Member]
Guarantor Obligations [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired			-4,970
Other Acquisitions [Member]
Guarantor Obligations [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired	-1,388	-292	-83
Parent Company [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	1,426	1,775	657
Payments for Advance to Affiliate	-1,756	-402	-857
Payments to Acquire Businesses, Net of Cash Acquired	0	0	0
Capital expenditures	-1	-6	-5
Sale or casualty of property, plant and equipment, and other net assets net of removal costs	0	0	0
Proceeds from Sale of Equity Method Investments		0
Proceeds from disposal of discontinued operations	875	994	0
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	93	41	16
Contributions to investments	0	-6	-15
Other, net	0	0	0
Net Cash Provided by (Used in) Investing Activities	-1,339	553	-2,682
Proceeds from Issuance of Debt	10,594	3,028	8,001
Repayments of Debt	-5,479	-3,624	-5,692
Debt issue costs	-74	-15	-91
Payments of Dividends	-1,760	-1,622	-1,184
Repurchases of shares and warrants	-192	-637	-157
Cash consideration of Merger Transactions (Note 1)	-3,937
Merger Transactions costs	-74
Proceeds from Contributions from Parent	0	0	0
Contributions from noncontrolling interests	0	0	0
Payments of Ordinary Dividends	0	0	0
Distributions to noncontrolling interests	0	0	0
Other, net	0	1	-74
Net Cash Provided by (Used in) Financing Activities	-166	-2,293	2,071
Effect of Exchange Rate on Cash and Cash Equivalents	0	0	0
Cash and Cash Equivalents, Period Increase (Decrease)	-79	35	46
Cash and Cash Equivalents, at Carrying Value	4	83	48	2
Parent Company [Member] | KMP [Member]
Guarantor Obligations [Line Items]
Proceeds from disposal of discontinued operations			3,485
Parent Company [Member] | KMP and EPB [Member]
Guarantor Obligations [Line Items]
Investments in KMP and EPB	-550	-68	-94
Parent Company [Member] | El Paso Holdco and Finance Corp [Member]
Guarantor Obligations [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired			-5,212
Parent Company [Member] | Affiliated Entity [Member]
Guarantor Obligations [Line Items]
Funding from affiliates	756	576	1,268
Subsidiary Issuer and Guarantor [Member] | EPB [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	885	64	-151
Payments for Advance to Affiliate	-1,252	-661	42
Payments to Acquire Businesses, Net of Cash Acquired	0	0	0
Capital expenditures	0	0	0
Sale or casualty of property, plant and equipment, and other net assets net of removal costs	0	0	0
Proceeds from Sale of Equity Method Investments		0
Proceeds from disposal of discontinued operations	0	0	0
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	440	296	106
Contributions to investments	-189	-52	-454
Investments in KMP and EPB	0	0	0
Other, net	0	0	0
Net Cash Provided by (Used in) Investing Activities	-1,001	-417	-225
Proceeds from Issuance of Debt	922	87	658
Repayments of Debt	-322	-175	-855
Funding from affiliates	786	1,332	1,049
Debt issue costs	-4	0	-4
Payments of Dividends	0	0	0
Repurchases of shares and warrants	0	0	0
Cash consideration of Merger Transactions (Note 1)	0
Merger Transactions costs	0
Proceeds from Contributions from Parent	205	1	29
Contributions from noncontrolling interests	0	0	0
Payments of Ordinary Dividends	-1,549	-924	-391
Distributions to noncontrolling interests	0	0	0
Other, net	0	0	0
Net Cash Provided by (Used in) Financing Activities	38	321	486
Effect of Exchange Rate on Cash and Cash Equivalents	0	0	0
Cash and Cash Equivalents, Period Increase (Decrease)	-78	-32	110
Cash and Cash Equivalents, at Carrying Value	0	78	110	0
Subsidiary Issuer and Guarantor [Member] | Copano Energy, L.L.C. [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	-77	-408	0
Payments for Advance to Affiliate	0	-1	0
Payments to Acquire Businesses, Net of Cash Acquired	0	5	0
Capital expenditures	-63	-141	0
Sale or casualty of property, plant and equipment, and other net assets net of removal costs	202	0	0
Proceeds from Sale of Equity Method Investments		0
Proceeds from disposal of discontinued operations	0	0	0
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	0	0	0
Contributions to investments	0	0	0
Investments in KMP and EPB	0	0	0
Other, net	0	0	0
Net Cash Provided by (Used in) Investing Activities	139	-137	0
Proceeds from Issuance of Debt	0	0	0
Repayments of Debt	0	-854	0
Funding from affiliates	-63	1,400	0
Debt issue costs	0	0	0
Payments of Dividends	0	0	0
Repurchases of shares and warrants	0	0	0
Cash consideration of Merger Transactions (Note 1)	0
Merger Transactions costs	0
Proceeds from Contributions from Parent	0	0	0
Contributions from noncontrolling interests	0	0	0
Payments of Ordinary Dividends	0	0	0
Distributions to noncontrolling interests	0	0	0
Other, net	0	0	0
Net Cash Provided by (Used in) Financing Activities	-63	546	0
Effect of Exchange Rate on Cash and Cash Equivalents	0	0	0
Cash and Cash Equivalents, Period Increase (Decrease)	-1	1	0
Cash and Cash Equivalents, at Carrying Value	0	1	0	0
Subsidiary Issuer and Guarantor [Member] | KMP [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	3,998	4,173	3,867
Payments for Advance to Affiliate	-6,559	-7,145	-5,521
Payments to Acquire Businesses, Net of Cash Acquired	0	0	0
Capital expenditures	0	0	0
Sale or casualty of property, plant and equipment, and other net assets net of removal costs	0	0	0
Proceeds from Sale of Equity Method Investments		0
Proceeds from disposal of discontinued operations	0	0	0
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	0	0	0
Contributions to investments	0	0	0
Investments in KMP and EPB	0	0	0
Other, net	29	-12	-15
Net Cash Provided by (Used in) Investing Activities	-6,530	-7,157	-5,536
Proceeds from Issuance of Debt	13,057	10,213	9,270
Repayments of Debt	-11,849	-7,627	-8,003
Funding from affiliates	3,823	1,971	1,360
Debt issue costs	-11	-22	-16
Payments of Dividends	0	0	0
Repurchases of shares and warrants	0	0	0
Cash consideration of Merger Transactions (Note 1)	0
Merger Transactions costs	0
Proceeds from Contributions from Parent	1,178	1,533	1,681
Contributions from noncontrolling interests	0	0	0
Payments of Ordinary Dividends	-3,660	-3,168	-2,528
Distributions to noncontrolling interests	0	0	0
Other, net	-1	-1	-1
Net Cash Provided by (Used in) Financing Activities	2,537	2,899	1,763
Effect of Exchange Rate on Cash and Cash Equivalents	0	0	0
Cash and Cash Equivalents, Period Increase (Decrease)	5	-85	94
Cash and Cash Equivalents, at Carrying Value	15	10	95	1
Subsidiary Issuer and Guarantor [Member] | EPB [Member] | EPB [Member]
Guarantor Obligations [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired			81
Subsidiary Issuer and Guarantor [Member] | EPB [Member] | Copano Energy, L.L.C. [Member]
Guarantor Obligations [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired
Subsidiary Issuer and Guarantor [Member] | EPB [Member] | KMP [Member]
Guarantor Obligations [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired
Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	6,345	5,491	3,095
Payments for Advance to Affiliate	-4,706	-4,270	-3,515
Payments to Acquire Businesses, Net of Cash Acquired	-1,370	-297	-83
Capital expenditures	-3,050	-2,418	-1,423
Sale or casualty of property, plant and equipment, and other net assets net of removal costs	-9	87	64
Proceeds from Sale of Equity Method Investments		118
Proceeds from disposal of discontinued operations	-875	-994	1,791
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	183	183	184
Contributions to investments	-594	-218	-206
Other, net	27	18	121
Net Cash Provided by (Used in) Investing Activities	-10,394	-7,791	-6,482
Proceeds from Issuance of Debt	0	14	0
Repayments of Debt	-142	-106	-205
Debt issue costs	0	0	0
Payments of Dividends	0	0	0
Repurchases of shares and warrants	0	0	0
Cash consideration of Merger Transactions (Note 1)	0
Merger Transactions costs	0
Proceeds from Contributions from Parent	1,267	162	763
Contributions from noncontrolling interests	0	0	0
Payments of Ordinary Dividends	-6,213	-5,522	-3,763
Distributions to noncontrolling interests	0	0	0
Other, net	-2	0	-2
Net Cash Provided by (Used in) Financing Activities	4,048	2,288	3,405
Effect of Exchange Rate on Cash and Cash Equivalents	1	1	0
Cash and Cash Equivalents, Period Increase (Decrease)	0	-11	18
Cash and Cash Equivalents, at Carrying Value	17	17	28	10
Guarantor Subsidiaries [Member] | KMP [Member]
Guarantor Obligations [Line Items]
Proceeds from disposal of discontinued operations			-3,485
Guarantor Subsidiaries [Member] | KMP and EPB [Member]
Guarantor Obligations [Line Items]
Investments in KMP and EPB	0
Guarantor Subsidiaries [Member] | El Paso Holdco and Finance Corp [Member]
Guarantor Obligations [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired			70
Guarantor Subsidiaries [Member] | Affiliated Entity [Member]
Guarantor Obligations [Line Items]
Funding from affiliates	9,138	7,740	6,612
Non-Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	1,174	769	941
Payments for Advance to Affiliate	-1,088	-1,332	-1,448
Payments to Acquire Businesses, Net of Cash Acquired	-18	0	0
Capital expenditures	-705	-804	-594
Sale or casualty of property, plant and equipment, and other net assets net of removal costs	14	0	90
Proceeds from Sale of Equity Method Investments		372
Proceeds from disposal of discontinued operations	0	0	0
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	0	0	0
Contributions to investments	0	0	0
Investments in KMP and EPB		0	0
Other, net	-60	-12	-81
Net Cash Provided by (Used in) Investing Activities	-1,857	-1,776	-1,942
Proceeds from Issuance of Debt	0	239	219
Repayments of Debt	-9	-7	0
Debt issue costs	0	-1	0
Payments of Dividends	0	0	0
Repurchases of shares and warrants	0	0	0
Cash consideration of Merger Transactions (Note 1)	0
Merger Transactions costs	0
Proceeds from Contributions from Parent	64	132	30
Contributions from noncontrolling interests	0	0	0
Payments of Ordinary Dividends	-411	-150	-231
Distributions to noncontrolling interests	0	0	0
Other, net	0	0	0
Net Cash Provided by (Used in) Financing Activities	565	1,005	1,028
Effect of Exchange Rate on Cash and Cash Equivalents	-12	-22	8
Cash and Cash Equivalents, Period Increase (Decrease)	-130	-24	35
Cash and Cash Equivalents, at Carrying Value	279	409	433	398
Non-Guarantor Subsidiaries [Member] | KMP and EPB [Member]
Guarantor Obligations [Line Items]
Investments in KMP and EPB	0
Non-Guarantor Subsidiaries [Member] | El Paso Holdco and Finance Corp [Member]
Guarantor Obligations [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired			91
Non-Guarantor Subsidiaries [Member] | Affiliated Entity [Member]
Guarantor Obligations [Line Items]
Funding from affiliates	921	792	1,010
Consolidation, Eliminations [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	-9,284	-7,742	-5,601
Payments for Advance to Affiliate	15,361	13,811	11,299
Payments to Acquire Businesses, Net of Cash Acquired	0	0	0
Capital expenditures	202	0	0
Sale or casualty of property, plant and equipment, and other net assets net of removal costs	-202	0	0
Proceeds from Sale of Equity Method Investments		0
Proceeds from disposal of discontinued operations	0	0	0
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	-534	-335	-106
Contributions to investments	394	59	483
Other, net	1	0	0
Net Cash Provided by (Used in) Investing Activities	15,772	13,603	11,770
Proceeds from Issuance of Debt	0	0	0
Repayments of Debt	0	0	0
Debt issue costs	0	0	0
Payments of Dividends	0	0	0
Repurchases of shares and warrants	0	0	0
Cash consideration of Merger Transactions (Note 1)	0
Merger Transactions costs	0
Proceeds from Contributions from Parent	-2,714	-1,828	-2,503
Contributions from noncontrolling interests	1,767	1,706	1,939
Payments of Ordinary Dividends	11,833	9,764	6,913
Distributions to noncontrolling interests	-2,013	-1,692	-1,219
Other, net	0	0	0
Net Cash Provided by (Used in) Financing Activities	-6,488	-5,861	-6,169
Effect of Exchange Rate on Cash and Cash Equivalents	0	0	0
Cash and Cash Equivalents, Period Increase (Decrease)	0	0	0
Cash and Cash Equivalents, at Carrying Value	0	0	0	0
Consolidation, Eliminations [Member] | KMP and EPB [Member]
Guarantor Obligations [Line Items]
Investments in KMP and EPB	550
Consolidation, Eliminations [Member] | El Paso Holdco and Finance Corp [Member]
Guarantor Obligations [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired			0
Consolidation, Eliminations [Member] | Affiliated Entity [Member]
Guarantor Obligations [Line Items]
Funding from affiliates	-15,361	-13,811	-11,299
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member]
Guarantor Obligations [Line Items]
Net Cash Provided by (Used in) Operating Activities	4,467	4,122	2,808
Payments for Advance to Affiliate	0	0	0
Payments to Acquire Businesses, Net of Cash Acquired	-1,388	-292	-83
Capital expenditures	-3,617	-3,369	-2,022
Sale or casualty of property, plant and equipment, and other net assets net of removal costs	5	87	154
Proceeds from Sale of Equity Method Investments		490
Proceeds from disposal of discontinued operations	0	0	1,791
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	182	185	200
Contributions to investments	-389	-217	-192
Other, net	-3	-6	25
Net Cash Provided by (Used in) Investing Activities	-5,210	-3,122	-5,097
Proceeds from Issuance of Debt	24,573	13,581	18,148
Repayments of Debt	-17,801	-12,393	-14,755
Debt issue costs	-89	-38	-111
Payments of Dividends	-1,760	-1,622	-1,184
Repurchases of shares and warrants	-192	-637	-157
Cash consideration of Merger Transactions (Note 1)	-3,937
Merger Transactions costs	-74
Proceeds from Contributions from Parent	0	0	0
Contributions from noncontrolling interests	1,767	1,706	1,939
Payments of Ordinary Dividends	0	0	0
Distributions to noncontrolling interests	-2,013	-1,692	-1,219
Other, net	-3	0	-77
Net Cash Provided by (Used in) Financing Activities	471	-1,095	2,584
Effect of Exchange Rate on Cash and Cash Equivalents	-11	-21	8
Cash and Cash Equivalents, Period Increase (Decrease)	-283	-116	303
Cash and Cash Equivalents, at Carrying Value	315	598	714	411
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member] | KMP [Member]
Guarantor Obligations [Line Items]
Proceeds from disposal of discontinued operations			0
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member] | KMP and EPB [Member]
Guarantor Obligations [Line Items]
Investments in KMP and EPB	0	0	0
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member] | El Paso Holdco and Finance Corp [Member]
Guarantor Obligations [Line Items]
Payments to Acquire Businesses, Net of Cash Acquired			-4,970
Consolidated Entity Excluding Variable Interest Entities (VIE) [Member] | Affiliated Entity [Member]
Guarantor Obligations [Line Items]
Funding from affiliates	0	0	0
KMP and EPB [Member] | Guarantor Subsidiaries [Member]
Guarantor Obligations [Line Items]
Investments in KMP and EPB		0	0
KMP and EPB [Member] | Consolidation, Eliminations [Member]
Guarantor Obligations [Line Items]
Investments in KMP and EPB		$68	$94

Uncategorized_Items

Uncategorized Items
[us-gaap_SharesOutstanding]	2,154,022	6,382,885	7,373,294